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Home My WebLink About220-069CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: SRF Gas Storage Producer - SCU 42-05Z (PTD #220069) TIFL Passed Date:Thursday, February 6, 2025 2:25:40 PM From: Daniel Taylor <dtaylor@hilcorp.com> Sent: Friday, January 31, 2025 4:51 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Wyatt Rivard <wrivard@hilcorp.com> Subject: OPERABLE: SRF Gas Storage Producer - SCU 42-05Z (PTD #220069) TIFL Passed Hello Bryan, SCU 42-05Z had a passing test of the tubing hanger seals to 5000# on 1/25/25. We then performed a passing Tubing Integrity Fluid Level Survey (TIFL) on 1/28/25. The fluid level and pressure differential remained static for 1hr with a greater than 2,700psi differential between tubing and IA. The passing TIFL indicates two competent well barriers. IA pressurization can be managed by bleed below the well’s IA MOASP of 1500 psi. The well will remain OPERABLE and will continue to receive monitoring and TIO reporting per SIO 6. Please let me know if you have any questions. Regards, Daniel Taylor, P.E. Well Integrity O: 907-777-8319 C: 907-947-8051 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230728 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-23 50133206350000 214093 7/16/2023 HALLIBURTON PPROF BCU-24 50133206390000 214112 7/15/2022 HALLIBURTON PPROF BRU 223-34 50283201880000 223041 7/9/2023 HALLIBURTON RMT3D KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON EPX KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON MFC KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON EPX KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON MFC KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON EPX KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON MFC MPU B-24 50029226420000 196009 7/24/2023 HALLIBURTON WFL-TMD3D MPU B-34 50029235690000 216139 7/23/2023 HALLIBURTON WFL-TMD3D MPU B-50 50029232400000 204252 7/21/2023 HALLIBURTON WFL-TMD3D MPU E-23 50029225700000 195094 6/17/2023 HALLIBURTON COILFLAG MPU F-17 50029228230000 197196 7/2/2023 HALLIBURTON COILFLAG MPU L-13A 50029223350100 223017 6/21/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON RBT PBU 11-07 50029206870000 181177 6/28/2023 HALLIBURTON RMT3D SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON EPX SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON MFC SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON EPX SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON MFC Please include current contact information if different from above. T37886 T37887 T37888 T37889 T37889 T37890 T37890 T37891 T37891 T37892 T37893 T37894 T37895 T37897 T37898 T37898 T37899 T37900 T37900 T37901 T37901SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON EPX SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON MFC Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.01 10:05:02 -08'00' DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20695-00-00Well Name/No. SOLDOTNA CK UNIT 42-05ZCompletion Status1-GASCompletion Date1/7/2021Permit to Drill2200690Operator Hilcorp Alaska, LLCMD8173TVD8139Current Status1-GAS3/16/2021UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:MWD/ LWD, CBL 12-23-20, MudlogNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF12/23/202075 8173 Electronic Data Set, Filename: SCU 42-05Z LWD Final.las34465EDDigital DataDF12/23/2020 Electronic File: SCU 42-05Z LWD Final MD.cgm34465EDDigital DataDF12/23/2020 Electronic File: SCU 42-05Z LWD Final TVD.cgm34465EDDigital DataDF12/23/2020 Electronic File: SCU 42-05Z_Definitive Survey Report.pdf34465EDDigital DataDF12/23/2020 Electronic File: SCU 42-05Z_DSR.txt34465EDDigital DataDF12/23/2020 Electronic File: SCU 42-05Z_GIS.txt34465EDDigital DataDF12/23/2020 Electronic File: SCU 42-05Z_Surveys.xlsx34465EDDigital DataDF12/23/2020 Electronic File: SCU 42-05Z LWD Final MD.emf34465EDDigital DataDF12/23/2020 Electronic File: SCU 42-05Z LWD Final TVD.emf34465EDDigital DataDF12/23/2020 Electronic File: SCU 42-05Z LWD Final MD.pdf34465EDDigital DataDF12/23/2020 Electronic File: SCU 42-05Z LWD Final TVD.pdf34465EDDigital DataDF12/23/2020 Electronic File: SCU 42-05Z LWD Final MD.tif34465EDDigital DataDF12/23/2020 Electronic File: SCU 42-05Z LWD Final TVD.tif34465EDDigital Data0 0 2200690 SOLDOTNA CK UNIT 42-05Z LOG HEADERS34465LogLog Header ScansDF1/22/20218002 7681 Electronic Data Set, Filename: (3252) SCU 42-05Z, Perf, 1-7-21, LAS.las34610EDDigital DataDF1/22/2021 Electronic File: (3252) SCU 42-05Z, Perf, 1-7-21, Plot Job.pdf34610EDDigital Data0 0 2200690 SOLDOTNA CK UNIT 42-05Z LOG HEADERS34610LogLog Header ScansTuesday, March 16, 2021AOGCCPage 1 of 5Supplied byOpSupplied byOPSCU 42-05Z LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20695-00-00Well Name/No. SOLDOTNA CK UNIT 42-05ZCompletion Status1-GASCompletion Date1/7/2021Permit to Drill2200690Operator Hilcorp Alaska, LLCMD8173TVD8139Current Status1-GAS3/16/2021UICNoDF1/29/20218094 2499 Electronic Data Set, Filename: SCU 42-05Z RCBL MAIN PASS.las34637EDDigital DataDF1/29/2021 Electronic File: SRU 42-05Z RCBL.pdf34637EDDigital Data0 0 2200690 SOLDOTNA CK UNIT 42-05Z LOG HEADERS34637LogLog Header ScansDF3/11/202111 8250 Electronic Data Set, Filename: SCU 42-05Z.las34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Daily Reports.pdf34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Final Well Report.pdf34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Drilling Dynamcis Log MD 2in.pdf34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Drilling Dynamcis Log MD 5in.pdf34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Drilling Dynamcis Log TVD 2in.pdf34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Drilling Dynamcis Log TVD 5in.pdf34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Formation Log MD 2in.pdf34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Formation Log MD 5in.pdf34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Formation Log TVD 2in.pdf34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Formation Log TVD 5in.pdf34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Gas Ratio Log MD 2in.pdf34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Gas Ratio Log MD 5in.pdf34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Gas Ratio Log TVD 2in.pdf34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Gas Ratio Log TVD 5in.pdf34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z LWD Combo Log MD 2in.pdf34778EDDigital DataTuesday, March 16, 2021AOGCCPage 2 of 5SCU 42-05Z.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20695-00-00Well Name/No. SOLDOTNA CK UNIT 42-05ZCompletion Status1-GASCompletion Date1/7/2021Permit to Drill2200690Operator Hilcorp Alaska, LLCMD8173TVD8139Current Status1-GAS3/16/2021UICNoDF3/11/2021 Electronic File: SCU 42-05Z LWD Combo Log MD 5in.pdf34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z LWD Combo Log TVD 2in.pdf34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z LWD Combo Log TVD 5in.pdf34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Drilling Dynamics Log MD 2in.tif34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Drilling Dynamics Log MD 5in.tif34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Drilling Dynamics Log TVD 2in.tif34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Drilling Dynamics Log TVD 5in.tif34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Formation Log MD 2in.tif34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Formation Log MD 5in.tif34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Formation Log TVD 2in.tif34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Formation Log TVD 5in.tif34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Gas Ratio Log MD 2in.tif34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Gas Ratio Log MD 5in.tif34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Gas Ratio Log TVD 2in.tif34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Gas Ratio Log TVD 5in.tif34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z LWD Combo Log MD 2in.tif34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z LWD Combo Log MD 5in.tif34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z LWD Combo Log TVD 2in.tif34778EDDigital DataTuesday, March 16, 2021AOGCCPage 3 of 5 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20695-00-00Well Name/No. SOLDOTNA CK UNIT 42-05ZCompletion Status1-GASCompletion Date1/7/2021Permit to Drill2200690Operator Hilcorp Alaska, LLCMD8173TVD8139Current Status1-GAS3/16/2021UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYMud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYCompletion Date:1/7/2021DF3/11/2021 Electronic File: SCU 42-05Z LWD Combo Log TVD 5in.tif34778EDDigital DataDF3/11/2021 Electronic File: DbRaw.dbf34778EDDigital DataDF3/11/2021 Electronic File: DbRaw.mdx34778EDDigital DataDF3/11/2021 Electronic File: SCU42-05Z.dbf34778EDDigital DataDF3/11/2021 Electronic File: scu42-05z.hdr34778EDDigital DataDF3/11/2021 Electronic File: SCU42-05Z.mdx34778EDDigital DataDF3/11/2021 Electronic File: scu42-05zr.dbf34778EDDigital DataDF3/11/2021 Electronic File: scu42-05zr.mdx34778EDDigital DataDF3/11/2021 Electronic File: SCU42-05Z_SCL.DBF34778EDDigital DataDF3/11/2021 Electronic File: SCU42-05Z_SCL.MDX34778EDDigital DataDF3/11/2021 Electronic File: SCU42-05Z_tvd.dbf34778EDDigital DataDF3/11/2021 Electronic File: SCU42-05Z_tvd.mdx34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Beluga Conglomerate Pictures.pdf34778EDDigital DataDF3/11/2021 Electronic File: SCU 42-05Z Show Reports.pdf34778EDDigital Data0 0 2200690 SOLDOTNA CK UNIT 42-05Z LOG HEADERS34778LogLog Header Scans3/9/20212940 817341773CuttingsTuesday, March 16, 2021AOGCCPage 4 of 5 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20695-00-00Well Name/No. SOLDOTNA CK UNIT 42-05ZCompletion Status1-GASCompletion Date1/7/2021Permit to Drill2200690Operator Hilcorp Alaska, LLCMD8173TVD8139Current Status1-GAS3/16/2021UICNoComments:Compliance Reviewed By:Date:Date CommentsDescriptionRelease Date:11/18/2020Tuesday, March 16, 2021AOGCCPage 5 of 5M. 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avid Douglas Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: Date: 3/11/2021 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 42-05Z (PTD 220-069) GEOLOG: EOW DRILLING REPORT and MUDLOGS (12/07/2020 to 12/15/2020) 1.DAILY DRILLING REPORTS 2.FINAL EOW REPORT 3.DIGITAL DATA CD DISC 4.COLOR LOG PRINTS (2” & 5” MD / TVD) a.FORMATION EVALUATION MUDLOG b.GAS RATIO LOG c.DRILLING DYNAMICS LOG d.LWD COMBO LOG 5.SAMPLE PHOTOS 6.SHOW REPORTS Please include current contact information if different from above. PTD: 2200690 E-Set: 34778 Received by the AOGCC 03/11/2021 03/15/2021 Date: 03/08/2021 David Douglas Hilcorp Alaska, LLC GeoTechnician 3800 CenterPoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com To: Alaska Oil & Gas Conservation Commission Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 42-OSZ (PTD 220-069) Washed and Dried Well Samples B Set (4 Boxes): WELL BOX SAMPLE INTERVAL (FEET / MD) SCU 42-05Z BOX 1 OF 4 2940'- 4500' MD SCU 42-05Z BOX 2 OF 4 4500' - 6000' MD SCU 42-05Z BOX 3 OF 4 6000'- 7200' MD SCU 42-05Z BOX 4 OF 4 7200'- 8173' MD (TD) Please include current contact information if different from above. RECEIVED MAR 0 9 2021 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal via Email or FAX to: (907)777-8510 Receive By: Date: Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 01/29/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 42-05Z (PTD 220-069) RCBL Radial Cement Bond Log 12/23/2020 Please include current contact information if different from above. Received by the AOGCC 01/29/2021 PTD: 2200690 E-Set: 34637 Abby Bell 02/01/2021 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): Swanson River Field GL:153.7' BF:153.7' 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 16" X-56 120' 7-5/8" L-80 2,957' 5-1/2" L-80 8,139' 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 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, TUBING RECORD 2,767'5-1/2" Tieback SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): L - 239 sx / T - 55 sx Cond Surface 2,957' L - 355 sx / T - 160 sx Driven STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 1/7/2021 3360' FNL, 600' FEL, Sec 5, T7N, R9W, SM, AK 2392' FSL, 654' FEL, Sec 5, T7N, R9W, SM, AK 220-069 / 320-539 Tyonel 77-3 Gas Storage Pool 171.7' 8,081' MD / 8,049' TVD HOLE SIZE AMOUNT PULLED 50-133-20695-00-00 SCU 42-05Z 341714 2457872 2345' FSL, 661' FEL, Sec 5, T7N, R9W, SM, AK CEMENTING RECORD 2458305 SETTING DEPTH TVD 2458353 BOTTOM TOP 6-3/4" 28 bbls 26 bbls Surface 9-7/8"Surface CASING WT. PER FT.GRADE 341655 341662 TOP SETTING DEPTH MD Surface Per 20 AAC 25.283 (i)(2) attach electronic information 17# 2,767' DEPTH SET (MD) 2,767' MD / 2,767' TVD PACKER SET (MD/TVD) 84# 29.7# 120' 2,767' 8,173' Gas-Oil Ratio:Choke Size:Water-Bbl: PRODUCTION TEST 1/25/2021 Date of Test: 200 1/26/2021 24 Flow Tubing 0 9377 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 09377 Flowing 7,864' - 7,880' MD / 7,835' - 7,851' TVD, 6 SPF, 3-3/8", 1/7/2021 0 MWD/ LWD, CBL 12-23-20, Mudlog Sr Res EngSr Pet GeoSr Pet Eng N/A N/A Oil-Bbl: Water-Bbl: 002505 December 15, 2020 December 7, 2020 A028996 N/A N/A N/AN/A N/A 8,173' MD / 8,139' TVD WINJ SPLUGOther 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 10:36 am, Jan 27, 2021 Completion Date 1/7/2021 HEW RBDMS HEW 1/29/2021 GDSR-2/1/21SFD 1/29/2021 G Perforated in TY 77-3 gas storage pool (Production only well -- not approved for injection) gls Tyonel 77-3 Gas Storage Pool gls 3/11/21 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval TY 77-3 7,864' 7,835' 1,022' 1,022' 2,859' 2,858' 4,235' 4,234' 5,309' 5,308' 5,463' 5,462' 7,860' 7,832' Tyonek 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: 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 TY 77-3 Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top TY 53 ST B2 UB 47 ST A This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: LB 52-9 Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Reports. Signature w/Date: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. INSTRUCTIONS The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.01.27 09:11:10 -09'00' Monty M Myers CJD 1-25-21 SCHEMATIC Soldotna Creek Unit SCU 42-05Z PTD: 220-069 API: 50-133-20695-00-00 PBTD = 8,081’ MD / TVD = 8,049’ TD = 8,173 MD / TVD = 8,139’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8" Surf Csg 29.7 L-80 CDC 6.875” Surf 2,957’ 5-1/2" Prod Liner 17 L-80 CDC HTQ 4.892” 2,767’ 8,173’ 5-1/2” Tieback Tubing 17 L-80 CDC HTQ 4.892” Surf 2,767’ 1 16” 7-5/8” 9-7/8” hole 5-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 2,767’ 4.767” - 5-1/2” ZXP Liner Hanger Packer 2 2,767’ 4.767” - Baker Seal Assembly 6-3/4” hole PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size Status TY 77-3 7,864’ 7,880’ 7,835’ 7,851’ 16’ 1/7/2021 3-3/8” Open TY 77-3 OPEN HOLE CEMENT DETAIL Hole Section Cement 9-7/8” x 7-5/8” Lead: 12.0ppg 150 bbl, Tail: 15.4ppg 32.5 bbl 6-3/4” x 5-1/2” Lead: 12.0ppg 102 bbl, Tail: 15.3 ppg 12 bbl 2 TOC ~3,600’ MD per CBL (gas storage pool) Activity Date Ops Summary 12/2/2020 Continue and finishing testing tree 250L5 min and 5000H 15 min (ok) Pull TWC and vac out brine in csg t/ +- 15' and freeze protect w/ diesel / r/up test dn csg t/ 2580 - 2560 psi for 30 min on chart w/ 66.7 gal (ok) / bleed off and secure well head / continue r/dn modules and prep for trucks.;Continue rig dn modules and prep for trucks and cranes for rig move t/ SCU 42-05Z / continue haul misc loads and stage @ Swanson river / R/dn load out service shacks / work on weld projects / power wash and clean rig floor/ mez deck / R/dn gas detection system / R/dn handy berm / prep L/dn TDS.;Remove saver sub / R/dn and l/dn TDS / remove tarps / continue r/dn and prep modules for trucks / continue load trailers and haul to Swanson river / spot crane / remove wind walls on pits & clamshell behind derrick/ raise V-door pick BOP stack & secure in cradle / R/D hooch over centrifuge / crane;off centrifuge / R/U bridle to scope derrick / R/D derrick board / Disconnect mud man shack & Gen #3.;Disconnect S-pipe & bleeder manifold on floor / R/U HYD lines, electrical cables, & Pason cords from derrick / scope derrick to lay over position / disconnect & L/D bottom section of TQ tube / hung off blocks / secure TQ tube in derrick / unspooled drill line & cut 47' / secured kelly hose & service;loop in derrick / disconnected brake linkage / disconnected air lines to dog house / disconnected air, water, & steam interconnects and blew down same.;Crew change, held PTSM. Installed shipping beams in sub / removed rig floor heater / held PJSM on laying over derrick / laid over derrick / tie up lines & hoses in derrick / R/D & laid over poor boy gas buster / picked up misc. trash around rig & pad / started breaking down Handy berm containment;around rig / cont. loading out misc. equip. & tools / sent Peak hand to Swanson River to lay plywood down on bridge/ waiting to set felt, liner, and rig mats.;Solids Hauled to G&I 0 bbls Total Solids Hauled 0 bbls Fluid Hauled to G&I 0 bbls Total Fluid Hauled 0 bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 0 bbls Daily Losses to Hole 0 bbls Total Losses to Hole 0 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs 12/3/2020 Continue waiting to set felt, liner, and rig mats on SCU-42-05Z. Continue prep rig equipment and modules for trucks and cranes.;Trucks and cranes on location scatter rig and equipment and haul rig modules as per permitted to Swanson river and stage same as per blm permit. Spotted cranes / removed choke house & iron roughneck.;Remove derrick and trailer up same ( had build new wooden bolster old one split) / remove drlg line spool & dwk skid and trailer up same/ craned sub off pony sub and load onto low boy trailer/ loaded out pony subs w/ rig mats.;loaded out kill line & jumper hose onto pony subs. Peak hauled all big rig components to Swanson River & staged at sand pit and on Pad 42-05. P/U liner & felt on Pad 41-18. Sent rig crew to Swanson River Pad 42-05 / laid felt , liner, and started laying.;Finished setting rig mats over 42-05Z. Spotted hot house & hooked up Tioga heater to if for warm up shack for rig hands, set wear ring & test plug, RILD's, spotted & set pony subs. Cont. working on organizing on Pad 42-05 and loading out & cleaning up Pad 41-18.;Peak rig moving crew will be out at 07:00 hrs. to start spotting & setting rig over SCU 42-05Z.;Solids Hauled to G&I 0 bbls Total Solids Hauled 0 bbls Fluid Hauled to G&I 0 bbls Total Fluid Hauled 0 bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 0 bbls Daily Losses to Hole 0 bbls Total Losses to Hole 0 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs 18 n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: SRF GS SCU 42-05Z Swanson River Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:201-03740D SCU 42-05Z Drilling Spud Date: d rig mats on SCU-42-05Z. 12/4/2020 Cont. working on policing both pad. Had Peak on location @ 07:00 hrs. Set DWKS/carrier on sub, craned in and pined derrick, craned up drill line spool. Held power point spud meeting @ 08:00 hrs. w/ drilling engineer & Geologist. Moved in and spotted cranes, set sub on pony walls;Raised derrick board wind walls, spotted rig tank/dog house, scoped dog house & extended out to rig floor, spotted & set gen 1&2 module and pit module #1.;Had Mr. John Coston out to give both crews a Swanson river General orientation and acknowledgment form and BLM Noncompliance Assessments, Civil Penalties and Criminal Penalties Regulation acknowledgement forms.;Cont. spotting & setting modules- Pump house 1 &2, pit mods 2 & 3, TD HPU . Started running & plugging in interconnects around rig and hooking up mud, steam, air, fuel, and lines. Raised vacuum degasser & pit roofs, craned in and set choke house, iron roughneck, gas buster, & V- door wind wall.;Stopped, set, & plugged in office buildings, sleeper, and break shack. Got coms hooked up to office buildings.;Performed derrick inspection, raised & pinned derrick to floor. Installed floor plates and brake linkage. Hooked up equalizer lines to pits, put lights up on rig mods, hooked up Pason cables in dog house along w/ cameras.;Crew change, held PTSM, cont. R/U interconnects in pits and around rig, filled boiler w/ potable H2O, fired boiler @ 02:00 hrs. and started staging up pressure. Laid felt & liner for catwalk. Cut & welded on a piece of liner in the back yard to contain rental boiler, Hooked up lines for choke, &;gas buster. Hooked up rig HYD, lowered service loop & drill line to rig floor, prepped to spool drill line on drum.;Solids Hauled to G&I 0 bbls Total Solids Hauled 0 bbls Fluid Hauled to G&I 0 bbls Total Fluid Hauled 0 bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 0 bbls Daily Losses to Hole 0 bbls Total Losses to Hole 0 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs 12/5/2020 Continued stage up boiler pressure / Continue hook up interconnects / continue spool line on drum / put steam to rig chase leaks and warm same.;Continue warm rig / Truck and crane crew on location set 400 bbl water tank, set 150 hp boiler , set centrifuge, set two of three of the set out buildings, hang wind walls, scope up derrick , install handy berm.;Continue install tarps and warm rig / fire 150HP boiler and stage up pressure / P/up R/up TDS chg out torque bushing / Continue organize pad / continue haul loads from KGF / Prep and start to rack 7-5/8" csg / Mr. Brook Furlong Preformed VE readings on boilers and two heaters.;Set cat walk / took on fuel. At 18:00 hrs. received a phone call from Peak foreman Tommy regarding our BOP's, while loading out the BOP's & cradle w/ a winch truck had a bridle line come free of one of the skid ears causing the BOP's & cradle to roll onto its side w/ the HCR hitting the ground.;Had Peak load out BOP's & cradle and haul to there shop to warm and be inspected for damage in the morning.;Cont. running steam line to pair up boilers, R/U service loop & Kelly hose to TDS. connected TDS hydraulics to rig floor. spotted and set Mudman, MWD, & GeoLog shacks and powered up. Installed new saver sub to TDS and M/U clamp. R/U bails & elevators. Brought second boiler on line. off loaded;100 bbls of 120 degree H2O into rig tank. installed 4" ball valves on conductor.;Crew change, Held PTSM. Cont. R/U & working on rig acceptance check list. Inspected TDS, Adjusted load collar on TDS and added oil to gear box. Covered 4.5" DP tub w/ liner and put heater on pipe to thaw, put annular in hot box to warm up. Removed shipping beams in sub, hooked up choke line to;choke manifold, hooked up kill line to mez. Got handling equip to floor & R/U, run centrifuge wires & plugged in, installed steam traps around rig, fired gen #3 & MP motors, staged diverter equip. Installed S pipe. Replaced cracked valves on water line in pits. Currently staging diverter equip.;Solids Hauled to G&I 0 bbls Total Solids Hauled 0 bbls Fluid Hauled to G&I 0 bbls Total Fluid Hauled 0 bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 0 bbls Daily Losses to Hole 0 bbls Total Losses to Hole 0 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs 12/6/2020 Continue warm rig / Continue nip/up 21-1/4" 2M diverter system / Continue haul equipment from KGF / Continue organize pad / Take on water to pits and test tanks for water tight / continue work on rig acceptance chk list / Mr. Jay Compton inspected bop and cradle for damage it appears just;actuator of 3-1/8" HCR had damage ( Bent) / finish racking 7-5/8" csg / Quadco r/up and tested gas system ok / Witness waived of diverter system by Mr. Jim Regg w/ AOGCC.;Started building spud mud. Installed flow line, bleeder line and fill up line. Cont. N/U 21-1/4" 2M diverter system.;Cont. working on rig acceptance check list. Fixed HYD line leak on TDS extend hose, covered casing w/ line and started to warm, installed vertical water tank sensor, pulled test plug from starting well head, racked, strapped, & tallied 4.5" DP. Started building spud mud in pits.;Installed fittings on annular & hooked up koomey hoses. Performed diverter system test & koomey draw down test (ok), 47 sec to close annular & 2 sec to open knife valve. Obtained RKB's, cut & installed grating in cellar.;Cont. working on rig acceptance check list. Set drill TQ on TDS (15.5K), verified TQ of TDS against iron roughneck & tongs (ok). Installed new rotary table mouse hole for P/U pipe & racking back in derrick. Cont. mixing spud mud & building mud docks.;Crew change, held PTSM. Safe up cellar grating, orientated 4" bal l valves on conductor outlets, installed T-bars and ensured valves functioned. Cont. building spud mud. built wet & dry docks for mud product.;Started P/U 4.5" DP & rack back in derrick, Cont. building spud mud, staged MWD tools on rack & started testing/warming tools. Removed thread protectors from 7-5/8" casing.;Solids Hauled to G&I 0 bbls Total Solids Hauled 0 bbls Fluid Hauled to G&I 0 bbls Total Fluid Hauled 0 bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 0 bbls Daily Losses to Hole 0 bbls Total Losses to Hole 0 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs gy Cont. N/U 21-1/4" 2M diverter system. pgg . Currently staging diverter equip.r 12/7/2020 Continued P/U 4.5" DP & rack back in derrick / Continued building spud mud / Continued testing/warming MWD tools / Continued warming and tallying 7- 5/8" casing.;Continue building spud mud / continued testing and warming MWD tools / Trouble shoot Pason system / P/up rack back 12 jt 4-1/2" HWDP / Remove p/up mouse hole / single in w/ HWDP w/ stack washing tool and tag @ 114' rkb / fill hole w/ water and flood test diverter system (ok).;Flood pumps and HP lines w/ water and test t/ 4000 psi (ok) / accept rig / continue build and load dry and wet dock and pad organization / strap 9-5/8" csg.;Displace conductor from water to spud mud / blow dn lines. Rack back HWDP l/dn wash tool.;Installed last section of 16" diverter line & obtain measurements.;P/up 6-3/4" mud motor and chg AKO from 1.5 deg t/ 1.15 deg / P/up M/up 9-7/8" RR bit / rih clean out conductor f/ 114' t/ 137' Pooh to mud mtr chg out TDS robotics feed hose.;P/up Bha #1 as per DD and MWD, plugged in and up loaded tool, shallow hole tested tool (ok), loaded sources.;Spudded well @ 19:18 hrs. Drilled ahead F/137-T/247', noticed pressure loss on MP #1 (100 psi), isolated pumps from each other, verified pressure differences, shut down MP #1, checked suction screen (ok), made decision to pull into conductor. P/U-24K S/O-24K ROT-24K GPM-425 SPP-850 psi.;POOH F/247'-T/127'. P/U-24K S/O-24K. Cont. working through issues w/ small boiler.;Went through MP #1, found squirrel cage in pod #3 cocked and valve stuck open. Cleaned suction & discharge screen on both pumps (ok).;TIH F/127'-T/247, washed last std. to bottom, had 7' of fill on bottom..;Cont. drilling 9-7/8" surface hole F/247'-T/300'. P/U-27K S/O-26K ROT-27K GPM-425 SPP-1160 psi Diff-180 psi RPM-80 TQ-3-5K WOB-5K .;Crew change, held PTSM. Cont. drilling 9-7/8" surface hole F/300'-T/371'. Circ. hole clean. P/U-26K S/O-26K ROT-26K GPM-500 SPP-1450 psi Diff-160 psi RPM-80 TQ-3K WOB-5.5K .;POOH F/371'-T/123' w/ no issues. P/U-26K S/O-26K.;P/U remainder of BHA #1, flex collars & jars, TIH to bottom, washing last std. down, no fill on bottom.;Resumed drilling 9-7/8" surface hole F/371' to current depth of 646'. P/U-33K S/O-34K ROT-34K GPM-490 SPP-1499 psi Diff-100 psi RPM-80 TQ-3K WOB-5.5K . Distance to well plan: .90' .12 High .89' Right.;Solids Hauled to G&I 0 bbls Total Solids Hauled 0 bbls Fluid Hauled to G&I 0 bbls Total Fluid Hauled 0 bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 0 bbls Daily Losses to Hole 0 bbls Total Losses to Hole 0 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs 12/8/2020 Continued drilling 9-7/8" surface hole f/646' t/ 1366'. P/U-42K S/O-41K ROT-42K GPM-550 SPP-2145 psi Diff-240 psi RPM-80 TQ-4K WOB-10K . max gas 44 units and ECD @ 9.7 control drilling @ 150 fph.;Circ btm /up @ 550 gpm @ 1960 psi and 80 rpm @ 2.7 TQ.;Pooh on elevators f/ 1366' t/ 375' w/ no issues and calculated and actual bbls @ 8.8 bbls.;Service rig grease crown, blocks, TDS, linkage, DWK, drive shaft, IR, and wash pipe / clean suction and discharge screens and replace rod wash pump on #1 MP.;Rih on elevators f/ 375' t/ 1366' wash last std to btm w/ no fill or issues.;Resume drilling 9-7/8" surface hole f/ 1366' t/ 2140' 540 gpm 2100 psi 80 rpm 4.7k tq on 3.3k tq off MW 9.05 ppg ECD 9.56 ppg.;Drilling 9 7/8'' Surface Hole f/ 2140' t/ 2363' 540 gpm 2160 psi 81 rpm 3.3k tq on.;Circulate bottoms up, blow down top drive.;Make wiper trip t/ 1360' with no issues.;Service rig and top drive inspect breaks.;RIH f/ 1360' t/ bottom @ 2363' with no issues no fill resume Drilling Ahead.;Drilling Ahead f/ 2363' t/2468' 550 gpm 2295 psi 80 rpm 4k tq on 3.2k tq off, PUW 72k SOW 56k ROT 60k, MW 9.05 ppg ECD 9.44 ppg, Distance to plan 9.01' 2.78' low 8.57' left.;Solids Hauled to G&I 0 bbls Total Solids Hauled 212 bbls Fluid Hauled to G&I 212 bbls Total Fluid Hauled 318 bbls Cement Hauled to G&I 318 bbls Total Cement Hauled 0 bbls Daily Losses to Hole 0 bbls Total Losses to Hole 0 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs 12/9/2020 Continue control drilling 9-7/8" surface hole @ 150FPH f/2468' first TD @ t/2947' 550 gpm 2320 psi , diff 130 psi , 80 rpm 4.4 k tq on 3.6k tq off, WOB 6-12k PUW 57k SOW 56k ROT 56k, MW 9.05 ppg ECD 9.42 ppg, max gas 87 units.;Circ clean shaker came clean @ btm up / recover TD sample.;Obtain final survey / blow dn lines / rack back stand monitor well w/ .7 bph loss rate / Pooh on elevators f/ 2947' t/ 2047' w/ no issues Cal 6.3 bbls actual 9.9 bbls and 3.3 bbl difference new crew attended Swanson river orientation by Mr. John Coston.;RIH on elevators f/ 2047' t/ 2947' and tag btm w/ no fill or issue.;Pump fluid caliper sweep around back 20 bbls early 550= gpm, SPP= 2230 psi, 80 rpm @ 3k tq ( found csg pups in tally would not work).;Resume drilling 9-7/8" surface hole to fit short joint csg f/ 2947' t/ 2965 and re-TD hole section.;Circ hole clean and obtain TD sample and finial survey.;Pooh on elevators rack back DP and HWDP, L/D Jars stand and collars, Unload sources, Download MWD, L/D BHA components, break bit graded 2,3 in gauge Clear floor.;Drain stack pull wear ring, dummy run hanger, R/U Weatherford casing running equipment, bring up centralizers and load racks w/ casing.;PJSM, Run in the hole with 7 5/8' shoe track, check floats, good, Continue RIH w/ Surface casing as per detail t/ 2937', M/U hanger and landing jt, slack off taking wt 2' from landing on hanger. 65K PUW 56k SOW.;P/U circulating swedge, establish circulation stage pumps t/ 6 bpm 110 psi, setting down in the same spot unable to wash down, no over pull or sticking when picking up, set 20k down wt no change.;L/D Landing jt and hanger, 3 jts of casing change out 2 jts for shorter jts, 3.78' shorter, M/U 3 jts and hanger and landing jt, Land on hanger and break circulation, stage pumps t/ 6 bpm 86 psi, Rigging up cementers and cement equipment.;Solids Hauled to G&I 118 bbls Total Solids Hauled 330 bbls Fluid Hauled to G&I 202 bbls Total Fluid Hauled 520 bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 0 bbls Daily Losses to Hole 34 bbls Total Losses to Hole 34 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs p ;Cont. drilling 9-7/8" surface hole F/247'-T/300'. pygp short joint csg f/ 2947' t/ 2965 and re-TD hole section. Cont. drilling 9-7/8" surface hole F/300'-T/371'. g Continue control drilling 9-7/8" surface hole @ 150FPH f/2468' first TD @ t/2947' pp ;Drilling Ahead f/ 2363' t/2468' TD @ 2965 ft p Run in the hole with 7 5/8' shoegy g ggqp gp track, check floats, good, Continue RIH w/ Surface casing as per detail t/ 2937', Spud well 12/10/2020 Break circulation / stage pumps t/ 6 bpm 95 psi / R/dn casers / R/up cementers and cement equipment and lines / load plugs and r/up bail extensions / shut dn circ / install cmt head and lines / blow dn TDS and blow thru lines / come online w/ MP thru cmt head while Thaw hose and clear lines to;cutting box / PJSM / batch up spacer / dn mud pump and blow dn line / HES broke circ w/ 5 bbls water / Test lines 500L and 4000H good / blead off pressure / HES pumped 40 bbls of red tune spacer @ 10.5 ppg @ 2 bpm / drop btm plug w/ good indication of launch fallowed by 150 bbls of 12.0 ppg;type 1-2 lead cmt w/ 5.68 PPB bridge maker LCM @ 5 bpm fallow by 32.5 bbls type 1-2 tail cmt @ 15.8 ppg w/.20 ppb well life LCM @ 5 bpm / drop btm plug and launched w/ 10 bbls water and good indication of launch / HES displace w/ 121.6 bbls of mud @ 9.0 ppg / Bump plug .6 bbls early w/;FCP @ 890 psi pressured up t/ 1550 psi and held for 3 min ok / bled off 3/4 bbls floats held / CIP @ 11:48 hrs / got red spacer and 27.6 bbls cmt back to surface w/ 4.4 bbls lost through out job / pipe was reciprocated to 118 bbls into displacement and good cmt back then landed;w/ shoe @ 2956.63 ' / Wash up and blow dn Mud/Cmt lines / r/dn cmt head and lines / break bolts and 4 bolt diverter line and stack / drain flush stack / set pack-off and RILDS test seals t/ 3000 psi f/ 10 min.;N/D Diverter Assembly, break down vent line and knife valve and pull riser off the Annular, remove annular and T spool, pull spacer spool and DSA, wash up starting head and clean up and prep f/ B section.;Nipple Up B Section of wellhead, tighten bolts and test Void t/ 3200 psi f/ 10 min, N/U spacer spool and crane in stack and swap to trolley, N/U BOP and choke and kill lines, tighten bolts.;N/U Flow box and riser, install flow line and chains f/ stack, check bolts on stack, pull wear ring and rerun, fill stack and lines with water, shell test stack to 250/3750 psi, Auto IBOP Failed, replace valve, load racks with DP and tally.;Grease valves and shell test without top drive t/ 250/4000psi, prep and change out upper Auto IBOP, remove clamps and saver sub disconnect hydraulics break connections, swap out double ball.;Solids Hauled to G&I 55 bbls Total Solids Hauled 385 bbls Fluid Hauled to G&I 437 bbls Total Fluid Hauled 957 bbls Cement Hauled to G&I 28 bbls Total Cement Hauled 28 bbls Daily Losses to Hole 4 bbls Total Losses to Hole 38 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs 12/11/2020 Continue chg/out auto IBOP/ function test rebuild (would not close all the way, rotate actuator 180 deg and re-function test ok re test same ok) / continued building mud / continued chg out liners and swabs in MP / house keeping around rig and pad.;Continued building mud / continued chg/out liners and swabs in Mud pumps / Continue house keeping / Quadco repaired weight indicator and gas detectors and tested same / called out BLM inspector.;BLM inspector Quinn Sawyer on location Test bopes as per regulations 250L/4000H 5/10min on 4-1/2" & 2-7/8" test jt w/ two F/P 3-1/8" choke HCR serviced & fuctioned and re- tested (ok) lower rams on 2 7/8'' test jt functioned and retested (ok), perform drawdown test, Quadco tested gas alarms.;R/D test equipment pulled test plug set wear ring, M/U cross overs to test spare double ball valve that was rebuilt, Level derrick.;R/U and tested casing to 2500 psi f/ 30 min 1.3 bbls pumped in 1 bbl returned, good test, blow down lines and choke manifold.;R/U and P/U and Single in the hole w/ 4.5'' DP 45 stands and stack washer tool t/ 2855' set down 10k multiple times.;POOH racking back DP in derrick f/ 2855' t/ surface, break stack washer off.;Bring BHA components to floor, M/U BHA #2 6 3/4'' Drilling Assembly, M/U Bit motor and MWD tools, Upload MWD.;Solids Hauled to G&I 2 bbls Total Solids Hauled 387 bbls Fluid Hauled to G&I 78 bbls Total Fluid Hauled 1035 bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 28 bbls Daily Losses to Hole 0 bbls Total Losses to Hole 38 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs 12/12/2020 Continue Upload MWD and p/up BHA #2 as per DD and MWD and shallow hole test ok SLM HWDP and chk tally ok, load sources.;Single in w/ Bha #2 / P/up rabbiting and strapping 4-1/2" CDS-40 DP total 60 more jts w/ total 126 std in derrick t/ 2781'.;Fill pipe brk/circ wash dn f/ 2781' t/ 2881' started taking weight establish parameters 5' deep to csg tally.;Drill plugs cmt and float equipment t/ 2967' circ btm ( cmt in returns ) Continue drill new 6-3/4" hole t/ 2985'.;Chg over to 10.0 ppg 6% KCL/Polymer mud circ good 10.0 ppg mud back rack back stand.;R/up for FIT/LOT test against rams / pump 23.0 gals and applied 960 psi w/ leak off @ 927 psi giving us 16.03 EMW and hold for 10 min, chart and graph test w/ 20.7 gal returned blow dn lines.;Drill 6-3/4" hole f/ 2985' t/ 3026' blew a pop-off premature chg out pop-off on MP#1 / both MP bleeders leaking / pull into csg and work on same.;Change out pop off and Run pumps bleeders leaking Change out bleeder valve on #1 MP grease #2 bleeder valve.;Drilling Ahead f/ 3026' t/ 3522' 258 gpm 1720 psi 75 rpm 3.2k tq on 2.8k off PUW 55k SOW 55k Rot 57k 4k WOB.;Continue Drilling Ahead f/ 3522' t/ 3954' 258 gpm 1855 psi 80 rpm 4.0k tq on 3.1k tq off 10.2 ppg MW 11.2 ppg ECD 4-6k WOB Distance to plan 25.83' 3.31' Low 25.62' Left.;CBU Obtain SPR's and survey, Blow down top Drive.;Make wiper trip t/ shoe @ 2965' No hole issues.;Service rig and top drive.;Solids Hauled to G&I 49 bbls Total Solids Hauled 436 bbls Fluid Hauled to G&I 301 bbls Total Fluid Hauled 1336 bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 28 bbls Daily Losses to Hole 0 bbls Total Losses to Hole 38 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs g / HES pumped 40pp p p g ppp bbls of red tune spacer @ 10.5 ppg @ 2 bpm / drop btm plug w/ good indication of launch fallowed by 150 bbls of 12.0 ppg;type 1-2 lead cmt w/ 5.68 PPBp@ ppg@p ppgg y ppgyp bridge maker LCM @ 5 bpm fallow by 32.5 bbls type 1-2 tail cmt @ 15.8 ppg w/.20 ppb well life LCM @ 5 bpm / drop btm plug and launched w/ 10 bbls water g @ p y yp @ ppg pp @ p p p g and good indication of launch / HES displace w/ 121.6 bbls of mud @ 9.0 ppg / Bump plug .6 bbls early w/;FCP @ 890 psi pressured up t/ 1550 psi and held gp@ppgppgy for 3 min ok / bled off 3/4 bbls floats held / CIP @ 11:48 hrs / got red spacer and 27.6 bbls cmt back to surface MIT casing 2500 psi ()g ;R/up for FIT/LOT test against rams / pump 23.0 gals and applied 960 psi w/ ppg y g ppg leak off @ 927 psi giving us 16.03 EMW and hold for 10 min, FIT = 16 ppg pg p g g Test bopes as per regulations 250L/4000H 5/10min on 4-1/2" & 2-7/8" test jt w/ two F/P 3-1/8" choke g q ;R/U and tested casing to 2500 psi f/ 30 min ff cement 7 5/8" surface casing 12/13/2020 Rih on elevators w/ no issues wash last std to btm w/ no fill / pump 20 bbls high vis sweep.;Resume drilling 6-3/4" production hole / f/ 3955' t/ 5007' w/ slides as needed to maintain WP-03 / sweep back on time w/ 10% increase and holding Max rop to 250FPH w/ max gas of 96 units, ECD of 11.58 and MW of 10.50 ppg.;up/dn /rot 70/69/70k, SPP @ 2650 psi, GPM @ 300 , RPM 80 w/ 5k TQ.;Circ shakers clean, SPR , survey, Blow dn lines flow chk w/ slight seepage.;Pooh on elevators 5007'/ t/ 3897' w/ no real Issues / Clean suction and dis charge screens / Cal disp = 8.4 bbls, Act disp =8.3 bbls, Diff = .1.;Service rig and top drive, Change out ram on link tilt assembly.;RIH f/ 3897' t/ 5007' no issues.;Drilling Ahead f/ 5007' t/ 6063' 282 gpm 2506 psi 80 rpm 5.4k tq on 4.5k tq off 10.8 ppg MW 12.29 ppg ECD 78k PUW 75k SOW 75k ROT Distance to plan 10.47' 3.2' Low 9.97' Left.;Circulate bottoms up, obtain survey and SPR's, Blow down top drive.;Solids Hauled to G&I 102 bbls Total Solids Hauled 538 bbls Fluid Hauled to G&I 238 bbls Total Fluid Hauled 1574bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 28 bbls Daily Losses to Hole 0 bbls Total Losses to Hole 38 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs 12/14/2020 Pooh on elevators f/ 6063' t/4950'' w/ no real Issues 5-10 drag no over pulls / Clean suction and dis charge screens / Cal disp = 6.7 bbls, Act disp =8.7 bbls, Diff = 3.0.;Service rig grease traveling equipment / clean suction discharge screens & rod wash / adjust brake handle / while monitor well @ 1.25 bph loss rate.;Rih on elevators w/ no issue t/ 6063' fill pipe and wash last std to btm w/ no fill UP/DN 92/87k Calc = 19.5 bbls, Act = 17.4 bbls , Diff = 2.1 bbls.;Resume Drilling 6-3/4" production hole f/ 6063' t/ 7059' w/ slides as needed to maintain WP-03 and back reaming full stds / holding Max rop to 250FPH w/ max gas of 395 units coal , ECD of 12.50 and MW of 11.00 ppg.;Circulate hole clean for a wiper trip, Obtain surveys and SPR's, Blow down top drive Flow check the well slight losses.;POOH f/ 7059' t/ 6000' No issues.;Serviced the top drive and blocks, changed link tilt ram out both have been replaced now.;RIH f/ 6000' t/ 7059' saw slight drag going through coals at 6430', Fill Pipe and wash and ream to bottom no issues Pump Hi Vis Sweep 20% increase in cuttings back on time.;Drilling Ahead f/ 7059' t/ 7230' 276 gpm 2990 psi 80 rpm 5.5k tq on 4k tq off 92k PUW 90k SOW 87k ROT.;Drilling Ahead f/ 7230' t/ 7678' 278 gpm, 82 rpm 6k tq on 4.5k tq off, PUW 94k SOW 90k ROT 90k, MW 11 ppg ECD 12.85, Distance to plan 33.05' 24.84' Low 21.80' Left.;Solids Hauled to G&I 75 bbls Total Solids Hauled 613 bbls Fluid Hauled to G&I 175 bbls Total Fluid Hauled 1749 bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 28 bbls Daily Losses to Hole 30 bbls Total Losses to Hole 68 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs 12/15/2020 Continue Drilling 6-3/4" production hole f/ 7678' t/ TD at 8173' md/8139.5' tvd @ reduced ROP for good detection. 278 gpm, 82 rpm 6k tq on 4.5k tq off, PUW 94k SOW 90k ROT 90k, MW 11 ppg ECD 12.85, w/ max gas of 766 units. Sent BLM notice of upcoming liner run. Last two connections prior to TD,;connection gas increased doubled over background , so started increasing mud weight from 11.0 to 11.2 ppg while drilling last stand down. Distance to Plan 33.69' 32.42' low 9.18' Left.;CBU at 8173' and cont to circ while increasing mud weight to 11.2 ppg. 286 gpm-2684 psi, 84 rpm-5500 ft/lbs off bott torque. With good 11.2 in/out, obtained survey and SPR's, then shut down for flow check.;Flow check at 3 bph. Cont to circ at 260 gpm-2500 psi, 84 rpm-5200 ft/lbs torque, increase mud weight to 11.4 ppg. Had 757 units at bottoms up which dropped right off. With good 11.4 in/out, obtained SPR's and flow checked. Well flowing at 1.4 bph. Cont circ and increase mud weight to 11.6 ppg. 770;units at bottoms up. With good 11.6 in/out shut down and flow checked. Well flowing at 1.1 bph. Cont CBU with 483 units at bottoms up.;Weight up system t/ 11.85 ppg in and out, flow check well static slight loss dropped 1'' down riser, Circulate another bottoms up 396 units of gas, Obtain SPR's, Blow down top drive.;Make wiper trip f/ 8173' t/ 7170' with no issues.;Service rig and top drive, monitor well on trip tank loss rate of .8 bph cleaned suction screens and changed grabber dies on top drive.;RIh f/ 7170' t/ 8173' wash last stand to bottom no issues 10k drag seen @ 7340'.;Circulate bottoms up x 2, 260 gpm 2590 psi 539 units of gas on bottoms up shakers cleaned up, blow down top drive, flow check well.;Make wiper trip to shoe f/ 8173' t/ 4208' No Issues 10-20k drag through claystone area f/ 5700' to 5300'.;Solids Hauled to G&I 66 bbls Total Solids Hauled 679 bbls Fluid Hauled to G&I 155 bbls Total Fluid Hauled 1904 bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 28 bbls Daily Losses to Hole 20 bbls Total Losses to Hole 88 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs TD at 8173 ft gp ;Drilling Ahead f/ 5007' t/ 6063' 282 p g ;Drilling Ahead f/ 7230' t/ 7678' Continue Drilling 6-3/4" production hole f/ 7678' t/ TD at 8173' md/8139.5' 12/16/2020 Cont pulling up hole on elevators from 4208' to 2903' and park inside surface casing shoe. Calculated hole fill = 39.1 bbls for trip, actual hole fill = 39.9 bbls. Rig support rep went off the road enroute to rig (off lease), no injuries.;Monitor well on trip tank while serviced rig and topdrive. Mechanic changed oil in floor motor and transmission. Electrician installed master power switch on koomey unit. Hole taking 1/2 bph.;TIH on elevators from 2903’ to 8112’ filling pipe every 1500’. Had to MU topdrive and work through tight spot at 7730’. At 8112’ MU topdrive on last stand, filled pipe and washed to bottom. Calculated displacement = 95 bbls, actual displacement = 86.6 bbls.;CBU one time at 215 gpm-2222 psi, 83 rpm-5650 ft/lbs off bott torque. Had a max of 480 units gas at bottoms up. Also at bottoms up, MW dropped to 11.3 ppg, vis dropped to 41 and chlorides dropped to 23,000 (from 32,000)., possible water influx during trip. Followed CBU with a 20 bbl sweep that came;back on time and no increase in cuttings. Was not much for cuttings on initial bottoms up. Shut down and flow checked well for 15 minutes, well static.;Pulled up hole on elevators from 8173' 10 stands to 7553' with no issue, monitored well again, well static, dropped 2.38" hollow drift with wire, cont POOH on elevators from 7553' to 737' flow check the well static @ HWDP.;L/D BHA f/ 737' t/ surface, unloaded sources, download MWD, broke components and bit graded a 3-4 in gauge, cleaned and cleared floor.;Pull wear ring set test plug, change upper rams t/ 5.5'', Fill stack with water and test rams, leaking on the Hammer union, well started flowing .6 bph @ 0400 hrs, change hammer union and test plug seal, Test Annular and upper rams t/ 250/4000 psi f/ 5/10 min each w/ 5.5'' test jt.;Solids Hauled to G&I 6 bbls Total Solids Hauled 685 bbls Fluid Hauled to G&I 164 bbls Total Fluid Hauled 2068 bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 28 bbls Daily Losses to Hole 15 bbls Total Losses to Hole 103 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs 12/17/2020 Finished testing upper 5 1/2" rams and annular at 250/4000 psi for 5/10 min each with no issues. Well flowing at .65 bph out the annulus. Witness of this test was waived by BLM Rep Allie Schoessler on 12-15-20 at 13:49 pm.;RD test equipment, pulled test plug and set 9" ID wear ring. Filled stack with mud and well became static. Staged Weatherford equipment on catwalk.;RU Weatherford casing equipment and fill up line. Staged centralizers on floor, staged 5 1/2" liner on racks.;Held PJSM with rig crew, Baker Rep and Weatherford Rep. Inspected, PU and MU shoe track, checked floats (OK). PU single in hole with 5 1/2" 17# L-80 CDC HTQ liner at 40 ft/min. Stopped at 2941’, MU circ swedge and topdrive. Last rig crew, mud man and drill foreman oriented at office w/John Coston.;Started circ at 114 gpm-392 psi, staged up to 204 gpm-466 psi. Couple minutes into circ, pump pressure and flow rate started dropping off. Checked entire flow paths and pumps, no issues found. Shut down pump and well was static. Resumed pumping at 114 gpm-173 psi, flow up and down. Obtained rotating;parameters: 10 rpm = 1821 ft/lbs, 20 rpm = 2140 ft/lbs, 30 rpm = 2450 ft/lbs torque. Broke off topdrive and circ swedge, blew down topdrive.;Resumed PU single in hole at 30 to 40 ft/min from 2941' to 4875', appears we are pushing fluid away. Little to no displacement to start, but the deeper we got, the better displacement. Had numerous tight spots we had to work through from 4600' to 4875', but no significant overpulls.;Stopped at 4875' to attempt circ, just above the first of large coals starting at 5100'. MU circ swedge and topdrive. Pumped at idle, 114 gpm-528 psi, getting some returns. Added two drums NXS lube to suction pit to spot behind liner string. Obtained rotating parameters: 10 rpm = 2697 ft/lbs, 20 rpm;= 3300 ft/lbs, 30 rpm = 3200 ft/lbs torque. With lube spotted on backside, shut down and broke off topdrive, blew down same.;Cont PU single in hole from 4875' to 5342', M/U Hanger/Packer as per Baker Rep, RIH M/U XO t/ Drill pipe, R/D Weatherford Equipment.;RIH w/ 5.5'' liner on DP f/ 5342' t/ 8173' work last stand to bottom tag up attempt to establish circ w/ 1200 psi max psi limit unable to establish circ. establish rotary 15 rpm 5800 ft/lbs tq hole staying full very minimal returns, discuss options with baker rep and town engineer, decision made to;POOH t/ hanger and L/D Hanger, since hydraulic psi to set packer is so low don't want to chance setting packer while cementing.;POOH f/ 8173' t/ 7832' improper hole fill swabbing, begin pumping out of the hole t/ 6726' pressuring up to 500 psi and letting it bleed off as pipe was pulled out of the hole.;Solids Hauled to G&I 8 bbls Total Solids Hauled 693 bbls Fluid Hauled to G&I 112 bbls Total Fluid Hauled 2068 bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 28 bbls Daily Losses to Hole 311 bbls Total Losses to Hole 404 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs 12/18/2020 Cont pull up hole slowly from 7832’ to 5370’, cycling pump on/off keeping pressure between 400 and 700 psi. At 6636' started getting 2 to 4% return flow. Had a max of 1655 units gas at bottoms up. At 6097' we were able to keep pump running and minimal losses. Gas down to 195 units.;At 5370' we had liner hanger to rig floor. RU Weatherford tongs, broke out and LD liner hanger assembly, flushed some inside and out, MU XO and topdrive.;CBU at 114 gpm-638 psi, 18 rpm- 2200 ft/lbs torque, BGG 115 units, 0.9% returns. Returns tapered off to the point would not register on flowshow. Shut down at bottoms up, initial well flow at 10 bph and reduced to 3 bph.;Eased in hole 5 stands DP to 5675' and MU topdrive. Circulated at 114 gpm-525 psi, 20 rpm-2880 ft/lbs torque with partial returns. Getting 5% return flow on upstroke of string and just slight returns on down stroke. Shut down and blew down topdrive, well flowing at 4 bph.;Pulled up hole on elevators from 5675' to 5369' racking DP back in derrick. Up wt 65K.;POOH LD 5 joints 5 1/2" liner, MU XO and topdrive. Using pump #2 with 4 1/2" liners/swabs circulated at 90 gpm-500 psi. Pumped while pulling up hole, shut down pump to slack off. Pumped 48 bbls, lost 40 bbls. Blew down topdrive, well flowing at 6 bph.;Pulled up hole and LD 5 more joints 5 1/2" liner from 5169' to 4971', MU XO and topdrive.;CBU with pump #2 at 90 gpm-405 psi, 20 rpm-2280 ft/lbs torque. Initial .2% flow, cont pumping on upstroke, no pump on down stroke. Return flow increased each cycle of up and down stroke, pump on and off. 1/2 way into bottoms up return flow at 4.7%, at bott up 6.4%. Shut down and have 11 bph flow.;PU and singled in hole 10 joints 5 1/2" liner previously LD from 4971' to 5368'. MU XO and topdrive.;Circulate 91 gpm 414 psi 20 rpm 2100 tq flow out increasing slowly 66% returns.;RIH breaking circulation every 5 stands f/ 5368' t/ 8173' 91-120 gpm 20 - 30 rpm, no hole issues, returns increasing 6% flow to 12 % flow 66% returns t/ 80% Build volume.;Stage up rate f/ 91 gpm 594 psi t/ 173 gpm 1100 psi last 20' of hole ratty higher circulation pressures and torque.;Attempt to pull on elevators swabbing, POOH w/ pumps 91 gpm 400 psi f/ 8173' t/ 7606'.;Solids Hauled to G&I 0 bbls Total Solids Hauled 693 bbls Fluid Hauled to G&I 0 bbls Total Fluid Hauled 2180 bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 28 bbls Daily Losses to Hole 376 bbls Total Losses to Hole 780 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs run 5.5" casing Lost circ... POOH with DP to Liner hanger Finished testing upper 5 1/2" rams and annular at 250/4000 psi for 5/10 min p q M/U Hanger/Packer as per Baker Rep, g ;RIH w/ 5.5'' liner on DP f/ 5342' t/ 8173' work last stand to bottom tag up attempt to establish gp t pull up hole slowly from 7832’ to 5370’ pqpppg g U Weatherford casing equipment and fill up line. Staged centralizers on floor, staged 5 1/2" liner on gqp gqppg racks.;Held PJSM with rig crew, Baker Rep and Weatherford Rep. Inspected, PU and MU shoe track, checked floats (OK). Test Annular and upper rams t/ 250/4000 psi f/ ggp 5/10 min each w/ 5.5'' test jt.;Solids Hauled to G&I 6 bbls 12/19/2020 Cont pulling up hole slow, up wt 90K, pumping at idle 90 gpm, from 7606’ to 5370’ top of liner pipe. Had to stop at 5619' and change out grabber dies on topdrive.;Cleaned up rig floor, RU Weatherford tongs, staged Baker liner hanger assembly on catwalk, blew down topdrive, PU and MU hanger assembly, RIH on one stand 4 ½” DP and MU topdrive. Circulated at 90 gpm-500 psi with 9% return flow, 20 rpm-2200 ft/lbs torque. RD Weatherford equipment off rig floor.;Eased in hole 4 more stands, top filled pipe, MU topdrive and circulated for 10 min at 90 gpm. Tripped in hole at 20 ft/min, top filling every 5 stands, circulating 10 minutes every 10 stands. Washed last joint DP down to 8169' and could not get any deeper without excess torque or pump pressure.;Cont to work pipe and circulate staging up to 130 gpm-730 psi, 30 rpm-4000 ft/lbs torque. Max gas at bottoms up 1188 units. Staged Halliburton cementers.;Shut down pump and blew down topdrive, PU and MU Baker cement head, RU cement manifold and HP hoses. Transferred excess mud into pits 9-10.;Cont to circ at 170 gpm- 1080 psi, 30 rpm-4000 ft/lbs torque, shoe at 8169', RU cement hardline to rig floor manifold. Held PJSM with cementers, rig crew and Peak (CCI) crew.;Halliburton pumped 5 bbls water to flush lines, then 5 bbls to fill lines. Shut in at Baker cement head and PT lines at 710 psi low 4580 psi high. Good tests, Lined up Baker cement head to Halliburton, pumped 40 bbls 12 ppg Tuned Prime Spacer at 4 bpm-1100 psi, followed with 102 bbls (239 sx);12.0 ppg Type I II Lead cement at 4 bpm, 870 to 800 psi, followed with 12 bbls (55 sx) 15.3 ppg Premium G Tail cement at 2 bpm, 200 to 150 psi. Had Bridgemaker LCM in lead and tail. Baker released dart, Halliburton then displaced with 11.4 ppg 6% KCL mud at 5 bpm-760 psi;ICP, up to 1330 psi. Saw dart latch wiper plug 36 bbls into displacement. With 20 bbls to go, reduced rate to 2.5 bpm-1220 psi and bumped liner wiper plug/landing collar at 160 bbls into displacement (calculated at 161.8 bbls). FCP 1350 psi. Halliburton increased to and held 1850 psi (500 over fcp);for 3 minutes, bled off and floats held. Bled back .75 bbls to truck. Rotated pipe until 10 bbls before plug bumped. Up wt 105K, down wt 95K. Lost 0 bbls total, CIP at 23:35 on 12-19-20,Increase pressure as per Baker, to 1850 psi to set anchor. Saw indication anchor set, Slacked off from 80K to 40K,;anchor set. Increased pressure again, to 2350psi, increased to 4150psi and saw pusher tool neutralize. Bled off to 500 psi and held that, PU on blocks 7’ to clear dog sub from liner top, up wt 35K, and had good indication we released from liner assembly with run tool. As soon as 500 psi dropped;started rig pump and CBU at 420gpm-519psi, began rotating 15 rpm set down 35k x4 on dog sub attempt to shear no good indication it sheared. Had 40 of spacer to surface, 26bbls of lead cement, L/D cement head.;Load wiper ball in pipe, circulate 425 gpm 520 psi, Stand back 3 stands of DP t/ 7989' Blow down top drive and R/D cement lines, P/U cement head and break connections.;Slip and cut drilling line, service rig and drawork.;POOH w/ running tool f/ 2680' t/ surface L/D running tool and dog sub, upon inspection dog sub was sheared.;M/U Baker polish mill assembly and RIH as per Baker Rep t/ 1195'.;Solids Hauled to G&I 8 bbls Total Solids Hauled 701 bbls Fluid Hauled to G&I 72 bbls Total Fluid Hauled 2180 bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 28 bbls Daily Losses to Hole 40 bbls Total Losses to Hole 820 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs 12/20/2020 Cont TIH on 4 1/2" DP with Baker "TBR" dress and polish mill from 1195' to to 2738’, filled pipe and obtained rotating parameters. Eased down and tagged top of liner hanger with no-go at 2767’, putting landing collar on depth at 8085’ and shoe at 8173’. Circulated at 114 gpm, rotated at 44 rpm;and engaged liner top with polish mill 6 times. Racked and tallied 2 7/8" workstring.;PU and CBU one time at 114 gpm-90 psi, blew down topdrive. RD and released GeoLog Rep, gas trap and service shack. Called out Weatherford Rep.;POOH to surface , lay down and inspect Baker polish mill. Cont rack and tally 2 7/8" pipe.;Serviced rig and topdrive, staged Weatherford equipment and RU same.;MU 4.75” roller cone and scraper assembly for 5 1/2", PU and single in hole with 2 7/8” work string, drifting joints with 1.75" drift to 5366'. No issue at all going into liner lap at 2767’.;MU XO, RD Weatherford tongs and elevators, installed 4 1/2" DP elevators.;Cont TIH on 4 1/2" DP from derrick, from 5366' to 8081', tag up on wiper plug at 8081'. Combined plug lengths = 2.95', top of landing collar = 8085'.;PU to 8078' and start circ at 214 gpm-1670 psi, no rotation. Clean pits and transport to G&I, take on water to 9&10 build 300 bbls of brine, wait on trucks to return with water and offload before starting displacement.;RU test equipment, closed annular, tested 7 5/8" and 5 1/2" to 2500 psi for 30 minutes on chart, good test, RD test equipment.;Cont circ at 214 gpm-1670 psi, no rotation. Cont to clean pits and transport to G&I, wait on trucks to return with water and offload.;PJSM Displace well t/ 8.6ppg brine.;Solids Hauled to G&I 21 bbls Total Solids Hauled 722 bbls Fluid Hauled to G&I 615 bbls Total Fluid Hauled 2795 bbls Cement Hauled to G&I 26 bbls Total Cement Hauled 54 bbls Daily Losses to Hole 0 bbls Total Losses to Hole 820 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs 12/21/2020 Cont displacing well to 6% KCL brine at 224 gpm-1948 psi. With good clean brine back to surface shut down and blew down topdrive, RU vac pod on rig floor, start hauling off mud and dirty water.;POOH LD 4 1/2" DP: mousehole joints, insert two wiper balls, set in vac pod and vac wiper balls, LD joint, dope ends and install thread protectors., from 8080' to XO at 5380'.;RIH 40 stands of 4 1/2" DP from derrick, from 5380' to 8000'. Cont cleaning pits.;POOH LD 4 1/2" DP from 8000' to 5380'. Loaded and shipped out Sperry tools on Lynden truck.;RIH on 4 1/2" DP from 5380' to 7867' and MU topdrive. Built a 20 bbl BaraKlean pill in pill pit.;Pumped and flushed BaraKlean through all surface lines including kill and choke lines, choke manifold, pumps and topdrive. Blew down all surface lines and choke manifold.;POOH L/D 4.5'' DP f/ 7868' t/ 5831', R/U Weatherford casing equipment.;POOH L/D 2 7/8'' PH6 work string f/ 5831' t/ Surface.;Pull Wear Ring, change rig floor handling equipment t/ 5.5'', Dummy run hanger and mark, load racks with casing, service rig and top drive while waiting.;Solids Hauled to G&I 2 bbls Total Solids Hauled 724 bbls Fluid Hauled to G&I 776 bbls Total Fluid Hauled 3571 bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 54 bbls Daily Losses to Hole 0 bbls Total Losses to Hole 820 bbls Daily Metal Recovered 0 lbs Total Metal Recovered 0 lbs pp q g g () ;Halliburton pumped 5 bbls water to flush lines, then 5 bbls to fill lines. Shut in at Baker cement head and PT lines at 710 psi low 4580 psi high. Good tests, pp ppg Lined up Baker cement head to Halliburton, pumped 40 bbls 12 ppg Tuned Prime Spacer at 4 bpm-1100 psi, followed with 102 bbls (239 sx);12.0 ppg Type I IIp p p ppg p p p () ppg yp Lead cement at 4 bpm, 870 to 800 psi, followed with 12 bbls (55 sx) 15.3 ppg Premium G Tail cement at 2 bpm, 200 to 150 psi. Had Bridgemaker LCM in lead pp ()ppg ppg and tail. Baker released dart, Halliburton then displaced with 11.4 ppg 6% KCL mud at 5 bpm-760 psi;ICP, up to 1330 psi. Saw dart latch wiper plug 36 bbls into pppg pppp ppg displacement. With 20 bbls to go, reduced rate to 2.5 bpm-1220 psi and bumped liner wiper plug/landing collar at 160 bbls into displacement (calculated atpgpppppggp( 161.8 bbls). FCP 1350 psi. Halliburton increased to and held 1850 psi (500 over fcp);for 3 minutes, bled off and floats held. Bled back .75 bbls to truck. MIT casing 2500 psi pp t equipment, closed annular, tested 7 5/8" and 5 1/2" to 2500 psi for 30 minutes on chart, Cont displacing well to 6% KCL brine at 224 gpm-1948 psi. pp p gp pp Washed last joint DP down to 8169' and could not get any deeper w ppp gpp gp Had 40 of spacer to surface, 26bbls of lead cement, RU cement hardline to rig floor manifold. g gp p p p staged Baker liner hanger assembly on catwalk, Cont TIH on 4 1/2" DP with Baker "TBR" dress and polish mill from 1195' to to 2738’ 12/22/2020 Serviced rig and topdrive while staging Baker seal assembly and 5 1/2" tieback string on pipe racks. Crew noticed hydraulics seemed slow, found system pressure to be low and pump hotter than normal. Isolated pump and swapped to Chelsea pump on floor motor. Released night mud engineer.;MU Baker seal assembly, PU singled in hole 67 joints 5 1/2" 17# L-80 CDC-HTQ tubing to 2743’. Up wt 43K, dwn wt 43K. PU jnt 68, eased down 5’ increments, saw slight increase in drag as seals entered SBR, tagged/set down on no-go, putting liner top at 2767’, marked pipe, pulled up hole and LD joint.;MU 4.81’ pup joint, MU landing joint/hanger, SO and landed hanger putting seal assembly no-go 1.65’ off seat, bottom of muleshoe at 2775’.;Put 2 bbls diesel down backside then topped off with brine to hanger top. RD Weatherford equipment, pulled landing joint, MU packoff assembly and landed same. RILD’s and tested packoff body at 500 psi f/5 min, 5000 psi f/15 min. LD landing joint, topped off 5 1/2" tubing with brine.;RU test equipment on IA and tested 5 1/2" x 7 5/8" at 1500 psi for 30 min on chart. Pumped 16.1 gallons and bled back 16.1 gallons. Set BPV. Released Baker Rep. Both AOGCC (Jim Regg) and BLM (Mutasim Elganzoory) waived witness of MIT's on 12-22-20.;Opened and inspected lower rams, then changed upper rams back to variables. ND flowline, riser, drip pan and stack, installed trolly beam. RU and picked stack off wellhead, then picked spacer spool. Called out Vetco wellhead Rep Chris.;Worked dry hole tree into cellar, installed & M/U tree, tested hanger void @ 5 min/ 500 psi & 15 min/ 5000 psi. Tested pack off neck seal @ 5 min/ 500 psi & 15 min/ 5000 psi. Pulled BPV & set TWC, tested tree @ 5 min/ 500 psi & 15 min/ 5000 psi. Pulled TWC.;R/U testing equip, topped of tree w/ brine, opened IA valve. Tested 5.5" liner/Tie back T/3000 psi on chart for 30 min (ok), pumped in 2.02 bbls & bled back 2.0 bbls. Closed IA valve, R/D testing equip & shut in master valve on tree.;Cleaned & cleared rig floor, removed misc. sub, XO’s & handling equip. off rig floor to baskets. Changed MP #2 back to 5” liners & swabs, cont. cleaning & R/D in pits. Pressure washed IR and freeze protecting test pump in choke house. Loaded out frozen pallets of Barite & misc. mud product.;Continue with cleaning, R/D misc. equip, and working on maintenance around rig.;Solids Hauled to G&I 10 bbls Total Solids Hauled 734 bbls Fluid Hauled to G&I 320 bbls Total Fluid Hauled 3891 bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 54 bbls Daily Losses to Hole 0 bbls Total Losses to Hole 820 bbls Currently storing 300 bbls of 11.4 ppg 6%KCL PHPA mud at G&I 12/23/2020 Power wash topdrive, cleaned and organized choke house, load trailers with various equipment and mud product.;Yellow Jacket e-line on location at 08:00, RU for CBL, RIH with CCL/Sector Bond Temp/GR tool string, tagged top of wiper plugs at 8080’ WLM. Logged up hole from 8075' to 2500', POOH, RD released e- line, sent log files to town.;Topped off 20' of 5 1/2" with diesel to freeze protect well and shut in master valve on dry hole tree, installed tree cap. Pressure washed on rig floor. Opened up, cleaned out and RD centrifuge, RD vacuum degasser. Replaced oil pan gasket on gen #3, Loaded all mud products on trailers and parked on;staging pad. Shipped out Baker tools, shipped out Weatherford tools. Started pressure washing derrick.;Cleaned out suction lines to MP's & manifolds, cleaned suction & discharge screen of MP's. Cont. power washing mezz deck & bottom side or rotary table, changed out shradder valve on nitrogen bottle. Cont. loading out misc. equip & tools.;Crew change, held PTSM. Cont. power washing in mezz deck area, cut, modified, & installed grating in cellar, R/D MP shock hose between sub & pump house & MP suction line from pits. Policed & organized around pad.;Installed shipping beams in sub, R/D kill line, removed elevators for TDS bales, adjusted link tilt cylinder clamps on bails, R/D choke manifold lines going to pits, cont. power washing pit walls & roofs, R/D poor boy gas buster lines, removed saver sub clamp and broke out saver sub from quill.;Inspected & secured derrick board, R/D Pason cord in derrick. Cont. cleaning, R/D, & working on rig maintenance.;Solids Hauled to G&I 0 bbls Total Solids Hauled 734 bbls Fluid Hauled to G&I 0 bbls Total Fluid Hauled 3891 bbls Cement Hauled to G&I 0 bbls Total Cement Hauled 54 bbls Daily Losses to Hole 0 bbls Total Losses to Hole 820 bbls Currently storing 300 bbls of 11.4 ppg 6%KCL PHPA mud at G&I 12/24/2020 Removed vent line from poorboy degasser, removed Pason fluid level sensor on upright water tank, checked and filled k oomey nitrogen bottles to 1000 psi, changed oil in gear box and swivel on topdrive, lowered vacuum degasser into pit 4, spooled up Pason cables, checked endplay on topdrive (OK),;removed rotary table cover and pressure washed table, Swaco Rep came out and inspected centrifuge, then installed shipping blocks.;inspected shakers and found crack on #3 under weir, removed vac degasser lid and cleaned inside, installed lid, Swaco Rep inspected and installed shipping blocks on centrifuge, string cable through conduit in derrick for derrick house heater, removed hyd hoses and valve bank from pipe tub.;R/D power & Pason cables to directional shack, drained oil from rotary table, went through MP's & serviced, removed cap on annular & cleaned element, cleaned up lube room, removed broken stand pipe pressure gauge on rig floor & replaced, replumbed water line to rig floor.;Greased choke manifold, M/U new mud discharge hose for centrifuge.;Crew change, held PTSM, Cont. working on cleaning, R/D, & maintenance. Pickled Hotsy. Removed HYD rams from pipe tube & banded on pallet. Prepped turtle shells on MP's for removal & service of gaskets. Inspected & serviced tong sheaves in derrick. Replaced HYD pressure gauge on rig floor for rig HPU;Loaded out MWD & Geo-log shack, Removed buggy on skate for inspection for cracks.;Storing & treating 300 bbls of 11.4 ppg 6%KCL PHPA mud at G&I 12/25/2020 Cleaned lube room, removed Pason weight indicator sensor, removed trolly beam on cellar for measurement of pin holes, cleaning hopper rooms, completed PM’s on both winches on rig floor, iron roughneck, topdrive, catwalk, changeshack gen set, pulled gear end cover on pump #2,;removed die blocks on iron roughneck and clean, troubleshoot Eaton brake alarm and replaced air sensing pressure switch.;Siliconed gear end cover on mud pump and cut new gaskets, put protective cover on annular, installed die blocks on iron roughneck, un-wire agitator motor and remove same in pit #10 for gear box change, police pad including staging pads, inspect all fire extinguishers, installed gearbox cover;on pump #2, installed receptacle and plug for derrick house heater, unwired agitator motor pit 3 and removed motor, drained oil from gear box. Cleaned pipe rack bird baths and re-installed mats.;Finished cleaning out under rotary table & mezz deck, replaced teflon on skate buggy, removed bails from TDS, removed cuttings chutes from shakers. Cont. working on misc. cleaning & power washing around rig.;Crew change, held PTSM. Pressure washing BOP stack & cellar, cleaned & organized hose room on boiler house #1. Working on removing felt mud product barrier under hopper house grating. Banded misc. tools & equip onto pallets to be loaded out. Cont. working on weekly PM's & misc. R/D.;Storing & treating 300 bbls of 11.4 ppg 6%KCL PHPA mud at G&I pp pp pp pp singled in hole 67 joints 5 1/2" 17# L-80 CDC-HTQ tubing to 2743’. Up wt 43K, dwn wt py py ;RU test equipment on IA and tested 5 1/2" x 7 5/8" at 1500 psi for 30 min Serviced rig and topdrive while staging Baker seal assembly and 5 1/2" tieback string on pipe racks. run tie back ... 5.5" ;Yellow Jacket e-line on location at 08:00, RU pg qpp for CBL, RIH with CCL/Sector Bond Temp/GR tool string, tagged top of wiper plugs at 8080’ WLM. Logged up hole from 8075' to 2500', PO CBL over 5.5" 12/26/2020 Cleaned and organized topdrive connex, installed pump #2 side plates of gear end cover, installed shipping blocks on shakers, installed and adjusted skate bucket on catwalk, thawed and removed felt ground cover at mix hoppers, pressure washed BOP stack in cellar, completed PM’s on both boilers,;rig HP, and iron roughneck HPU, RD and stored standpipe manifold, staged paint in lube room.;Measured and marked for two wells on north end of Swanson Rive field, installed new gear box on agitator pit #3, removed belt guard from pump #1, removed side covers from gear end and gear end cover, cleaned gear end cover for new silicone, troubleshot voltage fluctuation on gen set #2,;installed electric motor on agitator #3, pressure washed floor in hopper room #3, cleaned out cellar box.;Installed BOP trolly beam in cellar after checking pin hole for wear, cleaned up and organized wiring under drillers console, installed gaskets on turtle shells on MP #1, cont. R/D Pason cables around rig, cleaned up and untangled wiring on sun deck. Cleaned DWKS, sanded icy areas around offices &;sleeper trailers, painted water lines in mud pits.;Crew change, held PTSM. Cont. cleaning & organizing HPU sea can, cleaned & organized choke house, premiered floor in hopper house #1. fixed leak on diesel line on boiler #1. Cleaned & organized skate control house. Removed flow paddle & scrubbed inside of flow line. Prepped dog house floor for;paint. premiered floor in hopper house #2, cleaned & organized accumulator room, painted entrance gate/handrails into cuttings box.;Storing & treating 300 bbls of 11.4 ppg 6%KCL PHPA mud at G&I 12/27/2020 Prep and paint doghouse floor, prep and paint utility lines in pits, cont to load unneeded items on trailer for shipping to town, install new gaskets on pump #1 gear end covers, install gear end covers, cont troubleshoot ground fault on shaker #1 , install new gear box and;install electric motor for agitator pit #10, repaired IBOP control wire in doghouse.;Disconnect Kelly hose and service loop, removed torque bushing, set topdrive in cradle and disconnect from blocks, secure compensator rams, removed topdrive from rig floor and staged in yard for HP gooseneck inspection. Set candlestick markers on new well stakes and notified Production;for line locates, installed belt guards on pump #1, mud Engineer stopped by, PU 4 sacks caustic and 2 cans aldacide, then went to G&I to check/treat mud in storage, electrician got voltage adjusted on gen #2 then test ran parallel and by itself with no issues. Drained fluid end on accumulator pumps.;Removed T-bar from TQ tube. Cleaned out shaker screen conex & installed support straps to hold screen in place during rig moves, cleaned koomey room, wood ward room, compressor room, & gen 1&2 house. Cleaned & organized spill conex. Went through MP' #2 fluid end, cleaned parts & reinstalled.;Unclamped swabs to test run pumps and check for seal leaks. Painted turtle shells on MP's.;Crew change, held PTSM & weekly safety meeting with rig crew. R/D TDS HYD hoses from sub base to HPU skid, primed air lines in compressor room, cleaned & organized drilling conex, inside TDS HPU skid, drillers side roughneck room on rig floor, & boiler houses. Painted steam lines in pits w/ Hi temp;silver paint. Organized cables & hoses in pipe skate control house. Replaced skate cable on catwalk.;Storing & treating 300 bbls of 11.4 ppg 6%KCL PHPA mud at G&I (Treated on 12-28) 12/28/2020 Finished installing cable for pipe skate, cont painting service lines in pits and in air compressor room, welded “D” rings on mousehole, welder installed cement line brackets along off side edge of beaver slide, wire in agitator on pit 10, Hilcorp Inspector inspecting HP lines on both mud pumps,;and suction lines of charge pumps. Inspect and prep derrick for scope down, , removed equalizer tubes between pit modules.;Scarified pad after rain storm and sanded traffic areas, re- welded broken weld on belt guard pump #2, HandyBerm tore out 2’ berm around aux fuel tank trailer, welder installed cement line brackets along Drillers side edge of beaver slide, Production did a line locate of both staked wells on north;end of field, found no issues, Inspectors cont inspecting charge pump plumbing in hopper rooms, removed drive belt from pump #2, installed replacement belt, found to be too long, swapped ends on old belt and re-installed on pump #2, cont painting in pits.;Welder fabricated oil fill tube for rotary table, adjusted motor skid for pump #2 to tighten drive belt, scoped derrick to lay over position, laid down bottom section of TQ tube. Hung off blocks, removed turnbuckles from upper section of TQ tube & secured to ODS derrick, unspooled drill line from;spool and cut off 30' of drill line (6 wraps), and coiled line up on rig floor. Removed drill line from dead man, R/D weight indicator, disconnected weight bucket line from front of DWKS skid. laid over floor motor stack. Cont. w/ cleaning & painting projects around rig.;R/D mud man shack & loaded out on trailer. Pulled out diesel auxiliary ISO tank from back yard of rig.;Crew change, held PTSM. Removed ice from containment around catwalk, R/D upper handrails & tarps on rig floor, cleaned MP room & wiped down MP motors. Cont. cleaning & painting in pits. Inspected derrick, finished securing derrick for lay down. R/D drive line for brake handle, brake linkage,;and camera system, removed ice from fuel containment liner, loaded BOP choke line on catwalk, R/D drillers control lines/ hoses from dog house to DWKS skid.;Storing & treating 300 bbls of 11.4 ppg 6%KCL PHPA mud at G&I 12/29/2020 Continue waiting on rig 401 to finish P&A of CLU-06 / Continued cleaning in pump room / R/dn brake handle linkage / r/dn skate controls / cleaned mud dock areas / Inspectors continued Mapping and inspection of rigs HP piping and hands continued cleaning plumbing infront of inspections;welder continued weld projects working on ODS trolly beam for better transistion and reweld of RT filler tube / Randys glasss chg out cracked broken windows in dog house / Continue painting projects / spot crane and remove IR wind wall for derrick lay over;Cleaned MP #1 engine/ Remove belt from MP #2 & installed new belt/ painted steam lines in pump room & lube room with Hi-temp paint/ welded safety chains on flag poles/ welded out two cracks on shaker bed #3/ Had Sean with Great Northern Hydraulic out, started plumbing in HYD for man rider;operations of tugger/ secured weight bucket for lay over.;Worked on installing new snail on mix pump in hopper house #2/Cleaned & painted in lube room/ Cleaned MP #2 engine/ Welded API in grating of pits for access hatches in pits/ Installed shipping bar in iron roughneck/ freed Handy from ice around rig for easy removal when time comes.;Crew change, held PTSM. Cont. working misc. cleaning & painting around rig/ R/D mud lines between modules/ Removed handrails on catwalk/ Laid over V-Door onto catwalk/ R/D & secured catwalk for move/ Bleed down HYD/ R/D power cables & HYD hoses from sub base to catwalk;R/D iron roughneck/ Thawing out rig mats in back yard w/ steam blanket.;Storing & treating 300 bbls of 11.4 ppg 6%KCL PHPA mud at G&I 12/30/2020 Continue wait on rig 401 to clear CLU -06 location / continue Thaw and clear ice on rig mats / clean and vac out cellar / continue r/dn electrical cables / install new mtr on hotsy pressure washer / Continue w/ weld projects / install cable for derrick heater / install cable for HPU ESD;Secured Kelly hose and service loop, un-pined derrick A legs and lower derrick / r/dn gen set #3 / Chg oil and filters on gen set #2 / chg oil and filters on camp generator / prep derrick and drill line spool for removal / Inspectors inspecting stand pipe / removed 400 bbl water tank /;shut boilers in and blew down steam lines & water lines / let boilers cool dn / removed pipe skate & loaded out / vacuumed out water tank / craned of wind walls & derrick house / loaded out Gen #3.;Craned out BOP's from cellar & secured in cradle for move / Cont. w/ welding projects / found leak in steam line in rig water tank, plan is to have welder fix after move / Craned iron roughneck off rig floor & secured on shipping skid / R/D & put away Handy Berm;R/D utility lines from pump room to pits / R/D jumper hoses between hopper houses / R/D & secured equip. in pits / R/D & lowered degasser into pit #4/ welded snub post on beaver side / craned centrifuge off stand & prepped for move.;Crew change, held PTSM. Cont. R/D misc. air, water, & electric lines / folding up walk ways / policing pad / lower pit module roofs / retracted dog house overhang in / lower dog house into rig tank.;Storing & treating 300 bbls of 11.4 ppg 6%KCL PHPA mud at G&I Activity Date Ops Summary 1/5/2021 Petrospec coiled tubing arrive. Conduct JSA and approve PTW. Spot coil unit, Peak crane, return tank, and choke skid. RU BOPE on xmas tree.,Test blind/shear ram, choke & kill lines to 250/4000 psi. Insert 1.75" test bar into BOP's and close pipe/slip ram, test to 250/4000 psi. Test accumulator system. AOGCC BOP test waived witness by Jim Regg.,Close blind/shear ram and install night cap.,Spot Fox energy N2 pump truck and air gas N2 transport. 1/6/2021 Petrospec, Peak Crane, Fox Energy arrive. Conduct JSA and approve PTW. MU 1.75" dual checks/nozzle, MU injector/lubricator on top of BOP's. RU Fox Energy N2 lines and cool down. PT to 4000 psi.,Test lubricator and stripper to 250/4000 psi.,Open well and RIH pumping N2. Tag at 8114' ctmd. POOH pumping N2, recover 175 bbls of fluid. Close in choke while POOH once all fluid returns stopped at surface.,POOH. Trap 3000 psi of pressure on well and shut- in well.,Fox energy RDMO. Coil continues to RD.,Coil RDMO. 1/7/2021 PTW and JSA. Rig up E-line. PT 250 psi low / 3600 psi high. Issues opening new valves initially. N2 in a new tree. Makes valves hard to turn.,RIH W/3 3/8'' x 16' HC razor, 6 SPF, 60 deg phase. and tie-in OHL. Ran correlation log and send to town. Got ok to perforate from 7864' to 7880' W/2607 psi. Spotted and fired gun. After 5 minutes - 2610 psi, 10 minutes - 2612 psi, 15 minutes - 2614 psi, 35 minutes - 2621 psi and still building.,Rigged down lubricator and equipment. Turn well over to field. n (LAT/LONG): evation (RKB): 50-133-20695-00-00API #: Well Name: Field: County/State: SRF GS SCU 42-05Z Swanson River Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:201-03740C SCU 42-05Z Completion Spud Date: y Got ok to perforate from 7864' to 7880' W/2607 psi. pg g Trap 3000 psi of pressure on well Petrospec coiled tubing arrive. Conduct 201-03740C SCU 42-05Z Completion 16 December, 2020 Soldotna CK Unit SCU 42-05 SCU 42-05Z 501332069500 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Soldotna CK Unit SCU 42-05 Halliburton Definitive Survey Report Well: Wellbore: SCU 42-05Z SCU 42-05Z Survey Calculation Method:Minimum Curvature Actual @ 171.70usft Design:SCU 42-05Z Database:NORTH US + CANADA MD Reference:Actual @ 171.70usft North Reference: Well SCU 42-05Z True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Soldotna CK Unit, Swanson River Field 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: SCU 42-05Z usft usft 0.00 0.00 2,457,872.331 341,714.763 153.70Wellhead Elevation:usft0.50 60° 43' 28.852 N 150° 53' 2.725 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) SCU 42-05Z Model NameMagnetics IFR 12/14/2020 14.99 73.70 55,477.50000000 Phase:Version: Audit Notes: Design SCU 42-05Z 1.0 ACTUAL Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:18.00 355.470.000.0018.00 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 12/16/2020 Survey Date 3_MWD+IFR1+MS+Sag A010Mb: IFR dec & multi-station analysis + sag142.65 2,919.30 SCU 42-05Z MWD+IFR1+MS+Sag (1) (S 12/01/2020 3_MWD+IFR1+MS+Sag A010Mb: IFR dec & multi-station analysis + sag2,987.50 8,133.40 SCU 42-05Z MWD+IFR1+MS+Sag (2) (S 12/14/2020 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 18.00 0.00 0.00 18.00 0.00 0.00-153.70 2,457,872.33 341,714.76 0.00 0.00 UNDEFINED 142.65 0.44 66.51 142.65 0.19 0.44-29.05 2,457,872.52 341,715.20 0.35 0.16 3_MWD+IFR1+MS+Sag (1) 202.94 0.20 42.08 202.94 0.36 0.7231.24 2,457,872.68 341,715.49 0.45 0.30 3_MWD+IFR1+MS+Sag (1) 264.43 0.32 74.31 264.43 0.49 0.9692.73 2,457,872.81 341,715.73 0.30 0.41 3_MWD+IFR1+MS+Sag (1) 326.31 0.72 317.50 326.31 0.82 0.86154.61 2,457,873.14 341,715.64 1.47 0.75 3_MWD+IFR1+MS+Sag (1) 391.53 0.73 312.75 391.52 1.40 0.28219.82 2,457,873.73 341,715.06 0.09 1.38 3_MWD+IFR1+MS+Sag (1) 452.92 0.94 324.94 452.90 2.08 -0.30281.20 2,457,874.42 341,714.50 0.45 2.10 3_MWD+IFR1+MS+Sag (1) 513.82 0.81 324.11 513.80 2.84 -0.83342.10 2,457,875.18 341,713.97 0.21 2.90 3_MWD+IFR1+MS+Sag (1) 575.11 0.75 325.55 575.08 3.52 -1.32403.38 2,457,875.87 341,713.49 0.10 3.61 3_MWD+IFR1+MS+Sag (1) 636.36 0.66 317.73 636.33 4.11 -1.78464.63 2,457,876.47 341,713.04 0.21 4.24 3_MWD+IFR1+MS+Sag (1) 697.65 0.64 315.36 697.61 4.62 -2.26525.91 2,457,876.98 341,712.57 0.05 4.78 3_MWD+IFR1+MS+Sag (1) 760.57 0.59 333.63 760.53 5.16 -2.65588.83 2,457,877.52 341,712.18 0.32 5.35 3_MWD+IFR1+MS+Sag (1) 822.60 1.00 331.38 822.55 5.92 -3.05650.85 2,457,878.29 341,711.79 0.66 6.14 3_MWD+IFR1+MS+Sag (1) 12/16/2020 11:58:55AM COMPASS 5000.15 Build 91E Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Soldotna CK Unit SCU 42-05 Halliburton Definitive Survey Report Well: Wellbore: SCU 42-05Z SCU 42-05Z Survey Calculation Method:Minimum Curvature Actual @ 171.70usft Design:SCU 42-05Z Database:NORTH US + CANADA MD Reference:Actual @ 171.70usft North Reference: Well SCU 42-05Z 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 884.28 0.91 338.61 884.22 6.85 -3.49712.52 2,457,879.23 341,711.37 0.24 7.10 3_MWD+IFR1+MS+Sag (1) 945.35 1.00 331.92 945.29 7.77 -3.91773.59 2,457,880.15 341,710.95 0.23 8.05 3_MWD+IFR1+MS+Sag (1) 1,008.49 0.76 339.62 1,008.42 8.65 -4.32836.72 2,457,881.04 341,710.56 0.42 8.96 3_MWD+IFR1+MS+Sag (1) 1,070.99 0.99 332.08 1,070.91 9.51 -4.72899.21 2,457,881.91 341,710.18 0.41 9.86 3_MWD+IFR1+MS+Sag (1) 1,131.90 0.84 334.32 1,131.81 10.38 -5.16960.11 2,457,882.78 341,709.75 0.25 10.76 3_MWD+IFR1+MS+Sag (1) 1,195.02 1.11 324.81 1,194.92 11.30 -5.711,023.22 2,457,883.70 341,709.21 0.50 11.71 3_MWD+IFR1+MS+Sag (1) 1,257.33 0.92 327.71 1,257.22 12.21 -6.321,085.52 2,457,884.63 341,708.60 0.32 12.68 3_MWD+IFR1+MS+Sag (1) 1,319.77 0.76 325.78 1,319.66 12.98 -6.821,147.96 2,457,885.40 341,708.11 0.26 13.48 3_MWD+IFR1+MS+Sag (1) 1,381.72 0.88 306.38 1,381.60 13.60 -7.441,209.90 2,457,886.03 341,707.51 0.49 14.15 3_MWD+IFR1+MS+Sag (1) 1,444.18 0.84 313.27 1,444.05 14.20 -8.161,272.35 2,457,886.64 341,706.80 0.18 14.80 3_MWD+IFR1+MS+Sag (1) 1,506.19 0.87 332.84 1,506.06 14.93 -8.701,334.36 2,457,887.38 341,706.26 0.47 15.57 3_MWD+IFR1+MS+Sag (1) 1,568.27 1.04 335.66 1,568.13 15.86 -9.151,396.43 2,457,888.32 341,705.83 0.28 16.54 3_MWD+IFR1+MS+Sag (1) 1,630.46 1.07 337.50 1,630.31 16.91 -9.611,458.61 2,457,889.37 341,705.39 0.07 17.62 3_MWD+IFR1+MS+Sag (1) 1,693.51 1.33 333.16 1,693.34 18.11 -10.161,521.64 2,457,890.58 341,704.85 0.44 18.86 3_MWD+IFR1+MS+Sag (1) 1,755.91 1.08 333.19 1,755.73 19.28 -10.751,584.03 2,457,891.75 341,704.27 0.40 20.07 3_MWD+IFR1+MS+Sag (1) 1,818.48 0.99 325.53 1,818.29 20.25 -11.331,646.59 2,457,892.73 341,703.71 0.26 21.09 3_MWD+IFR1+MS+Sag (1) 1,880.91 0.85 311.37 1,880.71 21.00 -11.981,709.01 2,457,893.49 341,703.07 0.43 21.89 3_MWD+IFR1+MS+Sag (1) 1,943.74 0.99 310.48 1,943.53 21.67 -12.741,771.83 2,457,894.16 341,702.32 0.22 22.60 3_MWD+IFR1+MS+Sag (1) 2,006.36 1.06 317.49 2,006.14 22.44 -13.541,834.44 2,457,894.95 341,701.52 0.23 23.44 3_MWD+IFR1+MS+Sag (1) 2,068.37 1.20 315.56 2,068.14 23.33 -14.391,896.44 2,457,895.85 341,700.69 0.23 24.39 3_MWD+IFR1+MS+Sag (1) 2,130.48 1.34 302.58 2,130.24 24.19 -15.451,958.54 2,457,896.72 341,699.64 0.51 25.33 3_MWD+IFR1+MS+Sag (1) 2,192.40 1.07 299.43 2,192.14 24.86 -16.572,020.44 2,457,897.41 341,698.53 0.45 26.09 3_MWD+IFR1+MS+Sag (1) 2,254.98 0.98 307.27 2,254.71 25.47 -17.502,083.01 2,457,898.03 341,697.61 0.27 26.77 3_MWD+IFR1+MS+Sag (1) 2,316.52 1.09 300.52 2,316.24 26.09 -18.432,144.54 2,457,898.66 341,696.69 0.27 27.46 3_MWD+IFR1+MS+Sag (1) 2,378.68 0.99 293.37 2,378.39 26.60 -19.432,206.69 2,457,899.19 341,695.70 0.26 28.05 3_MWD+IFR1+MS+Sag (1) 2,440.02 0.80 295.69 2,439.73 27.00 -20.302,268.03 2,457,899.60 341,694.83 0.32 28.51 3_MWD+IFR1+MS+Sag (1) 2,501.62 1.03 288.66 2,501.32 27.36 -21.212,329.62 2,457,899.97 341,693.92 0.41 28.95 3_MWD+IFR1+MS+Sag (1) 2,564.46 0.88 295.10 2,564.15 27.74 -22.182,392.45 2,457,900.37 341,692.96 0.29 29.41 3_MWD+IFR1+MS+Sag (1) 2,625.92 1.15 292.37 2,625.60 28.18 -23.182,453.90 2,457,900.82 341,691.96 0.45 29.92 3_MWD+IFR1+MS+Sag (1) 2,688.43 0.90 289.72 2,688.10 28.58 -24.222,516.40 2,457,901.24 341,690.93 0.41 30.41 3_MWD+IFR1+MS+Sag (1) 2,750.19 0.84 283.58 2,749.85 28.85 -25.122,578.15 2,457,901.52 341,690.03 0.18 30.75 3_MWD+IFR1+MS+Sag (1) 2,811.86 1.14 278.96 2,811.51 29.06 -26.172,639.81 2,457,901.73 341,688.99 0.50 31.03 3_MWD+IFR1+MS+Sag (1) 2,873.51 1.21 262.81 2,873.15 29.07 -27.422,701.45 2,457,901.76 341,687.74 0.55 31.14 3_MWD+IFR1+MS+Sag (1) 2,919.30 1.38 268.43 2,918.93 28.99 -28.452,747.23 2,457,901.70 341,686.71 0.46 31.15 3_MWD+IFR1+MS+Sag (1) 2,987.50 1.28 269.45 2,987.11 28.96 -30.032,815.41 2,457,901.69 341,685.13 0.15 31.25 3_MWD+IFR1+MS+Sag (2) 3,051.58 1.45 278.32 3,051.17 29.07 -31.552,879.47 2,457,901.83 341,683.61 0.42 31.48 3_MWD+IFR1+MS+Sag (2) 3,113.80 1.58 276.97 3,113.37 29.29 -33.182,941.67 2,457,902.07 341,681.98 0.22 31.82 3_MWD+IFR1+MS+Sag (2) 3,175.23 1.70 314.16 3,174.78 30.03 -34.673,003.08 2,457,902.82 341,680.50 1.71 32.67 3_MWD+IFR1+MS+Sag (2) 3,237.97 1.76 319.63 3,237.49 31.41 -35.973,065.79 2,457,904.22 341,679.23 0.28 34.15 3_MWD+IFR1+MS+Sag (2) 3,299.67 1.12 316.66 3,299.17 32.57 -36.993,127.47 2,457,905.40 341,678.21 1.04 35.39 3_MWD+IFR1+MS+Sag (2) 12/16/2020 11:58:55AM COMPASS 5000.15 Build 91E Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Soldotna CK Unit SCU 42-05 Halliburton Definitive Survey Report Well: Wellbore: SCU 42-05Z SCU 42-05Z Survey Calculation Method:Minimum Curvature Actual @ 171.70usft Design:SCU 42-05Z Database:NORTH US + CANADA MD Reference:Actual @ 171.70usft North Reference: Well SCU 42-05Z 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 3,361.81 1.16 318.22 3,361.30 33.48 -37.833,189.60 2,457,906.32 341,677.39 0.08 36.37 3_MWD+IFR1+MS+Sag (2) 3,424.06 1.23 322.13 3,423.53 34.48 -38.663,251.83 2,457,907.33 341,676.57 0.17 37.43 3_MWD+IFR1+MS+Sag (2) 3,486.62 1.23 318.44 3,486.08 35.51 -39.523,314.38 2,457,908.37 341,675.73 0.13 38.52 3_MWD+IFR1+MS+Sag (2) 3,547.62 1.41 324.01 3,547.06 36.61 -40.393,375.36 2,457,909.48 341,674.87 0.36 39.69 3_MWD+IFR1+MS+Sag (2) 3,609.55 1.63 320.55 3,608.97 37.91 -41.403,437.27 2,457,910.79 341,673.88 0.38 41.06 3_MWD+IFR1+MS+Sag (2) 3,670.74 1.10 318.91 3,670.14 39.02 -42.343,498.44 2,457,911.92 341,672.96 0.87 42.24 3_MWD+IFR1+MS+Sag (2) 3,733.16 0.98 318.50 3,732.55 39.87 -43.093,560.85 2,457,912.78 341,672.22 0.19 43.15 3_MWD+IFR1+MS+Sag (2) 3,794.94 1.06 299.54 3,794.32 40.55 -43.933,622.62 2,457,913.47 341,671.38 0.56 43.89 3_MWD+IFR1+MS+Sag (2) 3,857.07 0.97 314.64 3,856.44 41.20 -44.813,684.74 2,457,914.13 341,670.52 0.45 44.61 3_MWD+IFR1+MS+Sag (2) 3,917.81 1.17 358.97 3,917.17 42.18 -45.183,745.47 2,457,915.12 341,670.15 1.36 45.62 3_MWD+IFR1+MS+Sag (2) 3,980.98 1.20 6.51 3,980.33 43.49 -45.123,808.63 2,457,916.42 341,670.23 0.25 46.91 3_MWD+IFR1+MS+Sag (2) 4,043.33 1.32 5.06 4,042.66 44.85 -44.983,870.96 2,457,917.78 341,670.39 0.20 48.26 3_MWD+IFR1+MS+Sag (2) 4,105.08 1.33 332.68 4,104.40 46.20 -45.253,932.70 2,457,919.13 341,670.14 1.20 49.63 3_MWD+IFR1+MS+Sag (2) 4,166.88 1.34 324.68 4,166.18 47.42 -46.003,994.48 2,457,920.37 341,669.41 0.30 50.91 3_MWD+IFR1+MS+Sag (2) 4,229.33 1.57 326.89 4,228.61 48.74 -46.894,056.91 2,457,921.69 341,668.54 0.38 52.29 3_MWD+IFR1+MS+Sag (2) 4,290.69 0.95 314.47 4,289.96 49.80 -47.714,118.26 2,457,922.76 341,667.73 1.10 53.41 3_MWD+IFR1+MS+Sag (2) 4,352.76 1.08 333.03 4,352.02 50.68 -48.344,180.32 2,457,923.65 341,667.11 0.57 54.34 3_MWD+IFR1+MS+Sag (2) 4,414.46 1.48 330.92 4,413.70 51.89 -48.994,242.00 2,457,924.87 341,666.48 0.65 55.60 3_MWD+IFR1+MS+Sag (2) 4,475.91 1.44 336.75 4,475.13 53.30 -49.684,303.43 2,457,926.29 341,665.81 0.25 57.05 3_MWD+IFR1+MS+Sag (2) 4,537.94 1.61 336.79 4,537.14 54.81 -50.334,365.44 2,457,927.81 341,665.18 0.27 58.62 3_MWD+IFR1+MS+Sag (2) 4,599.97 1.80 347.14 4,599.14 56.56 -50.894,427.44 2,457,929.57 341,664.64 0.58 60.41 3_MWD+IFR1+MS+Sag (2) 4,661.93 1.02 319.85 4,661.08 57.93 -51.474,489.38 2,457,930.95 341,664.09 1.63 61.82 3_MWD+IFR1+MS+Sag (2) 4,723.72 0.70 302.85 4,722.87 58.56 -52.144,551.17 2,457,931.58 341,663.42 0.66 62.49 3_MWD+IFR1+MS+Sag (2) 4,785.16 0.63 306.86 4,784.30 58.96 -52.724,612.60 2,457,932.00 341,662.84 0.14 62.94 3_MWD+IFR1+MS+Sag (2) 4,847.22 0.78 302.16 4,846.36 59.39 -53.354,674.66 2,457,932.43 341,662.22 0.26 63.42 3_MWD+IFR1+MS+Sag (2) 4,909.64 0.68 310.41 4,908.77 59.86 -54.004,737.07 2,457,932.91 341,661.58 0.23 63.94 3_MWD+IFR1+MS+Sag (2) 4,969.73 0.80 308.86 4,968.86 60.35 -54.594,797.16 2,457,933.41 341,660.99 0.20 64.48 3_MWD+IFR1+MS+Sag (2) 5,033.24 0.82 344.75 5,032.36 61.07 -55.064,860.66 2,457,934.13 341,660.54 0.79 65.23 3_MWD+IFR1+MS+Sag (2) 5,096.36 0.89 3.00 5,095.48 62.00 -55.154,923.78 2,457,935.06 341,660.45 0.44 66.16 3_MWD+IFR1+MS+Sag (2) 5,158.16 1.12 18.36 5,157.27 63.05 -54.944,985.57 2,457,936.11 341,660.68 0.57 67.19 3_MWD+IFR1+MS+Sag (2) 5,219.13 1.57 334.42 5,218.22 64.37 -55.115,046.52 2,457,937.43 341,660.53 1.79 68.52 3_MWD+IFR1+MS+Sag (2) 5,280.88 1.57 341.06 5,279.95 65.93 -55.755,108.25 2,457,939.00 341,659.91 0.29 70.13 3_MWD+IFR1+MS+Sag (2) 5,340.23 1.72 347.64 5,339.27 67.57 -56.205,167.57 2,457,940.65 341,659.48 0.41 71.80 3_MWD+IFR1+MS+Sag (2) 5,404.24 1.79 351.28 5,403.25 69.50 -56.565,231.55 2,457,942.58 341,659.15 0.21 73.75 3_MWD+IFR1+MS+Sag (2) 5,466.98 2.05 11.72 5,465.96 71.56 -56.485,294.26 2,457,944.64 341,659.25 1.16 75.80 3_MWD+IFR1+MS+Sag (2) 5,528.23 2.10 11.52 5,527.17 73.74 -56.035,355.47 2,457,946.81 341,659.73 0.08 77.93 3_MWD+IFR1+MS+Sag (2) 5,590.46 3.72 10.62 5,589.32 76.84 -55.435,417.62 2,457,949.90 341,660.37 2.60 80.98 3_MWD+IFR1+MS+Sag (2) 5,653.08 4.79 7.74 5,651.76 81.43 -54.715,480.06 2,457,954.48 341,661.16 1.74 85.49 3_MWD+IFR1+MS+Sag (2) 5,714.85 6.55 4.57 5,713.23 87.49 -54.085,541.53 2,457,960.54 341,661.87 2.89 91.49 3_MWD+IFR1+MS+Sag (2) 5,777.47 7.94 1.32 5,775.35 95.38 -53.705,603.65 2,457,968.42 341,662.36 2.31 99.32 3_MWD+IFR1+MS+Sag (2) 12/16/2020 11:58:55AM COMPASS 5000.15 Build 91E Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Soldotna CK Unit SCU 42-05 Halliburton Definitive Survey Report Well: Wellbore: SCU 42-05Z SCU 42-05Z Survey Calculation Method:Minimum Curvature Actual @ 171.70usft Design:SCU 42-05Z Database:NORTH US + CANADA MD Reference:Actual @ 171.70usft North Reference: Well SCU 42-05Z 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 5,839.20 8.71 355.73 5,836.43 104.30 -53.955,664.73 2,457,977.34 341,662.23 1.81 108.24 3_MWD+IFR1+MS+Sag (2) 5,901.95 9.34 355.12 5,898.40 114.11 -54.735,726.70 2,457,987.16 341,661.58 1.02 118.08 3_MWD+IFR1+MS+Sag (2) 5,963.97 9.86 354.76 5,959.55 124.42 -55.655,787.85 2,457,997.48 341,660.80 0.84 128.42 3_MWD+IFR1+MS+Sag (2) 6,025.43 10.13 356.68 6,020.08 135.05 -56.445,848.38 2,458,008.12 341,660.15 0.70 139.09 3_MWD+IFR1+MS+Sag (2) 6,088.21 9.31 355.58 6,081.96 145.63 -57.155,910.26 2,458,018.70 341,659.58 1.34 149.69 3_MWD+IFR1+MS+Sag (2) 6,150.23 9.41 355.59 6,143.15 155.68 -57.935,971.45 2,458,028.77 341,658.94 0.16 159.77 3_MWD+IFR1+MS+Sag (2) 6,213.04 10.00 358.07 6,205.06 166.25 -58.516,033.36 2,458,039.34 341,658.50 1.15 170.35 3_MWD+IFR1+MS+Sag (2) 6,275.33 9.77 0.08 6,266.43 176.94 -58.686,094.73 2,458,050.04 341,658.47 0.67 181.03 3_MWD+IFR1+MS+Sag (2) 6,337.09 8.88 357.78 6,327.37 186.95 -58.866,155.67 2,458,060.04 341,658.43 1.56 191.01 3_MWD+IFR1+MS+Sag (2) 6,397.95 9.18 356.62 6,387.48 196.49 -59.336,215.78 2,458,069.58 341,658.09 0.58 200.56 3_MWD+IFR1+MS+Sag (2) 6,460.07 8.68 359.08 6,448.84 206.12 -59.696,277.14 2,458,079.22 341,657.85 1.01 210.19 3_MWD+IFR1+MS+Sag (2) 6,522.73 8.18 3.06 6,510.83 215.30 -59.536,339.13 2,458,088.40 341,658.14 1.23 219.33 3_MWD+IFR1+MS+Sag (2) 6,584.55 9.06 359.57 6,571.95 224.56 -59.336,400.25 2,458,097.65 341,658.46 1.66 228.54 3_MWD+IFR1+MS+Sag (2) 6,647.32 9.12 1.45 6,633.93 234.47 -59.246,462.23 2,458,107.56 341,658.68 0.48 238.42 3_MWD+IFR1+MS+Sag (2) 6,708.92 9.56 357.07 6,694.71 244.46 -59.386,523.01 2,458,117.55 341,658.68 1.36 248.39 3_MWD+IFR1+MS+Sag (2) 6,772.59 9.42 350.21 6,757.52 254.88 -60.546,585.82 2,458,127.98 341,657.66 1.79 258.86 3_MWD+IFR1+MS+Sag (2) 6,836.94 8.96 352.49 6,821.04 265.04 -62.096,649.34 2,458,138.16 341,656.25 0.91 269.11 3_MWD+IFR1+MS+Sag (2) 6,898.79 8.53 354.88 6,882.17 274.38 -63.136,710.47 2,458,147.52 341,655.34 0.91 278.51 3_MWD+IFR1+MS+Sag (2) 6,961.55 8.81 357.52 6,944.21 283.82 -63.756,772.51 2,458,156.96 341,654.84 0.78 287.97 3_MWD+IFR1+MS+Sag (2) 7,018.76 9.26 359.23 7,000.71 292.80 -64.006,829.01 2,458,165.94 341,654.71 0.92 296.94 3_MWD+IFR1+MS+Sag (2) 7,084.97 9.03 0.42 7,066.08 303.32 -64.046,894.38 2,458,176.46 341,654.82 0.45 307.43 3_MWD+IFR1+MS+Sag (2) 7,146.39 9.41 355.67 7,126.71 313.15 -64.386,955.01 2,458,186.29 341,654.61 1.38 317.25 3_MWD+IFR1+MS+Sag (2) 7,208.68 8.74 359.41 7,188.22 322.96 -64.817,016.52 2,458,196.11 341,654.31 1.43 327.07 3_MWD+IFR1+MS+Sag (2) 7,271.25 8.92 357.54 7,250.05 332.56 -65.077,078.35 2,458,205.71 341,654.18 0.54 336.66 3_MWD+IFR1+MS+Sag (2) 7,333.01 9.63 353.11 7,311.00 342.47 -65.907,139.30 2,458,215.63 341,653.49 1.63 346.60 3_MWD+IFR1+MS+Sag (2) 7,394.58 9.70 356.05 7,371.70 352.76 -66.877,200.00 2,458,225.93 341,652.65 0.81 356.94 3_MWD+IFR1+MS+Sag (2) 7,456.22 9.47 358.30 7,432.48 363.01 -67.387,260.78 2,458,236.18 341,652.28 0.71 367.19 3_MWD+IFR1+MS+Sag (2) 7,517.76 8.63 1.12 7,493.25 372.68 -67.447,321.55 2,458,245.86 341,652.35 1.54 376.84 3_MWD+IFR1+MS+Sag (2) 7,580.37 8.89 358.53 7,555.13 382.21 -67.477,383.43 2,458,255.39 341,652.45 0.75 386.35 3_MWD+IFR1+MS+Sag (2) 7,641.42 9.59 0.86 7,615.39 392.02 -67.527,443.69 2,458,265.19 341,652.53 1.30 396.12 3_MWD+IFR1+MS+Sag (2) 7,703.11 9.39 5.60 7,676.23 402.16 -66.957,504.53 2,458,275.33 341,653.24 1.31 406.19 3_MWD+IFR1+MS+Sag (2) 7,764.34 9.38 3.03 7,736.65 412.12 -66.207,564.95 2,458,285.27 341,654.12 0.68 416.06 3_MWD+IFR1+MS+Sag (2) 7,826.90 9.55 2.71 7,798.35 422.39 -65.687,626.65 2,458,295.54 341,654.78 0.28 426.26 3_MWD+IFR1+MS+Sag (2) 7,888.65 9.99 4.09 7,859.21 432.85 -65.067,687.51 2,458,305.99 341,655.54 0.81 436.64 3_MWD+IFR1+MS+Sag (2) 7,949.13 9.81 5.25 7,918.79 443.21 -64.217,747.09 2,458,316.34 341,656.53 0.44 446.90 3_MWD+IFR1+MS+Sag (2) 8,011.75 9.57 7.70 7,980.51 453.68 -63.037,808.81 2,458,326.79 341,657.85 0.76 457.24 3_MWD+IFR1+MS+Sag (2) 8,074.05 9.63 9.37 8,041.94 463.96 -61.487,870.24 2,458,337.04 341,659.53 0.46 467.36 3_MWD+IFR1+MS+Sag (2) 8,133.40 9.59 8.72 8,100.46 473.74 -59.937,928.76 2,458,346.80 341,661.22 0.19 477.00 3_MWD+IFR1+MS+Sag (2) 8,173.00 9.59 8.72 8,139.51 480.26 -58.937,967.81 2,458,353.31 341,662.31 0.00 483.42 PROJECTED to TD 12/16/2020 11:58:55AM COMPASS 5000.15 Build 91E Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Soldotna CK Unit SCU 42-05 Halliburton Definitive Survey Report Well: Wellbore: SCU 42-05Z SCU 42-05Z Survey Calculation Method:Minimum Curvature Actual @ 171.70usft Design:SCU 42-05Z Database:NORTH US + CANADA MD Reference:Actual @ 171.70usft North Reference: Well SCU 42-05Z True Approved By:Checked By:Date: 12/16/2020 11:58:55AM COMPASS 5000.15 Build 91E Page 6 Chelsea Wright Digitally signed by Chelsea Wright Date: 2020.12.16 09:06:42 -09'00' Benjamin Hand Digitally signed by Benjamin Hand Date: 2020.12.17 15:20:29 -09'00' TD Shoe Depth: PBTD: Jts. 2 72 Yes X No X Yes No 10 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? Yes X No Reciprocated?X Yes No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: 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: Casing (Or Liner) Detail Shoe 8 5/8 Rotate Csg Recip Csg Ft. Min. PPG9.05 Shoe @ 2956 FC @ Top of Liner2,876.00 Floats Held 183 27.6 155.4 Spud Mud CASING RECORD County State Alaska Supv.Hauck/Riley Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.SRF GS SCU 42-05Z Date Run 9-Dec-20 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top BTC 1.42 2,956.63 2,955.21 Csg Wt. On Hook:65,000 Type Float Collar:Weatherford No. Hrs to Run:5 9.05 5 100 817FIRST STAGE10.5Tune Primed 40 131.7/131.9 1553 27.6 Halliburton 15.8 33 Bump press Visual Bump Plug? 11:48 12/10/2020 0 2,956.002,965.00 CEMENTING REPORT Csg Wt. On Slips: Spud Mud 12 150 Type of Shoe:Weatherford Casing Crew:Weatherford www.wellez.net WellEz Information Management LLC ver_04818br 3 7 5/8'' Casing jts 7 5/8 29.7 L-80 USS-CDC 77.67 2,955.21 2,877.54 Float Collar 8 5/8 BTC 1.27 2,877.54 2,876.27 7 5/8'' Casing Jts 7 5/8 29.7 L-80 USS-CDC 2,851.01 2,876.27 25.26 7 5/8'' Casing Pup jt 7 5/8 29.7 L-80 USS-CDC 2.38 25.26 22.88 Casing Hanger 16 22.88 21.90 1 ll 355 2.4 A 160 1.16 5 39 TD Shoe Depth: PBTD: Jts. 1 1 130 X Yes No Yes X No Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?:X Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated?X Yes No Reciprocated? 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 ll 239 2.4 Class G 55 1.24 4 37.06 2,804.34 2,767.28ZXP Liner Hanger 6 5/8 CDC HTQ Baker 8,085.62 5.5'' Casing Jts 5 1/2 17.0 L-80 CDC HTQ 5,281.38 8,085.62 2,804.34 8,129.27 8,087.58 Landing Collar 6 CDC HTQ 1.96 8,087.58 1.23 8,130.50 8,129.27 5.5'' Casing Jt 5 1/2 17.0 L-80 CDC HTQ 41.69 Float Collar 6 CDC HTQ Innovex One per joint all 132 joints, bow spring type 5.5'' Casing Jt 5 1/2 17.0 L-80 CDC HTQ 41.47 8,171.97 8,130.50 HRD- E ZXP Flex Lock www.wellez.net WellEz Information Management LLC ver_04818br 2 Type of Shoe:Innovex Bullnose Casing Crew:Weatherford 12 102 8,173.008,173.00 8,085.62 CEMENTING REPORT Csg Wt. On Slips: 6% KCL Polymer 23:35 12/19/2020 3,600' 15.3 12 Bump press CBL Bump Plug? 160/161.8 1850 26 HalliburtonFIRST STAGE12Tuned primed 40 11.4 5 100 1350 Csg Wt. On Hook: Type Float Collar:Innovex No. Hrs to Run: CDC HTQ Innovex 1.43 8,173.40 8,171.97 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.SRF GS SCU 42-05Z Date Run 19-Dec-20 CASING RECORD County State Alaska Supv.Pederson / Riley 8,126.00 Floats Held 161.8 114 26 88 6% KCL Polymer Rotate Csg Recip Csg Ft. Min. PPG11.4 Shoe @ 8171 FC @ Top of Liner 2764 Casing (Or Liner) Detail Shoe 6 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 01/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 42-05Z (PTD 220-069) PERFORATING RECORD 01/07/2021 Please include current contact information if different from above. 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tŚĞŶĨŝŶĂůŶŝƚƌŽŐĞŶǀŽůƵŵĞŚĂƐďĞĞŶĂĐŚŝĞǀĞĚ͕ŝƐŽůĂƚĞǁĞůůĨƌŽŵEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ ďůĞĞĚĚŽǁŶůŝŶĞƐďĞƚǁĞĞŶǁĞůůĂŶĚEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϲ͘Ϳ KŶĐĞǇŽƵŚĂǀĞĐŽŶĨŝƌŵĞĚůŝŶĞƐĂƌĞďůĞĚĚŽǁŶ͕ŶŽƚƌĂƉƉĞĚƉƌĞƐƐƵƌĞĞǆŝƐƚƐ͕ĂŶĚŶŽŶŝƚƌŽŐĞŶŚĂƐ ĂĐĐƵŵƵůĂƚĞĚďĞŐŝŶƌŝŐĚŽǁŶŽĨůŝŶĞƐĨƌŽŵƚŚĞEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϳ͘Ϳ &ŝŶĂůŝǌĞũŽďůŽŐĂŶĚĚŝƐĐƵƐƐŽƉĞƌĂƚŝŽŶƐǁŝƚŚtĞůůƐŝƚĞDĂŶĂŐĞƌ͘ŽĐƵŵĞŶƚĂŶǇůĞƐƐŽŶƐůĞĂƌŶĞĚ ĂŶĚĐŽŶĨŝƌŵĨŝŶĂůƌĂƚĞƐͬƉƌĞƐƐƵƌĞͬǀŽůƵŵĞƐŽĨƚŚĞũŽďĂŶĚƌĞŵĂŝŶŝŶŐŶŝƚƌŽŐĞŶŝŶƚŚĞƚƌĂŶƐƉŽƌƚ͘ ϭϴ͘Ϳ ZDKEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdƌĂŶƐƉŽƌƚ͘ David Douglas Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or fax to 907 777-8510. Received By: Date: Date: 12/23/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 42-05Z (PTD 220-069) FINAL LWD FORMATION EVALUATION LOGS (12/07/2020 to 12/15/2020) •DGR, PCG-K, ADR, ALD, CTN (2” & 5” MD/TVD Color Logs) •Final Definitive Directional Survey SFTP Transfer - Data Folders: Please include current contact information if different from above. PTD: 2200690 E-Set: 34465 Received by the AOGCC 12/23/2020 Abby Bell 12/23/2020 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty M Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Tyonek 77-3 Gas Storage Pool, SCU 42-05Z Hilcorp Alaska, LLC Permit to Drill Number: 220-069 Surface Location: 3360’ FNL, 600’ FEL, Sec 5, T7N, R9W, SM, AK Bottomhole Location: 2479' FSL, 640' FEL, Sec 5, T7N, R9W, SM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of November, 2020. JMPi 18 1a. Type of Work:1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name:5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address:6. Proposed Depth: 12. Field/Pool(s): MD: 8,500' TVD: 8,459' 4a. Location of Well (Governmental Section):7. Property Designation: Surface: Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date: Total Depth:9. Acres in Property: 14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27):10. KB Elevation above MSL (ft): 172.2' 15. Distance to Nearest Well Open Surface: x-341714 y- 2457872 Zone-4 153.7' to Same Pool: 62' to SCU 42B-05 16. Deviated wells:Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 10 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD Cond 16" 84# X-56 Weld 120' Surface Surface 120' 120' 9-7/8" 7-5/8" 29.7# L-80 CDC 2,900' Surface Surface 2,900' 2,900' 6-3/4" 5-1/2" 17# L-80 CDC HTQ 5,750' 2,750' 2,750' 8,500' 8,459' Tieback 5-1/2" 17# L-80 CDC HTQ 2,750 Surface Surface 2,750' 2,750' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned?Yes No 20. Attachments:Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Contact Email: Contact Phone: Date: Permit to Drill API Number: Permit Approval Number:50- Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Sr Pet Eng Sr Pet Geo Sr Res Eng GL / BF Elevation above MSL (ft): 10/6/2020 See cover letter for other requirements. Perforation Depth MD (ft): 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Perforation Depth TVD (ft): Commission Use Only Effect. Depth MD (ft): Authorized Signature: Surface Production Liner Casing Intermediate Tieback Assy. L - 844 ft3 / T - 183 ft3 Effect. Depth TVD (ft): Conductor/Structural Length 4200 Total Depth MD (ft):Total Depth TVD (ft): Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) Driven STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 L - 515 ft3 / T - 58 ft3 3618 2375' FSL, 640' FEL, Sec 5, T7N, R9W, SM, AK 2479' FSL, 640' FEL, Sec 5, T7N, R9W, SM, AK N/A 1120 SCU 42-05Z Swanson River Field Tyonek 77-3 Gas Storage Pool 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 Hilcorp Alaska, LLC 3360’ FNL, 600’ FEL, Sec 5, T7N, R9W, SM, AK A028996 022224484 2019' to nearest unit boundary 11/28/2020 Authorized Name: Monty Myers Authorized Title: Drilling Manager Joe Engel jengel@hilcorp.com 777-8395 18. Casing Program:Top - Setting Depth - BottomSpecifications es N ype of W L l R L 1b S Class: os N es No s N o D s s s D 84 o : well is p G S S 20 S S S es No s No S G E S es No s Form 10-401 Revised 3/2020 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) By Samantha Carlisle at 2:44 pm, Oct 06, 2020 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2020.10.06 14:24:37 -08'00' Monty M Myers SFD 10/7/2020 DSR-10/12/2020 50-133-20695-00-00220-069 10- gls/20 Service - SupplyS Tyonek gas storage well * Gas Injection not allowed without AOGCC approval * CBL and witnessed MIT-IA required. *Sundry approval required to perforate and complete well PSI BOPE TEST*3500 gas storage producer only *3750 11/16/20 gls 11/16/20 3618 X s/200000000000000 y approval required 11/1111 16/20 11/18/2020 11/18/2020 SCU 42-05Z (43-05) Drilling Program Swanson River Unit Rev 1 Sept 30, 2020 Contents 1.0 Well Summary ........................................................................................................................... 2 2.0 Management of Change Information ........................................................................................ 3 3.0 Tubular Program:...................................................................................................................... 4 4.0 Drill Pipe Information: .............................................................................................................. 4 5.0 Internal Reporting Requirements ............................................................................................. 5 6.0 Planned Wellbore Schematic ..................................................................................................... 6 7.0 Drilling / Completion Summary ................................................................................................ 7 8.0 Mandatory Regulatory Compliance / Notifications .................................................................. 8 9.0 R/U and Preparatory Work ..................................................................................................... 11 10.0 N/U 21-1/4” 2M Diverter ......................................................................................................... 12 11.0 Drill 9-7/8” Hole Section .......................................................................................................... 14 12.0 Run 7-5/8” Surface Casing ...................................................................................................... 16 13.0 Cement 7-5/8” Surface Casing ................................................................................................. 19 14.0 BOP N/U and Test.................................................................................................................... 22 15.0 Drill 6-3/4” Hole Section .......................................................................................................... 23 16.0 Run 5-1/2” Production Liner ................................................................................................... 26 17.0 Cement 5-1/2” Production Liner ............................................................................................. 29 18.0 5-1/2” Liner Tieback Polish Run and Cleanout Run .............................................................. 33 19.0 5-1/2” Cleanout Run ................................................................................................................ 33 20.0 RDMO ...................................................................................................................................... 34 21.0 BOP Schematic ........................................................................................................................ 35 22.0 Wellhead Schematic ................................................................................................................. 36 23.0 Days Vs Depth .......................................................................................................................... 37 24.0 Formation Information ............................................................................................................ 38 25.0 Anticipated Drilling Hazards .................................................................................................. 39 26.0 Hilcorp Rig 147 Layout ........................................................................................................... 41 27.0 FIT Procedure .......................................................................................................................... 42 28.0 Choke Manifold Schematic ...................................................................................................... 43 29.0 Casing Design Information ...................................................................................................... 44 30.0 6-3/4” Hole Section MASP ....................................................................................................... 45 31.0 Spider Plot (Governmental Sections) ...................................................................................... 46 32.0 Surface Plat (As-Built NAD27 & NAD83) ............................................................................... 47 drilling well with rig 169 Page 2 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 1.0 Well Summary Well SCU 42-05Z Pad & Old Well Designation SCU 43-5 (HAK 42-05Z) / grass roots well Planned Completion Type 5-1/2” Cemented Production Liner Target Reservoir(s) Tyonek 77-3 Planned Well TD, MD / TVD 8,500 MD / 8,458’ TVD PBTD, MD / TVD 8,490’ MD / 8,448’ TVD Surface Location (Governmental) 3360’ FNL, 600’ F EL, Sec 5, T7N, R9W, SM, AK Surface Location (NAD 27) X=314714 Y=2457872 Surface Location (NAD 83) X=1481737 Y=2457633 Top of Productive Horizon (Governmental) 2375' FSL, 640' FEL, Sec 5, T7N, R9W, SM, AK TPH Location (NAD 27) X=341676 Y=2458336 TPH Location (NAD 83) X=1481698 Y=2458097 BHL (Governmental) 2479' FSL, 640' FEL, Sec 5, T7N, R9W, SM, AK BHL (NAD 27) X=341677 Y=2458440 BHL (NAD 83) X=1481700 Y=2458201 AFE Number 2013740 (D, C, F) AFE Drilling Days 3 MOB, 16 DRLG AFE Completion Days 3 AFE Drilling Amount $4,007,120 AFE Completion Amount $1,015,000 Maximum Anticipated Pressure (Surface) 3618 psi Maximum Anticipated Pressure (Downhole/Reservoir) 4200 psi Work String 4-1/2” 16.6# S-135 CDS-40 RKB – GL 172.2’ (153.7 + 18.5) Ground Elevation 153.7 BOP Equipment 11” 5M Control Tech Type 90 Annular BOP 11” 5M Control Tech Type 82 Double Ram 11” 5M Control Tech Type 82 Single Ram Target Reservoir(s)Tyonek 77-3 Storage Pool Page 3 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 2.0 Management of Change Information Page 4 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 3.0 Tubular Program: Hole Section OD (in) ID (in) Drift (in) Conn OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) Cond 16” 15.01” 14.822 17” 84 J-55 Weld 2980 1410 - 9-7/8” 7-5/8” 6.875” 6.75” 8.5” 29.7 L-80 CDC 6890 4790 683 6-3/4” 5-1/2” 4.892” 4.767” 6.30” 17 L-80 CDC HTQ 7740 6290 397 4.0 Drill Pipe Information: Hole Section OD (in) ID (in) TJ ID (in) TJ OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) All 4-1/2” 3.826 2.6875” 5.25” 16.6 S-135 CDS40 17,693 16,769 468k Cleanout 2-7/8” 2.323 2.265” 3.438” 7.9 P-110 PH-6 16,896 16,082 194k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 5 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. x Report covers operations from 6am to 6am x Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area – this will not save the data entered, and will navigate to another data entry tab. x Ensure time entry adds up to 24 hours total. x Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates x Submit a short operations update each work day to pmazzolini@hilcorp.com, mmyers@hilcorp.com, Frank.Roach@hilcorp.com, jengel@hilcorp.com, and cdinger@hilcorp.com 5.3 Intranet Home Page Morning Update x Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. Each rig will be assigned a username to login with. 5.4 EHS Incident Reporting x Notify EHS field coordinator. 1. This could be one of (3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don’t wait until an emergency to have to call around and figure it out!!!! a. John Coston: O: (907) 777-6726 C: (907) 227-3189 b. Matt Hogge: O: (907) 777-8418 C: (907) 227-9829 2. Spills: Keegan Fleming: O:907-777-8477 C:907-350-9439 x Notify Drlg Manager 1. Monty M Myers: O: 907-777-8431 C: 907-538-1168 x Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally x Send final “As-Run” Casing tally to mmyers@hilcorp.com, Frank.Roach@hilcorp.com, and cdinger@hilcorp.com 5.6 Casing and Cmt report x Send casing and cement report for each string of casing to mmyers@hilcorp.com, Frank.Roach@hilcorp.com, and cdinger@hilcorp.com Page 6 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 6.0 Planned Wellbore Schematic Liner packer 5 1/2" tieback For gas Production only. Not approved for Gas Injection Page 7 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 7.0 Drilling / Completion Summary SCU 42-05Z is a grassroots well to be drilled off of the SCU 43-05 pad. This well will be targeting the Tyonek 77-3 gas storage sand, but will be a producer only. The base plan is an near vertical wellbore with a kick off point at ~5555’ MD. Maximum hole angle will be 10 deg. and TD of the well will be 8,500’ TMD/ 8,458’ TVD. Drilling operations are expected to commence approximately November 28th 2020. The Hilcorp Rig # 147 will be used to drill the wellbore then run casing and cement. Surface casing will be run to 2,900’ MD / 2,899’ TVD and cemented to surface to ensure protection of any shallow freshwater resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6 – 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal / beneficial reuse depending on test results. General sequence of operations: 1. MOB Hilcorp Rig # 147 to well site 2. N/U diverter and test. 3. Drill 97/8” hole to 2,900’ MD. Run and cement 7-5/8” surface casing. 4. ND diverter, N/U & test 11” x 5M BOP. 5. Drill 6-3/4” hole section to 8,500’ MD. Perform Wiper trip. 6. Make cleanout run 7. POOH laying down drill pipe. 8. Run and cmt 5-1/2” production liner. 9. PU clean out assembly and RIH to clean out 5-1/2” to float collar 10. Displace well to 6% KCL completion fluid. 11. POOH and LD clean out assembly. 12. N/D BOP, N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole: GR + Res 2. Production Hole: GR + Res 3. No mud loggers will be used. Governed by Storage Injection Order No. 6 SFD 10/7/2020 g Tyonek 77-3 gas storage sand, but will be a producer only. 169 l beAOGCC will categorize well status as Service. (GSTOR) as Development Gas. gls 11/16/20 Page 8 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations and all BLM regulations pertaining to Onshore Order No.1. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. x BOPs shall be tested at (2) week intervals during the drilling of SCU 42-05Z. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. And BLM 48 hrs notice prior to testing. x The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 10/10 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. x If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. x All AOGCC regulations within 20 AAC 25.033 “Primary well control for drilling: drilling fluid program and drilling fluid system”. x All AOGCC regulations within 20 AAC 25.035 “Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements” x Ensure AOGCC and BLM approved drilling permits are posted on the rig floor and in Co Man office. Regulation Variance Requests: x BLM: Onshore Oil and Gas Order No. 1, Section III. D. 3. C. o Hilcorp requests approval to install a 2-1/16” 5M HCR valve on kill line in lieu of a check valve. Operator suspects a freeze plug risk associated with installation of a check valve in the kill line. o Hilcorp requests approval to utilize flexible choke and kill lines in lieu of hard piping. RIG 169 No variances required for AOGCC gls 11/12/20 Page 9 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure (psi) 9-7/8” x 21-1/4” x 2M Hydril MSP diverter Function Test Only 6-3/4” x 11” x 5M Annular BOP x 11” x 5M Double Ram o Blind ram in btm cavity x Mud cross x 11” x 5M Single Ram x 3-1/8” 5M Choke Line x 2-1/16” x 5M Kill line x 3-1/8” x 2-1/16” 5M Choke manifold x Standpipe, floor valves, etc Initial Test: 250/3500 (Annular 2500 psi) Subsequent Tests: 250/3500 (Annular 2500 psi) x Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon (12 x 11 gal bottles). x Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: x Well control event (BOPs utilized to shut in the well to control influx of formation fluids). x 24 hours notice prior to spud. x 24 hours notice prior to testing BOPs. x 24 hours notice prior to casing running & cement operations. x Any other notifications required in APD. Required BLM Notifications: x 48 hours before spud. Follow up with actual spud date and time. x 48 hours before casing running and cmt operations x 48 hours before BOPE tests x 48 hours before logging, coring, & testing x Any other notifications required in APD Additional requirements may be stipulated on APD and Sundry. Page 10 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Email: jim.regg@alaska.gov Guy Schwartz / Petroleum Engineer / (O): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz@alaska.gov Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Email: victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) BLM Mutasim Elganzoory / BLM Petroleum Engineer / (O): 907-271-4224 Email: melganzoory@blm.gov Use the below email address for BOP notifications to the BLM: BLM_AK_AKSO_EnergySection_Notifications@blm.gov 2016 Waste Prevention Rule - Waste Minimization Plan for Drilling: Hilcorp Alaska will not be venting or flaring any gas while drilling this well. The only waste produced from this well will be used mud and cuttings, and will be handled at the Kenai Gas Field G&I facility for beneficial reuse, if possible after testing, and disposal. Page 11 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 9.0 R/U and Preparatory Work 9.1 Set 16” conductor at +/-120’ below ground level. 9.2 Dig out and set impermeable cellar. 9.3 Install Seaboard slip-on 16-3/4” 3M “A” section. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Hilcorp Rig # 147, spot service company shacks, spot & R/U company man & toolpusher offices. 9.7 RU Mud loggers on surface hole section for gas detection only. No samples required 9.8 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.9 Mix mud for 9-7/8” hole section. 9.10 Install 5-1/2” liners in mud pumps. x HHF-1000 mud pumps are rated at 3036 psi (85%) / 370 gpm (100%) at 120 strokes with 5-1/2” liners. 169 Page 12 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 10.0 N/U 21-1/4” 2M Diverter 10.1 N/U 21-1/4” Hydril MSP 2M diverter System. x N/U 16-3/4” 3M x 21-1/4” 2M DSA (Hilcorp) on 16-3/4” 3M wellhead. x N/U 21-1/4” diverter “T”. x Knife gate, 16” diverter line. x Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). 10.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked “warning zone” is established on each side and ahead of the vent line tip. “Warning Zone” must include: x A prohibition on vehicle parking. x A prohibition on ignition sources or running equipment. x A prohibition on staged equipment or materials. x Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set wear bushing in wellhead. Notify AOGCC inspector to witness Page 13 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 10.5 Rig 147 Orientation and estimated Diverter line : Note: Actual layout may be different on location Page 14 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 11.0 Drill 9-7/8” Hole Section 11.1 P/U 9-7/8” directional drilling assy: x Ensure BHA components have been inspected previously. x Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. x Ensure TF offset is measured accurately and entered correctly into the MWD software. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. x Workstring will be 4.5” 16.6# S-135 CDS40 11.2 4-1/2” Workstring & HWDP will come from Hilcorp. 11.3 Begin drilling out from 16” conductor at reduced flow rates to avoid broaching the conductor. 11.4 Drill 9-7/8” hole section to 2,900’ MD/ TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Pump at 500 - 550 gpm. Ensure shaker screens are set up to handle this flowrate. x Utilize past experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team. x Keep swab and surge pressures low when tripping. x Make wiper trips every 500’ or every couple days unless hole conditions dictate otherwise. x Ensure shale shakers are functioning properly. Check for holes in screens on connections. x Adjust MW as necessary to maintain hole stability. x TD the hole section in a good shale between 1800’ MD / TVD. x Take MWD surveys every stand drilled (60’ intervals). 11.5 9-7/8” hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite 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. Pason 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. System Type: 8.8 – 9.5 ppg Pre-Hydrated Aquagel/freshwater spud mud Page 15 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL pH 120-2900’ 8.8 – 9.5 85-150 20 - 40 25 - 45 <10 8.5-9.0 System Formulation: Aquagel + FW spud mud Product Concentration FRESH WATER SODA ASH AQUAGEL CAUSTIC SODA BARAZAN D+ BAROID 41 PAC-L /DEXTRID LT ALDACIDE G X-TEND II 0.905 bbl 0.5 ppb 12-15 ppb 0.1 ppb (9 pH) as needed as required for weight if required for <12 FL 0.1 ppb 0.02 ppb 11.6 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16” conductor shoe. 11.7 TOH with the drilling assy, handle BHA as appropriate. 8.8 – 9.5 Page 16 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 12.0 Run 7-5/8” Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 7-5/8” casing running equipment. x Ensure 7-5/8” BTC x CDS 40 XO on rig floor and M/U to FOSV. x R/U fill-up line to fill casing while running. x Ensure all casing has been drifted on the location prior to running. x Be sure to count the total # of joints on the location before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U & thread locking shoe track assy consisting of: x (1) Shoe joint w/ float shoe bucked on (thread locked). x (1) Joint with coupling thread locked. x (1) Joint with float collar bucked on pin end & thread locked. x Install (2) centralizers on shoe joint over a stop collar. 10’ from each end. x Install (1) centralizer, mid tube on thread locked joint and on FC joint. x Ensure proper operation of float equipment. 12.5 Continue running 7-5/8” surface casing x Fill casing while running using fill up line on rig floor. x Use “API Modified” thread compound. Dope pin end only w/ paint brush. x M/U connections to the base of the triangle stamped on the pin end. Note M/U torque values required to achieve this position. x After making up several connections, use the torque required to M/U to base of triangle as the M/U torque and continue running string. x Install (1) centralizer every other joint to 300’. Do not run any centralizers above 300’ in the event a top out job is needed. x Utilize a collar clamp until weight is sufficient to keep slips set properly. Page 17 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 Page 18 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. Page 19 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 13.0 Cement 7-5/8” Surface Casing 13.1 Hold a pre-job safety meeting over the upcoming cmt 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 cmt unit at acceptable rates. x Pump 20 bbls of freshwater through all of Halliburton’s equipment, taking returns to cuttings bin, prior to pumping any fluid downhole x How to handle cmt returns at surface. x Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. x Positions and expectations of personnel involved with the cmt operation. 13.2 Document efficiency of all possible displacement pumps prior to cement job 13.3 R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.4 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. 13.5 Pump remaining 30 bbls of 10 ppg spacer. 13.6 Drop bottom plug. Mix and pump cmt per below recipe. 13.7 Cement volume based on annular volume + 50% open hole excess. Job will consist of lead & tail, TOC brought to surface. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol (ft3) 12.0 ppg LEAD: 16” Conductor x 7-5/8” casing annulus: 120’ x .1621 bpf = 19.4 108.9 12.0 ppg LEAD: 9-7/8” OH x 7-5/8” Casing annulus: (2400’ – 120’) x .0383 bpf x 1.5 = 131 735 Total LEAD: 150.4 bbl 844.3 ft3 15.4 ppg TAIL: 9-7/8” OH x 7-5/8” Casing annulus: (2900’ – 2400’) x .0383 bpf x 1.5 = 28.8 161.7 15.4 ppg TAIL: 7-5/8” Shoe track: 80 x .046 bpf = 3.7 20.8 Total TAIL: 32.5 bbl 182.5 ft3 343sx 149sx Cement volume based on annular volume + 50% open hole excess. Page 20 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 Cement Slurry Design: 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets “sticky”, land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug and displace cement with spud mud. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.11 Displacement calculation: 2900’- 80’ = 2820’ x .046 bpf = 129.72 bbls 13.12 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. Lead Slurry (2400’ MD to surface) Tail Slurry (2900’ to 2400’ MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.46 ft3/sk 1.22 ft3/sk Mixed Water 14.349 gal/sk 5.507 gal/sk Mixed Fluid 14.469 gal/sk 5.507 gal/sk Additives Code Description Concentration Code Description Concentration G Cement 94#/sk A Cement 94#/sk D110 Retarder 0.15 gal/sk BWOC D046 Anti Foam 0.2 % BWOC D046 Anti Foam 0.2 % BWOC D065 Dispersant 0.4 % BWOC D079 Extender 2.0 % BWOC S002 CaCl2 0.35 % BWOC D020 Extender 3.0 % BWOC D177 CaCl2 0.1 % BWOC 2.46 ft3/s 1.22 ft3/s Page 21 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 13.13 Do not overdisplace by more than ½ shoe track volume. Total volume in shoe track is 6.1 bbls. x Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 12 – 18 hours after CIP. x Be prepared with small OD top out tubing in the event a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5”. 13.14 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. 13.15 R/D cement equipment. Flush out wellhead with FW. 13.16 Back out and L/D landing joint. Flush out wellhead with FW. 13.17 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.18 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Send final “As-Run” casing tally & casing and cement report to cdinger@hilcorp.com and Frank.Roach@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 22 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 14.0 BOP N/U and Test 14.1 ND Diverter line and diverter 14.2 N/U multi-bowl wellhead assy. Install 9-5/8” packoff P-seals. Test to 3000 psi. 14.3 N/U 11” x 5M BOP as follows: x BOP configuration from Top down: 11” x 5M Type 90 annular BOP/11” x 5M Model 82 double ram /11” x 5M mud cross/11” x 5M Type 82 single ram x Double ram should be dressed with 2-7/8” x 5” variable bore rams in top cavity, blind ram in btm cavity. x Single ram should be dressed with 2-7/8” x 5” variable bore rams x N/U bell nipple, install flowline. x Install (2) manual valves & a check valve on kill side of mud cross. x Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 4-1/2” BOP test assy, land out test plug (if not installed previously). x Test BOP to 250/3500 psi for 10/10 min. Test annular to 250/2500 psi for 10/10 min. x Ensure to leave “B” section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 9.0 ppg 6% KCL PHPA mud system. 14.8 R/U mud loggers for production hole section. 14.9 Rack back as much 4-1/2” DP in derrick as possible to be used while drilling the hole section. 3500 pis BOPE test 3750 PSI Page 23 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 15.0 Drill 6-3/4” Hole Section 15.1 Pull test plug, run and set wear bushing 15.2 Ensure BHA components have been inspected previously. 15.3 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.4 TIH, Conduct shallow hole test of MWD and confirm all LWD functioning properly. 15.5 Ensure TF offset is measured accurately and entered correctly into the MWD software. 15.6 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.7 Workstring will be 4.5” 16.6# S-135 CDS40. Ensure to have enough 4-1/2” DP in derrick to drill the entire open hole section without having to pick up pipe from the pipeshed. 15.8 6-3/4” hole section mud program summary: Weighting material to be used for the hole section will be barite, salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. Pason 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. System Type: 9.0 ppg 6% KCL PHPA fresh water based drilling fluid. Properties: MD Mud Weight Viscosity Plastic Viscosity Yield Point pH HPHT 2,900 – 8,500 9.0 – 11.0 40-53 15-25 15-25 8.5-9.5 11.0 System Formulation: 6% KCL EZ Mud DP Product Concentration Water KCl Caustic 0.905 bbl 22 ppb (29 K chlorides) 0.2 ppb (9 pH) 9.0 – 11.0 – g Page 24 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 BARAZAN D+ EZ MUD DP DEXTRID LT PAC-L BARACARB 5/25/50 BAROID 41 ALDACIDE G BARACOR 700 BARASCAV D 1.25 ppb (as required 18 YP) 0.75 ppb (initially 0.25 ppb) 1-2 ppb 1 ppb 15 - 20 ppb (5 ppb of each) as required for a 9.0 – 10.0 ppg 0.1 ppb 1 ppb 0.5 ppb (maintain per dilution rate) 15.9 TIH w/ 6-3/4” directional assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. 15.10 R/U and test casing to 3500 psi / 30 min. Ensure to record volume / pressure and plot on FIT graph. AOGCC requirement is 50% of burst. 7-5/8” burst is 6880 psi / 2 = 3440 psi. 15.11 Drill out shoe track and 20’ of new formation. 15.12 CBU and condition mud for FIT. 15.13 Conduct FIT to 13.5 ppg EMW. Note: Offset field test data predicts frac gradient at the 7-5/8” shoe to be between 11 - 13 ppg EMW. A 13.5 ppg FIT results in a 4.5 ppg kick margin while drilling with the planned MW of 9.0 ppg, and a 3 ppg kick margin with a 10.5ppg planned MW at TD. Kick tolerance factor = (13.5-9.0)X(2899/8458) = 1.5 = (13.5-10.5)x(2899/8458) = 1.0 15.14 Drill 6-3/4” hole section to 8,500’ MD / 8458’ TVD x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Pump at 400 - 500 gpm. Ensure shaker screens are set up to handle this flowrate. x Keep swab and surge pressures low when tripping. x Make wiper trips every 1000’ unless hole conditions dictate otherwise. x On the third wiper trip (around 5,900’ MD), trip back to the 9-5/8” shoe to split the hole section in half x Ensure shale shakers are functioning properly. Check for holes in screens on connections. x Geologist to provide coal depth details x Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. x Ensure MW is at 11.0 ppg by 7000’, let MW climb as we drill ahead x Target gas sand 77-3 is estimated at 10.5 ppg EMW pore pressure x Past wells drilled into this sand have increased MW starting at 5,500 TVD, to as high as 12.4 by 6,500’ MD *2500 psi casing test is min. gls 11/13/20 13.5 ppg FIT test surface 7 5/8" casing to 2500 psi ok NOTE : 77-3 sand at 10.5 EMW Page 25 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 x Continue diligent flow checks when drilling this hole section x Take MWD surveys every 100’ drilled. Surveys can be taken more frequently if deemed necessary. x Take (3) sets of formation samples every 20’. 15.15 At TD; pump sweeps, CBU, and pull a wiper trip back to the 7-5/8” shoe. 15.16 TOH with the drilling assy, standing back drill pipe. 15.17 LD BHA 15.18 PU 6-3/4”clean out BHA, and TIH to TD. 15.19 Pump sweep, CBU and condition mud for casing run. 15.20 POOH LDDP and BHA 15.21 Install 5-1/2” pipe rams in BOP stack and test. install 5.5" rams Page 26 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 16.0 Run 5-1/2” Production Liner 16.1. R/U Weatherford 5-1/2” casing running equipment. x Ensure 5-1/2” TXP BTC x CDS 40 crossover on rig floor and M/U to FOSV. x Conform CDC HTQ is compatible with BTC x R/U fill up line to fill casing while running. x Ensure all casing has been drifted prior to running. x Be sure to count the total # of joints before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 16.2. P/U shoe joint, visually verify no debris inside joint. 16.3. Continue M/U & thread locking shoe track assy consisting of: x (1) Shoe joint w/ shoe bucked on & threadlocked (coupling also thread locked). x (1) Joint with float collar bucked on pin end & threadlocked (coupling also thread locked). x (1) Joint with Baker landing collar bucked on pin end & threadlocked. x Solid body centralizers will be pre-installed on shoe joint an FC joint. x Leave centralizers free floating so that they can slide up and down the joint. x Ensure proper operation of float shoe and float collar. x Utilize a collar clamp until weight is sufficient to keep slips set properly 16.4. Continue running 5-1/2” production liner x Fill casing while running using fill up line on rig floor. x Use “API Modified” thread compound. Dope pin end only w/ paint brush. x Install solid body centralizers on every joint across zones of interest, TBD after LWD. x Install solid body centralizers on every other joint to 7-5/8” shoe. Leave the centralizers free floating. 16.5. Continue running 5-1/2” production liner 5-1/2” 17# CDC - HTQ M/U torques Casing OD Minimum Maximum Yield Torque 5-1/2” 8,500 ft-lbs 11,500 ft-lbs 13,900 ft-lbs Page 27 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 Page 28 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 16.6. Run in hole w/ 5-1/2” liner to the 7-5/8” casing shoe. 16.7. Fill the casing with fill up line and break circulation every 1,000 feet to the shoe or as the hole dictates. 16.8. Obtain slack off weight, PU weight, rotating weight and torque of the casing. 16.9. Circulate 2X bottoms up at shoe, ease casing thru shoe. 16.10. Continue to RIH w/ casing no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.11. Set casing slowly in and out of slips. 16.12. PU 5-1/2” X 7-5/8” Baker liner hanger/LTP assembly. RIH 1 stand and circulate one liner volume to clear string. Obtain slack off weight, PU weight, rotating weight and torque parameters of the liner. 16.13. Continue running in hole at slow speeds to avoid surging well. Target 20 ft/min and adjust slower as hole conditions dictate. 16.14. Monitor PUW & SOW. Circulate BU if needed. Highlight zones of interest before running past, ex: coals 16.15. Swedge up and wash last stand to bottom. P/U 5’ off bottom. Note slack-off and pick-up weights. 16.16. Stage pump rates up slowly to circulating rate. Circ and condition mud with liner on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean. Reduce the low end rheology of the drilling fluid by adding water and thinners. 16.17. Rotate and reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 29 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 17.0 Cement 5-1/2” Production Liner 17.1. Hold a pre-job safety meeting over the upcoming cmt 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 cmt unit at acceptable rates. x Pump 20 bbls of freshwater through all of Halliburton’s equipment, taking returns to cuttings bin, prior to pumping any fluid downhole x How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. x Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. x Positions and expectations of personnel involved with the cmt operation. x Document efficiency of all possible displacement pumps prior to cement job. 17.2. Attempt to rotate and reciprocate the liner during cmt operations until hole gets sticky 17.3. Pump 5 bbls of 12.5 ppg Mud Push spacer. 17.4. Test surface cmt lines to 4500 psi. 17.5. Pump remaining 30 bbls 12.5 ppg Mud Push spacer. 17.6. Mix and pump lead and tail cement per below recipe. Ensure cement is pumped at designed weight. Job is designed to pump 10% OH excess. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol (ft3) 12.0 ppg LEAD: 7-5/8” csg x 5-1/2” casing annulus: 500’ x .01653 bpf = 8.3 46.6 12.0 ppg LEAD: 6-3/4” OH x 5-1/2” annulus: (8000’ – 2900’) x .01488 bpf x 1.1 = 83.5 468.8 Total LEAD: 91.8 bbl 515.4 ft3 15.4 ppg TAIL: 6-3/4” OH x 5-1/2” annulus: (8500’- 8000’) x .01488 bpf x 1.1 = 8.2 46.1 15.4 ppg TAIL: 5-1/2” Shoe track: 80 x .02325 bpf = 2 12 Total TAIL: 10.2 bbl 58.1ft3 209sx 48sx Page 30 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 Cement Slurry Design: Lead Slurry (7847’ MD to 2250’ MD) Tail Slurry (8347’ to 7847’ MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.46 ft3/sk 1.22 ft3/sk Mixed Water 14.349 gal/sk 5.507 gal/sk Mixed Fluid 14.469 gal/sk 5.507 gal/sk Additives Code Description Concentration Code Description Concentration G Cement 94#/sk A Cement 94#/sk D110 Retarder 0.15 gal/sk BWOC D046 Anti Foam 0.2 % BWOC D046 Anti Foam 0.2 % BWOC D065 Dispersant 0.4 % BWOC D079 Extender 2.0 % BWOC S002 CaCl2 0.35 % BWOC D020 Extender 3.0 % BWOC D177 CaCl2 0.1 % BWOC Page 31 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 17.7. Drop drillpipe dart and displace with drilling mud. 17.8. If hole conditions allow – continue rotating and reciprocating casing throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. 17.9. If elevated displacement pressures are encountered, position casing at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 17.10. Slow down displacement as drillpipe dart latches up to the liner wiper plug. Continue with displacement. 17.11. Bump the plug and pressure up to 500 psi over final lift pressure. Hold pressure for 3 minutes. 17.12. Do not overdisplace by more than ½ shoe track. Shoe track volume is 2 bbls. 17.13. Bleed pressure to zero to check float equipment. Watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. Slack off and confirm liner hanger is set. 17.14. Pick up to expose dogs and set liner top packer. 17.15. Pull above liner top and CBU 2x to flush any cement that could be above liner top. 17.16. RD cementers and flush equipment. 17.17. Install 2-7/8” x 5” variable bore rams in BOP stack and test. 17.18. WOC minimum of 12 hours, test casing to 2500 psi and chart for 30 minutes. Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Optional: VBR installed in other set of rams. and isolated from reservoir. gls 11/13/20 Page 32 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 Send final “As-Run” casing tally & casing and cement report to cdinger@hilcorp.com and Frank.Roach@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 33 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 18.0 5-1/2” Liner Tieback Polish Run and Cleanout Run 18.1. PU liner tieback polish mill assy per Baker rep and RIH on drillpipe. 18.2. RIH to top of liner assembly and establish parameters. Polish tieback receptacle per Baker procedure. 18.3. POOH, and LD polish mill. 19.0 5-1/2” Liner Cleanout Run 19.1 PU 5-1/2” clean out BHA. 19.2 RIH on 2-7/8” 10.4 with 2-3/8” connection workstring to top of landing collar per casing tally. 19.3 CBU and displace well to 6% KCl completion fluid. 19.4 POOH LDDP and BHA Page 34 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 20.0 Run 5-1/2” Tieback 20.1 RU 5-1/2” running equipment 20.2 MU seal assembly and RIH with 5-1/2” 17# CDC HTQ tieback Page 35 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 20.3 MU hanger and landout tieback 20.4 PU out of liner top seal assembly and spot 30 bbl of corrosion inhibited 6% KCl 20.5 Land hanger 20.6 RU test equip, perform pressure test of 5-1/2” liner and tieback, 3,000 psi for 30 min. Chart test 20.7 Perform MIT of the 5-1/2” x 7-5/8” annulus, 1500 psi for 30 minutes. Chart test. 21.0 RDMO 21.1 Install BPV in wellhead 21.2 N/D BOPE 21.3 N/U temp abandonment cap 21.4 RDMO 21.5 Completion program will be submitted in a separate sundry by Hilcorp Operations Engineer. CBL to be performed off rig. MIT-Casing MIT-IA Completion program will be submitted in a separate sundry by Hilcorp Operationsppg Engineer. CBL to be performed off rig. CBL required over 5 1/2" liner . Notify Inspector to witness MIT-IA. Page 33 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 18.0 5-1/2” Liner Tieback Polish Run and Cleanout Run 18.1. PU liner tieback polish mill assy per Baker rep and RIH on drillpipe. 18.2. RIH to top of liner assembly and establish parameters. Polish tieback receptacle per Baker procedure. 18.3. POOH, and LD polish mill. 19.0 5-1/2” Cleanout Run 18.4. PU 5-1/2” clean out BHA. 18.5. RIH on 2-7/8” 10.4 with 2-3/8” connection workstring to top of landing collar per casing tally. 18.6. CBU and displace well to 6% KCl completion fluid. 18.7. POOH LDDP and BHA 18.8. If not completed, test 5-1/2” casing to 2,500 psi and chart for 30 minutes 18.9. Completion program will be submitted in a separate sundry by Hilcorp Operations Engineer Cleano .4. un ipe. ish t 05 ed collar per casin sh m 1/ er t of wor d ish 1/2 r ti of liof l ish 1/ eanou PU 5- Ru drill rs. P Ru n ou n 2-7 CB un on mp ps f lin olis SUPERCEDED Page 34 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 20.0 RDMO 19.1. Install BPV in wellhead 19.2. N/D BOPE 19.3. N/U temp abandonment cap 19.4. RDMO Hilcorp Rig #147 SUPERCEDEDeadllhe PE N/U 1 ea Page 35 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 21.0 BOP Schematic (2 7/8" - 5") RIG 169 is scheduled to drill well gls 11/13/20 VBR BLIND VBR Page 36 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 22.0 Wellhead Schematic SSV Page 37 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 23.0 Days Vs Depth Page 38 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 24.0 Formation Information Objective: Reference Plan: SR_ST _A Sand/Coals Water ±50'1017.26 864.1 -845.63 2457854.53 341726.43 381 0.45 SR_ST _B2 Sand/Coals Water ±50'2841.13 2,687.7 -2669.17 2457886.19 341711.48 1201 0.45 SR_ST _B3 Sand/Coals Water ±50'2944.47 2,791.0 -2772.49 2457887.98 341710.63 1248 0.45 SR_ST _B5 Sand/Coals Water ±50'2974.91 2,821.4 -2802.92 2457888.51 341710.38 1261 0.45 SR_ST _B6 Sand/Coals Water ±50'3151.14 2,997.6 -2979.12 2457891.57 341708.94 1341 0.45 SR_ST _B7 Sand/Coals Gas/Water ±50'3272.11 3,118.6 -3100.06 2457893.67 341707.95 1395 0.45 UPPER_BELUGA Sand/Coals Water ±50'3465.16 3,311.6 -3293.08 2457897.02 341706.36 1482 0.45 SR_BEL_36-9AX Sand/Coals Water ±50'3510.02 3,356.4 -3337.94 2457897.8 341706 1502 0.45 SR_UB_36-9X Sand/Coals Water ±50'3582.92 3,429.3 -3410.82 2457899.06 341705.4 1535 0.45 SR_UB_39-1 Sand/Coals Water ±50'3791.2 3,637.6 -3619.06 2457902.68 341703.69 1629 0.45 SR_UB_47-0 Sand/Coals Water ±50'4240.54 4,086.8 -4068.32 2457910.48 341700.01 1831 0.45 SR_UB_50-6 Sand/Coals Water ±50'4666.95 4,513.2 -4494.65 2457917.88 341696.51 2023 0.45 SR_UB_50-8 Sand/Coals Water ±50'4891.25 4,737.4 -4718.91 2457921.77 341694.67 2124 0.45 SR_LB_52-9 Sand/Coals Water ±50'5321.14 5,167.2 -5148.72 2457929.24 341691.15 2317 0.45 TYONEK Sand/Coals Water ±50'5438.9 5,285.0 -5266.46 2457931.28 341690.18 2370 0.45 SR_TY_53-0 Sand/Coals Water ±50'5456.53 5,302.6 -5284.08 2457931.59 341690.04 2378 0.45 SR_TY_54-1 Sand/Coals Water ±50'5518.21 5,364.3 -5345.75 2457932.66 341689.53 2406 0.45 SR_TY_54-5 Sand/Coals Water ±50'5537.43 5,383.5 -5364.97 2457932.99 341689.38 2414 0.45 SR_TY_55-4 Sand/Coals Water ±50'5602.33 5,448.4 -5429.85 2457934.53 341688.87 2443 0.45 SR_TY_55-5 Sand/Coals Water ±50'5639.2 5,485.2 -5466.69 2457936.03 341688.61 2460 0.45 SR_TY_56-9 Sand/Coals Gas/Water ±50'5799.06 5,644.6 -5626.07 2457947.94 341687.77 2532 0.45 SR_TY_57-8 Sand/Coals Water ±50'5881.32 5,726.3 -5707.77 2457957.57 341687.52 2568 0.45 SR_TY_61-0 Sand/Coals Water ±50'5994.75 5,838.4 -5819.9 2457974.63 341687.38 2619 0.45 SR_TY_61-8 Sand/Coals Water ±50'6210.26 6,050.6 -6032.14 2458011.98 341687.38 2714 0.45 SR_TY_73-5 Sand/Coals Water ±50'7483.85 7,304.9 -7286.39 2458233.12 341687.38 3279 0.45 SR_TY_74-5 Sand/Coals Water ±50'7579.15 7,398.7 -7380.24 2458249.67 341687.38 3321 0.45 SR_TY_75-3 Sand/Coals Water ±50'7647.4 7,466.0 -7447.45 2458261.52 341687.38 3351 0.45 SR_TY_75-8 Sand/Coals Water ±50'7799.4 7,615.6 -7597.14 2458287.91 341687.38 3419 0.45 SR_TY_77-3_COAL Sand/Coals Water ±50'7822.17 7,638.1 -7619.57 2458291.87 341687.38 3429 0.45 SR_TY_77-3_ST Sand Gas ±50'7853.08 7,668.5 -7650.01 2458297.23 341687.38 4200 0.55 SR_TY_77-3_BS Gas ±50'7882.36 7,697.3 -7678.84 2458302.32 341687.38 4200 0.55 SR_TY_77-4 ±50'7890.25 7,705.1 -7686.61 2458303.69 341687.38 3459 0.45 SR_TY_77-6 ±50'7979.14 7,792.7 -7774.15 2458319.12 341687.38 3498 0.45 SR_TY_79-1 ±50'8099.69 7,911.4 -7892.87 2458340.05 341687.38 3552 0.45 EASTING Est. Pressure GradientEXPECTED FLUID MD (FT) TVD (FT) TVDSS (FT)NORTHINGDepth Uncertainty Target the 77-3 Sand for Additional Storage Deliverability. Hagrid's Hut wp03ANTICIPATED FORMATION TOPS & GEOHAZARDS Geo Summary/ Justification: See above TOP NAME LITHOLOGY Page 39 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 25.0 Anticipated Drilling Hazards 9-7/8” Hole Section: Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/ gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP between 25 – 45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of ~50 - ~60 lbs/100ft2 to combat this issue. Maintain low flow rates for the initial 200’ of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 25 –30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 40 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 6-3/4” Hole Section: Lost Circulation: Ensure 1000 lbs of each of the different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Given the volume of losses experienced in 241-34T, ensure all LCM inventory is fully stocked before drilling out surface casing. Hole Cleaning: Maintain rheology w/ viscosifier as necessary. Sweep hole w/ 20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP between 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain MW as necessary using additions of Calcium Carbonate as weighting material. A torque reduction lube may be used in this hole section in concentrations up to 3% if needed. Maintain 6% KCl in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. x Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. x Use asphalt-type additives to further stabilize coal seams. x Increase fluid density as required to control running coals. x Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: H2S is not present in this hole section. No abnormal temperatures are present in this hole section. High Pressure: Target sand 77-3 is high pressure, estimated 10.5 ppg EMW. All other formatonis are normally pressured. Past wells drilled have had higher MW, as high as 12.4 ppg through this interval, starting weight up at ~5,500’ TVD. Ensure sufficient MW before drilling into interval, perform flow checks each stand to ensure proper over balance Page 41 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 26.0 Hilcorp Rig 147 Layout Page 42 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 27.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 43 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 28.0 Choke Manifold Schematic Page 44 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 29.0 Casing Design Information Mud Density: 6.75 Mud Density:11 Mud Density: 3618 psi (See attached M ASP determination & calculation) 3618 psi (See attached M ASP determination & calculation) Collapse Calculation: Section Calculation 1, 2 Normal gradient external stress (0.57 psi/ft) and the casing evacuated for the internal stress 1234 5-1/2" 2,900 2,899 8,500 8,458 5,600 17 L-80 CDC/HTQ 95,200 95,200 397 4.17 4,821 6,290 1.30 3,618 7,740 2.14Worst case safety factor (Burst) DATE: 9/29/2020 WELL: SCU 42-05Z (43-5) FIELD: Soldotna Creek Unit DESIGN BY: Joe Engel Hole Size Hole Size Hole Size MASP: Production Mode Top (TVD) Minimum Yield (psi) Weight (ppf) Grade Connection Weight w/o Bouyancy Factor (lbs) Min strength Tension (1000 lbs) Collapse Resistance w/o tension (Psi) Worst Case Safety Factor (Collapse) MASP (psi) Worst Case Safety Factor (Tension) Collapse Pressure at bottom (Psi) Tension at Top of Section (lbs) Bottom (TVD) Length Bottom (MD) Drilling Mode Top (MD) Casing Section Design Criteria: Calculation & Casing Design Factors Swanson River Unit Calculation/Specification Casing OD MASP: Page 45 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 30.0 6-3/4” Hole Section MASP MD TVD Planned Top: 2900 2899 Planned TD: 8500 8458 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad SR_ST_B5 2,821 1261 Water 8.6 0.45 SR_ST_B6 2,998 1341 Water 8.6 0.45 SR_ST_B7 3,119 1395 Gas/Water 8.6 0.45 UPPER_BELUGA 3,312 1482 Water 8.6 0.45 TYONEK 5,285 2370 Water 8.6 0.45 SR_TY_55-5 5,485 2460 Water 8.6 0.45 SR_TY_56-9 5,645 2532 Gas/Water 8.6 0.45 SR_TY_64-8 6,393 2868 Water 8.6 0.45 SR_TY_67-0 6,647 2983 Water 8.6 0.45 SR_TY_68-3 6,767 3037 Water 8.6 0.45 SR_TY_75-8 7,616 3419 Water 8.6 0.45 SR_TY_77-3_COAL 7,638 3429 Water 8.6 0.45 SR_TY_77-3_ST 7,669 4200 Gas 10.5 0.55 SR_TY_77-3_BS 7,697 4200 Gas 10.5 0.55 SR_TY_77-4 7,705 3459 Water 8.6 0.45 SR_TY_79-1 7,911 3552 Water 8.6 0.45 Offset Well Mud Densities Well MW range Top (TVD) Bottom (TVD) Date SCU 42-05X 9.7 - 12.4 2,541 7,935 2006 SCU 42-05Y 9.2 - 12.4 3,027 7,981 2007 SCU 42B-05 9.8 - 12.5 3,444 10,433 1983 Assumptions: 1. Maximum planned mud density for the 6-3/4" hole section is 10.5 ppg. 2. Calculations assume reservoirs contain 100% gas (worst case). 3. Calculations assume worst case event is complete evacuation of wellbore to gas. 4. Anticipated fracture gradient at 8458' TVD = 14.0 ppg EMW Fracture Pressure at 6" window considering a full column of gas from window to surface: 2899 (ft) x 0.65(psi/ft)= 1884 1884 (psi) - [0.1(psi/ft)*2599(ft)]= 1624 psi MASP from pore pressure; entire wellbore evacuated to gas from storage sand to TD 7697 (ft) x 0.57(psi/ft)= 4387 psi 4387(psi) - [0.1(psi/ft)*7697 (ft)]= 3618 psi Summary: 1. MASP while drilling 6-3/4" production hole is governed by fracture pressure at 7-5/8" shoe Maximum Anticipated Surface Pressure Calculation 6-3/4" Hole Section SCU 42-05Z (43-5) Kenai, Alaska )= ) Page 46 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 31.0 Spider Plot (Governmental Sections) Page 47 Version 1 August, 2020 SCU 43-5 (42-05Z) Drilling Procedure Rev 1 32.0 Surface Plat (As-Built NAD27 & NAD83) !"## $ 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500True Vertical Depth (1000 usft/in)-500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 Vertical Section at 355.47° (1000 usft/in) SCU 43-05Z wp01 Tgt1 7 5/8" x 9 7/8" 4 1/2" x 6 3/4" 50 0 1 0 0 0 1 5 00 2000 25 00 30 00 350 0 4000 4500 500 0 5500 6 0 0 0 6 5 0 0 7 0 0 0 7 5 0 0 8 0 0 0 8 5 0 0 SCU 42-05Z wp03 Start Dir 3º/100' : 300' MD, 300'TVD End Dir : 336.86' MD, 336.86' TVD Start Dir 2º/100' : 5555.48' MD, 5554.51'TVD End Dir : 6006.1' MD, 6002.58' TVD Total Depth : 8500' MD, 8458.6' TVD SR_ST_A SR_ST_B2 SR_ST_B7 UPPER_BELUGA SR_LB_52-9 TYONEK SR_TY_56-9 SR_TY_57-8 SR_TY_70-8 SR_TY_77-3_COAL SR_TY_77-3_ST SR_TY_77-4 SR_TY_79-1 Hilcorp Alaska, LLC Calculation Method:Minimum Curvature Error System:ISCWSA Scan Method: Closest Approach 3D Error Surface: Ellipsoid Separation Warning Method: Error Ratio WELL DETAILS: Plan: SCU 42-05Z 153.70 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 2457872.331 341714.763 60° 43' 28.852 N 150° 53' 2.725 W SURVEY PROGRAM Date: 2020-09-11T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 18.50 2900.00 SCU 42-05Z wp03 (SCU 42-05Z) 3_MWD+IFR1+MS+Sag 2900.00 8500.00 SCU 42-05Z wp03 (SCU 42-05Z) 3_MWD+IFR1+MS+Sag FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 1036.33 864.13 1036.46 SR_ST_A 2859.87 2687.67 2860.34 SR_ST_B2 3290.76 3118.56 3291.31 SR_ST_B7 3483.78 3311.58 3484.37 UPPER_BELUGA 5339.42 5167.22 5340.35 SR_LB_52-9 5457.16 5284.96 5458.12 TYONEK 5816.77 5644.57 5818.37 SR_TY_56-9 5898.47 5726.27 5900.70 SR_TY_57-8 7183.15 7010.95 7204.88 SR_TY_70-8 7810.27 7638.07 7841.67 SR_TY_77-3_COAL 7840.71 7668.51 7872.58 SR_TY_77-3_ST 7877.31 7705.11 7909.75 SR_TY_77-4 8083.57 7911.37 8119.19 SR_TY_79-1 REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: SCU 42-05Z, True North Vertical (TVD) Reference:RKB As-Built @ 172.20usft Measured Depth Reference: RKB As-Built @ 172.20usft Calculation Method:Minimum Curvature Project:Soldotna CK Unit Site:SCU 43-05 Well:Plan: SCU 42-05Z Wellbore:SCU 42-05Z Design:SCU 42-05Z wp03 Soldotna CK Unit SCU 43-05 Plan: SCU 42-05Z SCU 42-05Z SCU 42-05Z wp03 4.339 CASING DETAILS TVD TVDSS MD Size Name 2899.52 2727.32 2900.00 7-5/8 7 5/8" x 9 7/8" 8458.60 8286.40 8500.00 4-1/2 4 1/2" x 6 3/4" SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 18.50 0.00 0.00 18.50 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 300' MD, 300'TVD 3 336.86 1.11 334.73 336.86 0.32 -0.15 3.00 334.73 0.33 End Dir : 336.86' MD, 336.86' TVD 4 5555.48 1.11 334.73 5554.51 91.39 -43.15 0.00 0.00 94.51 Start Dir 2º/100' : 5555.48' MD, 5554.51'TVD 5 6006.10 10.00 0.00 6002.58 134.54 -45.01 2.00 28.25 137.67 End Dir : 6006.1' MD, 6002.58' TVD 6 8006.10 10.00 0.00 7972.20 481.83 -45.01 0.00 0.00 483.88 SCU 43-05Z wp01 Tgt1 7 8500.00 10.00 0.00 8458.60 567.60 -45.01 0.00 0.00 569.38 Total Depth : 8500' MD, 8458.6' TVD -50 0 50 100 150 200 250 300 350 400 450 500 550 600 South(-)/North(+) (75 usft/in)-250 -200 -150 -100 -50 0 50 100 150 200 250 West(-)/East(+) (75 usft/in) SCU 43-05Z wp01 Tgt1 7 5/8" x 9 7/8" 4 1/2" x 6 3/4" 25050075010001250150017502000225025002750300032503500375040004250450047505000525055005750 6000 6250 6500 6750 7000 7250 7500 7750 8000 8250 8459 SCU 42-05Z wp03 Start Dir 3º/100' : 300' MD, 300'TVD End Dir : 336.86' MD, 336.86' TVD Start Dir 2º/100' : 5555.48' MD, 5554.51'TVD End Dir : 6006.1' MD, 6002.58' TVD Total Depth : 8500' MD, 8458.6' TVD Project: Soldotna CK Unit Site: SCU 43-05 Well: Plan: SCU 42-05Z Wellbore: SCU 42-05Z Plan: SCU 42-05Z wp03 WELL DETAILS: Plan: SCU 42-05Z 153.70 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 2457872.331 341714.763 60° 43' 28.852 N 150° 53' 2.725 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: SCU 42-05Z, True North Vertical (TVD) Reference:RKB As-Built @ 172.20usft Measured Depth Reference:RKB As-Built @ 172.20usft Calculation Method:Minimum Curvature CASING DETAILS TVD TVDSS MD Size Name 2899.52 2727.32 2900.00 7-5/8 7 5/8" x 9 7/8" 8458.60 8286.40 8500.00 4-1/2 4 1/2" x 6 3/4" -57 0 57 113 170 227 283 340 397 453 510 567 623 680 South(-)/North(+) (85 usft/in)-340 -283 -227 -170 -113 -57 0 57 113 170 227 West(-)/East(+) (85 usft/in) SCU 43-05Z wp01 Tgt1 2505007 5 0 1 0 0 012501500 1 7 5 0200022 50250027503000325035003750400042504500475050005250550057506000625065006750700072507500775080008250850087509000SCU 43-052505007 5 0 1 0 0 012501500 1 7 5 0200022 50250027503000325035003750400042504500475050005250550057506000625065006750700072507500775080008250SCU 13-04 2505007 5 0 1 0 0 012501500 1 7 5 0200022 50250027503000325035003750400042504500475050005250550057506000625065006750700072507500775080008250850087509000SCU 43A-05250500750100012501500 1750 2000 22502500275030003250350037504000425045004750 5000 5250 5500 5 7 5 0 6 0 0 0 6 2 5 0 6 5 0 0 6 7 5 0 7 0 0 0 7 2 5 07500 7750 8000 8045 SCU 42-05Y 250500 750 1000 1250 1 5 00 1 7 5 0 2 0 0 0 2250 2500 2750 3 0 00 3 2 5 0 350037504000425 04500 475050 005 2 5 0 5 5 0 057506 0 0 0 6250650067 5 070007250 SCU 42-05X 2505007501 0 0 0 1250150017502 0 0 0 2 2 5 02500275 03 0 0 032503500 37504000425045004750500052505 5 0 0 5 7 5 0 6000 6250 6500 6750 7000 7250 7500 7750 8000 8 2 5 0 8 5 0 0 SCU 21C-04 2505007501 0 0 0 1250150017502 0 0 0 2 2 5 02500275 03 0 0 032503500 37504000425045004750500052505 5 0 0 5 7 5 0 6000 6250 6500 6750 7000 7250 7500 7750 8000 8250850087 50900092509500 9750 SCU 44-05 2505007501 0 0 0 1250150017502 0 0 0 2 2 5 02500275 03 0 0 032503500 37504000425045004750500052505 5 0 0 5 7 5 0 6000 6250 6500 6750 7000 7250 7500 7750 8000 8250850087 5090009250950 09750100001025010500SCU 33-05 2505007501000 1250 150017502000225025002750 3 0 0 0 3250 3500375040 0042504500475050005250550057506 0 0 0 6 2 5 0 6 5 0 0 6 7 5 0 7 0 00 7 2 50 7500 7750 8000 SCU 42-05PB1 2505007501000 1250 150017502000225025002750 3 0 0 0 3250 3500375040 00425045004750500052505500575060006 2 5 0 6 5 0 0 6 7 5 0 7 0 0 0 7 2 5 0 7 5 0 0 SCU 42-05 2505007501000 1250 150017502000225025002750 3 0 0 0 3250 3500375040 00425045004750500052505500575060006 2 5 0 6 5 0 0 6 7 5 0 7 0 0 0 7 2 5 0 7 5 0 0 SCU 42A-05 250500750100 01250150017502000 22502500275030003250350 037 50 4 0 0 0 4250 4500 4750 5000 5250 5500 5750 6000 6 2 5 0 6 5 0 0 6 7 5 0 7 0 0 0 7 2 5 0 7500 7618SCU 42B-05PB1 250500750100 01250150017502000 225025002750300032503500 3 75 0 4 0 0 0 4 2 5 0 4 5 0 0 4 7 5 0 50 00 5 2 5 0 5 5 0 0 5 7 5 0 6 0 0 0 6 2 5 0 6500 6750 7000 7250 7500 7750 8000 8250 8500 8750 9000 9250 9500 9750 10000 10250 10500 SCU 42B-05 7 5/8" x 9 7/8" 4 1/2" x 6 3/4" 25050075010001250150017502000225025002750300032503500375040004250450047505000525055005750 6000 6250 6500 6750 7000 7250 7500 7750 8000 8250 8459 SCU 42-05Z wp03 REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: SCU 42-05Z, True North Vertical (TVD) Reference:RKB As-Built @ 172.20usft Measured Depth Reference:RKB As-Built @ 172.20usft Calculation Method:Minimum Curvature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(/; ). (/5 . (/:; )+ (> 3> ((3;,5 3 ( 4 *%32#3 (3; )+3 +!)$, -).*+(/()*% !"#"$% "#&" "#&" "#&'!; )+. (/ 9; 0* '(),*+%+ ')"*+,+ ')"*+, 0/&-" .%& %"&%/ .,%&-" *&**.%& + '(),*+%+ ')"*+,+ ')"*+, "&* .-& /,&% .1-*&- &1*.-&' + '(),*+%+ '),*+%+ '),*+% /&-, "1&% %1&0 ",&*, 0&",-"1&%' + '(),*+%+ '),*+%+ '),*+% 0/&-" .%& %"&%/ .,%&-" *&**.%& + '(),*+%+ '),*+%+ '),*+% "&* .-& /,&% .1-*&- &1*.-&' + '(),*+%+ '),*+%+ '),*+% /&-, "1&% %1&0",&*, 0&",-"1&%' + '(),*+%+ '),*+%+ '),*+% 0/&-" .%& %"&*/ .,%&-" *&".%& + '(),*+%+ '),*+%+ '),*+% "&* .-& /,&* .1-*&- &010.-&' + >. (/?. (/ -A$ -?"1&% .-& '),+%4* *567!"!6 ! 8.-& 1.%& '),+%4* *567!"!6 ! 8 9 : ;<+& : =&' : : $ &' > $#? $+ @& 8 == & : :869:9': ; : 9& 0.001.503.004.50Separation Factor0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500Measured DepthSCU 43-05SCU 21C-04SCU 42-05PB1SCU 42-05SCU 42B-05PB1SCU 42B-05No-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: SCU 42-05Z NAD 1927 (NADCON CONUS)Alaska Zone 04153.70+N/-S +E/-W Northing EastingLatittudeLongitude0.000.00 2457872.331 341714.763 60° 43' 28.852 N 150° 53' 2.725 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: SCU 42-05Z, True NorthVertical (TVD) Reference:RKB As-Built @ 172.20usftMeasured Depth Reference:RKB As-Built @ 172.20usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-09-11T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool18.50 2900.00 SCU 42-05Z wp03 (SCU 42-05Z) 3_MWD+IFR1+MS+Sag2900.00 8500.00 SCU 42-05Z wp03 (SCU 42-05Z) 3_MWD+IFR1+MS+Sag0.0030.0060.0090.00120.00150.00Centre to Centre Separation (50.00 usft/in)0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500Measured DepthSCU 43-05SCU 13-04SCU 43A-05SCU 42-05XSCU 21C-04SCU 21C-04SCU 44-05SCU 44-05SCU 33-05SCU 33-05SCU 42-05PB1SCU 42-05SCU 42A-05SCU 42B-05PB1SCU 42B-05PB1SCU 42B-05SCU 42B-05SCU 42B-05GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference18.50 To 8500.00Project: Soldotna CK UnitSite: SCU 43-05Well: Plan: SCU 42-05ZWellbore: SCU 42-05ZPlan: SCU 42-05Z wp03Ladder / S.F. PlotsCASING DETAILSTVD TVDSS MD Size Name2899.52 2727.32 2900.00 7-5/8 7 5/8" x 9 7/8"8458.60 8286.40 8500.00 4-1/2 4 1/2" x 6 3/4"SCUS-05 Revised 2/2015 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: ____________________________ POOL: ______________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit No. _____________, API No. 50-_______________________. Production should continue to be reported as a function of the original API number stated above. Pilot Hole In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name (_______________________PH) and API number (50-_____________________) from records, data and logs acquired for well (name on permit). Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (_____________________________) as Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for well ( ) until after ( ) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (________________________) must contact the AOGCC to obtain advance approval of such water well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (_______________________________) in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. 220-069 Swanson River X Tyonek 77-3 Gas Storage Pool Soldotna Creek Unit 42-05Z WELL PERMIT CHECKLISTCompanyHilcorp Alaska, LLCWell Name:SOLDOTNA CK UNIT 42-05ZInitial Class/TypeDEV / PENDGeoArea820Unit51994On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2200690SWANSON RIVER, 77-3 TYNK GS ST - 772805NA1 Permit fee attachedYes Entire well in FEDA028996.2 Lease number appropriateYes3 Unique well name and numberYes Swanson River, 77-3 Tyonek Gas Storage Pool – 772805, is governed by SIO 6.4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryYes Gas storage well (producer only): no spacing restrictions. Well will be more than 1500’ from lease boundary.6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitYes Storage Injection Order No. 6.14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For sNA Storage producer only.15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes18 Conductor string providedYes 7 5/8" surface casing will be set at 2800 ft and fully cemented.19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgYes 5 1/2" liner will be cemented to LTP. Tieback will be run to surface.21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes BTC calculations provided.23 Casing designs adequate for C, T, B & permafrostYes Rig 169 has steel pits… all waste to approved disposal wells.24 Adequate tankage or reserve pitNA25 If a re-drill, has a 10-403 for abandonment been approvedYes No issue with close crossings.26 Adequate wellbore separation proposedYes Diverter schematic is provided by Hilcorp.27 If diverter required, does it meet regulationsYes Max form pressure = 4200 psi (.55 psi /ft) will drill with 9-11 ppm mud28 Drilling fluid program schematic & equip list adequateYes Rig 169 has 5000 psi WP BOPE29 BOPEs, do they meet regulationYes MASP = 3618 PSI (will test BOPE to 3750 psi ) annular to 2500 psi30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes Sundry required to complete well. CBL and MIT-IA submitted to AOGCC.32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableNA Gss storage well for offtake of TY 77-3 pool only.34 Mechanical condition of wells within AOR verified (For service well only)Yes H2S not anticipated—numerous offset wells.35 Permit can be issued w/o hydrogen sulfide measuresYes Tyonek 77-3 storage sand expected pressure is 10.5 ppg EMW, otherwise remainder of36 Data presented on potential overpressure zonesNA drilled section expected to exhibit normal pressure. Mud program adequate for anticipated37 Seismic analysis of shallow gas zonesNA pressures. Weighting materials will be onsite to allow mud weight to be raised 1.0 ppg above38 Seabed condition survey (if off-shore)NA highest anticipated pressure.39 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate10/7/2020ApprGLSDate11/16/2020ApprSFDDate10/7/2020AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateDrilling Gas storage production well into Tyonek 77-3 pool… will be used for off take only. AOGCC approval required to inject gas into well. GlsJMP 11/18/2020dts 11/17/2020JLC 11/17/2020