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Home My WebLink About220-065Samuel 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 : 03/15/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KU 44-01B (PTD 220-065) PERFORATING RECORD 01/07/2021 Please include current contact information if different from above. PTD: 2200650 E-Set: 34783 Received by the AOGCC 03/15/2021 03/15/2021 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20692-00-00Well Name/No. KENAI UNIT 44-01BCompletion StatusGSTORCompletion Date1/13/2021Permit to Drill2200650Operator Hilcorp Alaska, LLCMD7250TVD4664Current StatusGSTOR3/11/2021UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:LWD/MWD Logs + PB1, Mudlog + PB1, CBL 12-17-20NoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF12/16/202011 7300 Electronic Data Set, Filename: KU 44-01B.las34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Daily Reports.pdf34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B and KU 44-01B PB1 Final Well Report.pdf34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Drilling Dynamics Log MD 2in.pdf34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Drilling Dynamics Log MD 5in.pdf34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Drilling Dynamics Log TVD 2in.pdf34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Drilling Dynamics Log TVD 5in.pdf34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Formation Log MD 2in.pdf34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Formation Log MD 5in.pdf34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Formation Log TVD 2in.pdf34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Formation Log TVD 5in.pdf34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Gas Ratio Log MD 2in.pdf34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Gas Ratio Log MD 5in.pdf34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Gas Ratio Log TVD 2in.pdf34401EDDigital DataThursday, March 11, 2021AOGCCPage 1 of 8PB1Supplied byOPSupplied byOPKU 44-01B.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20692-00-00Well Name/No. KENAI UNIT 44-01BCompletion StatusGSTORCompletion Date1/13/2021Permit to Drill2200650Operator Hilcorp Alaska, LLCMD7250TVD4664Current StatusGSTOR3/11/2021UICNoDF12/16/2020 Electronic File: KU 44-01B Gas Ratio Log TVD 5in.pdf34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B LWD Combo Log MD 2in.pdf34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B LWD Combo Log MD 5in.pdf34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B LWD Combo Log TVD 2in.pdf34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B LWD Combo Log TVD 5in.pdf34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Drilling Dynamics Log MD 2in.tif34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Drilling Dynamics Log MD 5in.tif34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Drilling Dynamics Log TVD 2in.tif34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Drilling Dynamics Log TVD 5in.tif34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Formation Log MD 2in.tif34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Formation Log MD 5in.tif34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Formation Log TVD 2in.tif34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Formation Log TVD 5in.tif34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Gas Ratio Log MD 2in.tif34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Gas Ratio Log MD 5in.tif34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Gas Ratio Log TVD 2in.tif34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Gas Ratio Log TVD 5in.tif34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B LWD Combo Log MD 2in.tif34401EDDigital DataThursday, March 11, 2021AOGCCPage 2 of 8 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20692-00-00Well Name/No. KENAI UNIT 44-01BCompletion StatusGSTORCompletion Date1/13/2021Permit to Drill2200650Operator Hilcorp Alaska, LLCMD7250TVD4664Current StatusGSTOR3/11/2021UICNoDF12/16/2020 Electronic File: KU 44-01B LWD Combo Log MD 5in.tif34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B LWD Combo Log TVD 2in.tif34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B LWD Combo Log TVD 5in.tif34401EDDigital DataDF12/16/2020 Electronic File: KU44-01B-1.dbf34401EDDigital DataDF12/16/2020 Electronic File: ku44-01b-1.hdr34401EDDigital DataDF12/16/2020 Electronic File: KU44-01B-1.mdx34401EDDigital DataDF12/16/2020 Electronic File: ku44-01b-1r.dbf34401EDDigital DataDF12/16/2020 Electronic File: ku44-01b-1r.mdx34401EDDigital DataDF12/16/2020 Electronic File: KU44-01B-1_SCL.DBF34401EDDigital DataDF12/16/2020 Electronic File: KU44-01B-1_SCL.MDX34401EDDigital DataDF12/16/2020 Electronic File: KU44-01B-1_TVD.DBF34401EDDigital DataDF12/16/2020 Electronic File: KU44-01B-1_TVD.mdx34401EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Show Reports.pdf34401EDDigital Data0 0 2200650 KENAI UNIT 44-01B LOG HEADERS34401LogLog Header Scans0 0 2200650 KENAI UNIT 44-01B PB1 LOG HEADERS34402LogLog Header ScansDF12/16/202011 7450 Electronic Data Set, Filename: KU 44-01B PB1.las34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Daily Reports.pdf34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B and KU 44-01B PB1 Final Well Report.pdf34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Drilling Dynamics Log MD 2in.pdf34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Drilling Dynamics Log MD 5in.pdf34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Drilling Dynamics Log TVD 2in.pdf34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Drilling Dynamics Log TVD 5in.pdf34402EDDigital DataThursday, March 11, 2021AOGCCPage 3 of 8KU 44-01B PB1.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20692-00-00Well Name/No. KENAI UNIT 44-01BCompletion StatusGSTORCompletion Date1/13/2021Permit to Drill2200650Operator Hilcorp Alaska, LLCMD7250TVD4664Current StatusGSTOR3/11/2021UICNoDF12/16/2020 Electronic File: KU 44-01B PB1 Formation Log MD 2in.pdf34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Formation Log MD 5in.pdf34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Formation Log TVD 2in.pdf34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Formation Log TVD 5in.pdf34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Gas Ratio Log MD 2in.pdf34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Gas Ratio Log MD 5in.pdf34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Gas Ratio Log TVD 2in.pdf34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Gas Ratio Log TVD 5in.pdf34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 LWD Combo Log MD 2in.pdf34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 LWD Combo Log MD 5in.pdf34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 LWD Combo Log TVD 2in.pdf34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 LWD Combo Log TVD 5in.pdf34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Drilling Dynamics Log MD 2in.tif34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Drilling Dynamics Log MD 5in.tif34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Drilling Dynamics Log TVD 2in.tif34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Drilling Dynamics Log TVD 5in.tif34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Formation Log MD 2in.tif34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Formation Log MD 5in.tif34402EDDigital DataThursday, March 11, 2021AOGCCPage 4 of 8 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20692-00-00Well Name/No. KENAI UNIT 44-01BCompletion StatusGSTORCompletion Date1/13/2021Permit to Drill2200650Operator Hilcorp Alaska, LLCMD7250TVD4664Current StatusGSTOR3/11/2021UICNoDF12/16/2020 Electronic File: KU 44-01B PB1 Formation Log TVD 2in.tif34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Formation Log TVD 5in.tif34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Gas Ratio Log MD 2in.tif34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Gas Ratio Log MD 5in.tif34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Gas Ratio Log TVD 2in.tif34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Gas Ratio Log TVD 5in.tif34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 LWD Combo Log MD 2in.tif34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 LWD Combo Log MD 5in.tif34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 LWD Combo Log TVD 2in.tif34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 LWD Combo Log TVD 5in.tif34402EDDigital DataDF12/16/2020 Electronic File: KU44-01B.dbf34402EDDigital DataDF12/16/2020 Electronic File: ku44-01b.hdr34402EDDigital DataDF12/16/2020 Electronic File: KU44-01B.mdx34402EDDigital DataDF12/16/2020 Electronic File: ku44-01br.dbf34402EDDigital DataDF12/16/2020 Electronic File: ku44-01br.mdx34402EDDigital DataDF12/16/2020 Electronic File: KU44-01B_SCL.DBF34402EDDigital DataDF12/16/2020 Electronic File: KU44-01B_SCL.MDX34402EDDigital DataDF12/16/2020 Electronic File: KU44-01B_tvd.dbf34402EDDigital DataDF12/16/2020 Electronic File: KU44-01B_tvd.mdx34402EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Show Reports.pdf34402EDDigital DataDF12/16/2020120 7250 Electronic Data Set, Filename: KU 44-01B LWD Final.las34403EDDigital DataDF12/16/2020 Electronic File: KU 44-01B LWD Final MD.cgm34403EDDigital DataThursday, March 11, 2021AOGCCPage 5 of 8KU 44-01B LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20692-00-00Well Name/No. KENAI UNIT 44-01BCompletion StatusGSTORCompletion Date1/13/2021Permit to Drill2200650Operator Hilcorp Alaska, LLCMD7250TVD4664Current StatusGSTOR3/11/2021UICNoDF12/16/2020 Electronic File: KU 44-01B LWD Final TVD.cgm34403EDDigital DataDF12/16/2020 Electronic File: KU 44-01B - Definitive Survey Report.pdf34403EDDigital DataDF12/16/2020 Electronic File: KU 44-01B DSR Actual_Plan View.pdf34403EDDigital DataDF12/16/2020 Electronic File: KU 44-01B DSR Actual_Sect View.pdf34403EDDigital DataDF12/16/2020 Electronic File: KU 44-01B DSR.txt34403EDDigital DataDF12/16/2020 Electronic File: KU 44-01B DSR_GIS.txt34403EDDigital DataDF12/16/2020 Electronic File: KU 44-01B Final Surveys .xlsx34403EDDigital DataDF12/16/2020 Electronic File: KU 44-01B LWD Final MD.emf34403EDDigital DataDF12/16/2020 Electronic File: KU 44-01B LWD Final TVD.emf34403EDDigital DataDF12/16/2020 Electronic File: KU 44-01B LWD Final MD.pdf34403EDDigital DataDF12/16/2020 Electronic File: KU 44-01B LWD Final TVD.pdf34403EDDigital DataDF12/16/2020 Electronic File: KU 44-01B LWD Final MD.tif34403EDDigital DataDF12/16/2020 Electronic File: KU 44-01B LWD Final TVD.tif34403EDDigital Data0 0 2200650 KENAI UNIT 44-01B LOG HEADERS34403LogLog Header ScansDF12/16/202090 7344 Electronic Data Set, Filename: KU 44-01B PB1 LWD Final with Realtime data.las34404EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 LWD Final MD.cgm34404EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 LWD Final TVD.cgm34404EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 - Definitive Survey Report.pdf34404EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 DSR.txt34404EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 DSR_GIS.txt34404EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 Final Surveys .xlsx34404EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 LWD Final MD.emf34404EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 LWD Final TVD.emf34404EDDigital DataThursday, March 11, 2021AOGCCPage 6 of 8KU 44-01B PB1 ,LWD Final with Realtime data.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20692-00-00Well Name/No. KENAI UNIT 44-01BCompletion StatusGSTORCompletion Date1/13/2021Permit to Drill2200650Operator Hilcorp Alaska, LLCMD7250TVD4664Current StatusGSTOR3/11/2021UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalINFORMATION RECEIVEDDF12/16/2020 Electronic File: KU 44-01B PB1 LWD Final MD.pdf34404EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 LWD Final TVD.pdf34404EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 LWD Final MD.tif34404EDDigital DataDF12/16/2020 Electronic File: KU 44-01B PB1 LWD Final TVD.tif34404EDDigital Data0 0 2200650 KENAI UNIT 44-01B PB1 LOG HEADERS34404LogLog Header ScansDF12/22/20201101 893 Electronic Data Set, Filename: KU_44-01B_RCBL_17DEC20_FreePipe.las34441EDDigital DataDF12/22/20207248 1810 Electronic Data Set, Filename: KU_44-01B_RCBL_17DEC20_Main.las34441EDDigital DataDF12/22/20207272 7016 Electronic Data Set, Filename: KU_44-01B_RCBL_17DEC20_Repeat.las34441EDDigital DataDF12/22/2020 Electronic File: KU_44-01B_RCBL_17DEC20.pdf34441EDDigital DataDF12/22/2020 Electronic File: KU_44-01B_RCBL_17DEC20_img.tiff34441EDDigital DataDF12/22/2020 Electronic File: KU_44-01B_RCBL_17DEC20_FreePipe.dlis34441EDDigital DataDF12/22/2020 Electronic File: KU_44-01B_RCBL_17DEC20_Main.dlis34441EDDigital DataDF12/22/2020 Electronic File: KU_44-01B_RCBL_17DEC20_Repeat.dlis34441EDDigital Data0 0 2200650 KENAI UNIT 44-01B PB1 LOG HEADERS34441LogLog Header Scans1/28/20212100 725031770Cuttings1/28/20211970 7430 PB1 samples41771CuttingsThursday, March 11, 2021AOGCCPage 7 of 8 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20692-00-00Well Name/No. KENAI UNIT 44-01BCompletion StatusGSTORCompletion Date1/13/2021Permit to Drill2200650Operator Hilcorp Alaska, LLCMD7250TVD4664Current StatusGSTOR3/11/2021UICNoCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date: 1/13/2021Release Date:10/20/2020Thursday, March 11, 2021AOGCCPage 8 of 8M. Guhl3/11/2021 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): Kenai Gas Field GL: 59' BF:59' 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 13-3/8" X-56 120' 9-5/8" L-80 1,833' 7" L-80 4,664' 7" L-80 1,648' 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, Tieback Assy.Tieback TUBING RECORD 7,159' MD1-3/4" x 2-3/8" Coil SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): L - 315 sx / T - 80 sx Cond Surface 2,239' L - 330 sx / T - 232 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 1/13/2021 655' FSL, 1842' FEL, Sec 31, T5N, R11W, SM, AK 895' FSL, 454' FEL, Sec 1, T4N, R12W, SM, AK 220-065 / 320-521 Sterling Pool 6 Gas Storage 77' 7,225' MD / 4,651' TVD HOLE SIZE AMOUNT PULLED 50-133-20692-00-00 KU 44-01B 270783 2368008 1107' FSL, 445' FEL, Sec 1, T4N, R12W, SM, AK CEMENTING RECORD 2363090 SETTING DEPTH TVD 2362879 BOTTOM TOP 8-1/2" 39 bbls 25 bbls Surface 12-1/4"Surface CASING WT. PER FT.GRADE 26# 270568 270555 TOP SETTING DEPTH MD Surface Surface Per 20 AAC 25.283 (i)(2) attach electronic information 26# 1,904' 1,642' Surface DEPTH SET (MD) N/A PACKER SET (MD/TVD) 68# 40# 120' 1,893' 7,250' Gas-Oil Ratio:Choke Size:Water-Bbl: PRODUCTION TEST 1/16/2021 Date of Test: 0 1/23/2021 24 Flow Tubing 0 3900 Oil-Bbl: suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A3900 Flowing ** Please see attached schematic for perforation detail ** 0 LWD/MWD Logs + PB1, Mudlog + PB1, CBL 12-17-20 Sr Res EngSr Pet GeoSr Pet Eng N/A N/A Oil-Bbl: Water-Bbl: 0057 December 4, 2020 November 9, 2020 ADL392668, ADL392670, FEE AA093836 N/A N/A N/AN/A N/A 7,250' MD / 4,664' 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 2:08 pm, Feb 02, 2021 RBDMS HEW 2/3/2021 Completion Date 1/13/2021 HEW G KU 44-01B approved for production only. not authorized for injection. gls. Sterling Pool 6 Gas Storage SFD 2/4/2021 /320- CBL 12-17-20 NOTE: lost RA BHA in wellbore (PB1) Gas Storage SFD 2/4/2021 DSR-2/8/21gls 3/11/21 503 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 7,020' P6 4,536' 5,624' 3,745' 5,768' 3,827' 5,911' 3,908' 6,007' 3,962' 6,194' 4,065' 6,459' 4,217' 6,992' 4,521' Pool 6 C1 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 P5.2 B5 P6 C1 Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top P5.1 B4 P4 B1 P4 B2A P3 A11 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: P5.1 B3 Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Reports, PB Summary 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 2.2.2021Digitally 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: 2021.02.02 11:19:33 -09'00' Monty M Myers Updated by CJD 1-28-21 SCHEMATIC Kenai Gas Field KU 44-01B PTD: 220-065 API: 50-133-20692-00-00 PBTD = 7,225’ MD / TVD = 4,651’ TD = 7,250’ MD / TVD = 4,664’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 13-3/8” Conductor – Driven to Set Depth 68 X-56 Weld 12.415” Surf 120' 9-5/8" Surf Csg 40 L-80 DWC/C 8.835” Surf 2,239’ 7" Prod Tieback 26 L-80 CDC HTQ 6.276” Surf 1,904’ 7" Prod Lnr 26 L-80 CDC HTQ 6.276” 1,893’ 7,250’ TUBING DETAIL 1-3/4” Coil Tubing String -- -- -- 1.532” Surf 7,148’ 2-3/8” Coil Tubing String -- -- -- 2.125” Surf 7,159’ 2 13-3/8” 9-5/8” 12-1/4” hole 7” JEWELRY DETAIL No. Depth ID OD Item 1 1,893’ 6.151” 7.360” Baker tieback Seal Assembly 2 1,893’ 6.180” 8.430” Baker ZXP Liner Top Packer Flex-Lock V liner hanger 3 7,149’ 1.35” -- XN Nipple (installed in 1.75” CT BHA) 4 7,172’ -- -- Shear sub (sheared open / installed in 2.375” CT BHA) 8-1/2” hole 1 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Gun Size SPF Date Status Pool 6 Sand 7,020’ 7,041’ 4,536’ 4,548’ 21’ 3-1/8” 12 1/9/21 Open Pool 6 Sand 7,041’ 7,062’ 4,548’ 4,560’ 21 3-1/8” 12 1/9/21 Open Pool 6 Sand 7,062’ 7,083’ 4,560’ 4,571 21’ 3-1/8” 12 1/8/21 Open Pool 6 Sand 7,083’ 7,104’ 4,571’ 4,583’ 21’ 3-1/8” 12 1/8/21 Open Pool 6 Sand 7,104’ 7,125’ 4,583’ 4,595’ 21’ 3-1/8” 12 1/8/21 Open Pool 6 Sand 7,125’ 7,146’ 4,595’ 4,607’ 21’ 3-1/8” 12 1/7/21 Open Pool 6 Sand 7,146’ 7,150’ 4,607’ 4,609’ 6’ 3-1/8” 12 1/9/21 Open 3 TOC ~2,000’ MD per CBL 12-17-20 OPEN HOLE CEMENT DETAIL Hole Section Cement 12-1/4” x 9-5/8” Lead: 12.0ppg 140 bbl, Tail: 15.8 ppg 48 bbl 8-1/2” x 7” Lead: 12.0ppg 135 bbl, Tail: 15.3 ppg 17 bbl 4 XN Concentric Coil tubing for gas lift Pool 6 sands 7020-7150 ft Activity Date Ops Summary 11/3/2020 PJSM Unpin blocks F/ TD. Remove service loop guideline straps. Tie service loop and mud line together. Rotate 4" stand pipe valve for laying down. Cont cleaning pits and prep for rig move. Cont dressing MP #1 W/ 5.5" liners. Disconnect poor boy and lines. Remove turnbuckles and Tee Bar F. Trq tube.;Prep catwalk area for move. Disconnect TD HPU F/ sub base. Disconnect Sperry & Baroid shacks. Disconnect inner connects & lines F/ pits to pump room. 11/4/2020 Finish working on mud pump #1 in prep for move. Remove windwall tarps on pits. Disconnect lines and ready pits for move. Ready BOP and Poorboy for crane. Remove hyd lines f/ drk.;Crane arrived on pad. LD poorboy. PU and lay over BOPs Load BOPs on truck. Remove TD from rig floor and set in cradle. Remove and store handy berm. Move Sperry and mudmans shacks.;Pull mud pit windwalls w/ crane. Blow dn steam lines. Trucks arrived at 1400 hrs and we started pulling the back of the rig apart. Set out all the building except for the combo building, water tank doghouse.;PJSM Cont moving modules of matt boards. Remove turnbuckles F/ Trq Tube. Bridle up. Lift mast and unpin. Started to lower and found stand needed turned. Lift mast and re pin. Loosen clamps to stand pipe and turn stand pipe. Lift mast and unpin, lower mast W/ Trq tube tailing out beaver slide.;Unpin lower Trq Tube and L/D. Remove rig matts and send to KU 44-01B. Fold over beaver slide onto catwalk and R/D hydraulics. Secure blocks in mast. Prep to spool off drilling line.;PJSM Close becket on blocks. Remove upper turnbuckles F/ Trq Tube. Lower Vee Door. Ready dog house to lower. Slip off and cut 18 wraps of drilling line. Disconnect brake linkage & air manifold. Pin boom line in place. Secure service loop and kelly hose. Unpin and lower dog house.;Secure and prep mast to be laid over. Send partial crew to KB 44 to lay Herculite. Peak trucks start braking down gen mod.. 11/5/2020 Prep to lay over drk. Have frozen air line on drwks hyd pump. Thawing frozen air lines. Load out water tank, doghouse, accumulator, combo building. Peak loading out and hauling loads to Kenai Gas Field.;Fold up drk board. Got air thawed out about 1000 hrs and layed the drk over. Prep drk to pick w/ cranes. Pick iron roughneck off floor w/ crane.;RU cranes to drk. Pick drk off carrier and set on blocks on stretch trailer. RU cranes and pick drwks skid. Set on lowboy trailer. Got felt and liner plus enough mats to set sub on KU44-01B.;Spot cranes to pick sub. Lay dn landings on sub. Pick sub and set on trailer. Load 4 mats and both pony subs on another trailer. Finish PU mats and loading them out. PU liner and felt;PJSM Unload matts at KU 44 and misc Equip. Set pony sub and sub center over well. Install carrier and mast W/ cranes. Set test pump. Set and raise dog house. Set pit mod 1. Peak crane and trucks timed out 23:00.;PJSM Raised pit roof. Install lights. Trouble shot Chelsea pump in carrier. Unspool tugger line for replacement. Install hand rails on rig floor. Install brake linkage drive line. C/O boom line. 11/6/2020 Peak on location at 06:30. Set Pump Mod 1 & 2, Pit Mod 3 & 4 & Boiler room. Raise roofs in pit mod and degasser. R/U TD HPU & cable trays. Connect inner connects between mods. Set Iron Roughneck on rig floor. Electrician run cables around rig. Spread felt for Catwalk.;Peak arrived at KGSF 1A 08:00. R/D office camp, lines, Gen & sewer boxes. Clean pad and turn over to operations.;Set Gen mod and R/U electrical. Cont setting fuel mods. Perform derrick inspection and raise. Repair sight glass leak on HPU tank. Install Elec, air & H2O lines around rig. L/O felt and herculite for catwalk. Thaw out carrier air to dog house driller console.;Prep MP's for 5.5" liners. M/U stand pipe and bleeder manifold on rig floor. Connect gas buster discharge to pit roof. Hang wind walls in pits. Lower kelly hose and drill line to rigfloor. Prep to spool up drilling line. Set centrifuge in pits. SIMOPS Spot and R/U office camp.;Set matt boards and crane in catwalk and gas buster. Cont r/u in pits. Lower derrick board and pin legs and back wind wall. R/U misc light on roof mods. Set misc conex and trailers around yard. R/U top drive service and control lines. Spool up drilling line and slip on 3.5 layers to drawworks.;Prep derrick for scoping up. Stage up boiler and charge system. Install upper section Trq tube turnbuckles. Un dog derrick. Hang weight indicator & sensator. Raise V-door. Install wind wall frames on rig floor. Spot cutting box. Released Crane 18:30, Peak trucks 20:00;Cont installing upper trq tube section turnbuckles. Cont installing wind wall frames and tarps on rig floor. Plug in service shacks. P/U lower trq tube and pin to upper section in derrick. Scope up derrick and pin. Install climb assist. Remove transport frame F/ drawwork skid.;Remove flow box F/ cellar. Install surface riser to conductor. Install Geronimo line. 11/7/2020 Finish nippling up conductor riser. Finish prepping mud pumps w/ 5 1/2" swabs. Assist electrician w/ running wires & hanging lights. Hang tarps in cellar, rig floor, & pits. Install lines between pits and pumps. Bridle dn and hang off bridle lines. RU drain hoses f/ rig floor to cellar.;Install dog house camera. RU T-bracket on TD rail. RU Pason equip. Assist Quadco hand with gas detector RU and test gas alarms. Clean and organize rig floor. Welder finished building flow line.;Perform KGF orientation W/ all day personnel. Prep to PU TD. Install flowline. Not enough drop on the flow line. Pulled riser back off and add 10" to riser. Still working on wiring around rig. Change out cotter pins in TD rail. PU TD. Install Trq tube turnbuckles and adjust alignment.;Finished dressing pumps W/ 5.5" Liner/ Swabs. Pin top drive to blocks. Unpin top drive cradle and L/D. P/U install Trq bushing onto Trq tube, pin arms to top drive. R/U Hydraulic and service loop to top drive.;Cont installing service loop & hydraulics to top drive. Welder working on lowering V-Door containment for pipe clearance on rig floor and brackets for top drive supply & return lines. Found ESD to be engaged on HPU control panel for top drive. Function top drive, good. Test Irion Roughneck;manual control working remote control box no power to IR. Electrician coming in morning to trouble shoot. M/U & clack kelly hose. Bump tested shakers and all agitators. Install stairs and stage floor Equip on catwalk. Cont working rig acceptance check list. Begin rigging up floor Equip. M/U bleeder;ans 1/4 turn to bleeder manifold. MWD start working on smart tools. Canrig rigged up to possum belly W/ gas trap.;Perform KGF orientation W/ all night personnel. Orientate stand pipe and kelly hose in derrick, tighten all clamps. Install service loop guideline strap. Cont working on rig floor acceptance list. Install light in derrick. Put away and organize shaker screens.;Install bleeder F/ mud pump manifold to flow line. Brace F/ 20" riser to possum belly. Take on spud mud to pits. Install toggle on crown saver. Function test hole fill pump. Stage 4.5" D.P. & 4.5" HWDP on pipe racks. Lock out #3 KIll Valve (Mezz) Install bails & 4.5" elevators.;Daily H2O F/ G&I: 400 bbls Daily metal: 0 lb Toatl H2O F/ G&I: 400 bbls Total Metal: 0 lb Daily Fluid to G&I: 0 bbls Total Fluid to G&I: 0 bbls Daily cutting to G&I:0 bbls Total cutting to G&I: 0 bbls n (LAT/LONG): evation (RKB): 50-133-20692-00-00API #: Well Name: Field: County/State: GS KU 44-01B Kenai Gas Field Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Hilcorp Rig 147 Job Name:201-03613D KU 44-01B Drilling Spud Date: Finish nippling up conductor riser 11/8/2020 RU equip on the rig floor. Center conductor. Assist electrician w/ trouble shooting Iron roughneck. IR repaired and tested. Install splash guard under rotary. Inspect diveline bolts. Do a derrick inspection. Strap and tally DP & HWDP. Function test pumps through bleeder.;Dress shakers with 80 mesh screens. Bring handling tool and subs to rig floor. Function test centrifuge, crown o matic, and rotary table.;Test ESDs. Set torque on TD. Check tong torque. Flood stack and check for leaks. Test mud line to 3500 psi. Good test. Adjust equalizer on drwks brakes. Check load collar on TD.;Rig accepted at 1500 hrs. Prep to PU DP. PU 4 1/2 CDS 40 DP and standing it back in the drk.;Finish PU 4 1/2 DP and standing it back in the derrick.;Grease blocks, TD, and iron roughneck.;Adjust torque tube for hole center and elevator clearance. Loosen clamps on standpipe and adjust to operating position. Reclock Kelly hose so it's not in contact with the DP.;PU and stand back in drk 8 stds of 4 1/2 HWDP w/ jars. L/D Mule Shoe.;Daily H2O F/ G&I: 0 bbls Daily metal: 0 lb Toatl H2O F/ G&I: 400 bbls Total Metal: 0 lb Daily Fluid to G&I: 330 bbls Total Fluid to G&I: 330 bbls Daily cutting to G&I:0 bbls Total cutting to G&I: 0 bbls 11/9/2020 MU XOs for wear ring running tool. Drain stack. Run wear ring and lock in 4 LDS. Pull running tool and break out XOs.;PU mud motor and screw on Kymera bit. Went to set it in the table and it wouldn't go dn into the bushings to seat the bit breaker. Backed the Kymera back off and got the 12 1/4 roller cone bit to the floor. Went to make it up an could only get about half the torque we needed.;Doubled the line on the tong pull line and got the bit torqued up.;Run in w/ bit and motor. MU bell sub and XO back to CDS40. RIH w/ HWDP out of drk.;Fill pipe and break circ. Check all lines and equip. Tag at 138'.;Drill 12 1/4" hole f/ 138' t/ 219' at a reduced rate. 350 GPM, 420 Psi, 20 RPM, 2.5k TQ.2 7 WOB.;Circ clean and line up hole fill. POH to motor with no issues.;Had tools on the catwalk ready to start picking them up and the cable on the catwalk winch jumped the sheave. Working on getting cable re-strung. P/U M/U to motor 8" DM collar, 8" EWR, 8" ALD, 8" CTN, 8" TM HOC, 8" Bell Sub, RFO 6.94/8.09= 308.83°.;PJSM Upload MWD and shallow hole test tools, good. Load Nuclear sources as per MED personnel onsite. Cleared all area of personnel.;PJSM P/U M/U 6 3/4" NM FC's and 1 stand 4.5" HWDP.;PJSM Drill/slide 12-1/4" surface F/ 219' to 374' MD (374' TVD) total 115' (38.7' AROP) 420 GPM, 650-800 PSI, 33% flow, 40-60 RPM, TRQ on 3K, TRQ off 2.5K, 9.5 ECD's w/ 8.9 MW, 145 Vis mud. Kick off at 290' for 3°/100 build. MADD pass slides greater then 19.8'. P/U 38K SLK 36K ROT 36K.;PJSM Drill/slide 12-1/4" surface F/ 374' to 561' MD (560' TVD) total 187' (31.2' AROP) 450 GPM, 820 PSI, 36% flow, 40-60 RPM, TRQ on 3.5K, TRQ off 2.5K, 9.7 ECD's w/ 8.9 MW, 135 Vis mud. 4°/100 build. Sliding as needed MADD pass slides greater then 19.8'. P/U 40K SLK 39K ROT 38K.;Slide Hrs 2.34 Rot Hrs 3.16. Distance to WP 04: 3.84' 0.25' High 3.83 Left.;Daily H2O F/ G&I: 100 bbls Daily metal: 0 lb Toatl H2O F/ G&I: 500 bbls Total Metal: 0 lb Daily Fluid to G&I: 45 bbls Total Fluid to G&I: 375 bbls Daily cutting to G&I:55 bbls Total cutting to G&I: 55 bbls 11/10/2020 Cont. to drill 12-1/4" surface hole from 561' to 807' (total = 246', AROP = 41 fph); 450 gpm, 939 psi, WOB 5-15K, 60 rpms, 4.4Kft-lbs. PUW 40K, SOW 39K, ROTW 38K. Slide as needed for 3-4°/100' build rate. MADD Pass all slides.;Cont. to drill 12-1/4" surface hole from 807' to 1178' (total = 371', AROP = 62 fph); 500 gpm, 1250 psi, WOB 10K, 60 rpms, 6.5Kft-lbs. PUW 50K, SOW 46K, ROTW 48K. Slide as needed for 4°/100' build rate. MADD Pass all slides to 1072' bit depth.;Cont. to drill 12-1/4" surface hole from 1178' to 1676' (total = 498', AROP = 83 fph); 500 gpm, 1325 psi, WOB 8-12K, 60 rpms, 8Kft-lbs. PUW 55K, SOW 43K, ROTW 49K. Max gas 59U. Slide as needed for 4°/100' build rate.;Cont. to drill 12-1/4" surface hole from 1676' to 2046' (total = 370', AROP = 62 fph); 500 gpm, 1290 psi, WOB 5-15K, 80 rpms, 8.7Kft-lbs. PUW 58K, SOW 39K, ROTW 48K. Max gas 59U. Slide as needed for 4°/100' build rate to 1809', followed by tangent section.;Daily H2O from G&I = 460 bbls, Total = 960 bbls Daily Fluid to G&I = 390 bbls, Total = 765 bbls Daily Cutting to G&I = 190 bbls, Total = 245 bbls Distance to WP04: 1.61', 1.55' High, 0.46' Left 11/11/2020 Cont. to drill 12-1/4" surface hole from 2046' to 2244' / 1839' TVD (total = 198', AROP = 50 fph); 500 gpm, 1290 psi, WOB 5-15K, 80 rpms, 8.8Kft-lbs. PUW 62K, SOW 42K, ROTW 48K. Max gas 51U. Drill and CBU @ 2120' (sand), 2161' (sand), 2203' (sand) and final 2244' (90% sand/sandstone-10% clay).;Circulate Btms up @ TD 2244' MD. 500 gpm, 1320 psi, 36% flow, 80 rpm, 9.2k tq. Pump 25 bbls 9.1 ppg / 300 vis sweep - Back on time with 25% increase in cuttings. 68k up, 42k dn pumps off/on.;Monitor well (static). POOH on elevators F/ 2244' - T/ 186' MD. Pulled clean with only a few 5k bobbles in upper build section. 11 bbls loss over calc disp.;Service rig - Grease blocks, TDS, drawworks, crown and Iron Roughneck. Monitor well via trip tank during rig svc (1.5-2 bph loss rate).;RIH on elevators F/ 186' - T/ 2244' MD. Light tag on btm with no fill. 4.5 bbl loss for trip. Tripped clean with no issue. Did see 3-5k drag thru 45° and higher inclination in tangent.;Circulate hole clean; pump 20 bbls high vis sweep, sweep on time with 10% increase in cuttings.;POOH from 2243' to 156' with no issues, pulling 5 stands with no indication of swabbing prior to pumping dry job. Rack back HWDP, DC. Calc hole fill 20 bbls, actual 31 bbls.;L /D BHA. Remove sources. download MWD data. L/D TM collar, rig up sheave for L/D line. L/D CTN, ALD, EWR , DM collar. Break bit, L/D motor. Bit grade 1-1-BU-A-E-2-WT-TD. Clean and clear rig floor. Static loss rate ~2bph.;P/U and M/U Wear bushing running tool. Attempt to pull wear ring. While attempting to J into wear bushing rubber hole cover fell below rotary and off pipe while pulling running tool out of hole. Unsuccessfully attempt to fish out with hook from surface. Split riser to fish out by hand and;discovered hole cover (22" x 22") had fallen farther downhole and out of sight (fluid level ~6' below riser flange). Re-install riser. Pull wear bushing.;Service rig, grease and inspect crown, blocks, TD and drawworks.;Rig up to RIH with casing. R/U power tongs, C/O elevators, R/U fill up hose, install Weatherford Rotary bowl. Bring centralizers to rig floor.;Daily H2O from G&I = 630 bbls, Total = 1590 bbls Daily Fluid to G&I = 252 bbls, Total = 1017 bbls Daily Cutting to G&I = 83 bbls, Total = 328 bbls Daily losses to well = 30 bbls, Total = 30 bbls Distance to WP04 6.08', 4.41' high, 4.18' left. Cont. to drill 12-1/4" surface hole from 2046' to 2244' / 1839' TVD Cont. to drill 12-1/4" surface hole from 561' to 807' qp Tag at 138'.;Drill 12 1/4" hole f/ 138' t/ 219' at a pp q p g reduced rate. 350 GPM, 420 Psi, 20 RPM, 2.5k TQ.2 7 W OB.;Circ clean and line up hole fill. POH to motor with no issues.;Had tools on the catwalk ready to start 11/12/2020 P/U 9-5/8" fluted hanger. RIH with landing joint and landout as per Wellhead rep (BHGE). Mark and L/D hanger/landing joint. M/U TIW w/ 9-5/8" BTC swedge.;PJSM, Flashlight float equipment. M/U 9-5/8" BTC 40# shoe track. Bakerlok shoe track. Check floats (good). Run 9-5/8" DWC/C 40# L-80 casing as per detail F/ 84' - T/ 944' MD. Fill on fly, top off every 10 jts. 32k tq on DWC/C connections. 6.5 bbl loss thus far.;CBU @ 944' MD staging up to 6 bpm, 60 psi, 18% flow. Reciprocate pipe, 48k up, 35k dn.;Continue run 9-5/8" DWC/C 40# L-80 casing as per detail F/ 944' - T/ 2230' MD. Attempt to tag but gauld tag jt #55. C/O jts and tag up W/ 3k dn at TD depth of 2244' MD (no fill). L/D jt #56 (54 total jts in hole). M/U hanger with landing jt and landout on depth.;R/D Weatherford casing equipment. Attempt to M/U circ swedge and circulate. Swedge and landing jt collar fouled. B/O swedge and inspect threads (good). R/U HES cementing equipment, Dual plug quick latch cmt head (Loaded and witness plug install - Shane Barber), R/U manifold and circ hoses.;Break circulation at 84 gpm and stage up to 260 gpm, 235 psi. Circulating hole clean and conditioning mudto a YP of 17 for cement job PUW 75K, SOW 45K.;Perform cement job. HES pump 5 bbls water to flood lines. PT to 430/3200 psi. Pump 58 bbls 10.5 ppg Tuned prime spacer with 4# of red dye at 3 bpm, 76 psi. Drop bottom plug. Pump 140 bbls 12.0 ppg Type I/II lead cement at 4.5 bpm, 120 psi. 10 bbls into lead cement, dry cement hose packed off.;Attempt to clear cement hose. Replace hose and continue with cement job. Down 30 minutes. Cement pumps lost prime numerous times while pumping lead cement. Pump 48 bbls of 15.8 ppg Class G tail cement at 4 bpm, 120 psi. Drop top plug.;Displace with 10 bbls water at 4 bpm, 153 psi followed by 148.5 bbls (153 bbls calculated) of 9.4 ppg Spud mud at 6 bpm. Slow to 2 bpm with 10 bbls to go, FCP 440 psi. Observe spacer returns at 20 bbls into displacing, and cement 110 bbls into displacement.;Bump Plug and pressure up to 790 psi and hold for five minutes. Check floats, good, bled back 2.5 bbls. CIP at 00:18. No losses during job. 38.5 bbls of cement returned to surface. Reciprocated pipe throughout job, until hole became sticky 35 bbls into displacing with Spud Mud.;Blow down surface lines and R /D iron on rig floor. Back out landing joint and L/D. M/U pack-off running tool. Drain stack and flush with black water x 2. Land pack-off. RILDS. PT pack-off 500/3000 psi for 10 minutes - good.;SimOps: L/D landing joint, R/D elevators and bale extensions. Holt bolt riser. Fold back catwalk and spot crane. Start emptying pits.;Remove riser sections with tugger and crane. Lower flowline section. Spot wellhead, spacer spool and flowbox in cellar. Clean rig grooves and prep studs.;Daily H2O from G&I = 50 bbls, Total = 1640 bbls Daily Fluid to G&I = 260 bbls, Total = 1277 bbls Daily Cutting to G&I = 0 bbls, Total = 328 bbls Daily losses to well = 30 bbls, Total = 60 bbls 11/13/2020 Install Cactus 16-3/4" x 11" 3/5K Wellhead. Test void 500/3000 psi w/ 5/15 min hold (DSM witnessed - good).;Install 11" Test plug. N/U 2' riser, Install flowbox and pin same. N/U BOP stack (2-7/8"x5" VBR's top & btm). Svc Choke Manifold. Install flowline and tighten hammer seals. C/O to 5" swabs/liners on MP #2. Mix 6% KCL EzMud and dress shakers for drillout.;N/U Choke, kill manual and HCR valves. N/U choke and kill lines. M/U gas buster line from choke manifold. 4 pt stack. Fabricate and install bell nipple riser. C/O low nitrogen backup bottle for koomey, replace annular gauge on koomey w/ line snubbers. Strap and tally 160 jts 4.5" CDS 40 DP.;Lift cellar grating to gain better access and tighten BOP to spool flange. Removed and reclocked LPR and choke HCR hydraulic fittings. Replace bad flange stud on stack. Made up accumulator lines and func tested. M/U hole fill line and attempted to flood stack. Leaked at riser. Re-centered stack;aired up riser boot. Flood stack. Change out to 5" liners on MP1.;M/U test joint. Shell tested stack 250/3500 - good. Flood choke manifold and attempt to shell test, not obtaining pressure. Function bag and re-flood stack. Shell test - good.;Test BOPE's 250/3500 psi on 4-1/2" test joint. AOGCC Austin McLeod witnessed. F/P on manual choke, HCR kill. Test PVT system. Accumulator draw down starting pressure 3050 psi, final 1375 psi. First 200 psi recharge in 24 seconds, final recharge 96 seconds. (4) N2 bottles at 2550 psi average.;Rig down test equipment. Blow down lines.;Daily H2O from G&I = 550 bbls, Total = 2190 bbls Daily Fluid to G&I = 520 bbls, Total = 1797 bbls Daily Cutting to G&I = 0 bbls, Total = 328 bbls Daily losses to well = 0 bbls, Total = 60 bbls 11/14/2020 R/D BOP test equipment. Install 9" ID wear bushing. B/D choke, TDS and mud lines. Transfer HWDP w/ jars from ODS to DS in derrick. Install mousehole.;PJSM, M/U 6' Johnny wacker and single in with 4.5" CDS40, 16.6#, S-135 drill pipe to 1208' MD. Drift - 2.563". Make and break new connections as per break in procedure. 34k up/dn.;Continue single in with 4.5" CDS40, 16.6#, S-135 drill pipe F/ 1208' - T/ 1678' MD. Drif t - 2.563". Make and break new connections as per break in procedure. POOH and rack back in derrick. Single in with another 54 jts to 1780' MD (108 total jts picked up).;Service rig. Lubricate top drive, blocks, crown and drawworks . Inspect brake linkages and driveshaft bolts.;POOH from 1780' racking back 27 stands of CDS40 drill pipe. Clean and clear rig floor.;M/U BHA: PDC bit, motor, DM collar, DGR collar. Measure RFO = 2.43/6.68=130.96°. PWD, ADR collar, ALD collar, CTN collar, HOC. Attempt to upload MWD, comms issues. Pump through tools to warm up. Upload MWD. Shallow pulse test. Install sources.;B/O and L/D XO and TIW. Turn elevators to RIH from derrick. Blowdown top drive and mud lines.;RIH from 194' to 750' with drill collars, HWDP and Jars out of derrick.;Pick up, drift, and single in the hole with CDS40 DP from 750' to 1958'. Wash down from 1958' to 2031' at 2 bpm, tag cement stringer. Wash and ream from 2031' to 2121' at 350 gpm, 1027 psi, 30 rpms, 6800 ft-lbs. Firm cement. PUW 55K, SOW 40K, ROTW48K.;Circulate hole clean, surface to surface at 350 gpm, 1150 psi, 30 rpm, 6000 ft-lbs. MW in 9.2 ppg, MW out 9.2 ppg.;Daily H2O from G&I = 0 bbls, Total = 2190 bbls Daily Fluid to G&I = 65 bbls, Total = 1862 bbls Daily Cutting to G&I = 0 bbls, Total = 328 bbls Daily losses to well = 0 bbls, Total = 60 bbls 11/15/2020 Continue circulate and condition mud @ 2122' MD. 350 gpm, 1190 psi, 30 rpm, 5.6k tq, 55k up, 40k dn w/ 9.2 ppg spud mud.;R/U test equipment Flood lines, purge air. Close upper pipe rams. Pressure up using test pump to 2580 psi. Chart and record same. 2566 psi / 15 min, 2564 psi for final @ 30 min hold. 1 bbl pumped / Bled back 1 bbl. R/D test equipment.;Wash down and drill firm cement from 2122' to 2239' MD. Tagged all float equipment on depth. 450 gpm, 1550 psi, 30 rpm, 7.2k tq, 3-6k wob.;Continue drilling shoe track with and additional 20' new formation from 2244' to 2264' MD. Pump @ 450 gpm, 1550 psi, 30 rpm, 7.2k tq, 3-6k wob.;Pump 25 bbls spacer to minimize interface. Displace 9.2 spud mud with 9.0 6% KCL EZMud @ 450 gpm, 1500 psi. Condition mud w/ 9# In/Out @ 215 gpm, 330 psi.;Pull out of open hole to 2233' (shoe @ 2239' MD / 1836' TVD). R/U test equipment. Perform FIT to 13.5 EMW. 430 psi w/ 9.0# mud. Pump .5 bbls in / .3 bbls out. Chart and record same.;Wash down and drill ahead 8.5" hole F/ 2264' - T/ 2360' (tot =96' AROP=28fph). Drill at diminshed rate to due cold mud over running shakers. Screen down accordingly while still continuing to drill ahead. 395 gpm, 860 psi, 7.2k tq on, 6.6k tq off, 60k up, 3-5k wob. 50k rot, 40k dn.;Drill 8.5" hole from 2360' to 2826' (tot = 466' AROP =78 fph) WOB 4K, 430 gpm, 1020 psi with 25 psi diff, 75 r pms, 8Kft-lbs on btm, 7.2Kft-lbs off. Max gas 15U, ECD's 9.5 ppg with 9.0 ppg mud. PUW 68K, SOW 45K, ROTW 51K.;Drill 8.5" hole from 2826' to 3290' (tot = 464' AROP =77 fph) WOB 1-4K, 455 gpm, 1195 psi with 45 psi diff, 75 rpms, 8Kft-lbs on btm, 7.5Kft-lbs off. Max gas 26U, ECD's 9.49 ppg with 9.0 ppg mud. PUW 73K, SOW 43K, ROTW 53K. Obtain SPR's.;Daily H2O from G&I = 350 bbls, Total = 2550 bbls Daily Fluid to G&I = 740 bbls, Total = 2602 bbls Daily Cutting to G&I = 45 bbls, Total = 373 bbls Daily losses to well = 0 bbls, Total production = 0 bbls Total losses on surface hole = 60 bbls;Distance to WP04: 2.21', 2.04' Low, 0.86' Right Surface cmt job 95/8" . R/U HES cementing gqp p g g gj g p (g ) g equipment, Dual plug quick latch cmt head (Loaded and witness plug install - Shane Barber), R/U manifold and circ hoses.;Break circulation at 84 gpm and stageqp pgq ( pg )gp g up to 260 gpm, 235 psi. Circulating hole clean and conditioning mudto a YP of 17 for cement job PUW 75K, SOW 45K.;Perform cement job. HES pump 5 bblspgpp g g j jpp water to flood lines. PT to 430/3200 psi. Pump 58 bbls 10.5 ppg Tuned prime spacer with 4# of red dye at 3 bpm, 76 psi. Drop bottom plug. Pump 140 bbls 12.0 p p ppg p p y p p p pg p ppg Type I/II lead cement at 4.5 bpm, 120 psi. 10 bbls into lead cement, dry cement hose packed off.;Attempt to clear cement hose. Replace hose and continue ppg yp p p y p p p with cement job. Down 30 minutes. Cement pumps lost prime numerous times while pumping lead cement. Pump 48 bbls of 15.8 ppg Class G tail cement at 4j p p p p p g p ppg bpm, 120 psi. Drop top plug.;Displace with 10 bbls water at 4 bpm, 153 psi followed by 148.5 bbls (153 bbls calculated) of 9.4 ppg Spud mud at 6 bpm. Slow to 2pppppgp pp y ( )ppg p p bpm with 10 bbls to go, FCP 440 psi. Observe spacer returns at 20 bbls into displacing, and cement 110 bbls into displacement.;Bump Plug and pressure up to pgpp pg ppg p 790 psi and hold for five minutes. Check floats, good, bled back 2.5 bbls. CIP at 00:18. No losses during job. 38.5 bbls of cement returned to surface. Install Cactus 16-3/4" x 11" 3/5K Wellhead. Te @gp p Perform FIT to 13.5 EMW. (g ) culation a jg p Shell test - good.;Test BOPE's 250/3500 psi on 4-1/2" test joint. AOGCC Austin McLeod gp g g p j witnessed. F/P on manual choke, HCR kill. Test PVT system. Accumulator draw down starting pressure 3050 psi, final 1375 psi. First 200 psi recharge P/U 9-5/8" fluted hanger. @ gp p p q p ppg p qp Close upper pipe rams. Pressure up using test pump to 2580 psi. Chart and record same. 2566 psi / 15 min, 2564 psi for final @ 30 min hold. ;Install 11" Test plug. N/U 2' riser, Install flowbox p( and pin same. N/U BOP stack (2-7/8"x5" VBR's top & btm). Svc Choke Manifold. Install flowline RIH with landing joint and landout as per Wellhead rep (BHGE) 11/16/2020 Circulate and condition @3290' MD. Rot/Recip. 455 gpm, 1140, 60 rpm, 7.6k tq, 23u max gas. 25 bbls hi vis sweep with no increase in cuttings. Monitor well (static to very slight seepage).;POOH on elevators F/ 3290' - T/ 2236' MD. Pulled clean with no issue entering shoe @ 2239' MD. Proper displacement for trip. 63k up, 53k dn @ shoe.;Serviced rig. B/D TDS & MP's. Grease crown, blocks, TDS, drawworks and washpipe. Inspect rig hydraulics, brake linkeage and driveshaft from drawworks (good).;RIH on elevators F/ 2236' - T/ 3290' MD. Washed last stand down. Trip was clean with no issues. Proper displacement for trip.;Drill 8.5" hole from 3290' to 3416' (tot = 126' AROP =63 fph) WOB 1-4K, 450 gpm, 1220 psi with 30 psi diff, 80 rpms, 8.5Kft-lbs on btm, 7.5Kft-lbs off. Max gas 25u, ECD's 9.59 ppg with 9.05 ppg mud. PUW 75K, SOW 45K, ROTW 55K. Obtain SPR's.;Drill 8.5" hole from 3416' to 3539' (tot = 123' AROP =123 fph) WOB 4K, 465 gpm, 1275 psi with 75 psi diff, 80 rpms, 8.5Kft-lbs on btm, 8.0Kft-lbs off. ECD's 9.59 ppg with 9.05 ppg mud. PUW 75K, SOW 45K, ROTW 55K.;Observe wash pipe leaking. Attempt to grease and tighten - still leaking. Rack back 1 stand, blow down top drive. Install TIW and head pin. Circulate at 118 gpm 197 psi. Change out wash pipe. RIH to 3539'.;Drill 8.5" hole from 3539' to 3850' (tot = 311' AROP =89 fph) WOB 2-6K, 465 gpm, 1330 psi with 100 psi diff, 80 rpms, 9Kft-lbs on btm, 8.5Kft-lbs off. Max gas 32u, ECD's 9.6 ppg with 9.05 ppg mud. PUW 76K, SOW 46K, ROTW 56K.;Drill 8.5" hole from 3850' to 4095' (tot = 245' AROP =81 fph) WOB 2-5K, 465 gpm, 1220 psi with 30 psi diff, 80 rpms, 8.5Kft-lbs on btm, 7.5Kft-lbs off. Max gas 44u, ECD's 9.6ppg with 9.05 ppg mud. PUW 78K, SOW 48K, ROTW 57K.;Service rig. Leaking cap gasket on MP 1 pod 1. Tighten, still leaking, replace gasket. Grease and lubricate drawworks, roughneck. Tighten driveshaft bolts. Circulate on MP 2 at 220 gpm, 390 psi.;Drill 8.5" hole from 4095' to 4281' (tot = 186' AROP =75 fph) WOB 2-5K, 465 gpm, 1350 psi with 50 psi diff, 80 rpms, 9.6Kft-lbs on btm, 8.4Kft-lbs off. Max gas 31u, ECD's 9.7ppg with 9.1 ppg mud. PUW 80K, SOW 50K, ROTW 59K.;Pump high vis sweep (on time, no increase) and circulate hole clean at 450 gpm, 1260 psi, 60 rpms, 9Kft-lbs. Obtain SPR's. Blow down top drive. Monitor well, static. Turn elevators.;POOH from 4281' to 3,231'. No issues, calculated hole fill. PUW 74K, SOW 42K.;Service rig, grease and inspect top drive, iron roughneck.;RIH from 3,231' to 4,281' washing last stand to bottom at 3 bpm, 210 psi. Calculated displacement observed. PUW 75K, SOW 53K. No fill.;Drill 8.5" hole from 4281' to 4467' (tot = 186' AROP =93 fph) WOB 3K, 465 gpm, 1390 psi with 50 psi diff, 80 rpms, 9.6Kft-lbs on btm, 8Kft-lbs off. Max gas 31u, ECD's 9.7ppg with 9.1 ppg mud. PUW 83K, SOW 48K, ROTW 60K. Pump high viscosity sweep at 4281' (25% increase on time).;Daily H2O from G&I = 445 bbls, Total = 2995 bbls Daily Fluid to G&I = 255 bbls, Total = 2857 bbls Daily Cutting to G&I = 105 bbls, Total = 478 bbls Daily losses to well = 0 bbls, Total production = 0 bbls Total losses on surface hole = 60 bbls;Distance to WP04: 9.01', 7.89' high, 4.34' right 11/17/2020 Drill 8.5" hole from 4467' to 4904' (tot = 437' AROP =73 fph) WOB 3K, 465 gpm, 1470 psi, 80 rpms, 11Kft-lbs on btm, 11Kft-lbs off. Max gas 27u, ECD's 9.74ppg with 9.2 ppg mud. PUW 90K, SOW 49K, ROTW 62K. Maintenance slides as necessary to maintain WP04.;Drill 8.5" hole from 4904' to 5337' (tot = 432' AROP =86 fph) WOB 5K, 465 gpm, 1500 psi with 75 psi diff, 80 rpms, 11.8Kft-lbs on btm, 11.5Kft-lbs off. Max gas 86u, ECD's 9.9ppg with 9.2 ppg mud. PUW 94K, SOW 53K, ROTW 63K. Maintenance slides as necessary to maintain WP04.;Circulate bottoms up at 465 gpm, 1250 psi. Flow check - static.;POOH from 5337' to 4215' with no issues. Calculated hole fill 10.2 bbls, actual 11.2 bbls.;Service rig. Inspect and tighten driveline bolts. Grease and lubricate top drive, blocks, crown and drawworks. Inspect brake linkage.;RIH from 4215' to 5337', washing last stand to bottom at 2 bpm, 265 psi. No issues, no fill. Calculated disp 18.3 bbls, actual 17.1 bbls.;Drill 8.5" hole from 5337' to 5648' (tot = 311' AROP =78 fph) WOB 5K, 465 gpm, 1575 psi with 75 psi diff, 80 rpms, 12Kft-lbs on btm, 11.3Kft-lbs off. Max gas 205u, ECD's 9.8ppg with 9.2 ppg mud. PUW 95K, SOW 54K, ROTW 66K. Maintenance slides as necessary to maintain WP04.;Pump 20 bbls high vis sweep at 5337' after wiper trip. Came back on time with 10% increase in cuttings.;Drill 8.5" hole from 5648' to 6019' (tot = 369' AROP = 62fph) WOB 5K, 445 gpm, 1580psi with 30 psi diff, 80 rpms, 12Kft-lbs on btm, 11.5Kft-lbs off. Max gas 151u, ECD's 9.8ppg with 9.2 ppg mud. PUW 102K, SOW 52K, ROTW 68K. Maintenance slides as necessary to maintain WP04.;Stalled out and packed off while backreaming at 5861' (ALD stab in coal). Drop down and re- establish rotary. Cont. backreaming, lowering rotary to 40 rpms, pumps to 400 gpm with multiple stalls from 5861' to 5845' until clean.;Daily H2O from G&I = 180 bbls, Total = 3175 bbls Daily Fluid to G&I = 174 bbls, Total = 3031 bbls Daily Cutting to G&I = 196 bbls, Total = 574 bbls Daily losses to well = 0 bbls, Total production = 0 bbls Total losses on surface hole = 60 bbls;Distance to WP04: 8.32', 8.1' high, 1.92' right. 11/18/2020 Drill 8.5" hole from 6019' to 6331' (tot = 312' AROP = 78fph) WOB 5K, 455 gpm, 1540psi with 40 psi diff, 80 rpms, 13.3Kft-lbs on btm, 12.5Kft-lbs off. Max gas 250u, ECD's 9.8 ppg with 9.2 ppg mud. PUW 112K, SOW 51K, ROTW 70K. Maintenance slides as necessary to maintain WP04.;Circulate bottoms up at 450 gpm, 1480 psi, 80 rpm, 12.5Kft-lbs reciprocating pipe. max gas 171U. Monitor well, static. BD top drive.;POOH from 6,331' to 5275'. Tight at 5,530' with 20K overpull, wipe clean. RIH one stand to 5,333'. Calculated hole fill 7.2 bbls, actual 9 bbls.;Service rig: check linkage on dr iveline bolts. Grease and inspect draworks, top drive, blocks and crown.;RIH from 5,333' to 6331', washing last stand down. No issues. Calc displ. 17.1 bbls, actual 16.8 bbls.;Drill 8.5" hole from 6331' to 6702' (tot = 371' AROP = 82fph) WOB 4-7K, 455 gpm, 1600psi with 50 psi diff, 80 rpms, 14.8Kft-lbs on btm, 14.4Kft-lbs off. Max gas 202u, ECD's 9.8ppg with 9.2 ppg mud. PUW 115K, SOW 54K, ROTW 69K. Maintenance slides as necessary to maintain WP04.;Pump 25 bbls high vis sweep at 6,331', 50% increase in cuttings, 10 bbls late.;Drill 8.5" hole from 6702' to 7198' (tot = 496' AROP = 82fph) WOB 2-8K, 455 gpm, 1700psi with 100 psi diff, 80 rpms, 16.4Kft- lbs on btm, 14.5Kft-lbs off. Max gas 246u, ECD's 9.8ppg with 9.2 ppg mud. PUW 122K, SOW 55K, ROTW 70K. Maintenance slides as necessary to maintain WP04.;Just after a connection, Rig lost power, Troubleshoot. Gen #2 overcurrent. Attempt to work pipe while working on generators, pull 40K over without breaking over; out of room in derrick. Unable to break out due to loss of power. Get gen power working Establish rotary to break pipe.;Drill 8.5" hole from 7198' to 7340' (tot = 142' AROP = 57fph) WOB 5K, 455 gpm, 1730psi with 75 psi diff, 80 rpms, 15.5Kft-lbs on btm, Max gas 43u, ECD's 9.8ppg with 9.2 ppg mud. PUW 133K SOW 58K, ROTW 78K. Maintenance slides as necessary to maintain WP04.;At 7340' lost all returns. Rack one stand back to 7320'. Turn hole fill on and line up to kill line. Pull 40K over, without breaking over. Pick up working single, still trying to fill back side. Wor k pipe pulling 20-30K over and setting down 30K. Pump 100 bbls LCM pill down drill pipe,;310 bbls to fill hole. Circulate 197 gpm, 512 psi with partial returns. Observe gas coming up to 2700U. Shut annular and line up to gas buster to prevent gassing up mud and pits. Pumped 14.5 bbls to fill choke and gas buster. ICP=340 at 2.3 bpm, stage up to 3bpm, 490 psi, max gas 670 U. ~30% returns;Daily H2O from G&I = 450 bbls, Total = 3625 bbls Daily Fluid to G&I = 0 bbls, Total = 3031 bbls Daily Cutting to G&I = 400 bbls, Total = 974 bbls Distance to WP04: 5.98', 0.23' Low, 5.97' Right ;At 7340' lost all returns Drill 8.5" hole from 6019' to 6331' ( Drill 8.5" hole from 4467' to 4904' (tot = 11/19/2020 Cont. to circulate bottoms up through gas buster to minimize gas in mud at 3 bpm, 490 psi. Shut down, verify no pressure and open annular.;Pump 22 bbl lube pill and spot outside of bit. Work pipe 250K up, 20K down attempting to work torque down string, pumping lube pill up hole in 2 bbl increment. Pump second pill and continue to work pipe.;Cont. to work pipe, 255K up, 20K down, working torque down string stalling out at 18Kft-lbs. Pump 50 bbls LCM pill and work pumps up from 3.5 bpm to 7 bpm 935 psi. Loss rate ~5 bph.;Pump 22 bbls of diesel and spot 5 bbls outside of bit. Continue working pipe 255K up, 20K down with and without torque. Circulate 5 bbls every 15 minutes until diesel completely out of bit. Continue working pipe moving diesel pill up hole at 1.5 bpm, 140 psi.;Once diesel is above lower pressured zones at 5500'MD, circulate out diesel pill. Stage pumps up to 7 bpm, 900 psi, max gas 23U. CBU. Loss rate 5 bph. Sim Ops : perform derrick inspection and grease crown, blocks and drawworks.;Rig up and spot 50 bbls diesel out side of bit, pump diesel at 2 bpm, 446 psi, chase with mud at 5 bpm, 492 psi.;Continue to work string while pumping diesel uphole at 1.5 bpm, 80 psi. Work pipe, pulling up to 250K, slacking off to 20K while attempting to rotate. Bring diesel pill up to 3300' - 4300', above top of lower pressure zones at 5500'MD.;Circulate diesel out of hole and 2 x BU staging pumps up to 10 bpm, 1485 psi. Max gas 32U. Perform derrick inspection. Check drilling line. Tighten driveshaft bolts, grease drawworks.;Continue working pipe with and without torque, 250K up max, 20K down. Pumping 4 bpm, 430 psi.;Daily H2O from G&I = 640 bbls, Total = 4265 bbls Daily Fluid to G&I = 0 bbls, Total = 3031 bbls Daily Cutting to G&I = 270 bbls, Total = 1244bbls Daily losses to well = 583 bbls, Total production = 583 bbls Total losses on surface hole = 60 bbls 11/20/2020 Cont. to work pipe 250K up, 20K down working torque down string. Pumping 4 bpm, 430 psi.;Circulate hole clean, staging pumps up to 460 gpm, 1660 psi. Max gas 29U. No losses. Perform derrick inspection, measure bales and prep for free point run. Remove elevators. Pick up 6' Bale extensions.;Rig up E-line. Install 5" elevators. M/U TIW, 4.5" IF XO, pup joint, pump in sub and pack off. M/U to stump. Rig up E-line sheave.;RIH with free point tool on E-line, calibrate and test at 1997' in free pipe. RIH to 2278', below casing shoe and determine pipe is stuck. Move up hole, and determine free point at 2258'. POOH with W- line.;Rig up tongs and slips for back-off operations. RIH with string shot. Put 1-1/4" turns in pipe with rotary and rig tongs, work torque down between 30K and 70K. Set pipe in nuetral at 50K. Correlate string shot on depth at tool joint at 2179', fire string shot. Observe pipe rotate on surface.;POOH with E-line. Remove XO assembly from stump. C/O elevators to 4.5". M/U TD to stump, rotate to the left and pick up off fish. PUW 44K, SOW 41K. Fish at 2179'.;Rig down E-Line. Break out adn L/D working single. Remove elevators and bail extensions. R/D E-line sheave. Break down TIW and XO's.;Circulate bottoms up, staging pumps up to 10 bpm, 214 psi, max gas 21U. Blow down top drive and mud lines.;POOH from 2179' to surface. Check torque on all connections. Inspect threads on last joint, slight galling. Calc hole fill 11.5 bbls, actual 16 bbls.;Perform drill line inspection. Verify pipe count. TOF 2179'.;Bring fishing BHA to rig floor. Check OD, ID, Lengths and fishnecks of all components. M/U fishing BHA: screw in sub, XO, drilling jars, XO, (8) drill collars,XO's, Intensifier, XO's.;RIH with fishing assembly from 299' to 690'. PUW 52K, SOW 50K.;Daily H2O from G&I = 90 bbls, Total = 43555 bbls Daily Fluid to G&I = 245 bbls, Total = 3827 bbls Daily Cutting to G&I = 0 bbls, Total = 692bbls Daily losses to well = 32 bbls, Total production = 615 bbls Total losses on surface hole = 60 bbls 11/21/2020 Cont to RIH on elevators from 690' to 2159'. Pick up working single and wash down to top of fish at 2179', tagged on depth. Engage fish with rotary, observe torque stall. PUW 50K, SOW 50K, ROTW 45K.;Circulate bottoms up through drilling BHA (MWD detection) at 450 gpm, 1630 psi. Max gas 30U.;Work stuck pipe. Begin firing jars down and trying to work tq down with no success. Start firing jars up with and without tq. Max pull 260K, set down 15K, TQ stalled at 18Kft- lbs.;Circulate bottoms up at 450 gpm, 1625 psi, max gas 31U. Perform derrick inspection; crown, top drive, deadman, blocks.;Continue to work stuck pipe Max pull 260K, set down 15K, TQ stalled at 18Kft-lbs. Observe jars stop firing with overpull, start firing jars down several times and then stopped firing.;Circulate hole at 420 gpm, 1430 psi, Max gas 34U while Pollard E-line mobilizes to location.;Rig up to perform backoff with string shot. Rig up bail extensions, derrick sheave , M/U TIW, XO and wireline pack-off. Rig up E-Line sheave. Rig up tongs and slips. RIH with string shot. Put 1-1/4 wraps in pipe using rotary table and holding with tongs. Fire string shot at 2179'.;Observe pipe on surface rotate. POOH with E-line. Pick up on pipe PUW 45K. SOW 41K.;R/D E-line. Remove elevators and bail extensions. Install 4.5" elevators. Rig down WL sheave from derrick. Break down TIW and XO's. Rack 1 stand back to 2089'.;Observe broken bolts on brake bands and multiple pads shifted free. Hang off blocks and change out both brake bands on drawworks.;Cut and slip 62' of drilling line. Brak in new brake bands. Set block height and check crown saver. Inspect drawworks and kick back rollers.;Cont working on top drive. Turn link pins and install retainer plate. Adjust drawworks brakes.;POOH on elevators from 2,089' to 299'. Calculated hole fill. PUW 43K, SOW 46K.;L/D single. C/O elevators. L/D intensifier. Rack back 4 stands of drill collars. L/D jars. Inspect screw in sub.;M/U fishing BHA #2. P/U fishing jars and bumper sub. RIH with 4 stands of drill collars. P/U intensifier. C/O elevators.;RIH with BHA. P/U single. RIH on elevators from 294' to 915'. PUW 40K, SOW 38K.;Daily H2O from G&I = 0 bbls, Total = 4355 bbls Daily Fluid to G&I = 0bbls, Total = 3827 bbls Daily Cutting to G&I = 0 bbls, Total = 692bbls Daily losses to well = 12 bbls, Total production = 627 bbls Total losses on surface hole = 60 bbls 11/22/2020 Cont. to RIH on elevators from 915' to 2123' PUW 50K, SOW 40K, ROTW45K. Kelly up and wash down to TOF at 2,179', tagged on depth. Engage fish, rotate into fish and TQ stall at 17Kft-lbs.;Work pipe attempting to free fish. Work pipe down using bumpers, down to 20K. Pick up to 175K and fire jars then straight pull to 260K. Unable to gain any movement.;Circulate bottoms up at 11 bpm, 1651 psi, max gas 25U. SimOps: Perform derrick and drawworks inspection. Grease crown, blocks, top drive, and drawworks.;Rig up E-Line. Blow down top drive and mud lines. Rig up bail extensions, derrick sheave. M/U TIW, XO and packoff to stump.;Rig up tongs and slips. RIH with string shot on E-Line. Put 1-1/4 wraps in pipe with rotary table and work torque down using tongs to hold torque. Correlate and fire string shot at 2179'. Observe pipe on surface rotate. Remove XO assembly from stump. Rotate to the left and verify successful.;Rig down E- line. Remove elevators and bail extensions. Install 4-1/2" elevators. Rig down E-line sheave. Breakdown TIW and XO's.;POOH on elevators to 294'. PUW 33K, SOW 32K.;L/D BHA. C/O elevators. L/D intensifier. Rack back 4 stands of drill collars. L/D jars, screw in sub.;Clean and clear rig floor. Change elevators, and P/U handling equipment.;M/U fishing BHA #3: Smooth ID shoe, XO, 4 joints of washpipe, drive sub, bumper sub, fishing jars, XO (8) drill collars from derrick, XO's intensifier, XO's.;RIH with wash pipe from 426' to 2158'. Obtain parameters: PUW 50K, SOW 40K, ROTW 45K; 215 gpm 143 psi, 20 rpms 4500 ft-lbs, 40 rpms, 5000 ft-lbs.;Wash down to top of fish at 215 gpm, 143 psi. tag TOF at 2179'. Establish rotary at 20 rpms, slack off over TOF. Wash and ream over fish from 2179', at 215 gpm, 143 psi, 20rpms, 4.5Kft-lbs. Tag up at 2233', observe torque increase to 7Kft-lbs.;Continue to wash and ream from 2233' to 2272' at 40 rpms, 6-16Kft-lbs, 290 gpm, 300 psi with 3-5K WOB. Observe mostly sand with trace cement come over shakers.;Daily H2O from G&I = 0 bbls, Total = 4355 bbls Daily Fluid to G&I = 0 bbls, Total = 3827 bbls Daily Cutting to G&I = 0 bbls, Total = 692bbls Daily losses to well = 25 bbls, Total production = 652 bbls Total losses on surface hole = 60 bbls p Fire string shot at 2179'. Stuck BHA Unable to gain any movement. pp pp pipe, pulling up to 250K, slacking off to 20K while gp p Rig up E-Line sheave. Rig up tongs and slips. RIH with string shot. Kelly up and wash down to TOF at 2,179', tagged on depth. gp p gp p RIH with string shot on E-Line. Put 1-1/4 wraps in pipe with rotary table and work torque down using tongs to hold torque. pgpg p Correlate and fire string shot at 2179'. O ppj p p p RIH to 2278', below casing shoe and determine pipe is stuck. 11/23/2020 Continue milling over fish with washpipe from 2272' to 2276', 290 gpm, 320 psi, max gas 16U, 30-70 rpms, 6-11Kft-lbs, WOB 4K. Observe little progress at 2276, increase WOB up to 10K, and 70 rpms with minimal increase in torque.;Monitor well, static. POOH from 2,276' to 426', calculated hole fill.;C/O elevators, L/D intensifier, rack back 4 stands of drill collars. L/D jars and bumper sub. Rack back wash pipe. Observe mill shoe not on BHA, left in hole.;L/D 4 joints of wash pipe from derrick.;Clean and clear rig floor, perform derrick inspection. Grease crown, blocks, top drive, drawworks, iron rouhgneck. C/O oil and filters on drawworks motor. Prep tongs for 6" wash pipe while waiting on wash pipe. ID wash pipe and OD drill pipe tool joint, wash pipe will not fit over hardbanding.;M/U Fishing BHA #4: screw in sub, XO, Jars with bumper sub, (9) joints of spiral drill collars, intensifier. Change out elevators.;RIH on elevators to 2123', M/U 5' pup and wash down to TOF at 2179'. Engage fish at 20 rpms and observe torque stall. PUW 52, SOW 44K, ROT 48K.;Circulate bottoms up at 11 bpm, 1850 psi, max gas 27U.;Work pipe, jarring from 180K to 230K with 280K straight pull with and without torque, at 3 bpm, 355 psi. No progress.;Circulate hole at 11 bpm, 1680 psi. Max gas 23U. Perform derrick and drawworks inspection.;Continue working pipe, jarring at 235K with straight pull to 280K, no progress.;AK E-Line on site, minimum RCT to cut CDS40 is 2.5" OD, jar ID 2.25" Circulate bottoms up at 11 bpm, 1620 psi. Sim Ops, remove elevators, install bail extensions, install elevators.;Back off operations. Hang sheave in derrick. M/U TIW, XO, pup jt, packoff onto stump. RIH with string shot on E-line.;Daily H2O from G&I = 0 bbls, Total = 4355 bbls Daily Fluid to G&I = 90 bbls, Total = 3917 bbls Daily Cutting to G&I = 0 bbls, Total = 692bbls Daily losses to well = 26 bbls, Total production = 678 bbls Total losses on surface hole = 60 bbls 11/24/2020 PJSM RIH W/ string shot. Put 1.5 wraps of left hand trq into string using rotary table. P/U out of slips and work trq down string P/U 70K SLK 25K park W/ 40K on weight indicator. Space out string shot across screw in sub at 2,179' ELM. Fire shot, no movement observed. Apply left hand trq, work;trq out of string. POOH W/ C/O string shot. RIH to 2,210' to 2,206' ELM. Work 1.5 wraps LH trq in string. Work trq down P/U 70K SLK 30K. Locate bumper sub stroke and set down 5K. Fire shot, observed pipe slack down. Successful back off. POOH W/ ELine.;PJSM Break down ELine tools. Set slips and reverse string W / rotary table and P/U observed free pipe. L/D 5' pup. C/O tong heads and break out TIW, X/O and 3.5' pup. L/D elevators and bale ext. Install 4.5" elevators. Monitor well, static.;POOH racking back in derrick 4.5" D.P. 2,211' to 324' MD.;PJSM L/D BHA C/O elevators to 5". L/D Intensifier, rack back 4 stands and 1 jnt spiral collar. L/D Jars, bumper sub, screw in sub and X/O. Clean and clear rig floor. C/O elevators to 4.5".;RIH on elevators W/ 4.5" D.P. to 2,170' MD. Wash down F/ 2,170' to 2,211' MD. Tag TOF. 2 bpm 168 psi set down 5K and saw Press increase 250 psi. P/U 38K SLK 35K.;PJSM R/D ELine Sheave. L/D 1 jnts F/ string. P/U 5' pup, TIW, pump in sub and X/O to 15' pup. M/U to string. Establish free trq 2.5K. Slack down 5 K on TOF 2,211' MD. Rotate @ 3 rpm 4 3/8 wraps in string and see 3.9K trq increase. Stage up pumps to 11 bpm 1,678 PSI matched previous circ parameters.;Indicating successful make up to fish.;Circ & cond CBU 2X 10 bpm 1,400 PSI RF 30% Max Gas 21U.;Decision was made to cement BHA and 750' above Pool 6 zone. Wait on cement plan and cementers to show up on location. Circ 5 bpm 500 PSI RF 16% Max Gas 25U. Loss rate 1.5 bph. SIMOPS Perform Derrick inspection, Drawworks, grease crown, blocks, top drive, iron roughneck & handling Equip.;Cont circ 5 bpm 500 PSI. Halliburton on location 00:00. R/U Halliburton hard lines, HP hoses and cement manifold on rig floor.;PJSM Shut down pumps. Unscrew TD, shut TIW and load wiper ball. M/U TD. R/U cement line to 1502 pump in sub. Halliburton pump 5 bbls H2O and test low kick out 761 PSI, 4135 PSI high. Pump 5 bbl H2O 3 bpm 396 PSI. Cement 63 bbls 14# Lead cmt, 1.525 yld, 3 bpm ICP 420 PSI 3.5 bpm FCP 118 PSI.;Displace w/ 2 bbls H2O. Open TIW loaded W/ wiper ball. Turn over to rig. Rig disp w/ 85.35 bbls 8.75 ppg mud, 5 bpm caught press at 15 bbls away ICP 51 PSI. Cont pumping 5 bpm to 65 bbls away 702 PSI. Slowed pumps to 3 bpm ICP 480 PSI. At 78 bbls away Press climbed to about ~750 PSI when it appeared;jars fired, Press max ~930 PSI slowed pumps to 1.5 bpm 606 PSI. No change in flow out or string weight. Cont pumping at 1.5 bpm FCP 594 PSI to 85.35 bbls 1 bbl under displacement. CIP at 03:27. Lost 2.5 bbls for entire job. Broke off low trq and checked for balanced, static.;PJSM R/D Halliburton cement lines and release. Monitor hole W/ trip tank, static.;PJSM Break out and R/D X/O, Pump in Sub, TIW & 5' pup. Blow down TD. WOC.;Daily H2O from G&I = 0 bbls, Total = 4355 bbls Daily Fluid to G&I = 0 bbls, Total = 3917 bbls Daily Cutting to G&I = 0 bbls, Total = 692bbls Daily losses to well = 25 bbls, Total production = 703 bbls Total losses on surface hole = 60 bbls 11/25/2020 WOC Monitor well W/ TT ~1 bbl static loss rate. Inspect drawworks and drill line. Clean and clear rig floor. Service/ Inspect Iron Roughneck & Skate.;PJSM M/U X/O & Bowen. Hang wireline sheave in derrick. P/U packoff and M/U 1.69" WT Bar and CCL BHA. RIH W/ BHA and install pack off. RIH to 5,996' ELM and WOC till 12:00. House keeping around rig. Cont monitor well W/ TT ~1 bph static loss rate.;PJSM RIH W/ ELine BHA to 7,192' ELM W/O tagging cement/ wiper ball. POOH and attach 2.1" OD sample bailer. RIH W/ bailer and tagged again at 7,192' ELM. POOH checked bailer, smelled of cement not even signs of red dye. R/D pack off and set wireline back.;PJSM M/U to drill string and break circ at .75 bpm Press up to 400 PSI and shut down. Press bled slightly then dumped after approximately 1 min. Broke Circ W/O seeing DP Press. Broke out to check DS appeared to have static loss. Make back up to stump and Circ 1.3 bpm took ~10 bbl to catch Press at;112 PSI. Cycling pumps at 1.3 bpm every 15 min catching Press at 112 PSI to keep string full. Total of 4X for 40 bbls lost in string. Total pumped down string 72 bbls. Cont monitor well W/ TT ~1 bph static loss rate.;PJSM Break and blow down top drive. M/U pack off and RIH W/ CBL. Found fluid top at~750' ELM. Calibrate tools. Log down W/ CBL F/ 1,840' to 6,678' ELM at 80 ft/min. Saw first sign of cement at 5,648' ELM with minimal traces. Saw high side cement F/ 5,862' to 6,670' ELM unable to read thru HWDP.;Logged out of hole same.;Cont POOH. Remove pack off and L/D BHA. Break down tools and R/D ELine. Remove sheave F/ derrick.;Decision was made to cement off drill string F/ 7,333' to TOC~5,532' MD W/ 20 bbls cement. R/U X/O, pump in sub, XO, TIW and 5' Pup to stump. Cont monitor well W/ TT static loss rate ~1 bph. Filling drill string at 1.3 bpm catching Press at 113 psi every 30 min W/ 5 bbls. Total 44 bbls.;Halliburton blending at plant. Clean and organize around rig. Added gear oil to MP 1&2. Full service on MP's. Plumbed in dry air to MP #2. Heating H2O for cement job.;PJSM R/U Halliburton HP lines and manifold on rig floor. Run wash up line to cutting tank.;Daily H2O from G&I = 260 bbls, Total = 4595 bbls Daily Fluid to G&I = 52 bbls, Total = 3969 bbls Daily Cutting to G&I = 0 bbls, Total = 692bbls Daily losses to well = 92 bbls, Total production = 795 bbls Total losses on surface hole = 60 bbls gg p / derrick.;Decision was made to cement off drill string F/ 7,333' to TOC~5,532' MD W/ 20 bbls cement. Continue milling over fish with washpipe from 2272' to 2276', 290 gpm, 11/26/2020 Shut in TIW, unsrew top drive and load wiper ball. M/U top drive, Halliburton HP cement line to pump in sub.;PJSM Hal liburton pump 5 bbls H2O and test low kick out 830 PSI, 4,070 PSI high. Pump 5 bbl H2O 2 bpm 285 PSI. Cement 20 bbls 15.8# Premium G Lead cmt W/ 15 ppb LCM & red dye, 1.174 yld, 2 bpm ICP 265 PSI FCP 54 PSI. Displace w/ 2 bbls H2O. Open TIW loaded W/ wiper ball.;Turn over to rig. Rig disp w/ 75.5 bbls 8.75 ppg mud, 3 bpm ICP 225 PSI. Cont pumping 3 bpm to 69 bbls away 338 PSI. Slowed pumps to 1.4 bpm FCP 574 PSI. Shut down and hold 500 PSI for 60 min on chart. CIP @ 08:02. Bled back 0.5 bbls to TT.;SIMOPS B/D cement lines and wash up lines. R/D cementers.;PJSM Break off X/O, Pump in, X/I, TIW & 5' pup. M/U top drive and pump 0.3 bbls 460 PSI and hold until AK ELine arrived at 10:00. Bled back 0.3 bbls to TT. Break out blow down.;PJSM M/U X/O. R/U AK Eline sheave to elevators. P/U pack off W/ ELine and M/U CCl and weight bar RIH tag TOC 5,945' ELM. Monitor well W/ TT static loss 0.7 bph.;PJSM POOH W/ ELine. Make up RCT and RIH. Correlate, set depth at 5,438' ELM. String in tension W/ 5K and make cut. Observed line jump. POOH W/ RCT and L/D ELine tools and Equip.;M/U top drive and back off fish. L/D 15' pup.;PJSM Service rig. Replace broken stainless steel grease line on Drawworks. Fix rotary table ghosting from doghouse controls. Grease crown, blocks, top drive and iron roughneck.;PJSM POOH racking back 4.5" D.P. F/ 2,211' to surf. Clean and clear rig floor. C/O elevators to 5" and prep for jarring BHA. Lost 4 bbls for trip.;Rig crew partake in Thanksgiving Dinner.;PJSM P/U working single M/U X/O, Jars, bumper sub, 4 stands and a single 6.25" Spiral Collars, intesifier and 4 jnts 4.5" HWDP BHA 475' MD. Drift off skate 2.3" rabbit. P/U 36K SLK 39K.;PJSM RIH W/ 4.5" D.P. F/ 475' to 2,150' MD. P/U 5' pup and M/U stand 28. Wash down at 2 bpm 91 PSI and tag TOF 2,211' MD Press increased to 730 PSI. P/U rack back 1 stand. L/D 5' pup. P/U M/U 15' pup and stand 28. Wash down at 1.5 bpm tag 2,211' MD Press increased to 730 PSI. P/U 50K SLK 45K.;PJSM Shut down pumps. Rotate 20 RPM easing down on TOF till string stall at 17K TRQ. Work Trq down 30-55K 5X. Turn on pumps 0.75 bpm and Press up to 1,330 PSI, after 5 min 1,214 PSI stabilized. Bleed off Press. Start jarring operations. Pull 50K over string weight to 150K and firing jars.;Straight pull to 260K. Stage firing jars up F/ 150K to 235K and staging up straight pull after jars fire to 280K with no movement. Attempt to pump at 1 bpm Press up to 1,458 PSI held for 5 min final Press 1,327 PSI. Notified AK ELine to come to location.;Back out top drive and blow down all surface Equip. Perform derrick inspection and post jarring inspection. Found loose service loop clamp on top drive. R/D elevators and R/U bail Ext.;Service rig. Grease crown, top drive and drawworks.;PJSM P/U M/U TIW & X/O's for Eline. R/U AK ELine sheave in derrick. R/U ELine tools and Equip.;PJSM P/U CCl and 400 gram String shot BHA. RIH and set pack off. Cont RIH W/ string shot correlating W/ CCL to 2,211' ELM.;Daily H2O from G&I = 180 bbls, Total = 4775 bbls Daily Fluid to G&I = 80 bbls, Total = 4049 bbls Daily Cutting to G&I = 0 bbls, Total = 692bbls Daily losses to well = 161 bbls, Total production = 956 bbls Total losses on surface hole = 60 bbls 11/27/2020 Cont correlate CCL and string shot. Decision was made to shoot shot at 2.270' ELM. Apply 8.6K LH trq W/ rotary table and hold back trq W/ rig tong. Work pipe F/ 70K to 30K working down trq. ELine confirmed fire and trq fell to zero at rig floor. POOH and L/D Eline.;Left in hole 139 jnts 4.5" D.P., 17 jnts 4.5" HWDP, X/O CDS 40 B X 4.5" IF P, 6 3/4" Jars, X/0 and BHA #2 318'.;PJSM POOH F/ 2,270' to 353' MD. P/U 35K SLK 35K. Lost 2.4 bbls for trip.;PJSM L/D Intensifier, X/O, 5 jnts 6.25" spiral collars. bumper sub, Jars, X/O and working single. L/D 2 recovered jnt from abandon string. Clean and clear rig floor.;PJSM Drain Stack. P/U 4.5" test jnt M/U wear ring puller. BOLDS. Pull wear ring.;PJSM M/U test pug and set. M/U 4.5" TIW, Dart, test sub to TD and HP hoses. Flood and purge air through BOPE. Shell test to 1,500 PSI.;PJSM Perform BOPE test W/ 4.5" to 250 PSI low and 3,500 PSI high for 5 Min. Annular, Tested Choke Manifold valves 1- 13, 4.5" Dart, 4.5" TIW, Upper and lower IBOP, Mez Kill, HCR and manual Choke and Kill, Upper and lower VRB Rams (2,875" X 5.5") Blind Rams and manual choke.;Koomey draw drown Initial System: System 3,000 PSI, Manifold 1,200 PSI, Annular 1,100 PSI, after System 1,450 PSI, Man 1,400 PSI, Annular 1,290 PSI. 200 PSI increase 30 Sec, full charge 111 sec. Nitrogen 4 bottle average 2,500 PSI. Witnessed waived by AOGCC Rep Jim Regg.;Observed leak on spacer spool on test #3 of the high. Tighten studs and continued testing.;Cont testing BOPE. Re adjust actuator on Super Choke and tested good. Test PVT high/ low level alarms. R/D and blow down test Equip.;Pull test plug and check well bore fluid level, it took 3 bbls to fill. Installed test plug.;Bleed down Koomey and safe out. Installed neck down 1.25" to 1" hard line and install dampener to KR valve. Load and strap 4.5" HWDP & D.P. Pull test plug and install wear ring.;Load and strap 4.5" HWDP & D.P. Pull test plug and install wear ring. (9.125" ID 10.875" OD).;Daily H2O from G&I = 0 bbls, Total = 4775 bbls Daily Fluid to G&I = 90 bbls, Total = 4139 bbls Daily Cutting to G&I = 0 bbls, Total = 692bbls Daily losses to well = 20 bbls, Total production = 976 bbls Total losses on surface hole = 60 bbls 11/28/2020 PJSM Cont processing and strapping 4.5" D.P. Total 140 jnts.;PJSM Single in hole 4.5" D.P. using break in procedure on re cut connections to 1,430' MD. Rabbit off skate 3.82" OD. Quadco tested H2S & LEL alarms.;PJSM Cont single in hole 4.5" D.P. using break in procedure on re cut connections to F/ 1,430' to 2,180' MD. Rabbit off skate 2.3" OD. P/U 40K SLK 36K POOH rack back F/ 2,180' to Surf. Lost 8 BBLS for trip.;Rig service. Grease crown, blocks, top drive, wash pipe, iron roughneck, Drawworks and handling Equip. Inspect Drawworks.;PJSM P/U M/U Baker cement retainer assy 17.1 '. Single in hole 10 jnts 4.5" CDS 40 D.P. & rabbit. Cont RIH W/ 4.5" F/ derrick to 2,185' MD. P/U 39 SLK 37K.;Set cement retainer as per Baker rep onsite. P/U to 2,2,27' MD. Rotate 10 wraps to right Trq 1.4K. SLK off to set depth 2,231' MD. P/U to 75K SLK to 15K, P/U to 80K SLK to 15K 2X. Slack to 40K. Rotate 15X to right Trq 1.5K. P/U and released W/O issue. Top of cement retainer 2,231' MD.;PJSM Break Circ at 5 bpm 105 PSI CBU. Latch into retainer 0.75 BPM 0 PSI. Attempt to establish ejection rate. Caught press at 2 bbls away injected 18.3 bbls at 267 PSI. Shut down for 10 min Press dropped F/ 267 PSI to 154 PSI. Bled off and bled back 2.4 bbls. Started injection rate at 1.5 bpm.;injected 23.3 bbls at 390 PSI continuing to climb. Shut down for 10 min Press drop F/ 390 PSI to 242 PSI almost stable. Bled back 3.3 bbls. Injected a total of 35.9 bbls. MW 8.8 FIT 13.5 ppg at 1,836' TVD. Max press for shoe 448 PSI. P/U unlatch from retainer.;Rack back 1 stand and R/U test Equip. X/O, Pump in sub, X/O & TIW W/ HP test lines.;PJSM Press test 9 5/8" Csg and cement retainer to 2,550 PSI bled down to 2,537 PSI after 30 min on chart. Pumped at 0.75 bpm pumped 1.6 bbls bled back 1.3 bbls.;PJSM blow down test Equip and lines. R/D test Equip.;PJSM P/U 15' pup and working single. R/U X/O, side entry sub, X/O and TIW for cement job. Spot Halliburton Equip and R/U HP lines and manifold on rig floor.;Daily H2O from G&I = 0 bbls, Total = 4775 bbls Daily Fluid to G&I = 50 bbls, Total = 4189 bbls Daily Cutting to G&I = 0 bbls, Total = 692bbls Daily losses to well = 20 bbls, Total production = 996 bbls Total losses on surface hole = 60 bbls SLK off to set depth 2,231' MD. P/ g ;Cont testing BOPE. cement in RA BHA p Press test 9 5/8" Csg and cement retainer to 2,550 PSI bled down to 2,537 PSI g MW 8.8 FIT 13.5 ppg at 1,836' TVD. y qgg pp ;Left in hole 139 jnts 4.5" D.P., 17 jnts 4.5" HWDP, X/Ogq CDS 40 B X 4.5" IF P, 6 3/4" Jars, X/ pp pp Cement 20 bbls 15.8# Premium G Lead cmt W/ 15 ppb LCM & red dye, yg K 37K.;Set cement retainer as per Baker rep onsite. P/U to 2,2,27' MD. 11/29/2020 PJSM Cont spotting and rigging up Halliburton cementers Equip.;PJSM R/D cement assembly and manifold F/ rig floor. Halliburton going back to blend Premium G cement for plug due to long set time of original. Prep to POOH and L/D retainer running tool.;PJSM POOH F/ 2,227' MD and rack back in derrick. L/D Baker running assy.;PJSM RIH open ended W/ 4.5" D.P. to 2,227' MD. P/U 39L SLK 37K.;PJSM R/U X/O side entry and TIW for cement job. R/U Halliburton cement manifold on rig floor and lines.;PJSM, Wet lines w/ 5 bbls H2O (HES) and P/T 3000 high, Pump 12 bbls 15.8# Premium G, 1.16 yld (58 sx) 3.3 bpm ICP 158 PSI FCP 166 PSI. Pump 2 bbls H20 displace w/ 25.3 bbls 8.8# mud, 4 bpm caught Press 12 bbls away FCP 101 PSI. Shut down 2 bbls early, calculated was 29.3 bbls.;Break out of top drive and disconnect cement line. Break down pump in stub and X/O. POOH at 30 fpm racking back 5 stands to 1,938’ MD. Observed first to stands weight and came dry for last 3 stands. CIP @ 13:01.;PJSM Drop wiper ball and break Circ at 10 bpm 178 PSI CBU 2X. Recovered wiper ball at surface. Blow down top drive SIMOPS Blow down and R/D Halliburton lines and Equip. Break X/O pump in sub and TIW.;PJSM POOH F/ 1,938' to surf.;PJSM P/U M/U 8.5" PDC Bit, bit sub, watermelon mill, jars, X/O and 10 jnts 4.5" HWDP to 366' MD. Use break in procedure for HWDP. Rabbit 2.37" OD.;Cont RIH W/ 4.5" D.P. F/ 366' to 1,961' MD.;PJSM Service rig. Grease crown, blocks, top drive, wash pipe. Iron roughneck and handling Equip.;WOC Perform derrick inspection, adjust brake handle and house keeping around rig.;Sample cup of cement looked to be setting up. Break Circ st 5 bpm 156 PSI. Wash down F/ 1,962' to 2,084' MD. At 2,070' estimated TOC wt increased ~1K and 10 PSI increase of Press. POOH to 2,020' MD CBU 5 BPM 166 PSI dumping 40 bbls contaminated mud and green cement at shakers.;Rack back stand to 2,020' MD. WOC.;WOC Blow down top drive and surface lines. Perform misc rig maintenance and house keeping.;WOC Change out dies and inspect handling Equip. Level pipe racks on skate. Clean and organize cellar and catwalk.;PJSM Wash down F. 2,084' to 2,087' MD 1 bpm 170 PSI with out seeing wt or change in pump press. POOH to 2,080' CBU at 7 bpm 320 PSI with slight green cement at surface. W OC to get to 2,101' MD to set anchor for whipstock and keep 100' of cement above cement retainer.;WOC Perform house keeping around rig. Rebuild dog collars and slips for whipstock run.;Daily H2O from G&I = 90 bbls, Total = 4865 bbls Daily Fluid to G&I = 135 bbls, Total = 4324 bbls Daily Cutting to G&I = 0 bbls, Total = 692bbls Daily losses to well = 35 bbls, Total production = 1031 bbls Total losses on surface hole = 60 bbls 11/30/2020 Wash down 1 bpm 70 PSI F/ 2,087' to 2,107' taking 10-15K. Picked up and CBU 7 bpm 300 PSI saw cement returns at surface. Cont wash & ream down F/ 2,107' to 2,112' MD 7 bpm 200-300 PSI 50 RPM 6.5K Trq and WOB 2-5K. CBU at 2,112' 7 bpm 300 PSI W/ good cement at surface. Wash down and tag 10K.;PJSM POOH F/ 2,112' to 170' MD P/U 45K SLK 39K.;PJSM Rack back 4." HWDP and L/D Jars. L/D single jnt 4.5" D.P. X/O. bit sub and bit.;PJSM Load catwalk W/ Baker whipstock components. P/U 1 Jnt HWDP, X/O, 8.5" Upper mill assy, 6.375" Flex Jnt, 8.375" Lower mill and 8.5" Window Mill. P/U Whipstock W/ tugger and set in rotary table. M/U 35K Shear bolt F/ window mill to slide. Anchor shear set 2 pins 12K.;Cont RIH Whipstock BHA F/ 76' W/ X/O, float sub (Solid), TM, DM, X/O, 6 ea 6.25" Spiral DC X/O's and 8 stands 4.5" HWDP to 777' MD. MWD, DD, Baker and Co Rep onsite RFO 0.07/6.68= 3.77.;PJSM RIH Whipstock BHA W/ 4.5" D.P. F 777' to 2,079' MD. 90 fpm P/U 44K SLK 40K.;Fill pipe and break Circ 367 gpm 638 PSI. P/U 50K SLK 42K. Orient toolface to 26R working string. Wash down F/ 2,079' to 2,110' MD tag W/ 5K. Set down 10K P/U Set down 20K and anchor sheared. P/U 10K over string wt to 60K anchor set. Slack down to 15K (Block WT) and sheared off bolt. P/U free.;Perform milling operations. Start 367 gpm 638 PSI 90 RPM free Trq 8.5K. Begin milling window at 2,088' MD. Mill first 5' @ 2 fph to 2,093' MD 367 gpm 638 PSI 90-100 RPM TRQ 8.5-16K WOB 1-4K RF 26%.;Cont milling F/ 2,093' to 2,105' MD Mill @ 2-6 fph 325-400 gpm 505-705 PSI 90-100 RPM TRQ 7.5-15K WOB 2-7K RF 23-26%. TOW 2,088' BOW 2,105' MD.;Control drill new formation F/ 2,105' to 2,130' MD Mill 6-20 fph 350 gpm 502 PSI 90 RPM TRQ 6-8K WOB 2-7K RF 26%. P/U 50K SLK 42K ROT 44K. Reamed through window W/ drilling parameters 3X no issue. Shut off rotary and worked through with out issues.;Pumped 17 bbl 200+ Vis sweep 350 GPM, 560 PSI, 34 RPM, TRQ 5K. Once sweep exited the bit pulled up to 2,083' MD Sweep back 300 stks early W/ 10% increase.;SPR at 2,130' MD (1,775' TVD) MW 8.8 ppg. MP #1 45-64, 55-85. MP #2 45-65, 55-85.;POOH F/ 2,130' to 2,083' MD L/D working single and 1 jnt in mouse hole. P/U 50K SLK 41.;PJSM R/U Pump in sub, IA and test pump. Attempt FIT unable to catch Press. Re rig test Equip W/ head pin, low trq, Tee and HP test lines W/ test pump.;PJSM Perform FIT to 13.5 ppg 433 PSI W/ 8.8 ppg MW 1,775' TVD Pumped 7 Gal Bled back 7 Gal.;Daily H2O from G&I = 90 bbls, Total = 4955 bbls Daily Fluid to G&I = 70 bbls, Total = 4394 bbls Daily Cutting to G&I = 0 bbls, Total = 692bbls Daily losses to well = 0 bbls, Total production = 1031 bbls Daily Metal=25 Total Metal 25 12/1/2020 R/D FIT test equipment. B/D surface lines.;POOH F/ 2083' - T/ surface. Rack back 8 stds HWDP, L/D DC's, FS, milling assy. Upper mill in gauge, Lower mill 1/2" out, Window mill 1/4" out.;M/U johnny wacker and flush stack to clear metal debris. B/O and L/D same.;M/U 8.5" PDC Mtr drilling assy. 12k tq on bit, M/U MWD, LWD. RFO - 23.43°. Download MWD. M/U stab, flex DC's and XO. Shallow pulse test (good) @ 360 gpm, 500 psi. M/U 9 stds HWDP w/ jars. Total BHA length 711' MD.;TIH F/ 711' - T/ 2072' MD PU 50K SLK 42K.;Grease crown, block, top drive, wash pipe, iron roughneck and drawworks.;Break circ. Orientate 20R. Shut down pumps and trip through window F/ 2,072' to 2,112' MD W/O issue. Wash down F/ 2,112' to 2,130' tag on depth. 405 GPM, 835 PSI, Free trq 6.5K @ 40 rpm. P/U 50K SLK 42K ROT 47K.;PJSM Slide & ROT 8.5" Hole F/ 2,130' to 2,630' MD (2,041' TVD) 500' total (76.9' AROP) 380 GPM, 845 PSI, 80 RPM, TRQ ON 7.6K, TRQ OFF 8.5K, WOB 2-6K, RF 29% Max Gas 19U, ECD 9.4, MW 8.9 ppg. P/U 59K, SLK 41K, ROT 49K. Cont 4°/100 build. Clean survey at 2,283' MD.;PJSM Slide & ROT 8.5" Hole F/ 2,630' to 3,138' MD (2,332' TVD) 508' total (84.7' AROP) 405 GPM, 1,040 PSI, 80 RPM, TRQ ON 8.1K, TRQ OFF 7.8K, WOB 3K, RF 29% Max Gas 28U, ECD 9.7, MW 8.9 ppg. P/U 62K, SLK 42K, ROT 53K. Cont 4°/100 build.;ROT Hrs 3.57 Slide Hrs 2.56, Distance to WP #5: 6.55' 1.71' Low 6.33' Right.;Daily H2O from G&I = 175 bbls, Total = 5130 bbls Daily Fluid to G&I = 96 bbls, Total = 4490 bbls Daily Cutting to G&I =33 bbls, Total = 725bbls Daily losses to well = 0 bbls, Total production = 1031 bbls Daily Metal=30 Total Metal 55 catwalk W/ Baker whipstock components. P/U 1 2088-2105 ft . TOW 2,088' BOW 2,105' MD. ;Perform milling operations. R/U Halliburton cement gy p yj manifold on rig floor and lines.;PJSM, Wet lines w/ 5 bbls H2O (HES) and P/T 3000 high, Pump 12 bbls 15.8# Premium G, 1.16 yld (58 sx) 3.3 bpm ICP 158 PSIg()gpy()p FCP 166 PSI. Pump 2 bbls H20 displace w/ 25.3 bbls 8.8# mud, 4 bpm caught Press 12 bbls away FCP 101 PSI. Shut down 2 bbls early, calculated was 29.3 pp bbls.;Break out of top drive and disconnect cement line. Mill window at pp y p t F/ window mill to slide. Anchor shear set 2 pins 12K.;Cont RIH Whipstock BHA F/ 76' W / X/O, float subgg y p p (Solid), TM, DM, X/O, 6 ea 6.25" Spiral DC X/O's and 8 stands 4.5" HWDP to 777' MD. MWD, DD, Baker and Co Rep onsite RFO 0.07/6.68= 3.77.;PJSM RIH() p p Whipstock BHA W/ 4.5" D.P. F 777' to 2,079' MD. 90 fpm P/U 44K SLK 40K.;Fill pipe and break Circ 367 gpm 638 PSI. pppp M Perform FIT to 13.5 ppg 433 PSI W/ 8.8 ppg MW 1,775' 12/2/2020 PJSM Slide & ROT 8.5" Hole F/ 3138' to 3,186' MD (2,364' TVD) 48' total (96' AROP) 405 GPM, 1,040 PSI, 80 RPM, TRQ ON 8.1K, TRQ OFF 7.8K, WOB 3K, RF 29% Max Gas 28U, ECD 9.7, MW 8.9 ppg. P/U 62K, SLK 42K, ROT 53K. Cont 4°/100 build.;CBU 1.5x rot/recip @ 3186' MD / 2364' TVD. 405 gpm, 1020 psi, 40 rpm, 8.2k tq. 18u BGG. Obtain svy and SPR's. 50k dn, 68k up after cleanup cycle.;Monitor well (slight seepage). POOH on elevators F/ 3186' - T/ 2940' MD. Pulled clean. 48k dn, 64k up.;Heard what appeared to be an unidentified alarm on production side. Shut down tripping operatio ns. Secured well and mustered @ secondary muster pt due to wind direction. Contacted production foreman and was informed the sound was actually a pneumatic starter for turbine. Called all clear.;Opened well (static). Continued pulling on elevators with no overpull after sitting static for 20 min. POOH F/ 2940' - T/ 2070' MD. Pulled clean thru window without issue. 1.4 bbl loss for trip. 40k dn, 55k up.;Serviced rig. Inspected floor motor. Greased crown.;RIH F/ 2070' - T/ 3186' MD. Tripped out window clean with blind toolface. 1 bbl loss for trip. Washed dn last stand w/ no fill.;PJSM Slide & ROT 8.5" Hole F/ 3186' to 3250' MD (2395' TVD) 64' total (64' AROP) 405 GPM, 1080 PSI On, 1040 PSI off, 80 RPM, TRQ ON 8.5K, TRQ OFF 8.4K, WOB 3K, RF 29% Max Gas 12, ECD 9.6, MW 8.9 ppg. P/U 62K, SLK 48K, ROT 53K. 20 bbl 180 vis sweep (slight inc/on time).;PJSM Slide & ROT 8.5" Hole F/ 3250' to 3784' MD (2700' TVD) 534' total (89' AROP) 450 GPM, 1227 PSI On, 1185 PSI off, 80 RPM, TRQ ON 9.1K, TRQ OFF 8.9K, WOB 3K, RF 30% Max Gas 26, ECD 9.6, MW 8.9 ppg. P/U 76K, SLK 47K, ROT 56K.;Cont Slide & ROT 8.5" Hole F/ 3,784' to 4,241' MD (2,956' TVD) 457' total (83' AROP) 430 GPM, 1257 PSI On, 1160 PSI off, 80 RPM, TRQ ON 8.7K, TRQ OFF 8.3K, WOB 5K, RF 30% Max Gas 31, ECD 9.6, MW 9.0 ppg. P/U 81K, SLK 51K, ROT 60K.;PJSM CBU Rot & Rec F/ 4,241' to 4,181' MD 430 GPM, 1,190 PSI 80 RPM, 8K Trq, RF 30%, ECD 9.6 MW 9.0, Max GAs 27U. No increase at BU. SPR @ 4,241' MD (2,956' TVD) MW 9.0. MP #1 38-181, 57-242. MP #2 38-178, 57-239.;PJSM Monitor well 10 min, slight seepage. POOH on elevators F/ 4,241' to 3,186' MD. Pull 5 stands no swabbing. P/U 67K SLK 47K Lost 2.6 bbls for trip. No issues.;PJSM RIH on elevators 3,186' to 4,241' MD. Washed down last 60' no fill. 100 GPM 210 PSI. P/U 82K SLK 53K. Lost 3.1 bbls for trip. No issues.;PJSM Slide & ROT 8.5" Hole F/ 4,241' to 4,533' MD (3,124' TVD) 292' total (83.4' AROP) 430 GPM, 1260 PSI On, 1220 PSI off, 80 RPM, TRQ ON 9K, TRQ OFF 9.6K, WOB 3-6K, RF 29% Max Gas 37, ECD 9.6, MW 9.0 ppg. P/U 80K, SLK 52K, ROT 63K.;Pumped 20 bbl 200+ Hi Vis/ Nut Plug sweep at 2,421' MD on time, no increase at shakers.;Distance to WP #5: AT 4327' MD 1.98' 1.92' High 0.49' Left. ROT Hrs 8.16 Slide Hrs 1.68.;Daily H2O from G&I = 275 bbls, Total = 5405 bbls Daily Fluid to G&I = 318 bbls, Total = 4808 bbls Daily Cutting to G&I =122 bbls, Total = 847bbls Daily losses to well = 3 bbls, Total production = 1034 bbls Daily Metal=15 Total Metal 70 12/3/2020 Continue drill 8.5" Hole F/ 4533' to 5048' MD (3410' TVD) 515' total (86' AROP) 430 GPM, 1370 PSI On, 1320 PSI off, 80 RPM, TRQ ON 10.6K, TRQ OFF 9.6K, WOB 3-6K, 32% F/O, Max Gas 118u, ECD 9.6, MW 9.0 ppg. P/U 91K, SLK 53K, ROT 63K. 15 ppb background LCM (baracarb).;Continue drill 8.5" Hole F/ 5048' to 5297' MD (3552' TVD) 249' total (100' AROP) 430 GPM, 1400 PSI On, 1300 PSI off, 80 RPM, TRQ ON 10.5K, TRQ OFF 9.7K, WOB 3-6K, 32% F/O, Max Gas 118u, ECD 9.6, MW 9.0 ppg. P/U 88K, SLK 57K, ROT 62K. 15 ppb background LCM (baracarb).;CBU @ 5297' MD / 3552' TVD (rot/recip). 437 gpm, 1300 psi, 32% F/O, 9# MW, 9.7# EMW. 37u BGG. Pump 25 bbl hi vis sweep w/ nut plug (slight increase/on time). 58k dn, 88k up.;Monitor well (slight seepage). B/D TDS, spin elevators for tripping position. POOH F/ 5297' - T/ 4240' MD. Saw 7-12k drag. Wiped thru once without issues. Drag was intermittent and seemed to correlate more to slide intervals. 2 bbl loss for trip out.;Service rig. Grease traveling equipment, Crown and drawworks. Inspect drive shaft bolts and linkages.;Trip in hole F/ 4240' - T/ 5297' MD. Attempted to trip last stand down, tagged up with 10k @ 5260' MD. P/U and kelly'd up. Wash down last stand without issue. 4 bbl loss for trip in. Trip in was clean without any issues.;Continue drill 8.5" Hole F/ 5,297' to 5,755' MD (3,820' TVD) 458' total (83.3' AROP) 435 GPM, 1,450 PSI On, 1,325 PSI off, 80 RPM, TRQ ON 11.2K, TRQ OFF 10.6K, WOB 7K, 32% F/O, Max Gas 228U, ECD 9.8, MW 9.0 ppg. P/U 90K, SLK 58K, ROT 67K.;Wash pipe started leaking. POOH F/ 5,755' to 5,438' MD to get above XX low press zone. R/U TIW and head pin.;PJSM C/O wash pipe with rebuilt. Grease and inspect bolts on drawwork drive. Circ at 165 GPM 340 PSI Max Gas 78U.;PJSM POOH F/ 5,483' to 5,298' point of last wiper trip. P/U 97K SLK 55K. Break circ 430 GPM 1,269 PSI RF 32% checking wash pipe for leaks, good.;PJSM RIH F/ 5,298' to 5,755' MD Wash down last 124 GPM 280 PSI No fill. Turn elevators for drilling. SPR @ 5,755' MD (3,820' TVD) MW 9.0. MP 1 38-230, 57-285. MP 2 38-225, 57-285.;Continue drill 8.5" Hole F/ 5,755' to 5,981' MD (3,947' TVD) 226' total (90.4' AROP) 435 GPM, 1,380 PSI On, 1,320 PSI off, 80 RPM, TRQ ON 11.5K, TRQ OFF 11K, WOB 5K, 32% F/O, Max Gas 148U, ECD 9.6, MW 9.0 ppg. P/U 109K, SLK 54K, ROT 70K.;AT 5,981 made connection and drill string was stalled out at 17.6K TRQ. Worked string up stalling and could see slight Rot down. Racked back stand. Using drilling parameters 440 GPM 1,328 PSI FO 32% Worked String F/ 5,981’ to 5,914’ stalling on up stroke and intermittent rotation down W/ 8-10 RPM.;Stalling W/ 17.6K TRQ no motion. Cont working string out of hole F/ 5,914’ to 5,729’ MD W/ 400 GPM 1,150 PSI FO 30% attempting to rotate at 40 RPM, up stroke 8-15 RPM TRQ 16.6-17.4K working string down 15-20 RPM TRQ 12.6-14K. No changes pulling into last wiper depth at 5,755’ MD. P/U SLK ROT wts;never really changed. No losses. No drag. Max Gas 49U. P/U 106K SLK 60K. Cont POOH 400 GPM 1,150 PSI attempting to establish rotary W/O stalling.;Distance to WP #5: AT 5875' MD 3.29' 1.10' Low 3.10' Left. ROT Hrs 9.81 Slide Hrs 1.50.;Daily H2O from G&I = 270 bbls, Total = 5675 bbls Daily Fluid to G&I = 164 bbls, Total = 4972 bbls Daily Cutting to G&I =106 bbls, Total = 953bbls Daily losses to well = 8 bbls, Total production = 1039 bbls Daily Metal=5 Total Metal 75 12/4/2020 Continue BROOH F/ 5729' - T/ 5418' MD while verifying 17k tq stalls were actually downhole. Troubleshoot displayed Pason tq vs load cell tq. Found hi/lo hydraulic drive on top drive was set to hi. Tq downhole was actually ~11k not the 17k previously thought.;Switch TDS to lo side with no more stalling issues. 80 rpm, 11k, 400 gpm, 1150 psi.;Trip back to bottom on elevators F/ 5418' - T/ 5981' MD without issue. Spin elevators for drilling operations. 110k up, 66k dn.;Continue drill 8.5" Hole F/ 5981' to 6290' MD (4121' TVD) 309' total (77' AROP) 435 GPM, 1485 PSI On, 1405 PSI off, 80 RPM, TRQ ON 11.7K, TRQ OFF 12.2K, WOB 5K, 32% F/O, Max Gas 119u, ECD 9.8, MW 9.0 ppg. P/U 104K, SLK 61K, ROT 76K.;Continue drill 8.5" Hole F/ 6290' to 6870' MD (4452' TVD) 580' total (97' AROP) 435 GPM, 1575 PSI On, 1480 PSI off, 80 RPM, TRQ ON 13.4K, TRQ OFF 14K, WOB 5K, 32% F/O, Max Gas 528u, ECD 9.8, MW 9.0 ppg. P/U 112K, SLK 60K, ROT 73K.;Continue drill 8.5" Hole F/ 6,870' to TD 7,250' MD (4,664' TVD) 380' total (76' AROP) 440 GPM, 1,600 PSI On, 1,450 PSI off, 80 RPM, TRQ ON 15.4K, TRQ OFF 13.7K, WOB 4-7K, 32% F/O, Max Gas 58u, ECD 9.7 MW 9.05 ppg. P/U 115K, SLK 62K, ROT 75K. TD Called by Geologist.;Rot & Rec F/ 7,250' to 7,184' MD 440-400 GPM 1,550-1,312 PSI TRQ 13.6K rf 30-32%. Pump 25 bbl 200+ Hi Vis Sweep returned on time W/ 15% increase. Max Gas 5U.;PJSM POOHF/ 7,250' had 25K over pull, slaked off. Idled pumps 160 GPM 400 PSI 15 RPM TRQ 14.5K P/U String 10' and stopped rotary and was able to cont pulling with no over pull. Did this the first two stands to 7,124' MD. Cont POOH on elevators F/7,124' to 2,035' MD. Intermittent 10-15K drag spots.;Pulled through window NM FC at 2,261' saw 20K over pull and fell off. At 6,198' ILS saw 17K over pull and dropped off. Lost 12 bbls f or trip.;PJSM ROT & REC F/ 2,035' to 1,981' MD CBU 400 GPM 925 PSI 20 RPM TRQ 4.7K FO 26% No increase at shakers. Blow down top drive.;Monitored well 10 min at TD 7,250' MD, seepage loss. Pumped 10.9 ppg dry job at 6,509' MD. SPR at 7,250' (4,664' TVD) MW 9.05. MP 1 43-236, 53-275. MP 2 41-230, 51-270.;Distance to WP #5: at TD 7,250' MD 4.89' 4.78' Low 0.99' Left. ROT Hrs 8.74 Slide Hrs 0.74.;Daily H2O from G&I = 180 bbls, Total = 5855 bbls Daily Fluid to G&I = 235 bbls, Total = 5207 bbls Daily Cutting to G&I =105 bbls, Total = 1058bbls Daily losses to well = 0 bbls, Total production = 1039 bbls Daily Metal= 0 Total Metal 75 gp p p ;Continue drill 8.5" Hole F/ 5981' to 6290' MD (4121' TVD) 309' total (77' AROP) Continue BROOH F/ 5729' - T/ 5418' MD w TD well 76K.;Continue drill 8.5" Hole F/ 6290' to 6870' MD Continue drill 8.5" Hole F/ 4533' to 5048' MD TD Called by Geologist.;Rot 12/5/2020 PJSM Cut and slip 15 warps (71') drilling line. Calibrate blocks. Grease drive line and inspect trq on drive belts on carrier motor. Grease crown, top drive, and handling Equip. Monitor well W/ TT 2 bph static loss rate. 5 bbls.;PJSM RIH F/ 2,044' to 7,250' MD Fill pipe every 2,400'. Took 15K wt at 5,871' & 6,905' MD worked area clean. No fill seen on bottom. P/U 124K SLK 68K Lost 11 bbls for trip.;Circ & cond for liner run. ROT & REC F/ 7,250' to 7,185 MD 430 GPM 1,485 PSI 60 RPM TRQ 13K. 2-3 bph dynamic loss rate. Pump 25 bbl Hi Vis sweep returned on time, 10% increase. Condition to 16 YP. Monitor well 10 min, seepage loss. Max Gas 116U. P/U 124K SLK 68K.;PJSM POOH L/D working single, cont POOH F/ 7,210' to 2,074' MD Pulled 5 stands no swabbing. Pumped 20 bbl 11.9 ppg Dry Job. Blow down top drive. 10-15K over pull at 6,887' & 6,700' wiped clean. Pulled through window W/ BHA 1-2K bobbles seen. AT 2,074' MD dropped 2" OD rabbit on wire.;Cont POOH F/ 2,074' to 156' MD. L/D 17 jnts 4.5" HWDP and Jars. Lost 13bbls for trip.;PJSM Cont L/D NM FC and ILS, No Wear. MWD perform down load. L/D Subs and X/O's.;PJSM L/D TM, ADR, PWD & DGR. Milk motor and break off 8.5" Bit. Bit Grade 1-1-NO-A-X-I-TD.;PJSM Drain Stack P/U Test jnt and pull wear ring. P/U 7" test jnt, Install and set test plug. RILDS. Open upper ram doors, inspect cavity for any cement. C/O VRB rams to 7" solid body. Test 7" rams 250 PSI low 3,500 PSI high 5 min on chart.;Daily H2O from G&I = 90 bbls, Total = 5945 bbls Daily Fluid to G&I = 50 bbls, Total = 5257 bbls Daily Cutting to G&I =0 bbls, Total = 1058bbls Daily losses to well = 60 bbls, Total production = 1099 bbls Daily Metal= 0 Total Metal 75 12/6/2020 Finish rigging down BOP test equipment. Install 9-1/8" ID wear bushing. Clean and clear rig floor.;R/U Weatherford 7" casing equipment. Double stack power tongs (WOT hydraulics), Side doors (150T). Function test tongs (good). M/U circulating swedge to TIW for 7" CDC HTQ. Stage 75 solid body centralizers on floor.;M/U 7" CDC HTQ, 26#, L-80 shoe track. Flashlight float equipment and landing collar. Bakerlok shoetrack (BTC tq'd to M/U mark). Fill pipe and check floats (good). Run 7" liner F/ 88' - T/ 1191' MD. Fill on the fly. Calc disp every 10 jts. P/U 30k, S/O 30k. Seeing ~2-3 BPH loss rate.;Continue run 7" CDC HTQ liner F/ 1191' - T/ 1971' MD as per detail. 17.5K Tq on connections.;Circulate and condition mud @ 1971' MD. Stage up to 6 bpm, 140 psi, 19% F/O. Obtain parameters 5 rpm / 3.4k tq, 10 rpm / 3.8k tq, 15 rpm - 4k tq. 47k up, 44k dn, 46k rot. 4u BGG.;Continue run 7" CDC HTQ liner F/ 1971' - T/ 4,695' MD as per detail. 17.5K Tq on connections. Exited window (TOW 2088', BOW 2105') clean without issue. Tripped clean.;M/U Swedge and X/O stage up pumps to 6 bpm 290 PSI F/O 22% P/U 106K SLK 44K CBU 2X. R/D Blow Down.;Continue run 7" CDC HTQ liner F/ 4,695' to 5,320' MD as per detail. 17.5K Tq on connections. P/U M/U ZXP as per Baker rep onsite. Mix and apply PAL Mix. R/D Weatherford tools and Equip. P/U 140K SLK 55K.;PJSM Convey 7" Liner & ZXP W/ 4.5" D.P. F/ derrick F/ 5,366' to 5,429' MD. Break Circ and Circ liner volume. Stage up pumps to 210 GPM 340 PSI. P/U 120K SLK 44K Blow down.;Cont Convey 7" Liner & ZXP W/ 4.5" D.P. F/ derrick F/ 5,429' to 7,224' MD. Working string down W/ 5-8K drag. AT 7,224' MD worked string up to 230K to break over. P/U 170K SLK 40K. Break Circ 75 gpm 425 PSI. Lost 18 bbls for trip.;PJSM Shut down pumps. P/U M/U 5' pup, X/O on Baker cement head. P/U Single in mouse hole and M/U to cement head. M/U Top Drive and Trq through all connections. Circ at 3 bpm 365 PSI RIH to 7,250' MD slack down 5-7K. Work string up to 230K to break over. P/U 165K SLK 45K.;Stage pumps up to 5 bpm 575 PSI Reciprocate F/ 7,250' to 7,223' MD Circ surf to surf MW 9.2 ppg YP 17. Dynamic loss 5 bph.;PJSM W/ all personnel. Set shoe at 7,249’ MD. R/U Cement HP lines to cement head. Halliburton pumped 5 bbls H2O P/T low 430 PSI high 5,000 PSI. Pump 40 bbls 10.5 ppg Tuned Spacer W/ red dye 3 bpm 360 PSI, 135 bbls 12.0 ppg Lead cement 5 BPM ICP 455 PSI FCP 143 PSI. 17 bbls 15.3 ppg Tail Cement 2 bpm;143 PSI. Drop dart and clear lines W/ 10 H2O. Was able to reciprocate during pumping cement. Parked at 7,249’ MD. Swap to rig pumps and was unable to get string moving. Rig pump 9.2 ppg Mud at 5 bpm caught Press at 15 bbls away 41 PSI at 20 bbls away saw dart latch plug and press up to 965 PSI to;to release. Cont Pumping at 5 bpm ICP 295 PSI FCP 1,071 PSI at 200 bbls away slowed down to 3 bpm ICP 1,024 PSI. Pump plug 3 bbls early 950 PSI shut down at 1,513 and held 5 min. CIP at 05:15. Bled back .5 bbls Floats good. Lost 6 bbls during job.;Halliburton Press up to 2,000 PSI to set Flex Loc, Cont Press up to 2,500 PSI and saw Pusher Tool shear at 2,162 PSI. Slacked off to 14K on Wt indicator. Set. Cont Press up 3,000 & 3,500 PSI HRD released Press up to 4,500 PSI Neutralizer released. Bled down to 628 PSI P/U to 37K press;bled off released from ZXP, good.;Daily H2O from G&I = 90 bbls, Total = 6035 bbls Daily Fluid to G&I = 0 bbls, Total = 5257 bbls Daily Cutting to G&I =0 bbls, Total = 1058bbls Daily losses to well = 37 bbls, Total production = 1136 bbls Daily Metal= 0 Total Metal 75 12/7/2020 Circulate excess cement from top of liner. 420 gpm, 320 psi. 38k up, 36k dn. Overbaord 40 bbls spacer, 24 bbls green cmt, 19.5 bbls contaminated mud.;S/O and tag TOL @ 1894' MD w/ 8k dn. Shut annular and pressure test liner hanger w/ 1000 psi and 5 min hold (test good). Bleed down and R/D cmt head. L/D single. B/D surface lines.;POOH F/ 1894' - T/ surface. B/O and L/D LRT. Liner running tool showed good indication the setting tool worked as advertised. Proper displacement for trip.;P/U working single and pull wear bushing. Flush stack @ 10 BPM w/ 10 rpm rotation. Set wear bushing and L/D single. P/U and B/O XO subs from cement head. L/D same.;M/U 6-1/8" STX-1 (Milltooth / .4964 TFA), Bit sub, XO, Single in w/ 16 jts 4.5" CDS-40 HWDP (total length - 496.08'). Drift 2.4" OD.;Trip in out of derrick F/ 496' - T/ 2040' MD. Tripped past TOL @ 1894' without any issues (didn't see a bobble).;Serviced rig. Greased and inspected drawworks, linkages, Traveling equipment and crown. Check fluid levels (good).;Continue Trip in F/ 2040' to 7,127' MD. Washed down last stand 435 GPM 1,925 PSI. Adjust top drive max Trq 15K.;Circ surf to surf 435 GPM 1,925 PSI P/U 92K SLK 49K.;M/U Sub, X/O, pump in sub & X/U. R/U HP test lines. Test 9 5/8" X 7" Csg on chart to 2,500 PSI for 30 min, good. Pumped 2.9 bbls Bled 2.8 bbls. Blow down R/D test Equip.;Wash and tag at 7,162' MD Drill up plug and landing collar 350 GPM PSI on 1,340 PSI, PSI off 1,430 PSI, 35 RPM TRQ 11-12.5, WOB 10-11K FO 26%. Cont drill no real WOB to FC at 7,206' MD drill W/ same parameters. Cont drill to 7,225' MD. Wiped through shoe track W/O issue.;Found plug rubber and semi cured cement at shakers.;PJSM Pump 20 bbl Hi Vis sweep Surf to Surf. 385 GPM 1,500 PSI 35 RPM TRQ 13-13.5K, Rec 38' Sweep on time no increase. Monitor well 10 min, static. Pump Dry job and blow down. P/U 120K SLK 58K.;POOH racking back 4.5" D.P. 7,225' to 494' MD.;PJSM L/D 4.5" HWDP F/ 494'. Break off Bit and sub. Rinse. cleaned and re doped box and pins.;Daily H2O from G&I = 630 bbls, Total = 6665 bbls Daily Fluid to G&I = 900 bbls, Total = 6157 bbls Daily Cutting to G&I =5 bbls, Total = 1063bbls Daily losses to well = 15 bbls, Total production = 1151 bbls Daily Metal= 0 Total Metal 75 Overbaord 40 bbls spacer, 24 bbls green cmt, cement 7" liner g p p p p p ppg y p Set shoe at 7,249’ MD. R/U Cement HP lines to cement head. Halliburton pumped 5 bbls H2O P/T low 430 PSI high 5,000 PSI. Pump 40 bbls 10.5 ppg p pp g p ppg Tuned Spacer W / red dye 3 bpm 360 PSI, 135 bbls 12.0 ppg Lead cement 5 BPM ICP 455 PSI FCP 143 PSI. 17 bbls 15.3 ppg Tail Cement 2 bpm;143 PSI. Dropp y p ppg ppg p dart and clear lines W / 10 H2O. Was able to reciprocate during pumping cement. Parked at 7,249’ MD. Swap to rig pumps and was unable to get string moving. pgppg pgpp ggg Rig pump 9.2 ppg Mud at 5 bpm caught Press at 15 bbls away 41 PSI at 20 bbls away saw dart latch plug and press up to 965 PSI to;to release. Cont Pumping atg p p ppg p g y y p g p p pg 5 bpm ICP 295 PSI FCP 1,071 PSI at 200 bbls away slowed down to 3 bpm ICP 1,024 PSI. Pump plug 3 bbls early 950 PSI shut down at 1,513 and held 5 min. py CIP at 05:15. Bled back .5 bbls Floats good. Lost 6 bbls during job.;H Circulate excess cement from top of (y) () ;M/U 7" CDC HTQ,26#, L-80 shoe track. p r trip.;Circ & cond for liner 12/8/2020 Clean and clear rig floor. P/U working single and johnny whacker then flush the stack and wear ring. B/O and L/D same. B/D TDS.;Close blind rams. Pressure test 9-5/8" x 7" casing to 2500 psi w/ ~10 min hold (test good). Bleed down. Open blinds.;M/U bit, 7" scraper, bit sub, xo, single (39.81' length), 85 stands + single = 5303.09' DP length. M/U XO's, 9-5/8" scraper assy, xo. Trip in F/ 5385' - T/ 7241' (16' deep). 0 losses for trip. Tag btm w/ 10k no rotation or pump. 128k up, 60k dn.;Break circulation staging up 342 gpm, 1190 psi. Displace out 9.1 mud w/ 25 bbl spacer followed by 8.6 ppg 6% KCL brine w/ corrosion inhibitor. Shut down and monitor well (static).;Service rig. Fix hydraulic leak on iron roughneck. Grease traveling equipment. B/D TDS.;POOH from 7,241' laying down 11 joints HWDP to 6930'. Rack back stands to 5,342'. B/O and L/D 9-5/8" casing scraper. Cont. to rack back total 31 stands to 5,000'. Cont. to POOH laying down drill, pipe sucking dp wiper ball through DP. L/D BHA, 7" casing scraper, bit.;Clean and clear rig floor, remove wiper ball stand.;Pick up and M/U polish mill assembly and RIH to 1878', establish parameters: PUW 36, SOW 34K, ROTW 36K, 5bpm, 54 psi, 20 rpms, 4Kft-lbs. Wash and ream from 1878' to 1906', tag TOL with dressing mill with 6K. Pick up to 1903'.;CBU x2 at 475 gpm, 250 psi, monitor well, static. Blow down top drive.;POOH laying down drill pipe from 1903' to 299'; sucking drill pipe wiper ball through drill pipe.;Daily H2O from G&I = 270 bbls, Total = 6935 bbls Daily Fluid to G&I = 840 bbls, Total = 6997 bbls Daily Cutting to G&I =0 bbls, Total = 1063bbls Daily losses to well = 0 bbls, Total production = 1151 bbls Daily Metal= 0 Total Metal 75 12/9/2020 Cont. to POOH from 299', laying down drill pipe. L/D polish mill assembly.;Clean and clear rig floor, pull wear bushing.;Rig up to RIH with 7" tie-back, rig up Weatherford power tongs, elevators, M/U TIW valve to 7" XO.;Pick up and inspect tie back seal assembly. RIH with 7", 26#, L-80, CDC HTQ tieback string as per detail. No-Go at 1892'. Calculate and M/U space out pups. M/U hanger and land casing. Pressure up to 425 psi and pick up until pressure drops.;Circulate and spot 50 bbls corrosion inhibiter brine on backside of 7" tie-back; 235 gpm, 50 psi.;Land tie-back string. B/O circ swedge. Drain stack. Pull landing joing and L/D. Install pack off and test void 250psi/5min, 5000 psi/15 minutes - good.;Rig up and MIT-IA to 2500 psi for 30 minutes - good. Pumped 37.5 gallons, returned 36. MIT-casing to 3500 psi for 30 minutes - good. Pumped 3.6 bbls, bled 3.5 bbls back.;Suck out stack and install BPV. Flush and blowdown top drive, mud line, mud pumps, and choke.;N/D BOPE: open ram doors and remove rams. Wash out ram cavities and close doors. N/D Kill line and valves. Disconnected fittings and plugged annular, kill and choke HCR valves. N/D choke jumper line. Pull mouse hole and L/D. Deflate air boots and break union to pull riser. Bleed accumulator.;remove remaining ram hyd. fitting and plug. N/D choke side cleaning BOP equipment.;Remove manual and HCR valvs, clean and grease ring grooves, palletize. Clean rams, grease, and wrap, palletize. Cont. working on cleaning mud pump pods and suction/discharge lines. Move corrosion inhibited fluid around in all pits.;Break bolts and break down BOP stack, cleaning and greasing ring grooves. Set down on pallets/wood to keep ring grooves clean until plates are fabricated. Cont cleaning pits, mud pumps.;Daily H2O from G&I = 180 bbls, Total = 7115 bbls Daily Fluid to G&I = 271 bbls, Total = 7268 bbls Daily Cutting to G&I =0 bbls, Total = 1063bbls Daily losses to well = 0 bbls, Total production = 1151 bbls Daily Metal= 0 Total Metal 75 12/10/2020 N/U 11" dry hole tree. Test hanger void 250/5000 with 5/15 min hold (test good), Test hanger neck seals 250/5000 with 5/15 min hold (test good). Fill tree with diesel and test tree 250/5000 with 5/15 min hold (test good). Continue clean pits. Reassemble mud pumps. Continue N/D stack.;Continue Clean pits, Dress down shakers, Clean cellar area. Secure well and release rig from AFE @ 12:00 12/10/2020. Continue nippling down BOP's cleaning and stacking to ship out (remove all ram blocks). Remove saver sub, elevators, and bails. Pin grabber box for demob.;Isolate hydraulics from TDS and remove lines. Remove service loop from TDS and label service connections (rig electrician / Jeremy Cole). Remove washed bleeder valves from mud manifold on floor, rebuild same.;L/D TD bails and unnecessary floor equipment. Disconnect kelly hose and service loop. Unpin TD from extend fram and L/D same. Pick up TD cradle and pin to top drive. Unpin block hook from becket. Prep TD for crane pick. Clean and lubricate block hook pins. Bridle up.;Remove lower turnbuckles and T-brace from torque tube. R/D tongs and misc floor equipment. Crane topdrive from rig floor. Tie back kelly hose and service loop to ower mast section. Remove washpipe from topdrive. Drain mast service lines. Clock standpipe for board clearance. Drain service loop;R/D roughneck console and install shipping pin. R/U lay down line to pull out torque tube.;Cont. to prep derrick for scoping. Remove torque tube pin. Scope derrick laying down lower section of torque tube. Bridle down.;Work on stack out list: pressure wash throughout substructure. Obtain critical BOP spare inventory list, clean fluid end components on mud pump #1, grease and re-install valves, plugs and caps. Remove HP shock hose from pump room to sub. Assist rigging down gas monitoring system. R/D flow line;and flow box. Remove turn buckles from upper section of torque tube.;Daily H2O from G&I = 90 bbls, Total = 7205 bbls Daily Fluid to G&I = 210 bbls, Total = 7478 bbls Daily Cutting to G&I =0 bbls, Total = 1063bbls Daily losses to well = 0 bbls, Total production = 1151 bbls Daily Metal= 0 Total Metal 75 12/11/2020 Cont. to work on stack-out list: Clean grease and re-install fluid end components on mud pump #2. R/D top drive hydraulic lines from unit to sub. Cont pressure washing projects on substructure and rig equipment. Change dies in iron roughneck. Rid down interconnect lines between pump r oom and pit;Work on critical spare inventory list for top drive and accumulator. Install substructure beams in cellar.;Cont. to work on stack-out list: Cont. Clean, grease and dress BOPE. Clean rig tongs, grease and prep for storage. Organize rig floor. Pressure wash doghouse roof, sundeck, rig floor and substructure. Wash flowbox, flowlines and misc equipment. Completed agitator gearbox fluid change.;wrap electric motors with plastic. Wash drawworks skid down to rear of substructure. Remove pop- offs, clean, inspect and re-install. Clean inventory and prep lube room for stack. R/D and store pump and drawworks camera.;C ont. to work on stack-out list: Clean and prep pump skids. Cont. pressure washing modules. Grease iron roughneck. Lower degasser and corrosion inhibit rams. Remove lights and camera from doghouse roof. Store lights in seacan. Grease floor motor driveshaft. Lubricate degasser cables.;Lubricate catwalk cabl es. Grease V-door ram pins, clean hydraulic pumps and motors. Grease wash pipe threads and store. Clean lube room, label filters in cabinet. Install plugs on all valves to lube bulk tanks. Grease all door hinges. Cover accumulator pumps. Organize accumulator room. 12/12/2020 Cont. to work on stackout list: offload pipe handling equipment from catwalk. Remove cover from pump 2 gear end, clean old silicone and sealing surface. Cont. cleaning pump room and organize parts. Rinish removal of MP discharge line. Remove annular KR valve. Start cleaning walls in motor room.;Complete MP inventory. Clean walls in accumulator room. Clean under sub. Label electrical lines, install dessicant packs around rig. Install rebuilt KR valve on annular. Finish pressure washing tank modules. Install gear end cover on MP 2. Prep sub bridge cranes for removal.;Cont. to work on stackout list: Remove bridge cranes. Clean gen house walls. Finish prep in pump and pit rooms for trucks. prep boiler house for move. Prep choke room for move. R/D Aux fuel tank for move. Blow-down water in pump room, pits and boiler room for short looped system.;Inventory pump and accumulator critical spare parts. Undress derrick board in prep for rig down.;Cont. with stackout list: remove chains from ODS winch. Hang blocks in derrick and chain off. Remove windwalls behind iron roughneck. Hang kelly hose and service loop in derrick. Unspool drill line from drawworks, cut 10 wraps. Prep iron roughneck for removal. Pin boom to derrick and;unspool boom line to rig floor. Lower weight bucket, remove tong pull lines. Remove brake linkage from sub to DW skid. Remove lights from rig floor. Remove drive line from brake handle to sub linkage. Disconnect air to doghouse. Remove windwalls and frame from floor. Disonnect geronimo line. ggp gp RIH with 7", 26#, L-80, CDC HTQ tieback string as per pg detail. No-Go at 1892'. C pp g ;Rig up and MIT-IA to 2500 psi for 30 minutes 12/13/2020 Cont. work on stack out/rig move list. Shut in boiler and bleed off, allow to cool. Blow down steam lines. Disconnect interconnect hoses. Prep to lay derrick over. Disconnect pason cables, remove service fittings from rig floor. Stage floor heaters in roughneck house.;Cont. work on stack out/rig move list. Lay derrick over. Remove winch lines, and tong hanginge lines from derrick. Prep doghouse to slide in and lower. Remove derrick ram pins and hydraulic lines. Prep pump rooms for trucks. Disconnect power to change shack. Prep boiler, and aux fuel tank.;Cont. work on stack out/rig move list. Pickle boiler feed pump. Disconnect electrical cables. Remove all roof lights. Slide in doghouse and lower same. R/D catwalk. Prep to lower roofs in pits. Prep pits, pumps, TD HPU and change shack for trucks.;Trucks/cranes for rig move arriving at 06:00. Crews broke tour. 12/14/2020 Pull rig modules apart. P/U rig mats. Crane drill line onto derrick. Finished removing hand rails from rig floor. Cont. rigging down hand rail and braces around rig mods as they come apart. Pull windwalls from pit modules. R/D gas buster with crane. Crane iron roughneck from floor.;Mobe out Pit modules, mud pump modules, water tank, gen building, boiler, Aux fuel ank, change house, parts c-can, TD HPU, gas buster and auxillary loads. Crane board from derrick. Set felt and liner at Peak yard.;Crane derrick, drawworks and sub. Mob out derrick, drawwoks, poney subs to Peak yard.;P/U rig mats. Roll up old liner and felt. Clean location.;Last report for KU 44-01B. Activity Date Ops Summary 1/5/2021 Travel to location, Contact DSO, Inspect location. Get permit signed. PJSM,Move in spot coil unit, Crane, N2 pump and f luid pump, Rig up hydraulic hoses to BOPE. Rig up hardline and flow back tank.,Test BOPE as per Hilcorp & AOGCC requirements, witnessed waived 1/04/2021 @ 13:11 PM by AOGCC Inspections Supervisor Jim Regg, 250/4000. Emailed BOPE Test Report to AOGCC.,Secure well and locaiton. Job in progress. 1/6/2021 Travel to location, contact DSO, inspect location. Fill out permit. PJSM,Wait for crane to finish moving well house for the 401.,Crane back on location, Fire up equipment, PU injector, make up MHA. ( CTC 1.90" X .12') ( XO 2.2" X .42') ( XO 2.2" X .42') ( STINGER 2" X 4') ( BIG HOLE NOZZLE 2.2" X .58') TOL= 5.12',Stab on well, PT low/high 250/4000. Open well, swab 34, T/I/O=0/0/0. RIH,At 2000', stop here till we get40 bbls to the tank.,RIH another 2,000', parked at 4050', got back 70 bbls so far. Pumping at 800 scfm, WHP 2200, CTP 10,RIH to 6,000', park here for 60 min, got back 169 bbls so far. Continue pumping 800 SCFM, whp 2200 psi, CTP 10,RIH to 7,000' park here for 60min, WHP 2500, CTP 8, Continue pumping at 1100 SCFM, Recovered 250 bbls,RIH to tag @ 7225', PU 30' continuing to pump at 1100 scfm down the tubing up the coil. Recovered 280 bbls 6% KCL.,POOH,Tagged up, continue to let the well bleed down.,Well is at zero. pump 8 bbls Diesel into well. Shut well in, pop off well, stack down lubricator, and injector head. Rig down hydraulic hoses and all hardline. Secure well and location. Well ready for Eline. 1/7/2021 Travel to location, Contact DSO, Inspect location,Initiate work permit. PJSM Spot in equipment.,MIRU, Make up lubricator, GR/CCL. test wire. good test.,Stab on well, PT WLV and Lubricator. Low/High 250/3000. Pop off at QTS, Make up gun #1, 21', 12spf, 30*/150* VannGun, 175 gram MaxForce Charge.. Stab on well, pt qts low/high 250/3000,Open well, Swab 36 turns. WHP 0, RIH. Tag @ 7225' ELM. Log up to 6800', Send log to town for corrections. Make +24' correction. Good to shoot first 21' gun ( Ben Siks) 7146-7125',RIH to TD, pu getting on CCL depth @ 7117.5', CCL t/top shot 7.5', CCL t/bottom shot 28.5'. Shoot Interval 7125'-7146'. No change in WHP 0. Log up 200'. POOH,Tagged up, Swab closed, bleed down, pop off well. All shots fired, gun wet. Wire had three kinks in it from getting blow up hole. Lay down PCE, cut 300' of wire. Re-head, make up GR/CCL test wire.,Lay down lub, secure well and location for the night. Job in progress. 1/8/2021 Travel to location,Arrive on location, contact dso, inspect location. Get permit signed. PJSM,PU Lubricator, Make up GR/CCL. Test connection, good test. PU gun #2, 21', 12 spf, 30*/150* VannGun, 175 MaxForce Charge. Head to well, stab on well. pt low/high. 250/3000. Open well, swab 36, Whp 100. RIH,Tag 7225', pull log to 6800' getting on depth. RBIH to tag, pu getting on corrected CCL depth 7096.5'. CCL t/ top shot 7.5', CCL t/bottom shot 28.5'. WHP 100, Shoot 7104'- 7125'. Log up 200', Got 50 psi increase whp. POOH,Tagged up, swab shut, bleed down, pop off well. All shots fired. gun was wet. Break off spent gun, cut 300' wire. Re-head and test connection.,PU gun #3, 21', 12 spf, 30*/150* VannGun, 175 MaxForce Charge. Head to well, stab on well. pt low/high. 250/3000. Open well, swab 36, Whp 150. RIH,Tag @ 7225', log up to 6600' getting on depth. RBIH to tag, PU getting on CCL depth 7096.5, CCL t/top shot 7.5', CCL t/bottom shot 28.5'. Shoot 7083'-7104', WHP 150 psi, no change. log up 200', Looks like we lost communication with GR tool. POOH,Tagged up, swab shut, bleed down, pop off well. All shots fired, Gun was wet with Diesel. Have to cut more wire had another kink. cut 200'. Re-head, make up GR/CCL, test wire. good test,PU gun #4, 21', 12 spf, 30*/150* VannGun, 175 MaxForce Charge. Head to well, stab on well. pt low/high. 250/3000. Open well, swab 36, Whp 150. RIH,Tag 7225' log up getting on CCL depth 7054.5, CCL t/top shot 7.5', CCL t/bottom shot 28.5'. Shoot 7062'-7083', WHP 150 psi, no change. log up 200', POOH,Tagged up, swab shut, bleed down, pop off well. All shots fired. Gun wet, smells like diesel. Cut 200' wire, re-head, make up GR/CCL, test wire. Good test. Stack down, secure well and location. Job in progress. 1/9/2021 Travel to location. Sign in, sign PTW, PJSM,PU gun #5, 4', 12 spf, 30*/150* VannGun, 175 MaxForce Charge. Head to well, stab on well. pt low/high. 250/3000. Open well, swab 36, Whp 150.,RIH, Tag 7225', log up getting on CCL depth @ 7121.5', CCL T/top shot 24.5', CCL T/bottom shot 28.5'. Shoot 7146'-7150', Log up 200', POOH,Tagged up, swab shut, bleed down, pop off well. All shots fired. Gun wet with diesel. Inspect wire, looks good, Make up firing head, test connection. good test Make up Gun #6, 21', 12 spf, 30*/150* VannGun, 175 MaxForce Charge. Head to well, stab on well. pt low/high. 250/3000. Open well, swab 36, Whp 150.,RIH, Tag @7225', log up getting on depth, RBIH to tag, pu to CCL depth 7033.5', CCL T/top shot 7.5', CCL T/bottom shot 28.5'. Perf 7041'- 7062', WHP 150, no change. Log up 200', POOH,Tagged up, swab shut, bleed down, pop off well. All shots fired. Gun #6 slightly wet. Cut 200' wire, Re-head wire. Make up GR/CCL, Test wire, good test. Make up Gun #7, 21', 12 spf, 30*/150* VannGun, 175 MaxForce Charge. Head to well, stab on well. pt low/high. 250/3000. Open well, swab 36, Whp 150.,RIH, Tag at 7225', log up to 6600', RBIH to tag, pu getting on CCL depth of 7012.5', CCL T/Top shot 7.5', CCL T/bottom shot 28.5'. Shoot 7020'-7041'. Log up 200'. No change in WHP. POOH,Tagged up. swab shut, bleed down, Pop off well. All shots fired. Gun mostly dry. RDMO. ( All 130' were shot) Well ready for Coil. 1/11/2021 Travel to location,,Contact DSO, Get PTW signed, inspect location, PJSM,MIRU, Spot Equipment, move return tank into place. Rig up hardline, hydraulic hoses, and bop's.,Test BOPE as per Hilcorp & AOGCC requirements, witnessed waived 1/11/2021 @ 08:27 AM by AOGCC Inspections Supervisor Jim Regg, 250/4000. Emailed BOPE Test Report to AOGCC.,Make up CC, Pull test to 15k. Secure well and locaiton n (LAT/LONG): evation (RKB): 50-133-20692-00-00API #: Well Name: Field: County/State: GS KU 44-01B Kenai Gas Field Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:201-03613C KU 44-01B Completion Spud Date: p . Shoot 7083'-7104', CBL logged on 12.17.20 gp Good to shoot first 21' gun ( Ben Siks) 7146-7125',RIH to TD, N2 displace CTU g pg CCL T/top shot 24.5', CCL T/bottom shot 28.5'. Shoot 7146'-7150', p Recovered 280 bbls 6% KCL. 201-03613C KU 44-01B Completion p Perf 7041'- 7062', p Shoot 7020'-7041'. 1/12/2021 Travel to location,Contact DSO, Initiate PTW, PJSM.,PU injector head, 11' lubricator. Make up (EXT Slip CTC 3.25" X 1.82') ( XO 3.1" X .5') ( Stinger assembly with two centralizers 5.25" x 10.95') ( XN NIPPLE 2.875" X 1' Min ID of XN 1.25") ( Blow out sub 3500lbs),Stab on well, pt low/high 250/4000, Open well, swab 36, whp 155.,RIH, WT CK 2,000'=5K, WT CK 4,000'= 10K, WT CK 6,000'= 16.5K, WT CK 7150'=20K,Get into position to shut Slips/Pipes on coil. 7150.8', Perform No-flo test for 30 min. Good Test,No-Flow test good. Strip up on coil 5', perform cut on 2.375" coil,Make up inverted 3.25" OD Coil connector on stub sticking out of well. Make up 3.25" OD connector on up hole end of coil with 3" GS. Strip back down over coil. Pull test to 30k, RIH till we're at neutral wt 22k. Open up manual pipe/slips on bops. Open hydraulic pipe/slips Hanging wt 20k.,Try and rih to set landing sub in 7" hanger. Land in landing collar at 8.3' down. (7059.2') Tools left in hole. ( 3" G Profile landing sub 4" X 1.2') ( Inverted Ext. Slip CTC 2.375 Coil 3.250" x 1.82') ( 2.375" Coil 2.375" x 7,160') (EXT Slip CTC 3.25" X 1.82') ( XO 3.1" X .5') ( Stinger assembly with two centralizers 5.25" x 10.95') ( XN NIPPLE 2.875" X 1'. Min ID 1.35" ) ( Blow out sub 3500lbs),String landed, Draw down test done on 7" tubing hanger. Pass. Pressure up on coil with N2 to pump off tubing hanger, G-Spear Released at 3800 psi from tubing hanger. Bleed down coil, Pop off well, break down tools. Stack down Lubricator and injector head. Secure well and location. Job in progress. 1/13/2021 Travel to location.,Contact DSO, Get PTW signed. Inspect location. PJSM,Remove 7" swab valve and riser, pu 4.06" well head adapter, flange up to wellhead. Pt hanger to 5k, good test.,Test BOPE as per Hilcorp & AOGCC requirements, witnessed waived 1/12/2021 @ 08:53 AM by AOGCC Inspecti ons Supervisor Jim Regg, 250/4000. Emailed BOPE Test Report to AOGCC.,PU injector head, run down and dress coil for weld on connector. Weld connector on end of coil. Max OD 1.90". PU 11' Lubricator, Make up BHA with X nipple and WL entry guide. Stab on well. ( CTC 1.90" X .16') ( SPACER PIPE WITH X-NIPPLE Min ID 1.35", 1.9" X 2.78') TOL= 2.94',Open swab, RIH, WHP 0. Tag at 11.8' into wellhead. That's right at the XO from 2" to 7.06" spool. Unflang and rih guiding it in by hand.,Inside 2.375' coil. Flanged back up, RIH. WT CK 2000'= 5k, WT CK 5,000'= 9K,Tag @ 7148' That is right at the XO on the bha of the 2.375" coil. UP WT 10k. PU 15' to 7130'. Set slips, push/pull 10k/15k. Strip up off lubricator to begin our cut. Pipe is cut, Make up inverted CTC 3.25" X 1.82', tubing hanger adapter 3.75" X .6')Make up CTC 3.25" X 1.82' on the up hole end. Pull test to 20k, put on 3" G- spear. Stab on Tubing head adapter with spear. Strip down over coil. Make up Lubricator.,Land 1.75" coil on Tubing hanger. Pressure up on coil to 3800 psi, release G-Spear. Come up to our zero. Close swab. bleed pressure down on coil. Line up to pressure up on coil strings to blow out the blow out plug. Appears the blow out plug went. WHP at 190 psi. 180,000 scf total pumped. 7,148' of 1.75" coil left in hole. WHP 190 psi.,Start rigging d own Coil package. 1/14/2021 Travel to location,Arrive on location, Contact DSO, Inspect location, get PTW. PJSM,Remove Bop's, rig down hard line, unhook all hydraulic hoses, Load trailers with coil package. Make up rest of 4.06" Wellhead valves. Well secure, coil rigged down. Well ready for Slickline to set Standing Valve. ct pp p gg pp Close swab. bleed pressure down on coil. Line up to pressure up on coil strings to blow out the blow out plug. Appears thep blow out plug went. 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:;< 879%1 : < 859% : < /0 : < /0 : < 2 534 :< 2 74 :< 0 :< :;9&@< /5 : 9:8*8) ::*: )3*9 9):*) 393* 9*4 )39*$ 4 8 $9*$) 4)$ 94*83 4*$ 33$*9) ?&21="1&1 7+4- : 3)*8) :*3 )9*3 3$*: $3*4 9*94 94*9 4 8 38)*39 4)$ 94* *4: $$*38 ?&21="1&1 7+4- : 39$*9 ::*49 )9*4) 38*89 $3*$ 4$*$3 989*39 4 8 38*9 4)$ 94*) *$4 $34*)8 ?&21="1&1 7+4- 8 $*8 :*3 9*:$ 394*8 4*43 4$*4$ 3$*)8 4 8 98*34 4)$ 94*94 *4) *$4 ?&21="1&1 7+4- 8 $)* :*3 94*48 $3* 3*8 9*3 3* 4 8 94*)3 4)$ 94*$ $*39 38* ?&21="1&1 7+4- 8 89*3$ ::*3 9*)$ $:*9 4:*$8 8*) 3)8*)9 4 8 )84*4 4)$ 99*9 $*9: 48*88 ?&21="1&1 7+4- 8 4*4 ::*$9 9$*98 $3$*$ 438*) :*8$ $4*$ 4 8 )*8 4)$ 98*4: *4 43)*)4 ?&21="1&1 7+4- 8 43*3 ::*$3 )3*9: 4*8$ :*8$ :*43 $8*3$ 4 8 88*): 4)$ 9*33 *) )* ?&21="1&1 7+4- 8 :*9 ::*:: )3*4 :3*9 38*3 :*88 $94* 4 8 8$*98 4)$ 9*9 *$4 39*$ ?&21="1&1 7+4- 8 :*8 ::*3 )9*4 3*3: )*: 8*8) )*4: 4 8 ::3*9$ 4)$ 9*$ *44 3*$) ?&21="1&1 7+4- 8 ))*3) ::*3 ))*9 4$*) 33*$) 9*: :4*)) 4 8 :$9*4: 4)$ 9:*4: *4: :$$*8 ?&21="1&1 7+4- 8 :3*88 ::*3 )8*9 48:*4 :3*9 4*$ 9)*)4 4 8 :)* 4)$ 98*)3 $*9: ::*: ?&21="1&1 7+4- 8 8$*4 :8*$ )3*:9 433*33 8$$*98 44*84 444*43 4 8 $8*$ 4)$ 9)*3 *3 8$4*3 ?&21="1&1 7+4- 8 88*$ :8*4$ 9$*9 *4) 8:4*: 44* 4:8*:) 4 8 ::*4 4)$ 98*44 *) 8:*)8 ?&21="1&1 7+4- 8 )4:*4) :8*4 )3*39 89*99 )$*3$ 44*$8 43*9 4 8 $*3 4)$ 9*9: *: )$:*9 ?&21="1&1 7+4- 8 )98*98 ::* 94*)9 $*:4 ):*9 4$*9 4:*94 4 8 4:4*:4 4)$ 94*8: *$ ):8* ?&21="1&1 7+4- 8 99*8: :*34 )9*9$ 9*9: 9$:*9 4$* 8*: 4 8 4$*9) 4)$ 9$*38 :* 9$8*39 ?&21="1&1 7+4- 8 3*9 :*93 ))*38 )*39 9:8*9) 4*:3 3)*49 4 8 :$*) 4)$ 9* *$3 9:9*3 ?&21="1&1 7+4- 8 3)4*8 :*) ))*:) :$*4$ 3$8*)3 4*: 4*:$ 4 8 $$*:4 4)$ 94* $*:9 3$9* ?&21="1&1 7+4- ) $*9 :*3 )8*:) ::*)3 3:)*44 48*4 89*$3 4 8 $:$*$8 4)$ 9*$4 *8 3:9*94 ?&21="1&1 7+4- ) $38*)8 ::*9 )3*4 :9*:4 : $$9* 49*$ :$*94 4 84 339*3 4)$ 9*3: *) : $$3*3 ?&21="1&1 7+4- ) :3*4 ::*4 )9*3 8)*4 : $:3*8 49*3 :3*4 4 84 3)*8 4)$ 9*9 $* : $8*4: ?&21="1&1 7+4- ) 44*)3 ::*$ )9* 8:4*94 : $*33 $*$3 :):*4 4 84 938*4 4)$ 9:*$4 $*)8 : 4*8 ?&21="1&1 7+4- ) 49*9 :*98 ))*)8 899* : 8*)) *)9 8$*) 4 84 9:* 4)$ 9:*) $*3) : 8*: ?&21="1&1 7+4- ) $*$$ :*98 ))*)8 )4$*)8 : 4$)*8) *:) 8*$8 4 84 )33*:4 4)$ 98*8 $*$$ : 4$3*9 "/C,0,0 %!AD%!A A Benjamin Hand Digitally signed by Benjamin Hand Date: 2020.12.07 11:55:09 -09'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2020.12.07 14:03:42 -09'00' TD Shoe Depth: PBTD: Jts. 2 52 Yes X No X Yes No 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 10 3/4 L-80 134.75 15117.19 Rotate Csg Recip Csg Ft. Min. PPG9.4 Shoe @ 2239.23 FC @ Top of Liner #N/A2,153.14 Floats Held 131.94 188 38.5 149.5 Spud Mud CASING RECORD County State Alaska Supv.S Barber/ C Montague Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.GS KU 44-01B Date Run 12-Nov-20 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top BTC Downhole Solution 1.59 2,239.23 2,237.64 Csg Wt. On Hook:75 Type Float Collar:Conventional No. Hrs to Run:9 9.4 6 100 440FIRST STAGE10.5Tuned 58 148.5/153 790 38.5 Rig 15.8 48 Bump press CBL Bump Plug? 0:18 11/13/2020 2,000 2,239.232,244.00 CEMENTING REPORT Csg Wt. On Slips: Spud Mud 12 140 Type of Shoe:Bullnose Casing Crew:Weatherford www.wellez.net WellEz Information Management LLC ver_04818br 4108.4Water 4 (2) on joint 1, (1) on joints 2, 3 then every other joint to joint 46 (352') Casing 9 5/8 40.0 L-80 DWC/C 82.99 2,237.64 2,154.65 Float Collar 10 3/4 L-80 BTC Downhole Solutions 1.51 2,154.65 2,153.14 Casing 9 5/8 40.0 L-80 DWC/C 2,127.74 2,088.00 25.40 Pup Joint 9 5/8 40.0 L-80 DWC/C 2.39 25.40 23.01 Hanger 10 3/4 1.11 23.01 21.90 Type I/II 330 2.38 Type I/II 232 1.16 4.5 2,000020002000200022 CBLCBLCBLL TD Shoe Depth: PBTD: Jts. 134 Yes X No Yes X No 15.1 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? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: Casing (Or Liner) Detail Shoe ZXP Liner Top Packer 7 5/8 127 4123 Rotate Csg Recip Csg Ft. Min. PPG9.2 Shoe @ 7249 FC @ Top of Liner 18947,204.00 Floats Held 10 152 25 127 2500 EZ Mud CASING RECORD County State Alaska Supv.S Barber/ O Amend Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.GS KU 44-01B Date Run 7-Dec-20 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top BTC Baker 2.04 7,250.00 7,247.96 21.19 1,913.91 1,892.728 5/8 7" H565 Baker Csg Wt. On Hook:185,000 Type Float Collar: No. Hrs to Run:8 9.2 5 99 950FIRST STAGE10.5Tuned Spacer W/ red dye 35 215/218 1513 25 1 15.3 17 Bump press CBL Bump Plug? 5:15 12/8/2020 2,000 7,250.007,250.00 CEMENTING REPORT Csg Wt. On Slips:145,000 EZ Drill 12 135 Type of Shoe:Eccentric Casing Crew:Weatherford Baker ZXP Liner Top W/ RS www.wellez.net WellEz Information Management LLC ver_04818br 2.5 Ran 71 ea 7" Solid body centralizers. ! ea to 6,500' MD Every other joint to BOW 2,088' MD. 7" Liner 7 26.0 L-80 BTC US Steel 41.64 7,247.96 7,206.32 Float Collar 7 5/8 BTC Baker 1.28 7,206.32 7,205.04 7" Liner 7 26.0 L-80 CDC HT US Steel 41.62 7,205.04 7,163.42 Landing Collar 7 5/8 BTC Baker 1.76 7,163.42 7,161.66 7" Liner 7 26.0 L-80 CDC HT US Steel 5,232.27 7,161.66 1,929.39 Pup 7 26.0 L-80 CD HT Baker 3.75 1,929.39 1,925.64 XO 7 5/8 26.0 L-80 CDC HT Baker 1.64 1,925.64 1,924.00 Flex Loc Liner Hanger 8 5/8 7" H563 Baker 9.32 1,924.00 1,914.68 Coupling 7 5/8 7" H564 Baker 0.77 1,914.68 1,913.91 ExtendCem 315 2.38 Premium G 80 1.24 5 PB1 TD 7,340' MD / 4,721' TVD KOP Whipstock @ 2,088' MD / 1,751' TVD Date 11/30/2020 Note:Nuke BHA left in hole KU 44-01B PB Summary Nuke BHA left in hole 11denrp %Ltoka- UL \J -VC, Date: 01/28/2021 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 KU 44-01B, KU 44-01BPB1 (PTD 220-065) Washed and Dried Well Samples B Set - KU 44-OIB (3 Boxes): WELL BOX SAMPLE INTERVAL (FEET / MD) KU 44-01 B BOX 1 OF 3 2100'- 3900' MD KU 44-01 B BOX 2 OF 3 3900'- 5700' MD KU 44-01 B BOX 3 OF 3 5700'- 7250' MD (TD) B Set - KU 44-01BPB1 (4 Boxes): WELL BOX SAMPLE INTERVAL (FEET / MD) KU 44-01 BPB1 BOX 1 OF 4 1970'- 3500' MD KU 44-01 BPB1 BOX 2 OF 4 3500' - 4850' MD KU 44-01 BPB1 BOX 3 OF 4 4850'- 6200' MD KU 44-01 BPB1 BOX 4 OF 4 6200'- 7430' MD (TD) Please include current contact information if different from above. �D __00 5- RECEIVED ,SAN 2 8 2021 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal via Email or 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tĞĐĂŶƉĞƌŵŝƚǁĞůůĂƐĂŐĂƐƉƌŽĚƵĐĞƌĂƚƚŚŝƐƚŝŵĞ͘/Ĩ,ŝůĐŽƌƉǁĂŶƚƐƚŽŝŶũĞĐƚŐĂƐŝŶƚŚĞĨƵƚƵƌĞĂƐƵŶĚƌǇǁŝůůŶĞĞĚƚŽďĞ ƐƵďŵŝƚƚĞĚǁŝƚŚĐŚĂŶŐĞƐƚŽƚŚĞĐŽŵƉůĞƚŝŽŶƌĞƋƵŝƌĞĚ͘;ŝ͘Ğ͘ƚƵďŝŶŐĂŶĚƉĂĐŬĞƌͿ͘dŚĞKZĂŶĚŽƚŚĞƌƉƌĞͲŝŶũĞĐƚŝŽŶǁŽƌŬŚĂƐ ďĞĞŶĂůƌĞĂĚǇƐŽŝƚŝƐŽŶůǇĂŵĂƚƚĞƌŽĨĐŚĂŶŐŝŶŐƚŚĞĐŽŵƉůĞƚŝŽŶĐŽŶĨŝŐƵƌĂƚŝŽŶ͘ 'ƵǇ^ĐŚǁĂƌƚǌ ^ƌ͘WĞƚƌŽůĞƵŵŶŐŝŶĞĞƌ K' ϵϬϳͲϯϬϭͲϰϱϯϯĐĞůů ϵϬϳͲϳϵϯͲϭϮϮϲŽĨĨŝĐĞ CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). 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If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). &ƌŽŵ͗dĞĚ<ƌĂŵĞƌфƚŬƌĂŵĞƌΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗DŽŶĚĂǇ͕ĞĐĞŵďĞƌϮϭ͕ϮϬϮϬϵ͗ϬϬD dŽ͗^ĐŚǁĂƌƚǌ͕'ƵǇ>;ͿфŐƵǇ͘ƐĐŚǁĂƌƚǌΛĂůĂƐŬĂ͘ŐŽǀх Đ͗:ĂŬĞ&ůŽƌĂͲ;Ϳф:ĂŬĞ͘&ůŽƌĂΛŚŝůĐŽƌƉ͘ĐŽŵх͖ŽŶŶĂŵďƌƵǌфĚĂŵďƌƵǌΛŚŝůĐŽƌƉ͘ĐŽŵх͖ZŽďǇ͕ĂǀŝĚ^;Ϳ фĚĂǀĞ͘ƌŽďǇΛĂůĂƐŬĂ͘ŐŽǀх͖ŽǇĞƌ͕ĂǀŝĚ>;ͿфĚĂǀŝĚ͘ďŽǇĞƌϮΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗Z͗΀ydZE>΁<hϰϰͲϬϭƐƵŶĚƌǇƚŽƉĞƌĨ;WdϮϮϬͲϬϲϱͿ 'ƵǇ͕ ĨƚĞƌůŽŽŬŝŶŐŝŶƚŽƚŚĞƉĞƌŵŝƚƚŝŶŐĨŽƌƚŚŝƐǁĞůůŚĞƌĞĂƚ,ŝůĐŽƌƉ ǇŽƵĂƌĞĐŽƌƌĞĐƚŝƚǁĂƐƐƵďŵŝƚƚĞĚĂƐĂƉƌŽĚƵĐĞƌͬ ŝŶũĞĐƚŽƌ͘^ŝŶĐĞƚŚĂƚƉĞƌŵŝƚǁĂƐĨŝůĞĚ͕ŝƚǁĂƐĚĞĐŝĚĞĚŝŶƚĞƌŶĂůůǇ;Ăƚ,ŝůĐŽƌƉͿƚŚĂƚǁŚĂƚǁĂƐŶĞĞĚĞĚƚŽŵĞĞƚƚŚĞŶĞĐĞƐƐĂƌǇ ĚĞŵĂŶĚƚŚŝƐǁŝŶƚĞƌŝƐƚŽŵĂŬĞƚŚŝƐǁĞůůĂƉƌŽĚƵĐĞƌŽŶůǇ͘dŚŝƐǁŽƵůĚĂůůŽǁ,ŝůĐŽƌƉƚŽďĞĂďůĞƚŽƉƌŽĚƵĐĞĂƐŵƵĐŚůŽǁ ƉƌĞƐƐƵƌĞŐĂƐĂƐƉŽƐƐŝďůĞƵƉƚŚĞϮͲϯͬϴ͟yϳ͟ĂŶŶƵůƵƐ͘ ,ŝůĐŽƌƉďĞůŝĞǀĞƐƚŚĂƚƚŚĞƌĞŝƐĐƵƌƌĞŶƚůǇĞŶŽƵŐŚŝŶũĞĐƚŝŽŶĐĂƉĂĐŝƚǇƚŽƉƌĞƐƐƵƌĞƵƉƚŚĞƉŽŽůϲƌĞƐĞƌǀŽŝƌƚŚŝƐƐƵŵŵĞƌ͘ /ƐƚŚĞƌĞĂŵĞĐŚĂŶŝƐŵĨŽƌŵĂŬŝŶŐƚŚŝƐǁĞůůĂƉƌŽĚƵĐĞƌŽŶůǇŶŽǁ;ŝŶƚŚĞĐŽŵƉůĞƚŝŽŶ^ƵŶĚƌǇĂƐĂĐŽŶĚŝƚŝŽŶĨŽƌĂƉƉƌŽǀĂůͿ͕ ĂŶĚƚŚĞŶĂƚĂůĂƚĞƌĚĂƚĞĐŽŶǀĞƌƚŝŶŐŝƚƚŽĂƉƌŽĚƵĐĞƌͬŝŶũĞĐƚŽƌŝĨŶĞĞĚĞĚ͍ dĞĚ<ƌĂŵĞƌ ^ƌ͘KƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌ ,ŝůĐŽƌƉͲůĂƐŬĂ>> KĨĨŝĐĞʹϵϬϳͲϳϳϳͲϴϰϮϬ ĞůůʹϵϴϱͲϴϲϳͲϬϲϲϱ &ƌŽŵ͗^ĐŚǁĂƌƚǌ͕'ƵǇ>;Ϳ΀ŵĂŝůƚŽ͗ŐƵǇ͘ƐĐŚǁĂƌƚǌΛĂůĂƐŬĂ͘ŐŽǀ΁ ^ĞŶƚ͗&ƌŝĚĂǇ͕ĞĐĞŵďĞƌϭϴ͕ϮϬϮϬϭϮ͗ϭϰWD dŽ͗dĞĚ<ƌĂŵĞƌфƚŬƌĂŵĞƌΛŚŝůĐŽƌƉ͘ĐŽŵх Đ͗:ĂŬĞ&ůŽƌĂͲ;Ϳф:ĂŬĞ͘&ůŽƌĂΛŚŝůĐŽƌƉ͘ĐŽŵх͖ŽŶŶĂŵďƌƵǌфĚĂŵďƌƵǌΛŚŝůĐŽƌƉ͘ĐŽŵх͖ZŽďǇ͕ĂǀŝĚ^;Ϳ фĚĂǀĞ͘ƌŽďǇΛĂůĂƐŬĂ͘ŐŽǀх͖ŽǇĞƌ͕ĂǀŝĚ>;ͿфĚĂǀŝĚ͘ďŽǇĞƌϮΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗Z͗΀ydZE>΁<hϰϰͲϬϭƐƵŶĚƌǇƚŽƉĞƌĨ;WdϮϮϬͲϬϲϱͿ dĞĚ͕ dŚĞWdĂƉƉůŝĐĂƚŝŽŶĚŝĚŶŽƚŵĞŶƚŝŽŶƚŚŝƐǁĂƐĂƉƌŽĚƵĐĞƌŽŶůǇŐĂƐ^ƚŽƌĂŐĞǁĞůů;ƚǇƉŝĐĂůůǇƚŚŝƐŝƐƐƚĂƚĞĚŝŶƚŚĞǁĞůů ƐƵŵŵĂƌǇŝŶƐĞĐƚŝŽŶϳŽĨƚŚĞWdͿ͘/ƚǁĂƐƉĞƌŵŝƚƚĞĚĂƐĂŶŽƌŵĂů'^dKZǁĞůů͘>ŽŽŬŝŶŐĂƚƚŚĞŝŶŝƚŝĂůǁĞůůƉůĂŶ/ǁĂƐ ĂƐƐƵŵŝŶŐƚŚĂƚƚŚĞǁĞůůǁŽƵůĚŚĂǀĞĂƚƵďŝŶŐĂŶĚƉĂĐŬĞƌƚŽĂůůŽǁŝŶũĞĐƚŝŽŶĂƐǁĞůůĂƐƉƌŽĚƵĐƚŝŽŶƐŝŶĐĞϳ͟ĐĂƐŝŶŐǁĂƐƌƵŶ ƚŽd͘dŚĞƉƌŽƉŽƐĞĚĐŽŵƉůĞƚŝŽŶĚŽĞƐŶŽƚŵĞĞƚŽƵƌƌĞŐƵůĂƚŝŽŶƐĨŽƌŝŶũĞĐƚŝŽŶŽĨŐĂƐ͘ ůƐŽƚŚŝƐŝƐĂďŝƚƐƚƌĂŶŐĞĂƐƚŚĞ,WŽĨƚŚĞ^ƚŽƌĂŐĞƉŽŽůŝƐƐŽůŽǁĂƚƚŚŝƐƚŝŵĞƚŚĂƚǇŽƵǁŽƵůĚƉĞƌŵŝƚƚŚŝƐĂƐƉƌŽĚƵĐĞƌǀƐ ŚĂǀŝŶŐƚŚĞĂďŝůŝƚǇƚŽŝŶũĞĐƚŐĂƐƚŽďŽŽƐƚ,WŝŶƚŚĞĨƵƚƵƌĞ͘ 'ƵǇ^ĐŚǁĂƌƚǌ ^ƌ͘WĞƚƌŽůĞƵŵŶŐŝŶĞĞƌ K' ϵϬϳͲϯϬϭͲϰϱϯϯĐĞůů ϵϬϳͲϳϵϯͲϭϮϮϲŽĨĨŝĐĞ CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). &ƌŽŵ͗dĞĚ<ƌĂŵĞƌфƚŬƌĂŵĞƌΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗dŚƵƌƐĚĂǇ͕ĞĐĞŵďĞƌϭϳ͕ϮϬϮϬϭ͗ϱϯWD dŽ͗^ĐŚǁĂƌƚǌ͕'ƵǇ>;ͿфŐƵǇ͘ƐĐŚǁĂƌƚǌΛĂůĂƐŬĂ͘ŐŽǀх Đ͗:ĂŬĞ&ůŽƌĂͲ;Ϳф:ĂŬĞ͘&ůŽƌĂΛŚŝůĐŽƌƉ͘ĐŽŵх͖ŽŶŶĂŵďƌƵǌфĚĂŵďƌƵǌΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗Z͗΀ydZE>΁<hϰϰͲϬϭƐƵŶĚƌǇƚŽƉĞƌĨ;WdϮϮϬͲϬϲϱͿ 'ƵǇ͕ ^ƵƌĞ͘/ƚŝƐĂƉƌŽĚƵĐĞƌŽŶůǇ͘dŚĞĐŽŶĐĞŶƚƌŝĐƐƚƌŝŶŐŝƐŽŶůǇĨŽƌďůŽǁŝŶŐǁĂƚĞƌŽĨĨƚŚĞǁĞůůƐŚŽƵůĚĂŶǇĂĐĐƵŵƵůĂƚĞŽǀĞƌ ƚŝŵĞ͘ 'ĂƐĨůŽǁǁŝůůďĞƵƉƚŚĞϮͲϯͬϴ͟yϳ͟ĂŶŶƵůƵƐ͘ dŚĞϮͲϯͬϴ͟ĐŽŝůƐƚƌŝŶŐǁŝůůŚĂǀĞĂŶƵŶĚĞƌƐŝǌĞĚ,ŽŶŝƚ͘^ůŝĐŬůŝŶĞǁŝůůďĞƵƚŝůŝǌĞĚƚŽƌƵŶĂƐƚĂŶĚŝŶŐǀĂůǀĞƚŚƌŽƵŐŚƚŚĞϭͲ ϯͬϰ͟ĐŽŝůƐƚƌŝŶŐĂŶĚƐĞƚƚŚĞƐƚĂŶĚŝŶŐǀĂůǀĞŝŶƚŚĞϮͲϯͬϴ͟,͘ /ĨǁĂƚĞƌĂĐĐƵŵƵůĂƚĞƐŽŶƚŚĞďŽƚƚŽŵŽĨƚŚĞǁĞůůŝƚǁŝůůŽƉĞŶƚŚĞ ƐƚĂŶĚŝŶŐǀĂůǀĞĂŶĚĞŶƚĞƌƚŚĞĐŽŝů͘tĞǁŝůůƚŚĞŶŝŶũĞĐƚ ŚŝŐŚƉƌĞƐƐƵƌĞŐĂƐĚŽǁŶƚŚĞϮͲϯͬϴ͟ƐƚƌŝŶŐǁŚŝĐŚǁŝůůĨŽƌĐĞƚŚĞ^sĐůŽƐĞĚĂŶĚďůŽǁƚŚĞǁĂƚĞƌƵƉƚŚĞϭͲϯͬϰ͟ĐŽŝůƚŽĂƚĂŶŬ͘ KŶĐĞƚŚĞŐĂƐŝƐƐŚƵƚŽĨĨƚŽƚŚĞĐŽŝůĂŶĚƚŚĞƉƌĞƐƐƵƌĞŝƐďůĞĚĚŽǁŶ͕ĂƚƐŽŵĞƉŽŝŶƚƚŚĞ^sƉƌĞƐƐƵƌĞĂďŽǀĞĂŶĚďĞůŽǁƚŚĞ ďĂůůǁŝůůĞƋƵĂůŝǌĞĂŶĚƚŚĞďĂůůǁŝůůŽƉĞŶĂůůŽǁŝŶŐŵŽƌĞǁĂƚĞƌƚŽĞŶƚĞƌǁŝƚŚĂƐůŝŐŚƚǀĞŶƚƵƌĞͬƐŝƉŚŽŶĞĨĨĞĐƚ͘dŚĞƉƌŽĐĞƐƐŝƐ ƚŚĞŶƌĞƉĞĂƚĞĚ͘ dĞĚ<ƌĂŵĞƌ ^ƌ͘KƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌ ,ŝůĐŽƌƉͲůĂƐŬĂ>> KĨĨŝĐĞʹϵϬϳͲϳϳϳͲϴϰϮϬ ĞůůʹϵϴϱͲϴϲϳͲϬϲϲϱ &ƌŽŵ͗^ĐŚǁĂƌƚǌ͕'ƵǇ>;Ϳ΀ŵĂŝůƚŽ͗ŐƵǇ͘ƐĐŚǁĂƌƚǌΛĂůĂƐŬĂ͘ŐŽǀ΁ ^ĞŶƚ͗dŚƵƌƐĚĂǇ͕ĞĐĞŵďĞƌϭϳ͕ϮϬϮϬϭϮ͗ϮϴWD dŽ͗dĞĚ<ƌĂŵĞƌфƚŬƌĂŵĞƌΛŚŝůĐŽƌƉ͘ĐŽŵх Đ͗:ĂŬĞ&ůŽƌĂͲ;Ϳф:ĂŬĞ͘&ůŽƌĂΛŚŝůĐŽƌƉ͘ĐŽŵх͖ŽŶŶĂŵďƌƵǌфĚĂŵďƌƵǌΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗Z͗΀ydZE>΁<hϰϰͲϬϭƐƵŶĚƌǇƚŽƉĞƌĨ;WdϮϮϬͲϬϲϱͿ dĞĚ͕ ĂŶǇŽƵĞǆƉůĂŝŶƚŚĞĐŽŶĐĞŶƚƌŝĐĐŽŝůĐŽŵƉůĞƚŝŽŶ͍dŚŝƐŝƐĂŐĂƐƐƚŽƌĂŐĞƉŽŽůĐŽŵƉůĞƚŝŽŶĨŽƌƉƌŽĚƵĐƚŝŽŶŽŶůǇ͘ 'ƵǇ^ĐŚǁĂƌƚǌ ^ƌ͘WĞƚƌŽůĞƵŵŶŐŝŶĞĞƌ K' ϵϬϳͲϯϬϭͲϰϱϯϯĐĞůů ϵϬϳͲϳϵϯͲϭϮϮϲŽĨĨŝĐĞ CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). &ƌŽŵ͗dĞĚ<ƌĂŵĞƌфƚŬƌĂŵĞƌΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗dŚƵƌƐĚĂǇ͕ĞĐĞŵďĞƌϭϳ͕ϮϬϮϬϭϭ͗ϮϮD dŽ͗^ĐŚǁĂƌƚǌ͕'ƵǇ>;ͿфŐƵǇ͘ƐĐŚǁĂƌƚǌΛĂůĂƐŬĂ͘ŐŽǀх Đ͗:ĂŬĞ&ůŽƌĂͲ;Ϳф:ĂŬĞ͘&ůŽƌĂΛŚŝůĐŽƌƉ͘ĐŽŵх͖ŽŶŶĂŵďƌƵǌфĚĂŵďƌƵǌΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗Z͗΀ydZE>΁<hϰϰͲϬϭƐƵŶĚƌǇƚŽƉĞƌĨ;WdϮϮϬͲϬϲϱͿ 'ƵǇ͕ ,ĞƌĞŝƐƚŚĞ^ĐŚĞŵĂƚŝĐǁŝƚŚƚŚĞĐĞŵĞŶƚǀŽůƵŵĞƐŽŶŝƚ͘ dĞĚ<ƌĂŵĞƌŽŶŶĂ ^ƌ͘KƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌ ,ŝůĐŽƌƉͲůĂƐŬĂ>> KĨĨŝĐĞʹϵϬϳͲϳϳϳͲϴϰϮϬ ĞůůʹϵϴϱͲϴϲϳͲϬϲϲϱ &ƌŽŵ͗^ĐŚǁĂƌƚǌ͕'ƵǇ>;Ϳ΀ŵĂŝůƚŽ͗ŐƵǇ͘ƐĐŚǁĂƌƚǌΛĂůĂƐŬĂ͘ŐŽǀ΁ ^ĞŶƚ͗dŚƵƌƐĚĂǇ͕ĞĐĞŵďĞƌϭϳ͕ϮϬϮϬϵ͗ϬϯD dŽ͗dĞĚ<ƌĂŵĞƌфƚŬƌĂŵĞƌΛŚŝůĐŽƌƉ͘ĐŽŵх Đ͗:ĂŬĞ&ůŽƌĂͲ;Ϳф:ĂŬĞ͘&ůŽƌĂΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗΀ydZE>΁<hϰϰͲϬϭƐƵŶĚƌǇƚŽƉĞƌĨ;WdϮϮϬͲϬϲϱͿ dĞĚ͕ /ŶŶĞǁǁĞůůƐƚŚĞĐĞŵĞŶƚƐƵŵŵĂƌǇƐŚŽƵůĚďĞŝŶĐůƵĚĞĚĨŽƌƚŚĞƐƵƌĨĂĐĞĂŶĚƉƌŽĚƵĐƚŝŽŶĐĂƐŝŶŐ͘/ŬŶŽǁƚŚĞ>ŚĂƐŶ͛ƚďĞĞŶ ƌƵŶǇĞƚďƵƚƚŚĞƐĐŚĞŵĂƚŝĐĂƚƚŚŝƐƉŽŝŶƚƐŚŽƵůĚŚĂǀĞƚŚĞǀŽůƵŵĞƐƉƵŵƉĞĚ ŶĚĂƚůĞĂƐƚĂŶŽŵŝŶĂůdKƉŝĐŬ͘>ĚĂƚĂĐĂŶďĞĂĚĚĞĚůĂƚĞƌ͘ 'ƵǇ^ĐŚǁĂƌƚǌ ^ƌ͘WĞƚƌŽůĞƵŵŶŐŝŶĞĞƌ K' ϵϬϳͲϯϬϭͲϰϱϯϯĐĞůů ϵϬϳͲϳϵϯͲϭϮϮϲŽĨĨŝĐĞ CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). 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If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov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amuel 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: 12/21/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KU 44-01B (PTD 220-065) RCBL Radial Cement Bond Log 12/17/2020 Please include current contact information if different from above. PTD: 2200650 E-Set: 34441 Received by the AOGCC 12/22/2020 Abby Bell 12/23/2020 David Douglas Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: Date: 12/15/2020 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL KU 44-01B + PB1 (PTD 220-065) GEOLOG: EOW DRILLING REPORTS (11/09/2020 to 12/05/2020) 1.DAILY DRILLING REPORTS 2.FINAL EOW REPORT 3.DIGITAL DATA 4.LWD LOG PRINTS 5.MUDLOG PRINTS 6.SHOW REPORTS Folder Contents: Sub-Folder Contents: Please include current contact information if different from above. Received by the AOGCC 12/16/2020 PTD: 2200650 E-Set: 34401 Abby Bell 12/16/2020 David Douglas Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: Date: 12/15/2020 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL KU 44-01B + PB1 (PTD 220-065) GEOLOG: EOW DRILLING REPORTS (11/09/2020 to 12/05/2020) 1.DAILY DRILLING REPORTS 2.FINAL EOW REPORT 3.DIGITAL DATA 4.LWD LOG PRINTS 5.MUDLOG PRINTS 6.SHOW REPORTS Folder Contents: Sub-Folder Contents: Please include current contact information if different from above. Received by the AOGCC 12/16/2020 PTD: 2200650 E-Set: 34402 Abby Bell 12/16/2020 David Douglas Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or fax to 907 777-8510. Received By: Date: Date: 12/15/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KU 44-01B + PB1 (PTD 220-065) FINAL LWD FORMATION EVALUATION LOGS (11/08/2020 to 12/04/2020) •ROP, DGR, EWR, ADR, ALD, CTN (2” & 5” MD/TVD Color Logs) •Final Definitive Directional Survey Folder Contents: Sub-Folder Contents: Please include current contact information if different from above. Received by the AOGCC 12/16/2020 PTD: 2200650 E-Set: 33403 Abby Bell 12/16/2020 David Douglas Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or fax to 907 777-8510. Received By: Date: Date: 12/15/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KU 44-01B + PB1 (PTD 220-065) FINAL LWD FORMATION EVALUATION LOGS (11/08/2020 to 12/04/2020) •ROP, DGR, EWR, ADR, ALD, CTN (2” & 5” MD/TVD Color Logs) •Final Definitive Directional Survey Folder Contents: Sub-Folder Contents: Please include current contact information if different from above. Received by the AOGCC 12/16/2020 PTD: 2200650 E-Set: 34404 Abby Bell 12/16/2020 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Abandon BHA (RA) 2. Operator Name:4. Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.W ell Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 7,340'N/A Casing Collapse Structural Conductor Surface 3090 Intermediate Production (FISH) Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Yes Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:11/25/2020 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Joe Engel jengel@hilcorp.com 777-8395 4,721' 2,211' (TOF) 1,816' 1631 N/A Length Size COMMISSION USE ONLY Guy Schwartz 11/24/2020 Tubing Grade: Tubing MD (ft): N/A N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL392668, ADL392670, FEE AA093836 220-065 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 N/A 50-133-20692-00-00 Hilcorp Alaska, LLC Kenai Gas Field / Sterling Pool 6 Gas Storage KU 44-01B PRESENT WELL CONDITION SUMMARY N/A TVD Burst N/A MD 5750 120' 1,837' 120' 2,239' 13-3/8" 9-5/8" 120' 2,239' Perforation Depth MD (ft): N/A 4-1/2" Perforation Depth TVD (ft): Tubing Size: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 11/24/2020 7,320'5,109' N/A 4,711' N/A Authorized Title: Drilling Manager Authorized Name: Monty Myers Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:54 pm, Nov 25, 2020 320-503 Digitally signed by Joseph Engel DN: cn=Joseph Engel, ou=Users Date: 2020.11.25 14:33:16 - 09'00' Joseph Engel DSR-11/25/2020 X DLB11/25/2020 Abandon BHA (RA) gls 11/27/20 10-407 (final well report) Comm q 11/30/2020 dts 11/30/2020 JLC 11/30/2020 RBDMS HEW 12/2/2020 Well Prognosis Well: KU 44-01B Date: 11/25/20 Well Name: KU 44-01B API Number: 50-133-20692-00-00 Current Status: Abandon sources & OH Estimated Start Date: 11/24/2020 Rig: Rig 147 Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: 11/24/2020 Regulatory Contact: Cody Dinger 777-8389 Permit to Drill Number: 220-065 First Call Engineer: Joe Engel (907) 777-8395 (O) (805) 235-6265 (M) AFE Number: Brief Well Summary – While drilling ahead in our 8-1/2” production hole at 7,340’ TMD, we lost all returns. The BHA became stuck after returns were established. Over the course of the next few days we attempted to free the pipe conventionally, including pumping diesel around the BHA, with no luck. We ran a freepoint and it indicated we were stuck just outside the surface casing shoe at ~ 2270’ MD, as well as potentially differentially stuck at the BHA. We backed the drill string off at ~ 2170’ MD, inside casing shoe have attempted to free the pipe with fishing jars but have not been able to do so. We attempted to wash over the drill pipe at the stuck depth and that was also unsuccessful. Each time we screw into the drill pipe, we are able to circulate up to 10bpm with full returns. TOF is currently at 2,211’ MD. Due to risk of not being able to fish the BHA or isolate the Pool 6 reservoir from future communication if we begin cutting drillpipe in OH, the asset team has made the decision to cement the BHA in place in order to isolate the pool 6 reservoir for future management. Work performed: x Pump 63 bbls of 14# cement with red dye, bringing planned TOC 750’ above the Pool 6 sand (Pool 6 Top: 6963’ MD) x WOC until sufficient compressive strength has been reached Work to be performed: x RU ELine, RIH and tag top of cement in drill pipe (planned TOC: 6213’ MD) x RU with RCT and cut drillpipe above TOC tag, attempt to recover drillstring o If unable to recover from cut above TOC tag, cut drillipipe at ~ 3000’ MD x POOH with drill pipe. x RIH with 9-5/8” cement retainer and set inside surface casing shoe, ~ 2200’ MD. x Pump 200 bbl of cement below cement retainer o To ensure isolation of pool 6 o If unable to pump all cement beneath retainer, once pressure increased to FIT of surface casing shoe, un-sting from retainer and circulate cement out x Set whipstock on top of cement retainer & Mill Window x Sidetrack well to TD in Pool 6 C1 sand, above loss zone x *Note: o if we are able to retrieve a larger section of drillpipe from above TOC, we will spot and OH cement plug to ensure Pool 6 isolation o We will keep the AOGCC informed as things progress or change during these operations Attachments 1. Actual Schematic 2. Proposed Schematic 3. BHA Tally CBL ran also in drillpipe... submit PDF to AOGCC. *Note: if we are able to retrieve a larger section of drillpipe from above TOC, we will spot and OHo cement plug to ensure Pool 6 isolation We will keep the AOGCC informed as things progress or change during these operationso Updated by CJD 11-25-2020 Current SCHEMATIC Kenai Gas Field KU 44-01B PTD: 220-065 API: 50-133-20692-00-00 PBTD = ±6,213’ MD TD = 7,340’ MD / TVD = 4,721’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 13- 3/8” Conductor – Driven to Set Depth 68 X-56 Weld 12.415” Surf 120' 9-5/8" Surf Csg 40 L-80 DWC/C 8.835” Surf 2,239’ 4-1/2" Fish (Drill Pipe + BHA) 26 L-80 CDS40 3.826” 2,211’ 7,320’ 13-3/8” 9-5/8” 12-1/4” hole 4-1/2” DP + BHA JEWELRY DETAIL No. Depth ID OD Item 1 ~2,000’ 6.180” 8.430” Baker ZXP Liner Top Packer Flex-Lock V liner hanger 2 ~2,000’ 6.151” 7.360” Baker tieback Seal Assembly OPEN HOLE / CEMENT DETAIL 9-5/8" 188 BBL’s of cement in 12-1/4” hole – Returns to surface Fish 63 bbls of 14# Cmt in 8-1/2” hole, BHA and Drill Pipe – TOC ±6,213’ MD 8-1/2” hole TOC ±6,213’ MD 4.5" BHA DRILLPIPE HW DP Updated by CJD 11-25-2020 Proposed SCHEMATIC Kenai Gas Field KU 44-01B PTD: 220-065 API: 50-133-20692-00-00 PBTD = ±6,213’ MD TD = 7,340’ MD / TVD = 4,721’ RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 13- 3/8” Conductor – Driven to Set Depth 68 X-56 Weld 12.415” Surf 120' 9-5/8" Surf Csg 40 L-80 DWC/C 8.835” Surf 2,239’ 4-1/2" Fish (Drill Pipe + BHA) 26 L-80 CDS40 3.826” ±6,200’ 7,320’ 13-3/8” 9-5/8” 12-1/4” hole 4-1/2” DP + BHA w/ nuke JEWELRY DETAIL No. Depth ID OD Item 1 ~2,200’ Cement Retainer OPEN HOLE / CEMENT DETAIL 9-5/8" 188 BBL’s of cement in 12-1/4” hole – Returns to surface Fish 63 bbls of 14# Cmt in 8-1/2” hole, BHA and Drill Pipe – TOC ±6,213’ MD (TBD) Cmt Retainer Pump 200 bbls below Cmt Retainer 8-1/2” hole 1 WELL INFORMATION Created On : Nov 13 2020 Customer :Hilcorp Alaska, LLC Well Name :KU 44-01B Job Number :AK-XX-0906728503 Rig Name :HEC 147 Field Name :Kenai Gas Field Country :USA BHA Tally Drillstring IADC Rig BHA#2 Run#200 Length (ft)Length Cumulative COMPONENT DATA (ft) Item #Description Serial Number OD ID Gauge Weight Top Connection Bottom Connection(in)(in)(in)(lbpf) 1 Hycalog 8-1/2'' SK616M- J1D A271711 6.375 2.750 8.500 88.54 P 4-1/2" REG 0.90 0.90 2 6 3/4" StrataForce Lobe 6:7 - 6 stg 12942910 6.750 4.498 84.02 B 4-1/2" IF B 4-1/2" REG 31.10 32.00 Btm Sleeve Stabilizer 8.375 Bottom Stabilizer 8.380 3 6 3/4" DM Collar 12196837 6.670 3.125 103.40 B NC 50 P NC 50 9.16 41.16 4 6 3/4" DGR Collar 90678260 6.750 1.920 97.80 B NC 50 P NC 50 8.35 49.51 5 6 3/4" PWD 90678260 6.710 1.905 96.30 B NC 50 P NC 50 4.44 53.95 6 6 3/4" ADR Collar 90678260 6.730 1.920 109.40 B NC 50 B NC 50 26.17 80.12 7 6 3/4" ALD Collar 90628357 6.700 1.920 8.250 104.30 P NC 50 B NC 50 18.20 98.32 Stabilizer 8.250 8 6 3/4" CTN Collar 90628357 6.700 1.905 102.30 B NC 50 P NC 50 15.75 114.07 9 6 3/4" HOC 13071155 6.700 3.250 99.70 B NC 50 P NC 50 10.38 124.45 10 6 3/4" NM Integral Blade Stab 11113459 6.750 2.813 8.375 100.78 B 4-1/2" IF P 4-1/2" IF 8.61 133.06 11 6 3/4" NM Flex Collar 11564292 6.625 2.875 95.36 B 4-1/2" IF P 4-1/2" IF 29.62 162.68 12 6 3/4" NM Flex Collar 11964557 6.688 2.875 97.58 B 4-1/2" IF P 4-1/2" IF 29.30 191.98 13 X-Over Sub UOCD5089 6.063 2.813 77.20 P 4-1/2" IF 2.46 194.44 14 4 Jts 4 1/2" HWDP CDS40 4.500 2.500 40.70 122.89 317.33 15 X-Over Sub UOCD4841 6.250 2.875 82.43 B 4-1/2" IF 1.45 318.78 16 Yellowjacket Jar A30209 6.563 2.813 94.10 B 4-1/2" IF P 4-1/2" IF 32.42 351.20 17 X-Over Sub UOCD5090 6.063 2.875 76.25 P 4-1/2" IF 2.11 353.31 18 13 Jts 4 1/2" HWDP CDS40 4.500 2.500 40.70 397.49 750.80 Total:750.8 BIT DATA Bit Number :2 Nozzles :3x12,3x13 Bit Size (in) :8.500 TFA (in2) :0.7202 Manufacturer :NOV / ReedHycalog Dull Grade In :RBLT Model :SK616M-J1D Dull Grade Out : Serial Number :A271711 INSITE V9.2.0 Page 1Job No: AK-XX-0906728503 Well Name: KU 44-01B BHA Tally MOTOR DATA Motor Number : Bend (deg) :1.502 OD (in) :6.750 Nozzles (32nd) :0.0 Manufacturer :Sperry Drilling Avg Diff Press : Model :StrataForce Cumul Cir Hrs : Serial Number :12942910 BHA Weight (klb) (klb) in Air (Total) :43.54 in Mud (Total) :36.91 Mud Weight (ppg) :10.00 in Air (Below Jars) :24.15 in Mud (Below Jars) :20.47 COMMENTS Motor assembly for 8-1/2” Production Hole section 6-3/4” TerraForce Mud Motor, 8-3/8’’ motor stab @ 1.50°, 0.31 Rev/Gal Dir: xx.xx’, Gamma: xx.xx’ Res: xx.xx’, Density: xx.xx’, Porosity: xx.xx’, PWD: xx.xx’ RFO= xxx/xxx x 360 = xx.xx° Planned Parameters: 400-500 GPM, 60-80 RPM, 5k-20k WOB Torque Bit - 12K, 4-1/2” IF - 30K Jar Hrs. In: 19.99 / Jar Hrs. Out: XXXX INSITE V9.2.0 Page 2Job No: AK-XX-0906728503 Well Name: KU 44-01B BHA Tally 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: Kenai Gas Field, Sterling Pool 6 Gas Storage Pool, KU 44-01B Hilcorp Alaska, LLC Permit to Drill Number: 220-065 Surface Location: 655' FSL, 1842' FEL, Sec 31, T5N, R11W, SM, AK Bottomhole Location: 761' FSL, 186' FEL, Sec 1, T4N, R12W, SM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of October, 2020. y, 20 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: 7,415' TVD: 4,759' 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): 77' 15. Distance to Nearest Well Open Surface: x- 270783 y- 2368008 Zone-4 59' to Same Pool: KDU 01 1084' 16. Deviated wells:Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 55.6 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD Cond 13-3/8" 68# X-56 Weld 120' Surface Surface 120' 120' 12-1/4" 9-5/8" 47# L-80 DWC/C 2,200' Surface Surface 2,200' 1,814' 8-1/2" 7" 26# L-80 CDC HTQ 5,415' 2,000' 1,700' 7,415' 4,759' Tieback 7" 26# L-80 CDC HTQ 2,000' Surface Surface 2,000' 1,700' 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): 9/18/2020 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 - 783 ft3 / T - 269 ft3 Effect. Depth TVD (ft): Conductor/Structural Length 2107 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 - 813 ft3 / T - 94 ft3 1631 1174' FSL, 192' FEL, Sec 1, T4N, R12W, SM, AK 761' FSL, 186' FEL, Sec 1, T4N, R12W, SM, AK N/A 1273 KU 44-01B Kenai Gas Field Sterling Pool 6 Gas Storage 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 Hilcorp Alaska, LLC 655' FSL, 1842' FEL, Sec 31, T5N, R11W, SM, AK ADL392668, ADL392670, FEE AA093836 022224484 6358' to nearest unit boundary 10/15/2020 Authorized Name: Monty Myers Authorized Title: Drilling Manager Frank Roach frank.roach@hilcorp.com 777-8413 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 10:04 am, Sep 18, 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: 2020.09.18 09:47:02 -08'00' Monty M Myers X X 220-065 X X X 133-20692-00-00 X DLB 09/23/2020 X DSR-9/18/2020 Sterling Pool 6 Gas Storage Service - SupplyS X *3500 psi BOPE test *Sundry required to complete and perf well *CBL required on 7" casing *Diverter waived per 20AAC25.035(h)(2) gls 10/15/20 DLB 09/23/2020 rwaived perrrrerrrerrerrerrererrrerrerererrre 20A 10/1511111111111/2010//////115111111111111111/20 10/20/2020 10/20/2020 KU 44-01B Quarter Mile AOI Map Top of Injection Zone Base of Injection Zone Top Base All posted depths are in MD drilling with Rig 147 Area of Review KU 44-01B Pool 6 C1 - C2PTD API WELL STATUSTop of P6 C1 (MD)Top of P6 C1 (TVD)Base of P6 C2 (MD)Base of P6 C2 (TVD)CBL Top of Cement (MD)CBL Top of Cement (TVD)P6 C1-C2 statusZonal Isolation167-04550-133-20035-00-00 KDU 01 Shut in Tyonek Prod4,447' 4,447' 4,684' 4,684' Surface Surface Closed9-5/8" surface casing run to 4,984' MD/TVD and cemented to surface174-05050-133-10089-01-00 KU 14-06RD Shut in Sterling Pool 34,439' 4,439' 4,680' 4,680' 3,821' 3,821' AbandonedWell Recompleted in Sterling Pool 3, well plugged below old dual packer at 3,843' MD/TVD159-00350-133-10089-00-00 KU 14-06 P&A'd via Sidetrack4,431' 4,431' 4,682' 4,682' N/A N/A AbandonedWell P&A'd181-09250-133-20342-00-00 KU 14X-06 (KDU 08) Shut in Sterling Pool 64,441' 4,441' 4,682' 4,682' N/A N/A OpenOpen217-04150-133-20662-00-00 KU 11-07X Tyonek Prod4,469' 4,441' 4,709' 4,678' 2,500' 2,490' Closed7-5/8" csg run to 6,090' MD and cemented w/ 176 bbls207-14950-133-20572-00-00 KBU 14-06Y Beluga Prod4,462' 4,438' 4,673' 4,648' Surface Surface Closed9-5/8" csg run to 5,318' and Cemented with 189 bbls.181-09250-133-20342-00-00KU 14X-06 (KDU 08) Shut in Sterling Pool 64,441'4,441'4,682'4,682'N/AN/AOpenOpen KU 44-01B Drilling Program Kenai Unit Rev 0 September 18, 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 16” Conductor Riser ........................................................................................................ 12 11.0 Drill 12-1/4” Hole Section ........................................................................................................ 14 12.0 Run 9-5/8” Surface Casing ...................................................................................................... 16 13.0 Cement 9-5/8” Surface Casing ................................................................................................. 19 14.0 BOP N/U and Test.................................................................................................................... 22 15.0 Drill 8-1/2” Hole Section .......................................................................................................... 23 16.0 Run 7” Production Liner ......................................................................................................... 26 17.0 Cement 7” Production Liner ................................................................................................... 29 18.0 7” Liner Tieback Polish Run and Cleanout Run .................................................................... 32 19.0 7” Tieback Run ........................................................................................................................ 32 20.0 RDMO ...................................................................................................................................... 33 21.0 BOP Schematic ........................................................................................................................ 34 22.0 Wellhead Schematic ................................................................................................................. 35 23.0 Days Vs Depth .......................................................................................................................... 36 24.0 Geo-Prog .................................................................................................................................. 37 25.0 Anticipated Drilling Hazards .................................................................................................. 38 26.0 Hilcorp Rig 147 Layout ........................................................................................................... 40 27.0 FIT Procedure .......................................................................................................................... 41 28.0 Choke Manifold Schematic ...................................................................................................... 42 29.0 Casing Design Information ...................................................................................................... 43 30.0 8-1/2” Hole Section MASP ....................................................................................................... 44 31.0 Spider Plot (Governmental Sections) ...................................................................................... 45 32.0 Surface Plat (As-Built NAD27 & NAD83) ............................................................................... 46 Page 2 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 1.0 Well Summary Well KU 44-01B Pad & Old Well Designation Office Pad / grass roots well Planned Completion Type 7” Cemented Production Liner Target Reservoir(s) Sterling Pool 6 Planned Well TD, MD / TVD 7,415’ MD / 4,759’ TVD PBTD, MD / TVD 7,335’ MD / 4,714’ TVD Surface Location (Governmental) 655’ FSL, 1842’ FEL, Sec 31, T5N, R11W, SM, AK Surface Location (NAD 27) X=270783.57 Y=2368008.58 Top of Productive Horizon (Governmental) 1174’ FSL, 192’ FEL, Sec 1, T4N, R12W, SM, AK TPH Location (NAD 27) X=270823.00, Y=2363153.00 BHL (Governmental) 761’ FSL, 186’ FEL, Sec 1, T4N, R12W, SM, AK BHL (NAD 27) X=270821.26, Y=2362740.32 AFE Number AFE Drilling Days 3 MOB, 19 DRLG AFE Completion Days AFE Drilling Amount $3,976,900 AFE Completion Amount Maximum Anticipated Pressure (Surface) 1631 psi Maximum Anticipated Pressure (Downhole/Reservoir) 2107 psi Work String 4-1/2” 16.6# S-135 CDS-40 RKB – GL 77.0’ (59 + 18) Ground Elevation 59.0’ 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 Page 3 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 2.0 Management of Change Information Page 4 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 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 - 12-1/4” 9-5/8” 8.835” 8.750” 10.625” 40 L-80 DWC/C 5750 3090 916 8-1/2” 7” 6.276” 6.151” 7.875” 26 L-80 CDC HTQ 7250 5410 610 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). 7250 Page 5 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 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, jengel@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, jengel@hilcorp.com, and cdinger@hilcorp.com Page 6 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 6.0 Planned Wellbore Schematic CBL required over 7" casing. 7" tieback string Note ;Pool 6 at 4411-4567 SSTVD Page 7 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 7.0 Drilling / Completion Summary KU 44-01B is a grassroots development well to be drilled off of Office Pad. This well will be targeting the Sterling Pool 6 sand for gas storage. The base plan is deviated wellbore with a kick off point at ~350’ MD. Maximum hole angle will be 22 deg before dropping to 10 deg and TD of the well will be 8,499’ TMD/ 8,547’ TVD. Drilling operations are expected to commence approximately September 27th 2020. The Hilcorp Rig # 147 will be used to drill the wellbore then run casing and cement. Surface casing will be run to 1,800’ MD / 1,800’ 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 12-1/4” hole to 2,100’ MD. Run and cement 9-5/8” surface casing. 4. ND diverter, N/U & test 11” x 5M BOP. 5. Drill 8-1/2” hole section to 7,100’ MD. Perform Wiper trip. 6. Make cleanout run 7. POOH laying down drill pipe. 8. Run and cmt 7” production liner. 9. PU clean out assembly and RIH to clean out 7” to landing collar 10. Displace well to 6% KCL completion fluid. 11. POOH and LD clean out assembly. 12. RIH and land 7” tieback string in liner top. 13. N/D BOP, N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole: GR + Res 2. Production Hole: GR + Res 3. Mud loggers from surface casing point to TD. Sterling Pool 6 sand for gas storage. KU 44-01B is a grassroots development well to be drilled off of Office Pad. This well will be targeting thegp NOTE; sundry required to run completion and perforate. Gas Storage well. Pool 6 gls 10/12/20 7415 MD/4759 TVD 55 deg (MIT casing and MIT-IA ) Page 8 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. 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 KU 44-01B. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. 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 approved drilling permits are posted on the rig floor and in Co Man office. Regulation Variance Requests: x Diverter waiver request requested due to the recent drilling of KU 24-32 on the same pad and KU 11-07X and KU 42-12 on a nearby pad. No issues were experienced on either well drilling the surface hole. Surface casing will be set at the same depth on KU 44-01B. No shallow hydrocarbon zones will be penetrated. RIg 147 Regulation Variance Requests: Waiver granted... past drilling on pad had no shallow gas issues. gls 10/15/20 Page 9 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure (psi) 12-1/4” x 21-1/4” x 2M Hydril MSP diverter Function Test Only 8-1/2” 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. Additional requirements may be stipulated on APD and Sundry. Page 10 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 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) Page 11 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 9.0 R/U and Preparatory Work 9.1 13-3/8” conductor already set on pad. 9.2 Dig out and set impermeable cellar. 9.3 Install 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 12-1/4” 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. R/U Hilcorp Rig # 147, Page 12 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 10.0 N/U 16” Conductor Riser 10.1 N N/U 16” Conductor Riser x Ensure line does not direct flow from trip tank straight down the flowline. Fill up line and flowline should be oriented 90 degrees to each other at approx. the same height. x Ensure flowline outlet installed so that enough slope exists to carry cuttings to the shakers. x Consider adding additional drainage points at the bottom of the conductor riser if deemed necessary. x R/U fill up line to conductor riser. 10.2 Set wear bushing in wellhead. NOTE: Diverter waived ... gls 10/13/20 Page 13 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 10.3 Rig 147 Orientation: Note: Actual layout may be different on location KU 44-01B Page 14 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 11.0 Drill 12-1/4” Hole Section 11.1 P/U 12-1/4” 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 13-3/8” conductor at reduced flow rates to avoid broaching the conductor. 11.4 Drill 12-1/4” hole section to 2,200’ MD/ 1,813’ 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 2,150’ and 2,250’MD. x Take MWD surveys every stand drilled (60’ intervals). 11.5 12-1/4” 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 September, 2020 KU 44-01B Drilling Procedure Rev 0 Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL pH 120-2200’ 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 13-3/8” conductor shoe. 11.7 TOH with the drilling assy, handle BHA as appropriate. Note: EMW needed = 8.5 ppg. DLB 8.8 – 9.5 Page 16 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 12.0 Run 9-5/8” Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 9-5/8” casing running equipment. x Ensure 9-5/8” DWC 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 9-5/8” 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 September, 2020 KU 44-01B Drilling Procedure Rev 0 Page 18 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 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 September, 2020 KU 44-01B Drilling Procedure Rev 0 13.0 Cement 9-5/8” 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: 13-3/8” Conductor x 9-5/8” casing annulus: 120’ x .0597 bpf = 7.17 40.3 12.0 ppg LEAD: 12-1/4” OH x 9-5/8” Casing annulus: (1700’ – 120’) x .05578 bpf x 1.5 = 132.20 742.3 Total LEAD: 139.37 782.6 ft3 15.4 ppg TAIL: 12-1/4” OH x 9-5/8” Casing annulus: (2200’- 1600’) x .05578 bpf x 1.5 = 41.84 234.9 15.4 ppg TAIL: 9-5/8” Shoe track: 80 x .07582 bpf = 6.07 34.1 Total TAIL: 47.91 bbl 269.0 ft3 317 sx 220 sx Page 20 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 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: 2200’- 80’ = 2120’ x .07582 bpf = 161 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 (1700’ MD to surface) Tail Slurry (2200’ to 1700’ 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 21 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 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, jengel@hilcorp.com, and Frank.Roach@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. (notify AOGCC if TOP job is needed before proceeding) Page 22 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 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 5/5 min. Test annular to 250/2500 psi for 5/5 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 psi BOPE test Page 23 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 15.0 Drill 8-1/2” 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 8-1/2” 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 2,200’- 7,415’ 9.0 – 10.0 40-53 15-25 15-25 8.5-9.5 11.0 System Formulation: 6% KCL EZ Mud DP Product Concentration Water KCl Caustic BARAZAN D+ 0.905 bbl 22 ppb (29 K chlorides) 0.2 ppb (9 pH) 1.25 ppb (as required 18 YP) Note: Max MWE needed = 8.5 ppg DLB 9.0 – 10.0 – g Page 24 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 EZ MUD DP DEXTRID LT PAC-L BARACARB 5/25/50 BAROID 41 ALDACIDE G BARACOR 700 BARASCAV D 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/ 8-1/2” 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 2500 psi / 30 min. Ensure to record volume / pressure and plot on FIT graph. AOGCC requirement is 50% of burst. 9-5/8” burst is 5750 psi / 2 = 2875 psi. We are asking to test to 2500 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 9-5/8” shoe to be between 11 - 15 ppg EMW. A 13.5 ppg FIT results in a 4 ppg kick margin while drilling with the planned MW of 9.5 ppg. Kick tolerance = (13.5-9.0)X(1413/4759) = 1.3 15.14 Drill 8-1/2” hole section to 7,415’ MD / 4,759’ 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 5,750’ MD), trip back to the 9-5/8” shoe (LL from 224-24) to split the hole section in half x Ensure shale shakers are functioning properly. Check for holes in screens on connections. x Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. 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 9-5/8” shoe. 2500 psi OK ... gls 10/13/20 Conduct FIT to 13.5 ppg EMW. FIT to 13.5 ppg Page 25 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 15.16 TOH with the drilling assy, standing back drill pipe. 15.17 LD BHA 15.18 PU 8-1/2”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 7” pipe rams in BOP stack and test. Page 26 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 16.0 Run 7” Production Liner 16.1. R/U Weatherford 7” casing running equipment. x Ensure 7” CDC HTQ x CDS 40 crossover on rig floor and M/U to FOSV. x R/U fill up line to fill liner while running. x Ensure all liner has been drifted prior to running. x Be sure to count the total # of joints before running. x Keep hole covered while R/U liner 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 7” production liner x Fill liner 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 9-5/8” shoe. Leave the centralizers free floating. 16.5. Continue running 7” production liner 7” 26# CDC - HTQ M/U torques Casing OD Minimum Maximum Yield Torque 7” 15,500 ft-lbs 20,500 ft-lbs 25,600 ft-lbs Page 27 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 Page 28 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 16.6. Run in hole w/ 7” liner to the 9-5/8” casing shoe. 16.7. Fill the liner 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 liner. 16.9. Circulate 2X bottoms up at shoe, ease liner thru shoe. 16.10. Continue to RIH w/ liner no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.11. Set liner slowly in and out of slips. 16.12. PU 7” X 9-5/8” 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 2-5’ 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 September, 2020 KU 44-01B Drilling Procedure Rev 0 17.0 Cement 7” 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 20% OH excess. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol (ft3) 12.0 ppg LEAD: 9-5/8” csg x 4-1/2” drillpipe annulus: 200’ x .05616 bpf = 11.23 63.1 12.0 ppg LEAD: 9-5/8” csg x 7” liner annulus: 200’ x .02823 bpf = 5.65 31.7 12.0 ppg LEAD: 8-1/2” OH x 7” annulus: (6915’ – 2200’) x .02259 bpf x 1.2 = 127.78 717.4 Total LEAD: 144.66 bbl 812.2 ft3 15.4 ppg TAIL: 8-1/2” OH x 7” annulus: (7415’- 6915’) x .02259 bpf x 1.2 = 13.55 76.1 15.4 ppg TAIL: 7” Shoe track: 80 x .03826 bpf = 3.06 17.2 Total TAIL: 16.61 bbl 93.3 ft3 330 sx 76 sx Page 30 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 Cement Slurry Design: 17.7. Drop drillpipe dart and displace with drilling mud. 17.8. If hole conditions allow – continue rotating and reciprocating liner 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. Pressure up to set liner hanger Pick up and slack off to confirm liner hanger is set. Pressure up to release running tool. 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. POOH and LD running tool. Lead Slurry (6915’ MD to 2200’ MD) Tail Slurry (7415’ to 6915’ 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 September, 2020 KU 44-01B Drilling Procedure Rev 0 17.17. Install 2-7/8” x 5” variable bore rams in BOP stack and test. 17.18. WOC minimum of 12 hours, test liner 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 liner 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” liner tally & liner and cement report to cdinger@hilcorp.com, jengel@hilcorp.com, and Frank.Roach@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 32 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 18.0 7” 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. 18.4. PU 7” clean out BHA. 18.5. RIH on 2-7/8” 7.9 lb/ft PH-6 workstring to top of landing collar per liner tally. 18.6. CBU and displace well to 6% KCl completion fluid. 18.7. POOH LDDP and BHA 18.8. Install 7” pipe rams in BOP stack and test. 18.9. If not completed, test 7” liner to 2,500 psi and chart for 30 minutes 19.0 7” Tieback Run 19.1 PU 7” tieback assembly and RIH with 7” 26# L-80 CDC HTQ casing. 19.2 No-go tieback seal assembly in liner PBR and mark pipe. PU pup joint(s) if necessary to space out tieback seals in PBR. 19.3 PU hanger and land string in hanger bowl. Note distance of seals from no-go. 19.4 Install packoff and test hanger void. 19.5 Test 7” liner and tieback to 2,500 psi and chart for 30 minutes. 19.6 Test 9-5/8” x 7” annulus to 2,500 psi and chart for 30 minutes. 3500 psi MIT-IA MIT 7" csg 3500 psi gls 10/15/20 Page 33 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 20.0 RDMO 20.1 Install BPV in wellhead 20.2 Install 2-7/8” x 5” variable bore rams in BOP stack for the next well. 20.3 N/D BOPE 20.4 N/U temp abandonment cap 20.5 RDMO Hilcorp Rig #147 NOTE: Sundry approval required to complete well. A CBL will be required over 7" casing . Page 34 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 21.0 BOP Schematic VBR BLIND VBR Page 35 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 22.0 Wellhead Schematic Page 36 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 23.0 Days Vs Depth Page 37 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 24.0 Geo-Prog Page 38 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 25.0 Anticipated Drilling Hazards 12-1/4” 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 39 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 8-1/2” 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 KU 42-12 when drilling through Pool 6, 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. Given the volume of losses experienced in KU 42-12 when drilling through Pool 6, ensure all LCMp inventory is fully stocked before drilling out surface casing. Pool 6 zone is severely underpressured gls Page 40 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 26.0 Hilcorp Rig 147 Layout Page 41 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 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 42 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 28.0 Choke Manifold Schematic Page 43 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 29.0 Casing Design Information Page 44 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 30.0 8-1/2” Hole Section MASP Pool 6 Page 45 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 31.0 Spider Plot (Governmental Sections) Page 46 Version 1 September, 2020 KU 44-01B Drilling Procedure Rev 0 32.0 Surface Plat (As-Built NAD27 & NAD83) !!" #$ #$%% -800-400040080012001600200024002800320036004000440048005200True Vertical Depth (800 usft/in)0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600Vertical Section at 178.48° (800 usft/in)KGF Pool6 wp01 Tgt13 3/8"9 5/8" x 12 1/4"7" x 8 1/2"50010001500200025003000350040004500500055006000650070007415KU 44-01B wp04Start Dir 3º/100' : 300' MD, 300'TVDStart Dir 4º/100' : 600' MD, 598.77'TVDEnd Dir : 1797.08' MD, 1586.17' TVDTotal Depth : 7415.01' MD, 4759.42' TVDP3_A4P3_A8P3_A10P4_B1P5_B5P6_C1P6_C2U_BELUGAHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: KU 44-01B59.00+N/-S+E/-WNorthingEasting LatittudeLongitude0.00 0.00 2368008.584270783.57260° 28' 32.520 N 151° 16' 13.724 WSURVEY PROGRAMDate: 2020-09-03T00:00:00 Validated: Yes Version: Depth FromDepth ToSurvey/PlanTool18.00 2200.00 KU 44-01B wp04 (KU 44-01B) 3_MWD+IFR1+MS+Sag2200.00 7415.01 KU 44-01B wp04 (KU 44-01B) 3_MWD+IFR1+MS+SagFORMATION TOP DETAILSTVDPathTVDssPathMDPathFormation3333.00 3256.00 4889.67 P3_A43611.00 3534.00 5381.84 P3_A83683.00 3606.00 5509.31 P3_A103818.00 3741.00 5748.32 P4_B14200.00 4123.00 6424.61 P5_B54495.00 4418.00 6946.88 P6_C14653.00 4576.00 7226.60 P6_C24740.00 4663.00 7380.63 U_BELUGAREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: KU 44-01B, True NorthVertical (TVD) Reference:RKB As-Built @ 77.00usft (HEC 147)Measured Depth Reference:RKB As-Built @ 77.00usft (HEC 147)Calculation Method:Minimum CurvatureProject:Kenai Gas FieldSite:KGF 34-31 PadWell:Plan: KU 44-01BWellbore:KU 44-01BDesign:KU 44-01B wp04Kenai Gas FieldKGF 34-31 PadPlan: KU 44-01BKU 44-01BKU 44-01B wp045.852CASING DETAILSTVD TVDSS MD Size Name120.00 43.00 120.00 13-3/8 13 3/8"1813.76 1736.76 2200.00 9-5/8 9 5/8" x 12 1/4"4759.42 4682.42 7415.01 7 7" x 8 1/2"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 0.002 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 300' MD, 300'TVD3 600.00 9.00 150.00 598.77 -20.36 11.76 3.00 150.00 20.67 Start Dir 4º/100' : 600' MD, 598.77'TVD4 1797.08 55.61 179.14 1586.17 -631.29 69.42 4.00 32.80 632.90 End Dir : 1797.08' MD, 1586.17' TVD5 6915.01 55.61 179.14 4477.00 -4854.11 133.11 0.00 0.00 4855.94 KGF Pool6 wp01 Tgt6 7415.01 55.61 179.14 4759.42 -5266.67 139.34 0.00 0.00 5268.51 Total Depth : 7415.01' MD, 4759.42' TVD -5600 -5133 -4667 -4200 -3733 -3267 -2800 -2333 -1867 -1400 -933 -467 0 467 933 South(-)/North(+) (700 usft/in)-2333 -1867 -1400 -933 -467 0 467 933 1400 1867 2333 West(-)/East(+) (700 usft/in) KGF Pool6 wp01 Tgt 13 3/8" 9 5/8" x 12 1/4" 7" x 8 1/2" 25050075 0 1 0 0 0 1 2 5 0 1 5 00 17 50 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 47504759 KU 44-01B wp04 Start Dir 3º/100' : 300' MD, 300'TVD Start Dir 4º/100' : 600' MD, 598.77'TVD End Dir : 1797.08' MD, 1586.17' TVD Total Depth : 7415.01' MD, 4759.42' TVD Project: Kenai Gas Field Site: KGF 34-31 Pad Well: Plan: KU 44-01B Wellbore: KU 44-01B Plan: KU 44-01B wp04 WELL DETAILS: Plan: KU 44-01B 59.00 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 2368008.584 270783.572 60° 28' 32.520 N 151° 16' 13.724 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: KU 44-01B, True North Vertical (TVD) Reference:RKB As-Built @ 77.00usft (HEC 147) Measured Depth Reference:RKB As-Built @ 77.00usft (HEC 147) Calculation Method:Minimum Curvature CASING DETAILS TVD TVDSS MD Size Name 120.00 43.00 120.00 13-3/8 13 3/8" 1813.76 1736.76 2200.00 9-5/8 9 5/8" x 12 1/4" 4759.42 4682.42 7415.01 7 7" x 8 1/2" -5600 -5133 -4667 -4200 -3733 -3267 -2800 -2333 -1867 -1400 -933 -467 0 467 933 South(-)/North(+) (700 usft/in)-2333 -1867 -1400 -933 -467 0 467 933 1400 1867 2333 West(-)/East(+) (700 usft/in) 200400600800100 01200140016001800200022002400260028003000320034003600380040004200440046004800500052005400560058006000620064006600KDU-52004006008001000120014001600180020002200240026002800300032003330KU WD-1 2004006008001000120014001600180020002200240026002800300032003400360038004000420044004600480050005200540056005800600062006400660068006838KU 44-01 wp05 200400600800100012001400 1 6 0 0 1 8 0 0 2 0 0 0 2 2 0 0 2 4 0 0 2 60 0 2 8 0 0 3 0 0 0 3 2 0 0 3 4 0 0 3 6 0 0 3 8 0 0 4 0 0 0 4 2 0 0 4 4 0 0 4 6 0 04767 KU 13-60200400600800100012001400160018002000 2200240026002800300032003400360038004000420044004600KU 14-322004006 0 0 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 KDU-6 0 200400600800100012001400160018002000220024002600280030003200340036003800400042004400460048004904KU 21-6 0 200400600800100012001400160018002000220024002600280030003200340036003800400042004400460048004852KU 21-6 RD200400600800100012001400160018002000220024002600280030003200340036003800400042004267 KU 11-6200400600800100012001400160018002000220 0240026002800300032003400360038004000420044004 6 0 048004986 KU 22-6X 20040060080 0 1 0 0 0 1 2 0 0 1 4 0 0 1600 180 0 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4759 KU 44-01B wp04 Project: Kenai Gas Field Site: KGF 34-31 Pad Well: Plan: KU 44-01B Wellbore: KU 44-01B Plan: KU 44-01B wp04 -300 0 South(-)/North(+) (450 usft/in)-300 0 300 West(-)/East(+) (450 usft/in) Plan: KU 44-01B KDU-05 KU WD-1 KU 14-32 KDU-06 KU 21-6 KU 11-6 KU 22-6X 25050075010 001250150017502 5 0 5 0 07 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(/< ). (/7 . (/;< )+ ( %3 ((%3<,7 3 ( 5 *$36!43 (3< )+3 + )#, -).*+(/()*$ !" #"#$%!!"&"%!!"&"%!!"&'!< )+. (/ &< 0* . (/?. (/ -@# -?"0& -& '(,,*", )453!"!5 ! 6-& .-,"%&" '(,,*", )453!"!5 ! 6 7 8 9:*& 8 ;&1 8 8 $ &1 < $#= $* >& 6 ;; & 8 86578718 9 8 7& 0.001.503.004.50Separation Factor0 450 900 1350 1800 2250 2700 3150 3600 4050 4500 4950 5400 5850 6300 6750 7200 7650Measured DepthKU 44-01 wp05KU 13-6No-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: KU 44-01B NAD 1927 (NADCON CONUS)Alaska Zone 0459.00+N/-S +E/-W Northing EastingLatittudeLongitude0.000.00 2368008.584 270783.572 60° 28' 32.520 N 151° 16' 13.724 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: KU 44-01B, True NorthVertical (TVD) Reference:RKB As-Built @ 77.00usft (HEC 147)Measured Depth Reference:RKB As-Built @ 77.00usft (HEC 147)Calculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-09-03T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool18.00 2200.00 KU 44-01B wp04 (KU 44-01B) 3_MWD+IFR1+MS+Sag2200.00 7415.01 KU 44-01B wp04 (KU 44-01B) 3_MWD+IFR1+MS+Sag0.0030.0060.0090.00120.00150.00Centre to Centre Separation (50.00 usft/in)0 450 900 1350 1800 2250 2700 3150 3600 4050 4500 4950 5400 5850 6300 6750 7200 7650Measured DepthKDU-5KU 44-01 wp05KU 14-32KU 21-6KU 21-6 RDKU 11-6KU 22-6XGLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference18.00 To 7415.01Project: Kenai Gas FieldSite: KGF 34-31 PadWell: Plan: KU 44-01BWellbore: KU 44-01BPlan: KU 44-01B wp04Ladder / S.F. PlotsCASING DETAILSTVD TVDSS MD Size Name120.00 43.00 120.00 13-3/8 13 3/8"1813.76 1736.76 2200.00 9-5/8 9 5/8" x 12 1/4"4759.42 4682.42 7415.01 7 7" x 8 1/2" 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. KU 44-01B 220-065 X X X Kenai Gas Sterling Pool 6 Gas Storage WELL PERMIT CHECKLISTCompanyHilcorp Alaska, LLCWell Name:KENAI UNIT 44-01BInitial Class/TypeSER / PENDGeoArea820Unit51120On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2200650KENAI, STERLING 6 GAS STOR - 448809NA1 Permit fee attachedYes2 Lease number appropriateYes3 Unique well name and numberYes4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryYes6 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 waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For sYes15 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)Yes 13 3/8" conductor set at 120 ft18 Conductor string providedYes surface casing set and fully cemented from 1814 ft TVD19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgYes 7" production liner will be fully cemented to hanger.21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes BTC calculations are provided.23 Casing designs adequate for C, T, B & permafrostYes Rig 147 has steel pits.24 Adequate tankage or reserve pitNA grassroots well.25 If a re-drill, has a 10-403 for abandonment been approvedYes NO issues with collision.26 Adequate wellbore separation proposedNA Diverter waived per 20 AAC 25.035(h)(2) … several wells on pad drilled with no gas27 If diverter required, does it meet regulationsYes max formation pressure= 2107 psi (will drill with 10ppg mud28 Drilling fluid program schematic & equip list adequateYes Rig 147 has 11" BOPE 5000 psi WP29 BOPEs, do they meet regulationYes MASP = 1631 psi Will test BOPE to 3500 psi (annular 2500 psi )30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes Sundry requried for running completion and perforating.32 Work will occur without operation shutdownNo Not expected .33 Is presence of H2S gas probableYes 1/4mil review completed. One well (is open in pool 6 interval34 Mechanical condition of wells within AOR verified (For service well only)Yes Nearby wells did not encounter H2S gas. Measures not required.35 Permit can be issued w/o hydrogen sulfide measuresYes36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprDLBDate9/21/2020ApprGLSDate10/15/2020ApprDLBDate9/21/2020AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateUsing rig 147 to drill well. Gas storage well in Pool 6 . Gas Storage well. Pool 6 is serverly underpressureed…. LCM pills will be needed. GlsDaniel T. Seamount, Jr.Digitally signed by Daniel T. Seamount, Jr. Date: 2020.10.20 11:51:12 -08'00'JMP10/20/2020