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Home My WebLink About220-068DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20694-00-00Well Name/No. KENAI UNIT 44-08Completion Status1-GASCompletion Date12/13/2020Permit to Drill2200680Operator Hilcorp Alaska, LLCMD7628TVD4620Current Status1-GAS7/27/2021UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:LWD/MWD, Mud Log, CBL 12-9-20, GeoTapNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF12/7/202010 7750 Electronic Data Set, Filename: KU 44-08.las34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Daily Reports.pdf34355EDDigital DataDF12/7/2020 Electronic File: Hilcorp KU 44-08 EOW Report.pdf34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Drilling Dynamics Log MD 2in.pdf34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Drilling Dynamics Log MD 5in.pdf34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Drilling Dynamics Log TVD 2in.pdf34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Drilling Dynamics Log TVD 5in.pdf34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Formation Log MD 2in.pdf34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Formation Log MD 5in.pdf34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Formation Log TVD 2in.pdf34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Formation Log TVD 5in.pdf34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Gas Ratio Log MD 2in.pdf34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Gas Ratio Log MD 5in.pdf34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Gas Ratio Log TVD 2in.pdf34355EDDigital DataTuesday, July 27, 2021AOGCCPage 1 of 6Supplied byOpSupplied byOpKU 44-08.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20694-00-00Well Name/No. KENAI UNIT 44-08Completion Status1-GASCompletion Date12/13/2020Permit to Drill2200680Operator Hilcorp Alaska, LLCMD7628TVD4620Current Status1-GAS7/27/2021UICNoDF12/7/2020 Electronic File: KU 44-08 Gas Ratio Log TVD 5in.pdf34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 LWD Combo Log MD 2in.pdf34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 LWD Combo Log MD 5in.pdf34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 LWD Combo Log TVD 2in.pdf34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 LWD Combo Log TVD 5in.pdf34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Drilling Dynamics Log MD 2in.tif34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Drilling Dynamics Log MD 5in.tif34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Drilling Dynamics Log TVD 2in.tif34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Drilling Dynamics Log TVD 5in.tif34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Formation Log MD 2in.tif34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Formation Log MD 5in.tif34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Formation Log TVD 2in.tif34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Formation Log TVD 5in.tif34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Gas Ratio Log MD 2in.tif34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Gas Ratio Log MD 5in.tif34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Gas Ratio Log TVD 2in.tif34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Gas Ratio Log TVD 5in.tif34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 LWD Combo Log MD 2in.tif34355EDDigital DataTuesday, July 27, 2021AOGCCPage 2 of 6 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20694-00-00Well Name/No. KENAI UNIT 44-08Completion Status1-GASCompletion Date12/13/2020Permit to Drill2200680Operator Hilcorp Alaska, LLCMD7628TVD4620Current Status1-GAS7/27/2021UICNoDF12/7/2020 Electronic File: KU 44-08 LWD Combo Log MD 5in.tif34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 LWD Combo Log TVD 2in.tif34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 LWD Combo Log TVD 5in.tif34355EDDigital DataDF12/7/2020 Electronic File: DbRaw.dbf34355EDDigital DataDF12/7/2020 Electronic File: DbRaw.mdx34355EDDigital DataDF12/7/2020 Electronic File: KU44-08.dbf34355EDDigital DataDF12/7/2020 Electronic File: ku44-08.hdr34355EDDigital DataDF12/7/2020 Electronic File: KU44-08.mdx34355EDDigital DataDF12/7/2020 Electronic File: ku44-08r.dbf34355EDDigital DataDF12/7/2020 Electronic File: ku44-08r.mdx34355EDDigital DataDF12/7/2020 Electronic File: KU44-08_SCL.DBF34355EDDigital DataDF12/7/2020 Electronic File: KU44-08_SCL.MDX34355EDDigital DataDF12/7/2020 Electronic File: KU44-08_tvd.dbf34355EDDigital DataDF12/7/2020 Electronic File: KU44-08_tvd.mdx34355EDDigital DataDF12/7/2020 Electronic File: KU 44-08 Show Reports.pdf34355EDDigital Data0 0 2200680 KENAI UNIT 44-08 LOG HEADERS34355LogLog Header ScansDF12/17/202063 7625 Electronic Data Set, Filename: KU 44-08 LWD Final.las34406EDDigital DataDF12/17/2020 Electronic File: KU 44-08 LWD Final MD.cgm34406EDDigital DataDF12/17/2020 Electronic File: KU 44-08 LWD Final TVD.cgm34406EDDigital DataDF12/17/2020 Electronic File: KU 44-08 Rec GeoTap Press.cgm34406EDDigital DataDF12/17/2020 Electronic File: DSR KU 44-08.txt34406EDDigital DataDF12/17/2020 Electronic File: DSR KU 44-08_GIS.txt34406EDDigital DataDF12/17/2020 Electronic File: KU 44-08 - Definitive Survey Report.pdf34406EDDigital DataDF12/17/2020 Electronic File: KU 44-08 DSR Actual -Plan View.pdf34406EDDigital DataDF12/17/2020 Electronic File: KU 44-08 DSR Actual -VSec.pdf34406EDDigital DataTuesday, July 27, 2021AOGCCPage 3 of 6KU 44-08 LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20694-00-00Well Name/No. KENAI UNIT 44-08Completion Status1-GASCompletion Date12/13/2020Permit to Drill2200680Operator Hilcorp Alaska, LLCMD7628TVD4620Current Status1-GAS7/27/2021UICNoDF12/17/2020 Electronic File: KU 44-08 Final Surveys.xlsx34406EDDigital DataDF12/17/2020 Electronic File: KU 44-08 LWD Final MD.emf34406EDDigital DataDF12/17/2020 Electronic File: KU 44-08 LWD Final TVD.emf34406EDDigital DataDF12/17/2020 Electronic File: KU 44-08 Rec GeoTap Press.emf34406EDDigital DataDF12/17/2020 Electronic File: KU 44-08 Final Geotap Report.pdf34406EDDigital DataDF12/17/2020 Electronic File: KU 44-08 LWD Final MD.pdf34406EDDigital DataDF12/17/2020 Electronic File: KU 44-08 LWD Final TVD.pdf34406EDDigital DataDF12/17/2020 Electronic File: KU 44-08 Rec GeoTap Press.pdf34406EDDigital DataDF12/17/2020 Electronic File: KU 44-08 LWD Final MD.tif34406EDDigital DataDF12/17/2020 Electronic File: KU 44-08 LWD Final TVD.tif34406EDDigital DataDF12/17/2020 Electronic File: KU 44-08 Rec GeoTap Press.tif34406EDDigital Data0 0 2200680 KENAI UNIT 44-08 LOG HEADERS34406LogLog Header ScansDF12/23/20201432 1082 Electronic Data Set, Filename: KU 44-08, GPT, 12-16-20, Log-FL Pass.las34462EDDigital DataDF12/23/20201432 1082 Electronic Data Set, Filename: KU 44-08, GPT, 12-16-20, Log-Fluid Level Pass.las34462EDDigital DataDF12/23/20206827 6480 Electronic Data Set, Filename: KU 44-08, GPT, 12-16-20, Log-Perf Ver Pass.las34462EDDigital DataDF12/23/20206827 6480 Electronic Data Set, Filename: KU 44-08, GPT, 12-16-20, Log-Perf Verification Pass.las34462EDDigital DataDF12/23/2020 Electronic File: KU 44-08, GPT, Fluid Level, Perf Verification 12-16-20, Log.pdf34462EDDigital Data0 0 2200680 KENAI UNIT 44-08 LOG HEADERS34462LogLog Header Scans0 0 2200680 KENAI UNIT 44-08 LOG HEADERS34463LogLog Header ScansDF12/23/20206855 6284 Electronic Data Set, Filename: KU 44-08, Perf, 12-13-20, Final Log-Gun 1 Correlation.las34463EDDigital DataDF12/23/20206798 6448 Electronic Data Set, Filename: KU 44-08, Perf, 12-13-20, Final Log-Gun 1 Shot Pass.las34463EDDigital DataDF12/23/20206854 6284 Electronic Data Set, Filename: KU 44-08, Perf, 12-13-20, Final Log-Perf Correlation Pass.las34463EDDigital DataDF12/23/2020 Electronic File: KU 44-08 AOGCC FINAL PERF 12-13-2020 TRANSMITTAL.doc34463EDDigital DataTuesday, July 27, 2021AOGCCPage 4 of 6 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20694-00-00Well Name/No. KENAI UNIT 44-08Completion Status1-GASCompletion Date12/13/2020Permit to Drill2200680Operator Hilcorp Alaska, LLCMD7628TVD4620Current Status1-GAS7/27/2021UICNoDF12/23/2020 Electronic File: KU 44-08, Perf, 12-13-20, Final Log.pdf34463EDDigital DataDF1/29/20217556 2 Electronic Data Set, Filename: KU 44-08 CBL2 MAIN PASS.las34636EDDigital DataDF1/29/2021 Electronic File: KU 44-08 CBL2 Final.pdf34636EDDigital Data0 0 2200680 KENAI UNIT 44-08 LOG HEADERS34636LogLog Header ScansDF2/16/20217406 6890 Electronic Data Set, Filename: KU 44-08 26-29JAN2021 LAS.las34703EDDigital DataDF2/16/2021 Electronic File: KU 44-08 26-29JAN2021.pdf34703EDDigital DataDF2/16/2021 Electronic File: KU 44-08 26-29JAN2021_Uncomp.tif34703EDDigital Data0 0 2200680 KENAI UNIT 44-08 LOG HEADERS34703LogLog Header ScansDF6/28/20216590 6341 Electronic Data Set, Filename: 040621 ku 44-08_CORRELATION CIBP.las35288EDDigital DataDF6/28/20216562 6292 Electronic Data Set, Filename: 040621 ku 44-08_CORRELATION GUN 1.las35288EDDigital DataDF6/28/20215790 6562 Electronic Data Set, Filename: 040621 ku 44-08_GPT RUN 2.las35288EDDigital DataDF6/28/20216662 5792 Electronic Data Set, Filename: 040621 ku 44-08_GPT RUN1.las35288EDDigital DataDF6/28/2021 Electronic File: KU 44-08 FINAL PERF.pdf35288EDDigital Data0 0 2200680 KENAI UNIT 44-08 LOG HEADERS35288LogLog Header Scans0 0 2200680 KENAI UNIT 44-08 LOG HEADERS35289LogLog Header ScansDF6/28/20216753 6478 Electronic Data Set, Filename: 020421 ku 44-08_CORRELATION GUN 1.las35289EDDigital DataDF6/28/20216204 7016 Electronic Data Set, Filename: 020421 ku 44-08_GPT.las35289EDDigital DataDF6/28/2021 Electronic File: 020421 KU 44-08 PERF FINAL.pdf35289EDDigital DataDF6/28/2021 Electronic File: KU 44-08 CORRELATION GUN 1.pdf35289EDDigital DataDF6/28/2021 Electronic File: KU 44-08 GPT LOG TO 7000'.pdf35289EDDigital DataDF6/28/20216875 6512 Electronic Data Set, Filename: 011521 ku 44-08_CORRELATION PLUG.las35290EDDigital DataTuesday, July 27, 2021AOGCCPage 5 of 6 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20694-00-00Well Name/No. KENAI UNIT 44-08Completion Status1-GASCompletion Date12/13/2020Permit to Drill2200680Operator Hilcorp Alaska, LLCMD7628TVD4620Current Status1-GAS7/27/2021UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:12/13/2020Release Date:11/4/2020DF6/28/2021 Electronic File: 011521 KU 44-08 CORRELATION PLUG.pdf35290EDDigital DataDF6/28/2021 Electronic File: 011521 KU 44-08 PLUG FINAL.pdf35290EDDigital Data0 0 2200680 KENAI UNIT 44-08 LOG HEADERS35290LogLog Header Scans1/28/20211600 762541769CuttingsTuesday, July 27, 2021AOGCCPage 6 of 6M.Guhl7/27/2021 David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal or FAX to 907 564-4424 Received By: Date: Hilcorp North Slope, LLC Date: 06/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company KBU 11-08Y 50133205520000 205091 1/28/2021 SET PLUG Yellowjacket KBU 23-7 50133205320000 203217 12/20/2020 JET CUT Yellowjacket KBU 23-7 50133205320000 203217 1/4/2021 PERF GAMMA RAY Yellowjacket KBU 41-6 50133205550000 205141 2/8/2021 SET PLUG Yellowjacket KBU 43-07Y 50133206250000 214019 1/22/2021 PERF GAMMA RAY Yellowjacket KBU 44-06 50133204980000 200179 2/22/2021 SET PLUG - JET CUT Yellowjacket KBU 42-07RD 50133204880100 208052 5/31/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/2/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/7/2020 PERF GAMMA RAY/GPT Yellowjacket KDU 09 50133205780000 208106 11/25/2020 JET CUT Yellowjacket KDU 09 50133205780000 208106 5/17/2021 PERF / GPT Yellowjacket KTU 13-05 50133203700000 184108 1/12/2021 SET PLUG Yellowjacket KTU 24-06H 50133204900000 199073 6/19/2020 PERF Yellowjacket KTU 24-06H 50133204900000 199073 6/20/2020 GPT Yellowjacket KU 44-08 50133206940000 220068 1/15/2021 SET PLUG Yellowjacket KU 44-08 50133206940000 220068 2/4/2021 PERF GAMMA RAY/GPT Yellowjacket KU 44-08 50133206940000 220068 4/6/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. 06/28/2021 PTD: 2200680 E-Set: 35288 David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal or FAX to 907 564-4424 Received By: Date: Hilcorp North Slope, LLC Date: 06/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company KBU 11-08Y 50133205520000 205091 1/28/2021 SET PLUG Yellowjacket KBU 23-7 50133205320000 203217 12/20/2020 JET CUT Yellowjacket KBU 23-7 50133205320000 203217 1/4/2021 PERF GAMMA RAY Yellowjacket KBU 41-6 50133205550000 205141 2/8/2021 SET PLUG Yellowjacket KBU 43-07Y 50133206250000 214019 1/22/2021 PERF GAMMA RAY Yellowjacket KBU 44-06 50133204980000 200179 2/22/2021 SET PLUG - JET CUT Yellowjacket KBU 42-07RD 50133204880100 208052 5/31/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/2/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/7/2020 PERF GAMMA RAY/GPT Yellowjacket KDU 09 50133205780000 208106 11/25/2020 JET CUT Yellowjacket KDU 09 50133205780000 208106 5/17/2021 PERF / GPT Yellowjacket KTU 13-05 50133203700000 184108 1/12/2021 SET PLUG Yellowjacket KTU 24-06H 50133204900000 199073 6/19/2020 PERF Yellowjacket KTU 24-06H 50133204900000 199073 6/20/2020 GPT Yellowjacket KU 44-08 50133206940000 220068 1/15/2021 SET PLUG Yellowjacket KU 44-08 50133206940000 220068 2/4/2021 PERF GAMMA RAY/GPT Yellowjacket KU 44-08 50133206940000 220068 4/6/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. 06/28/2021 PTD: 2200680 E-Set: 35289 David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal or FAX to 907 564-4424 Received By: Date: Hilcorp North Slope, LLC Date: 06/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company KBU 11-08Y 50133205520000 205091 1/28/2021 SET PLUG Yellowjacket KBU 23-7 50133205320000 203217 12/20/2020 JET CUT Yellowjacket KBU 23-7 50133205320000 203217 1/4/2021 PERF GAMMA RAY Yellowjacket KBU 41-6 50133205550000 205141 2/8/2021 SET PLUG Yellowjacket KBU 43-07Y 50133206250000 214019 1/22/2021 PERF GAMMA RAY Yellowjacket KBU 44-06 50133204980000 200179 2/22/2021 SET PLUG - JET CUT Yellowjacket KBU 42-07RD 50133204880100 208052 5/31/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/2/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/7/2020 PERF GAMMA RAY/GPT Yellowjacket KDU 09 50133205780000 208106 11/25/2020 JET CUT Yellowjacket KDU 09 50133205780000 208106 5/17/2021 PERF / GPT Yellowjacket KTU 13-05 50133203700000 184108 1/12/2021 SET PLUG Yellowjacket KTU 24-06H 50133204900000 199073 6/19/2020 PERF Yellowjacket KTU 24-06H 50133204900000 199073 6/20/2020 GPT Yellowjacket KU 44-08 50133206940000 220068 1/15/2021 SET PLUG Yellowjacket KU 44-08 50133206940000 220068 2/4/2021 PERF GAMMA RAY/GPT Yellowjacket KU 44-08 50133206940000 220068 4/6/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. 06/28/2021 PTD: 2200680 E-Set: 35290 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: 6590, Total Depth measured 7,628 feet 6938, 7210 feet true vertical 4,620 feet N/A feet Effective Depth measured 6,590 feet 1,602 feet true vertical 3,901 feet 1,440 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)5-1/2" 17# / L-80 1,580' 1,426' Packers and SSSV (type, measured and true vertical depth)ZXP LTP; N/A 1,602' MD 1,440' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Jake Flora Authorized Title:Operations Manager Contact Email: Contact Phone:777-8442 jake.flora@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 6,192psi 120' 1,548'5,750psi Collapse 3,090psi 5,024psi Casing Structural 20" 9-5/8" Length 120' 1,789' 6,026' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 0 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 302-506 Additional Perf 0 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 8 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 220-068 50-133-20594-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 610 KU 44-08 N/A FEE A022330, FEE A028142 Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai Gas Field / Sterling Gas Pool 3, Sterling Gas Pool 4N/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 5-1/2"7,628'4,620' WINJ WAG 0 Water-Bbl MD 120' 1,789' 0 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:03 am, Apr 28, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.04.27 14:49:51 -08'00' Taylor Wellman (2143) 5.1 SFD 4/28/2021 A093856 302-506 Additional Perf SFD 4/28/2021 BJM 7/26/2021 RBDMS HEW 4/30/2021 SFD 4/28/2021DSR-4/29/21 320-506 Rig Start Date End Date E-Line 4/6/21 4/6/21 04/06/2021 - Tuesday Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT 250 psi low and 3,000 psi high, TP - 900 psi RIH w/GPT and tie into OHL. Tag fill at 6,640' and fluid level was at 4,642'. Run correlation log and send to town. Town said to subtract 1' from GPT correlation log. Looks like we have 1'to 3' existing perfs open 6,638' to 6,648'. Decision made to get N2 out and push fluid into the open perf. Wait on Fox N2 to rig down from another job and come to location. PTW, JSA and SIMOPS with Yellowjacket. Rig up hard lines. PT hard lines and Yellowjacket lubricator and GPT to 250 psi low and 4,000 psi high. Bled N2 down to 1500 psi and open well. RIH w/GPT tool and correlate with todays GPT log. Tag FL at 4,758'. Come on line with N2 built up to 1,500 scf/m at 1,130 psi and pushed fluid away for approx. 1 hr down to 5,932'. Bring pump back on line at 1,500 scf/m and in aprrox 30 min push fluid away. Well broke over at 1,300 psi to 1,250 psi and pumped another 5 min and it stayed at 1,250 psi. Checked with GPT and fluid was pushed away. Keeping Fox N2 on location until we dump cement and set plug to keep pressure on well. Mix cement (18 gals) and load 4' x 30' dump bailer with 16 ppg cement (18') and tie into GPT log. Tag fill at 6,639'. Pick up to 6,619'. Dump 18' of cement. Lost 350 lbs on wt indicator when bailer dumped. Out of hole & good dump. TP - Mix 18 gals of 16 ppg and fill 4" x 30' dump bailer with cement. RIH w/ 4" x 30' bailer filled with cement. Correlate log to 1st bailer run and set down at 6,407' PU to 6,380, cant go down. PU to 6,350' cant go down. PU to 6,326' and go back down to 6,395 with 1,200 psi on tubing. Cool down N2 and pump 1,000 scf/d at 1,200 psi and tools went down hole with no trouble. shut down N2. Stopped at 6,595' and dump cement from 6,621' to 6,603. RIH w/ 4.24" CIBP and tie into GPT log. Run correlation log and send to town. Get ok to set plug at 6,590'w/1,200 psi on tubing. Also log showed that the perf depths were on also. PU 30' and went back down and tag plug. POOH. Setting tool looked good. Good set. Yellowjacket had to go back to shop to get another bull plug for perf gun RIH w/ 2-7/8" x 20.' Razar HC, 6 spf, 60 deg phase and tie into Plug log. Ran correlation log and put it on my stick. Spotted and fired gun from 6,504' to 6,524' w/769.4 psi on tubing. After 5 min - 862 psi, 10 min- 872 psi and 15 min - 876 psi. POOH. All shots fired/gun was dry but bull plug packed with sand. Rig down lubricator and equipment and turn well over to field. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KU 44-08 50-133-20694-00-00 220-068 from 6,621' to 6,603. cement f Get ok to set Note: the remainder of Sundry 320-506 was reported on form 10-407 with the PTD and initial completion report. This additional plug and perf was done after the 10-407 was already isued. Spotted and fired gun from 6,504' to 6,524' w Dump 18' of cement. plug at 6,590'w Looks like we have 1'to 3' existing perfs open 6,638' to 6,648' Updated by JMF 4.8.2021 SCHEMATIC Kenai Gas Field KU 44-08 PTD: 220-068 API: 50-133-20694-00-00 PBTD = 6,590’ MD / TVD = 3,901 ’ TD = 7,628’ MD / TVD = 4,620’ RKB to GL = 18’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status/Size P3_A8 6,504’ 6,524’ 3,853’ 3,864’ 20’ 4/6/21 Open P3_A10 6,613’ 6,633’ 3,913’ 3,925’ 20’ 12/13/2020 Squeezed (1/19/21) P3_A10 6,638’ 6,648’ 3,928’ 3,934’ 10’ 2/4/21 Isolated P5.1_B4A 7,150’ 7,160’ 4,264’ 4,271’ 10’ 1/29/21 Isolated P5.1_B4B 7,234’ 7,244’ 4,325’ 4,332’ 10’ 1/26/21 Isolated CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20” Conductor – Driven to Set Depth 94 X-56 Weld 19.124” Surf 120' 9-5/8" Surf Csg 40 L-80 DWC/C 8.835” Surf 1,789’ 5-1/2" Prod Lnr 17 L-80 CDC HTQ 4.892” 1,602’ 7,628’ 5-1/2" Prod Tieback 17 L-80 CDC HTQ 4.892” Surf 1,610’ 1 20” 9-5/8” 12-1/4” hole 5-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 1,600’ 6.170” 8.250” Seal Assembly No go 1.48’ f/ locating 2 1,602’ 4.892” 8.430” Baker ZXP Liner Top Packer Flex-Lock V liner hanger 3 6,590’ CIBP 4/6/21 4 6,938’ 4.300” - CIBP 5 7,210’ 4.300” - CIBP OPEN HOLE / CEMENT DETAIL 9-5/8" 232 BBL’s of cement in 12-1/4” hole – 70 bbls returned to surface 5-1/2” 338 BBL’s of cement in 8-1/2” hole. TOC @ ~1,880’ (CBL) 8-1/2” hole 2 P3_A8 P3_A10 P5.1_B4A P5.1_B4B 4 5 6590’ CIBP set 4/6/21 6603-39’ 36’ cement dumped 6640’ top of fill 3 ()()()() P3_A8 6,504’6,524’3,853’3,864’20’4/6/21 Open ()()()() 1 Winston, Hugh E (CED) From:Jake Flora - (C) <Jake.Flora@hilcorp.com> Sent:Tuesday, April 6, 2021 1:23 PM To:McLellan, Bryan J (CED) Subject:RE: [EXTERNAL] RE: KU 44-08 (PTD: 220-068) Thanks for turning this so fast! From: McLellan, Bryan J (CED) [mailto:bryan.mclellan@alaska.gov] Sent: Tuesday, April 6, 2021 10:30 AM To: Jake Flora ‐ (C) <Jake.Flora@hilcorp.com> Subject: RE: [EXTERNAL] RE: KU 44‐08 (PTD: 220‐068) Jake, You have approval to proceed with dump bailing 35’ of cement on top of fill, placing cement top at +/‐6623’, as you propose in your email below. Hilcorp is granted a variance from 20 AAC 25.112(c)(1)(E) of the regulations for this well because the proposed plan will provide equally effective plugging of the well, as required in 20 AAC 25.112(i).  There is a cast iron bridge plug above the P5 perfs with 200+ feet of fill on top.  35’ of cement will be placed on top of the fill.  This will place 10’ of cement between the P5 and P3 perf intervals.  Cement will entirely cover the P3‐A10 open perfs from 6638‐6648’ MD, which are the only open perfs in the well.  Will bring top of cement mid‐way into the previously cement‐squeezed P3‐A10 perf interval.  An additional CIBP will be set within 50’ of the top of the P3_A10 perfs before adding perfs in the P3_A8 sands from +/‐6479‐6524’ MD. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Jake Flora ‐ (C) <Jake.Flora@hilcorp.com> Sent: Tuesday, April 6, 2021 8:38 AM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: KU 44‐08 (PTD: 220‐068) Bryan, Sorry to bother you again on this one. We tagged fill at 6658’ and are showing 280’ of fill over the CIBP at 6938’. Do we have permission to proceed with dumping the 35’ cement cap from 6623’ – 6658’? We are on this one now, I’ll give you a call in a bit. The attached schematic is updated to show the fill. 2 Thanks, Jake From: McLellan, Bryan J (CED) [mailto:bryan.mclellan@alaska.gov] Sent: Monday, April 5, 2021 2:41 PM To: Jake Flora ‐ (C) <Jake.Flora@hilcorp.com> Cc: Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> Subject: RE: [EXTERNAL] RE: KU 44‐08 (PTD: 220‐068) Yes, I’ll leave the existing Sundry open. You can proceed with dumping cement and Perforating any perfs listed in the Sundry 320‐506, assuming you are not comingling different pools without approval to do so. Submit any new work on a form 10‐404. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Jake Flora ‐ (C) <Jake.Flora@hilcorp.com> Sent: Monday, April 5, 2021 8:14 AM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: KU 44‐08 (PTD: 220‐068) Good Morning Bryan, Are you leaving the existing Sundry (320‐506) open? Are we OK to proceed with dumping cement on the lower plug at 6938’, setting a plug over the A‐10 (~6590’), then perforating the A‐8? Or do you want us to wait till the 10‐407 is closed first? I haven’t done a ton of these with the 10‐407 involved and wanted to be sure. Feel free to call if you need to, Thanks, Jake 720‐988‐53745 From: McLellan, Bryan J (CED) [mailto:bryan.mclellan@alaska.gov] Sent: Friday, April 2, 2021 5:29 PM To: Jake Flora ‐ (C) <Jake.Flora@hilcorp.com> 3 Cc: Benjamin Siks <bsiks@hilcorp.com> Subject: [EXTERNAL] RE: KU 44‐08 (PTD: 220‐068) Jake, On second thought, after discussing this internally, it will be easier/cleaner for me to process the existing 10‐407. Then you can perf the A8 using the existing Sundry 320‐506 and submit a 10‐404 to show the additional perf interval. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: McLellan, Bryan J (CED) Sent: Friday, April 2, 2021 3:59 PM To: Jake Flora ‐ (C) <Jake.Flora@hilcorp.com> Cc: Benjamin Siks <bsiks@hilcorp.com> Subject: RE: KU 44‐08 (PTD: 220‐068) Jake, You can perf off the existing sundry and halt the 10‐407. But you should initiate halting the 10‐407 from your end. Thank you Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Jake Flora ‐ (C) <Jake.Flora@hilcorp.com> Sent: Friday, April 2, 2021 8:22 AM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Benjamin Siks <bsiks@hilcorp.com> Subject: KU 44‐08 (PTD: 220‐068) Hi Bryan, This was a new well we drilled in late 2020 with the initial completion attempts in the Sterling B4 & A10 all looking wet. We have just decided to test the uppermost sundried Sterling sand (A‐8) per the initial completion sundry (320‐ 506) and it looks like we requested to close it out per the drilling 10‐407 submitted 3‐9‐21 and looking at our files it appears to be waiting on approval still. Would you prefer that we wait till the 10‐407 is approved and then submit a new sundry for the A8 test or can you halt the 10‐407 and allow us to test the A8 off of the existing sundry 320‐506? Attached is the current schematic. We would propose dumping 35’ of cement on the existing plug at 6938’ (covering the B4), set another plug over the A‐10 and perforate the A8. Have a good Easter, I’ll catch up with you next week‐ 4 Jake Jake Flora | Kenai Ops Engineer | Hilcorp Alaska | 720‐988‐5375 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Guhl, Meredith D (CED) From:McLellan, Bryan J (CED) Sent:Tuesday, April 6, 2021 10:30 AM To:Jake Flora - (C) Subject:RE: [EXTERNAL] RE: KU 44-08 (PTD: 220-068) Jake, You have approval to proceed with dump bailing 35’ of cement on top of fill, placing cement top at +/‐6623’, as you propose in your email below. Hilcorp is granted a variance from 20 AAC 25.112(c)(1)(E) of the regulations for this well because the proposed plan will provide equally effective plugging of the well, as required in 20 AAC 25.112(i).  There is a cast iron bridge plug above the P5 perfs with 200+ feet of fill on top.  35’ of cement will be placed on top of the fill.  This will place 10’ of cement between the P5 and P3 perf intervals.  Cement will entirely cover the P3‐A10 open perfs from 6638‐6648’ MD, which are the only open perfs in the well.  Will bring top of cement mid‐way into the previously cement‐squeezed P3‐A10 perf interval.  An additional CIBP will be set within 50’ of the top of the P3_A10 perfs before adding perfs in the P3_A8 sands from +/‐6479‐6524’ MD. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Jake Flora ‐ (C) <Jake.Flora@hilcorp.com> Sent: Tuesday, April 6, 2021 8:38 AM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: KU 44‐08 (PTD: 220‐068) Bryan, Sorry to bother you again on this one. We tagged fill at 6658’ and are showing 280’ of fill over the CIBP at 6938’. Do we have permission to proceed with dumping the 35’ cement cap from 6623’ – 6658’? We are on this one now, I’ll give you a call in a bit. The attached schematic is updated to show the fill. Thanks, Jake 2 From: McLellan, Bryan J (CED) [mailto:bryan.mclellan@alaska.gov] Sent: Monday, April 5, 2021 2:41 PM To: Jake Flora ‐ (C) <Jake.Flora@hilcorp.com> Cc: Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> Subject: RE: [EXTERNAL] RE: KU 44‐08 (PTD: 220‐068) Yes, I’ll leave the existing Sundry open. You can proceed with dumping cement and Perforating any perfs listed in the Sundry 320‐506, assuming you are not comingling different pools without approval to do so. Submit any new work on a form 10‐404. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Jake Flora ‐ (C) <Jake.Flora@hilcorp.com> Sent: Monday, April 5, 2021 8:14 AM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: KU 44‐08 (PTD: 220‐068) Good Morning Bryan, Are you leaving the existing Sundry (320‐506) open? Are we OK to proceed with dumping cement on the lower plug at 6938’, setting a plug over the A‐10 (~6590’), then perforating the A‐8? Or do you want us to wait till the 10‐407 is closed first? I haven’t done a ton of these with the 10‐407 involved and wanted to be sure. Feel free to call if you need to, Thanks, Jake 720‐988‐53745 From: McLellan, Bryan J (CED) [mailto:bryan.mclellan@alaska.gov] Sent: Friday, April 2, 2021 5:29 PM To: Jake Flora ‐ (C) <Jake.Flora@hilcorp.com> Cc: Benjamin Siks <bsiks@hilcorp.com> Subject: [EXTERNAL] RE: KU 44‐08 (PTD: 220‐068) Jake, On second thought, after discussing this internally, it will be easier/cleaner for me to process the existing 10‐407. Then you can perf the A8 using the existing Sundry 320‐506 and submit a 10‐404 to show the additional perf interval. 3 Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: McLellan, Bryan J (CED) Sent: Friday, April 2, 2021 3:59 PM To: Jake Flora ‐ (C) <Jake.Flora@hilcorp.com> Cc: Benjamin Siks <bsiks@hilcorp.com> Subject: RE: KU 44‐08 (PTD: 220‐068) Jake, You can perf off the existing sundry and halt the 10‐407. But you should initiate halting the 10‐407 from your end. Thank you Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Jake Flora ‐ (C) <Jake.Flora@hilcorp.com> Sent: Friday, April 2, 2021 8:22 AM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Benjamin Siks <bsiks@hilcorp.com> Subject: KU 44‐08 (PTD: 220‐068) Hi Bryan, This was a new well we drilled in late 2020 with the initial completion attempts in the Sterling B4 & A10 all looking wet. We have just decided to test the uppermost sundried Sterling sand (A‐8) per the initial completion sundry (320‐ 506) and it looks like we requested to close it out per the drilling 10‐407 submitted 3‐9‐21 and looking at our files it appears to be waiting on approval still. Would you prefer that we wait till the 10‐407 is approved and then submit a new sundry for the A8 test or can you halt the 10‐407 and allow us to test the A8 off of the existing sundry 320‐506? Attached is the current schematic. We would propose dumping 35’ of cement on the existing plug at 6938’ (covering the B4), set another plug over the A‐10 and perforate the A8. Have a good Easter, I’ll catch up with you next week‐ Jake 4 Jake Flora | Kenai Ops Engineer | Hilcorp Alaska | 720‐988‐5375 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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Data looks questionable both times. Remedial cement job pumped per Sundry 320-528. bjm Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 02/12/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KU 44-08 (PTD 220-068) PERF, GPT, PLUG, DRIFT 01-26_29-2021 Please include current contact information if different from above. Received by the AOGCC 02/16/2021 PTD: 2200680 E-Set: 34703 02/16/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 01/29/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KU 44-08 (PTD 220-068) RCBL Radial Cement Bond Log 12/09/2020 Please include current contact information if different from above. Received by the AOGCC 01/29/2021 PTD: 2200680 E-Set: 34636 Abby Bell 02/01/2021 Ihh,.,rp ,thtsk,,. 1.1.c: 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 44-08 (PTD 220-068) Washed and Dried Well Samples B Set (4 Boxes): WELL BOX SAMPLE INTERVAL (FEET / MD) KU 44-08 BOX 1 OF 4 1600'- 3340' MD KU 44-08 BOX 2 OF 4 3340'- 5080' MD KU 44-08 BOX 3 OF 4 5080' - 6700' MD KU 44-08 BOX 4 OF 4 6700'- 7625' MD (TD) Please include current contact information if different from above. RECEIVED JAN 2 8 2021 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal via Email or FAX to: (907) 777-8510 ReceiveT l4'.'C"�' C Date: _-2/ / �-' Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/23/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KU 44-08 (PTD 220-068) FINAL GPT, Fluid Level, PERFORATING RECORD Verification Log 12/16/2020 Please include current contact information if different from above. PTD: 2200680 E-Set: 34462 Received by the AOGCC 12/23/2020 Abby Bell 12/23/2020 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/23/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KU 44-08 (PTD 220-068) FINAL PERFORATING RECORD 12/13/2020 Please include current contact information if different from above. 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Increase rate in 4 steps. Dec 19, 2020 - 10:12:00 AM PUMP RATE: 1 BPM, P2 DIS PRESS: 232 PSI, Increase rate to 1.5 BPM Dec 19, 2020 - 10:14:52 AM PUMP RATE: 2 BPM, P2 DIS PRESS: 363 PSI, Increase rate to 1.75 BPM Dec 19, 2020 - 10:16:06 AM PUMP RATE: 2 BPM, P2 DIS PRESS: 494 PSI, Increase rate to 2.0 BPM. Dec 19, 2020 - 10:42:49 AM PUMP RATE: 0 BPM, P2 DIS PRESS: 112 PSI, finished pumping 65 BBL 1.5% KCL. Dec 19, 2020 - 10:45:07 AM PUMP RATE: 1 BPM, P2 DIS PRESS: 239 PSI, Pumped .75 BBL 50/50 methanol Final Readings (2020-12-19 10:45): B1 TOTAL: 0 BBL PUMP TOTAL: 69 BBL 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: 12/16/2020 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL KU 44-08 (PTD 220-068) Final LWD Logs (11/16/2020 to 11/26/2020) 1.2” & 5” (MD/TVD) Logs: AGR, DGR, EWR-M5, ADR, ALD, CTN 2.Time Log: GeoTap Formation Pressure Tester 3.Final Definitive Directional Survey 4.GeoTap Final Report Folder Contents: Please include current contact information if different from above. Received by the AOGCC 12/17/2020 PTD: 2200680 E-Set:34406 Abby Bell 12/17/2020 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: 12/07/2020 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL KU 44-08 (PTD 220-068) GEOLOG: EOW DRILLING REPORTS (11/16/2020 to 11/25/2020) 1.DAILY DRILLING REPORTS 2.FINAL EOW REPORT 3.DIGITAL DATA 4.LWD LOGS 5.MUDLOGS 6.SHOW REPORTS Folder Contents: Please include current contact information if different from above. Received by the AOGCC 12/07/2020 PTD: 2200680 E-Set: 34355 Abby Bell 12/08/2020 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: Initial Completion / N2 2.Operator Name:4.Current Well Class:5. Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 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): 7500'N/A Casing Collapse Structural Conductor Surface 3,090psi Intermediate Production 5,024psi Liner 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:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Jake Flora Operations Manager Contact Email: Contact Phone: 777-8442 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng jake.flora@hilcorp.com 4528'7420'4461'1522 psi N/A ZXP LTP ; N/A 1,580' MD / 1,426' TVD ; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE A022330, FEE A028142 220-068 50-133-20694-00-00 KU 44-08 Kenai Gas Field / Sterling Pool 3 Length Size CO 510A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 17# L-80 TVD Burst 1,580' 6,192psi MD 5,750psi 120' 1,548' 120' 1789' 4528'5-1/2" 20" 9-5/8" 120' 1789' 7500' Perforation Depth MD (ft): See Attached Schematic 5920' Authorized Title: 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: December 15, 2020 5-1/2" Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Wellbore schematic Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:57 am, Nov 30, 2020 320-506 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.11.30 10:24:41 -09'00' Taylor Wellman Perforate f SFD 12/1/2020 ^ X 10-407 (final well report) CTU DSR-11/30/2020 SFD 12/01/2020 Initial Completion / N2 , Sterling Gas Pool 4 *4000 psi BOPE test Gas gls 12/2/20 * Forward CBL to AOGCC for review before perforating Comm 12/2/2020 dts 12/2/2020 JLC 12/2/2020 RBDMS HEW 12/2/2020 Well Prognosis Well: KU 44-08 Date: 11/30/2020 Well Name: KU 44-08 API Number: 50-133-20694-00-00 Current Status: Gas Production Well Leg: N/A Estimated Start Date: December 15, 2020 Rig: N/A Reg. Approval Req’d? 10-403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 220-068 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) AFE Number: Bottom Hole Pressure: 1,957 psi @ 4351’ TVD (Based on normal gradient) Max. Potential Surface Pressure: 1,522 psi (Based upon Max. Expected BHP minus 0.1 PSI/ft. gas gradient to surface Brief Well Summary: KU 44-08 “Pippin” is a new drill prospect well. The purpose of this Sundry is to complete the well for gas production. Current Well Condition: x 5-1/2” liner ran to ~7,500’ MD and cemented, liner top packer at ~1,580’. x 5-1/2” liner was cleaned out to TD, Pressure tested to 3500 psi, and well displaced to 6% KCL brine. 5- 1/2” tie-back was run to surface. Coiled Tubing Procedure 1. MIRU coiled tubing, PT BOPE to 250 psi low / 4000 psi high. a) Notify AOGCC 24 hrs in advance of BOP test to allow for option to witness. 2. Log memory CBL from TD to surface, send results to AOGCC. 3. MIRU N2 pumping unit. a) Review standard nitrogen pumping procedure with all personnel. 4. MU BHA including jet swirl nozzle. 5. RIH and come online with N2 and jet well dry. a) Estimated volume of displaced 6% KCl is ~220 bbls. (Based on estimated PBTD of +/-7,500’). 6. Once well is dry trap 1500 psi on the casing for perforating. 7. POOH. 8. RDMO coiled tubing. E-Line Procedure 1. MIRU E-line and pressure control equipment. PT lubricator. Note that the well is pressurized with nitrogen. a) If necessary, bleed pressure down as requested by the OE. 2. PU RIH W/perf guns. Perforate each interval with 2-7/8” perf guns 6 SPF 60 degree phasing. 3. Proposed Perforated Intervals: MIT-IA on rig . Email PDF to AOGCC. Well Prognosis Well: KU 44-08 Date: 11/30/2020 Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom Pool CO P3_A8 ±6,479' ±6,524' 45' ±3,838' ±3,863' KENAI, STERLING 3 GAS CO 510A P3_A10 ±6,613' ±6,695' 82' ±3,913' ±3,960' KENAI, STERLING 3 GAS CO 510A P4_B1A ±6,866' ±6,897' 31' ±4,067' ±4,085' KENAI, STERLING 4 GAS CO 510A P4_B2A ±6,956' ±7,089' 133' ±4,126' ±4,222' KENAI, STERLING 4 GAS CO 510A P4_B4A ±7,145' ±7,174' 29' ±4,260' ±4,283' KENAI, STERLING 4 GAS CO 510A P4_B4B ±7,234' ±7,270' 36' ±4,323' ±4,351' KENAI, STERLING 4 GAS CO 510A a) Proposed perforations are also shown on the proposed schematic in red font. b) Final Perforation tie-in sheet will be provided in the field for exact perforation intervals. c) Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer (Trudi Hallett), and Geologist (Ben Siks) for confirmation. d) Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures at 5, 10, and 15 minute intervals after firing gun. e) The listed Sands cover separate pools. Prior to perforating sands in Pool 3, open perforations in Pool 4 will need to be abandoned with a CIBP & 35’ of cement. E-line Procedure (Contingency) 1. If any zone produces sand and/or water or needs isolated: 2. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 2,500 psi High. 3. RIH and set Casing Patch or set CIBP above the zone and dump 35’ of cement on top of the plug. Attachments: Current Schematic Proposed Schematic Standard Nitrogen Procedure Updated by FVR 11.20.2020 CURRENT SCHEMATIC Kenai Gas Field KU 44-08 PTD: 220-068 API: 50-133-20694-00-00 PBTD = 7,420’ MD / TVD = 4,461’ TD = 7,500’ MD / TVD = 4,528 RKB to GL = 18’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20” Conductor – Driven to Set Depth 94 X-56 Weld 19.124” Surf 120' 9-5/8" Surf Csg 40 L-80 DWC/C 8.835” Surf 1,789’ 5-1/2" Prod Lnr 17 L-80 CDC HTQ 4.892” 1,580’ 7,500’ 5-1/2" Prod Tieback 17 L-80 CDC HTQ 4.892” Surf 1,580’ 1 20” 9-5/8” 12-1/4” hole 5-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 1,580’ 4.892” 8.430” Baker ZXP Liner Top Packer Flex-Lock V liner hanger 2 1,580’ 4.892” 7.360” Baker tieback Seal Assembly OPEN HOLE / CEMENT DETAIL 9-5/8" 177 BBL’s of cement in 12-1/4” hole – Returns to surface (50% excess) 5-1/2” 303 BBL’s of cement in 8-1/2” hole. Est. TOC @ TOL – ~1,580’ (20% excess) 8-1/2” hole 2 Updated by FVR 11.20.2020 PROPOSED SCHEMATIC Kenai Gas Field KU 44-08 PTD: 220-068 API: 50-133-20694-00-00 PBTD = 7,420’ MD / TVD = 4,461’ TD = 7,500’ MD / TVD = 4,528 RKB to GL = 18’ Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom P3_A8 ±6,479' ±6,524' 45' ±3,838' ±3,863' P3_A10 ±6,613' ±6,695' 82' ±3,913' ±3,960' P4_B1A ±6,866' ±6,897' 31' ±4,067' ±4,085' P4_B2A ±6,956' ±7,089' 133' ±4,126' ±4,222' P4_B4A ±7,145' ±7,174' 29' ±4,260' ±4,283' P4_B4B ±7,234' ±7,270' 36' ±4,323' ±4,351' CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20” Conductor – Driven to Set Depth 94 X-56 Weld 19.124” Surf 120' 9-5/8" Surf Csg 40 L-80 DWC/C 8.835” Surf 1,789’ 5-1/2" Prod Lnr 17 L-80 CDC HTQ 4.892” 1,580’ 7,500’ 5-1/2" Prod Tieback 17 L-80 CDC HTQ 4.892” Surf 1,580’ 1 20” 9-5/8” 12-1/4” hole 5-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 1,580’ 4.892” 8.430” Baker ZXP Liner Top Packer Flex-Lock V liner hanger 2 1,580’ 4.892” 7.360” Baker tieback Seal Assembly OPEN HOLE / CEMENT DETAIL 9-5/8" 177 BBL’s of cement in 12-1/4” hole – Returns to surface (50% excess) 5-1/2” 303 BBL’s of cement in 8-1/2” hole. Est. TOC @ TOL – ~1,580’ (20% excess) 8-1/2” hole 2 Perf Sterling STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1 Guhl, Meredith D (CED) From:Schwartz, Guy L (CED) Sent:Saturday, November 21, 2020 10:00 AM To:Frank Roach Cc:Monty Myers Subject:RE: KU 44-08 (PTD 220-068) FIT Results Frank, I looked at the LOT plot this morning. I think LOT would be closer to 11.3 ppg EMW. Plot falls off at 200 psi and that is being generous. None the less… this still gives you just under a 10 bbl kick tolerance using my spreadsheet. It is close so use all precautions when you are getting close to TD. If you mud weight ends up changing much from 9.0 ppg let me know also. Guy Schwartz Sr. Petroleum Engineer AOGCC 907‐301‐4533 cell 907‐793‐1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Frank Roach <Frank.Roach@hilcorp.com> Sent: Friday, November 20, 2020 9:14 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Monty Myers <mmyers@hilcorp.com> Subject: KU 44‐08 (PTD 220‐068) FIT Results Mr. Schwartz, Rig 169 attempted to perform a FIT to 13.5ppg EMW this evening (11/20/2020). During the test, the shoe leaked off at an 11.7ppg EMW. This is within the predicted 11.0ppg – 15.0ppg EMW from offset field data. With the 11.7ppg EMW, the 9‐5/8” shoe at 1,554’ TVD, and predicted well TD at 4,528’ TVD: Kick tolerance = (11.7-9.0)X(1554/4528) = 0.92 We’re also calculating a 14.2 bbl kick tolerance from this test. With these values in hand, we’re proceeding to drill ahead to planned TD of 7,500’ MD. Attached are the test chart with the casing and leakoff tests as well as the Excel sheet with the tabular data. Let me know if you need any additional information. Regards, 2 Frank V Roach Drilling Engineer 907.854.2321 (c) 907.777.8413 (o) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Reviewed By: P.I. Supry BOPE Test Report for: KENAI UNIT 44-08 , Comm Contractor/Rig No.: Hilcorp 169 PTD#: 2200680 DATE: 11/20/2020 , Inspector Jeff Jones - Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: R. Pederson / J. Riley Rig Rep: Trick / Lynch inspector Type Operation: DRILL Sundry No: Test Pressures: Inspection No: bopJJ201129181547 Rams: Annular: Valves: MASP: Type Test: INIT 250/3500 250/3500 250/3500 1494 v✓ Related Insp No: MISC. INSPECTIONS: Quantity P/F Location Gen.: P --- -Housekeeping: Housekeeping: P PTD On Location _ P " Standing Order Posted P Well Sign P DO. Rig P Hazard Sec. P -_ Mise NA FLOOR SAFTY VALVES: TEST DATA MUD SYSTEM: Quantity P/F Upper Kelly 1 P Lower Kelly 1 P Ball Type I P Inside BOP 1, P FSV Misc 0 NA TEST DATA MUD SYSTEM: ACCUMULATOR SYSTEM: Visual Alarm Time/Pressure P/F Trip Tank -FP ' FP_ System Pressure 3050 P _ Pit Level Indicators FP ✓ FP Pressure After Closure 1700 P " Flow Indicator FP FP ' 200 PSI Attained 22 P Meth Gas Detector -_P-__ - P Full Pressure Attained 88 P H2S Gas Detector P -__-_P Blind Switch Covers: all P MS Misc NA _KA Nitgn. Bottles (avg): x_2525 - P - ACC Misc 0 NA BOP STACK: CHOKE MANIFOLD: Quantity Size P/F Quantity P/F Stripper 0_ NA _ No. Valves 15 P Annular Preventer 1 11_ " - P Manual Chokes 1 P , #I Rams 1 2 7/8 _x 5" P - Hydraulic Chokes I P " #2 Rams 1 ` Blind P CH Misc 0 NA #3 Rams 1 ` 2 7/8 x 5" P #4 Rams 0 NA #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 _3 1/8" P, Quantity P/F NCR Valves 2 " 3 1/8-2 1/16"- P - Inside Reel Valves _0 NA Kill Line Valves 2 2 1/16" P Check Valve 0 NA BOP Misc 0 NA Number of Failures: 6 Test Results Test Time 7 Remarks: Parker Drilling Inc. personnel performed the BOPE tests today in a safe and proficient manner with 6 failures witnessed. The electrronic pit volume totalizer alarm system (PVT) failed to operate (6 items) and was repaired and succes-sTuully retested. The gas detection alarm system was tested and operated properly. The rig and surrounding location appeared clean, orderly and in good condition. 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 Undefined Pool, KU 44-08 Hilcorp Alaska, LLC Permit to Drill Number: 220-068 Surface Location: 436' FNL, 361' FEL, Sec 18, T4N, R11W, SM, AK Bottomhole Location: 381' FSL, 209' FEL, Sec 8, T4N, R11W, 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 November, 2020. Jeremy M Price 4 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: 7,500' TVD: 4,528' 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): 85' 15. Distance to Nearest Well Open Surface: x-275450 y- 2356295 Zone-4 67' to Same Pool: 5884' to KU 12-17 16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 60 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD Cond 20" 94# X-56 Weld 120' Surface Surface 120' 120' 12-1/4" 9-5/8" 40# L-80 DWC/C 1,780' Surface Surface 1,780' 1,500' 8-1/2" 5-1/2" 17# L-80 CDC HTQ 5,920' 1,580' 1,400' 7,500' 4,528' Tieback 5-1/2" 17# L-80 CDC HTQ 1,580' Surface Surface 1,580' 1,400' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned? Yes No 20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Contact Email: Contact Phone: Date: Permit to Drill API Number: Permit Approval Number: 50- Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Sr Pet Eng Sr Pet Geo Sr Res Eng GL / BF Elevation above MSL (ft): 10/6/2020 See cover letter for other requirements. Perforation Depth MD (ft): 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Perforation Depth TVD (ft): Commission Use Only Effect. Depth MD (ft): Authorized Signature: Surface Production Liner Casing Intermediate Tieback Assy. L - 724 ft3 / T - 269 ft3 Effect. Depth TVD (ft): Conductor/Structural Length 1947 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 - 1550 ft3 / T - 148 ft3 1494 313' FSL, 749' FEL, Sec 8, T4N, R11W, SM, AK 381' FSL, 209' FEL, Sec 8, T4N, R11W, SM, AK N/A 4349 KU 44-08 Kenai Gas Field Sterling Undefined 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 Hilcorp Alaska, LLC 436' FNL, 361' FEL, Sec 18, T4N, R11W, SM, AK FEE 022330, FEE A028142 022224484 2638' to nearest unit boundary 11/6/2020 Authorized Name: Monty Myers Authorized Title: Drilling Manager Joe Engel jengel@hilcorp.com 777-8395 18. Casing Program: Top - Setting Depth - BottomSpecifications Stratigraphic Test No Mud log req'd: Yes No No Directional svy req'd: Yes No Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements BOP SketchDrilling Program Time v. Depth Plot Shallow Hazard Analysis Single Well Gas Hydrates No Inclination-only svy req'd: Yes No Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal No No 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 8:08 am, Oct 06, 2020 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2020.10.06 07:58:33 -08'00' Monty M Myers DSR-10/12/2020 X X 133-20694-00-00 X X X 220-068 DLB 10/07/2020 X X pDevelopment - Gas (pippin) *Sundry approval required for well completion and perforations gls 11/3/20 *3500 psi BOPE test (2500 psi annular) * CBL required over 5 1/2" liner *Diverter Waived per 20 AAC 25.035(h)(2) gls 11/3/20 11/4/2020 11/4/2020 KU 44-08 Drilling Program Kenai Gas Field 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 ..................................................................................................... 10 10.0 N/U 16” Conductor Riser ........................................................................................................ 11 11.0 Drill 12-1/4” Hole Section ........................................................................................................ 13 12.0 Run 9-5/8” Surface Casing ...................................................................................................... 15 13.0 Cement 9-5/8” Surface Casing ................................................................................................. 18 14.0 BOP N/U and Test.................................................................................................................... 21 15.0 Drill 8-1/2” Hole Section .......................................................................................................... 22 16.0 Run 5-1/2” Production Liner ................................................................................................... 25 17.0 Cement 5-1/2” Production Liner ............................................................................................. 28 18.0 5-1/2” Liner Tieback Polish Run and Cleanout Run .............................................................. 31 19.0 5-1/2” Tieback Run .................................................................................................................. 31 20.0 RDMO ...................................................................................................................................... 32 21.0 BOP Schematic ........................................................................................................................ 33 22.0 Wellhead Schematic ................................................................................................................. 34 23.0 Days Vs Depth .......................................................................................................................... 35 24.0 Geo-Prog .................................................................................................................................. 36 25.0 Anticipated Drilling Hazards .................................................................................................. 37 26.0 Hilcorp Rig 147 Layout ........................................................................................................... 39 27.0 FIT Procedure .......................................................................................................................... 40 28.0 Choke Manifold Schematic ...................................................................................................... 41 29.0 Casing Design Information ...................................................................................................... 42 30.0 8-1/2” Hole Section MASP ....................................................................................................... 43 31.0 Spider Plot (Governmental Sections) ...................................................................................... 44 32.0 Surface Plat (As-Built NAD27) ................................................................................................ 45 Page 2 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 1.0 Well Summary Well KU 44-08 Pad & Old Well Designation G&I Pad (41-18 Pad) / grass roots well Planned Completion Type 5-1/2” Cemented Production Liner Target Reservoir(s) Sterling A and B Sands Planned Well TD, MD / TVD 7,500’ MD / 4,528’ TVD PBTD, MD / TVD 7,420’ MD / 4,461’ TVD Surface Location (Governmental) 436’ FNL, 361’ F EL, Sec 18, T4N, R11W, SM, AK Surface Location (NAD 27) X=275450.20 Y=2356295.75 Top of Productive Horizon (Governmental) 313’ FSL, 749’ FEL, Sec 8, T4N, R11W, SM, AK TPH Location (NAD 27) X=280399.12, Y=2356830.15 BHL (Governmental) 381’ FSL, 209’ FEL, Sec 8, T4N, R11W, SM, AK BHL (NAD 27) X=280939.66, Y=2356888.47 AFE Number AFE Drilling Days 3 MOB, 19 DRLG AFE Completion Days AFE Drilling Amount $3,944,100 AFE Completion Amount Maximum Anticipated Pressure (Surface) 1494 psi Maximum Anticipated Pressure (Downhole/Reservoir) 1947 psi Work String 4-1/2” 16.6# S-135 CDS-40 RKB – GL 85.0’ (67 + 18) Ground Elevation 67.0’ 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 44-08 Drilling Procedure Rev 1 2.0 Management of Change Information Any SFD 10/14/2020approved in advance by Page 4 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 3.0 Tubular Program: Hole Section OD (in) ID (in) Drift (in) Conn OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) Cond 20” 19.12” 19” - 94 X-56 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” 5-1/2” 4.892” 4.767” 6.300” 17 L-80 CDC HTQ 7740 6290 397 4.0 Drill Pipe Information: Hole Section OD (in) ID (in) TJ ID (in) TJ OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) All 4-1/2” 3.826 2.6875” 5.25” 16.6 S-135 CDS40 17,693 16,769 468k Cleanout 2-7/8” 2.323 2.265” 3.438” 7.9 P-110 PH-6 16,896 16,082 194k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 5 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. x Report covers operations from 6am to 6am x Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area – this will not save the data entered, and will navigate to another data entry tab. x Ensure time entry adds up to 24 hours total. x Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates x Submit a short operations update each work day to pmazzolini@hilcorp.com, mmyers@hilcorp.com, Frank.Roach@hilcorp.com, jengel@hilcorp.com, and cdinger@hilcorp.com 5.3 Intranet Home Page Morning Update x Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. Each rig will be assigned a username to login with. 5.4 EHS Incident Reporting x Notify EHS field coordinator. 1. This could be one of (3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don’t wait until an emergency to have to call around and figure it out!!!! a. John Coston: O: (907) 777-6726 C: (907) 227-3189 b. Matt Hogge: O: (907) 777-8418 C: (907) 227-9829 2. Spills: Keegan Fleming: O:907-777-8477 C:907-350-9439 x Notify Drlg Manager 1. Monty M Myers: O: 907-777-8431 C: 907-538-1168 x Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally x Send final “As-Run” Casing tally to mmyers@hilcorp.com, Frank.Roach@hilcorp.com, 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 44-08 Drilling Procedure Rev 1 6.0 Planned Wellbore Schematic CBL log required over 5 1/2" liner Liner top packer and tieback 13.5 ppg FIT Page 7 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 7.0 Drilling / Completion Summary KU 44-08 is a grassroots development well to be drilled off of G&I Pad (41-18 Pad). This well will be targeting the Sterling A and B sands for gas production. The base plan is deviated wellbore with a kick off point at ~300’ MD. Maximum hole angle will be 60 deg before dropping to 31 deg and TD of the well will be 7,500’ TMD/ 4,528’ TVD. Drilling operations are expected to commence approximately November 6th 2020. The Hilcorp Rig # 147 will be used to drill the wellbore then run casing and cement. Surface casing will be run to 1,780’ MD / 1,500’ 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 1,780’ 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 7,500’ MD. Perform Wiper trip. 6. Make cleanout run 7. POOH laying down drill pipe. 8. Run and cmt 5-1/2” production liner. 9. PU clean out assembly and RIH to clean out 5-1/2” to landing collar 10. Displace well to 6% KCL completion fluid. 11. POOH and LD clean out assembly. 12. RIH and land 5-1/2” 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. The Hilcorp Rig # 147 w (diverter waived per 20 AAC 25.035 (h)(2) Page 8 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. 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 44-08. 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 5/5 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. x If the BOP is used to shut in on the well in a well control situation, 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, KU 11-07X, and KU 42-12 on a nearby pads. No issues were experienced on the wells drilling the surface hole. Surface casing will be set at the same depth on KU 44-08. No shallow hydrocarbon zones will be penetrated. (Diverter Waiver approved per 20 AAC 25.035(h)(2) tdilli fKU24 (Divert ) Page 9 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 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. 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 10 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 9.0 R/U and Preparatory Work 9.1 20” 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. Page 11 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 10.0 N/U 16” Conductor Riser 10.1 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. DIVERTER WAIVED Page 12 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 10.3 Rig 147 Orientation: Note: Actual layout may be different on location Page 13 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 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 20” conductor at reduced flow rates to avoid broaching the conductor. 11.4 Drill 12-1/4” hole section to 1,780’ MD/ 1,500’ 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 1,700’ and 1,800’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 8.8 – 9.5 ppg P– Drill 12-1/4” hole section to 1,780’ MD/ 1,500’TVD. Page 14 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL pH 120-1780’ 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 20” conductor shoe. 11.7 TOH with the drilling assy, handle BHA as appropriate. Note: EMW=8.3 ppg needed for this interval. See P. 43 for calcs. DLB 8.8 – 9.5 Page 15 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 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 16 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 Page 17 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. Page 18 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 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: 20” Conductor x 9-5/8” casing annulus: 120’ x .26529 bpf = 31.84 178.8 12.0 ppg LEAD: 12-1/4” OH x 9-5/8” Casing annulus: (1280’ – 120’) x .05578 bpf x 1.5 = 97.06 545.0 Total LEAD: 128.90 723.8 ft3 15.4 ppg TAIL: 12-1/4” OH x 9-5/8” Casing annulus: (1780’- 1280’) x .05578 bpf x 1.5 = 41.84 234.9 15.4 ppg TAIL: 9-5/8” Shoe track: 80 x .07583 bpf = 6.07 34.1 Total TAIL: 47.91 bbl 269.0 ft3 TOTAL CEMENT VOL: 176.81bbl 992.8 ft3 294 sx 220 sx Cement volume based on annular volume + 50% open hole excess. Page 19 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 Cement Slurry Design: 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets “sticky”, land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug and displace cement with spud mud. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.11 Displacement calculation: 1780’- 80’ = 1700’ x .07583 bpf = 129 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 (1280’ MD to surface) Tail Slurry (1780’ to 1280’ MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.46 ft3/sk 1.22 ft3/sk Mixed Water 14.349 gal/sk 5.507 gal/sk Mixed Fluid 14.469 gal/sk 5.507 gal/sk Additives Code Description Concentration Code Description Concentration G Cement 94#/sk A Cement 94#/sk D110 Retarder 0.15 gal/sk BWOC D046 Anti Foam 0.2 % BWOC D046 Anti Foam 0.2 % BWOC D065 Dispersant 0.4 % BWOC D079 Extender 2.0 % BWOC S002 CaCl2 0.35 % BWOC D020 Extender 3.0 % BWOC D177 CaCl2 0.1 % BWOC 2.46 ft3/sk 1.22 ft3/sk Mixed Water Keep the hangerpp gg elevated above the wellhead while working. Page 20 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 13.13 Do not overdisplace by more than ½ shoe track volume. Total volume in shoe track is 6.1 bbls. x Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 12 – 18 hours after CIP. x Be prepared with small OD top out tubing in the event a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5”. 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.15 R/D cement equipment. Flush out wellhead with FW. 13.16 Back out and L/D landing joint. Flush out wellhead with FW. 13.17 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.18 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Send final “As-Run” casing tally & casing and cement report to cdinger@hilcorp.com, jengel@hilcorp.com, and Frank.Roach@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 21 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 14.0 BOP N/U and Test 14.1 ND Diverter line and diverter 14.2 N/U multi-bowl wellhead assy. Install 9-5/8” packoff P-seals. Test to 3000 psi. 14.3 N/U 11” x 5M BOP as follows: x BOP configuration from Top down: 11” x 5M Type 90 annular BOP/11” x 5M Model 82 double ram /11” x 5M mud cross/11” x 5M Type 82 single ram x Double ram should be dressed with 2-7/8” x 5” variable bore rams in top cavity, blind ram in btm cavity. x Single ram should be dressed with 2-7/8” x 5” variable bore rams x N/U bell nipple, install flowline. x Install (2) manual valves & a check valve on kill side of mud cross. x Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 4-1/2” BOP test assy, land out test plug (if not installed previously). x Test BOP to 250/3500 psi for 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. Rig 147 Page 22 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 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 1,780’- 7,500’ 9.0 – 10.0 40-53 15-25 15-25 8.5-9.5 11.0 Note: EMW=8.3 ppg needed for this interval. See P. 43 for calcs. DLB 9.0 – 10.0 – g Page 23 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 System Formulation: 6% KCL EZ Mud DP Product Concentration Water KCl Caustic BARAZAN D+ EZ MUD DP DEXTRID LT PAC-L BARACARB 5/25/50 BAROID 41 ALDACIDE G BARACOR 700 BARASCAV D 0.905 bbl 22 ppb (29 K chlorides) 0.2 ppb (9 pH) 1.25 ppb (as required 18 YP) 0.75 ppb (initially 0.25 ppb) 1-2 ppb 1 ppb 15 - 20 ppb (5 ppb of each) as required for a 9.0 – 10.0 ppg 0.1 ppb 1 ppb 0.5 ppb (maintain per dilution rate) 15.9 TIH w/ 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(1500/4528) = 1.4 15.14 Drill 8-1/2” hole section to 7,500’ MD / 4,528’ 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 4,780’ MD), trip back to the 9-5/8” shoe to split the hole section in half x Ensure shale shakers are functioning properly. Check for holes in screens on connections. x 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. MIT casing 2500 psi FIT to 13.5 ppg Kick tolerance = (13.5-9.0)X(1500/4528) = 1.4 Page 24 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 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. 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 5-1/2” pipe rams in BOP stack and test. (3500 psi ram test)test 5" rams. ... gls)(can leave 5 1/2" rams in until tieback is RIH Page 25 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 16.0 Run 5-1/2” Production Liner 16.1. R/U Weatherford 5-1/2” casing running equipment. x Ensure 5-1/2” 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 5-1/2” 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 5-1/2” production liner 5-1/2” 17# CDC - HTQ M/U torques Casing OD Minimum Maximum Yield Torque 5-1/2” 8,500 ft-lbs 11,500 ft-lbs 13,900 ft-lbs Page 26 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 Page 27 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 16.6. Run in hole w/ 5-1/2” 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 5-1/2” 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. PU 5-1/2” X 9-5/8” Baker liner hanger/LTP assembly. Page 28 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 17.0 Cement 5-1/2” Production Liner 17.1. Hold a pre-job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. x Pump 20 bbls of freshwater through all of Halliburton’s equipment, taking returns to cuttings bin, prior to pumping any fluid downhole x How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. x Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. x Positions and expectations of personnel involved with the cmt operation. x Document efficiency of all possible displacement pumps prior to cement job. 17.2. Attempt to rotate and reciprocate the liner during cmt operations until hole gets sticky 17.3. Pump 5 bbls of 12.5 ppg Mud Push spacer. 17.4. Test surface cmt lines to 4500 psi. 17.5. Pump remaining 30 bbls 12.5 ppg Mud Push spacer. 17.6. Mix and pump lead and tail cement per below recipe. Ensure cement is pumped at designed weight. Job is designed to pump 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 5-1/2” liner annulus: 200’ x .04644 bpf = 9.29 52.2 12.0 ppg LEAD: 8-1/2” OH x 5-1/2” annulus: (7000’ – 1780’) x .04080 bpf x 1.2 = 255.57 1434.9 Total LEAD: 276.09 bbl 1550.2 ft3 15.4 ppg TAIL: 8-1/2” OH x 5-1/2” annulus: (7415’- 6915’) x .04080 bpf x 1.2 = 24.48 137.5 15.4 ppg TAIL: 5-1/2” Shoe track: 80 x .02325 bpf = 1.86 10.4 Total TAIL: 26.34 bbl 147.9 ft3 630sx 120sx pp p Job is designed to pump 20% OH excess. Page 29 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 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 (7000’ MD to 1380’ MD) Tail Slurry (7500’ to 7000’ MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.46 ft3/sk 1.22 ft3/sk Mixed Water 14.349 gal/sk 5.507 gal/sk Mixed Fluid 14.469 gal/sk 5.507 gal/sk Additives Code Description Concentration Code Description Concentration G Cement 94#/sk A Cement 94#/sk D110 Retarder 0.15 gal/sk BWOC D046 Anti Foam 0.2 % BWOC D046 Anti Foam 0.2 % BWOC D065 Dispersant 0.4 % BWOC D079 Extender 2.0 % BWOC S002 CaCl2 0.35 % BWOC D020 Extender 3.0 % BWOC D177 CaCl2 0.1 % BWOC 2.46 ft3/s Bump the plug and pressure up to 500 psi over final lift pressure. 1.22 ft3/s Page 30 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 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. Hilcorp may forego installing VBR . gls 11/3/20 Isolated from reservoir at this point. (need to run 5 1/2" tieback still) MIT 5 1/2" x 9 5/8" . 2500 psi Page 31 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 18.0 5-1/2” Liner Tieback Polish Run and Cleanout Run 18.1. PU liner tieback polish mill assy per Baker rep and RIH on drillpipe. 18.2. RIH to top of liner assembly and establish parameters. Polish tieback receptacle per Baker procedure. 18.3. POOH, and LD polish mill. 18.4. PU 5-1/2” 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 5-1/2” pipe rams in BOP stack and test. 18.9. If not completed, test 5-1/2” liner to 2,500 psi and chart for 30 minutes 19.0 5-1/2” Tieback Run 19.1 PU 5-1/2” tieback assembly and RIH with 5-1/2” 17# 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 5-1/2” liner and tieback to 2,500 psi and chart for 30 minutes. 19.6 Test 9-5/8” x 5-1/2” annulus to 2,500 psi and chart for 30 minutes. Test 5-1/2” liner and tieback to 2,500 psi and chart for 30 minutes. (5.5" rams may be installed already) Test 9-5/8” x 5-1/2” annulus to 2,500 psi and chart for 30 minutes. 2500 psi approved on 5.5" casing.. gls Page 32 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 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 (CBL required in 5 1/2" liner) Sundry required for well completion and perforations. Page 33 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 21.0 BOP Schematic VBR BLINDS VBR Page 34 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 22.0 Wellhead Schematic SSV Page 35 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 23.0 Days Vs Depth Page 36 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 24.0 Geo-Prog Page 37 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 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 38 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 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. Pool 6 LCM Pool 6, ensure all LCM inventory is fully stocked before drilling out surface casing. Given the volume of losses experienced in KU 42-12 when drilling through Pp Page 39 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 26.0 Hilcorp Rig 147 Layout Page 40 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 27.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 41 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 28.0 Choke Manifold Schematic RIG 147 Page 42 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 29.0 Casing Design Information Burst SF for 9 5/8" = 5750/1494 = 3.84 (GSL ) Page 43 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 30.0 8-1/2” Hole Section MASP Page 44 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 31.0 Spider Plot (Governmental Sections) Page 45 Version 1 September, 2020 KU 44-08 Drilling Procedure Rev 1 32.0 Surface Plat (As-Built NAD27) !""# $% $%&& -700-350035070010501400175021002450280031503500385042004550True Vertical Depth (700 usft/in)0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 6300 6650Vertical Section at 82.76° (700 usft/in)Pippin wp04 tgt120"9 5/8" x 12 1/4"5 1/2" x 6 3/4"50010001500200025003000350040004500500055006000650070007500KU 44-08 wp06aStart Dir 3º/100' : 300' MD, 300'TVDStart Dir 4º/100' : 500' MD, 499.63'TVDStart Dir 5º/100' : 800' MD, 792.54'TVDEnd Dir : 1644.57' MD, 1433.1' TVDStart Dir 3º/100' : 6532.57' MD, 3860.2'TVDTotal Depth : 7500' MD, 4528.47' TVDP3_A4P3_A11P4_B2P5_B3P5_B4XP5_B4P5_B5Hilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: KU 44-0867.00+N/-S+E/-WNorthingEastingLatittudeLongitude0.00 0.002356295.748275450.195 60° 26' 38.066 N 151° 14' 36.221 WSURVEY PROGRAMDate: 2020-09-15T00:00:00 Validated: Yes Version: Depth FromTool18.00 3_MWD+IFR1+MS+Sag170.00Depth ToSurvey/Plan170.00KU 44-08 wp06a (KU 44-08)7500.00KU 44-08 wp06a (KU 44-08)3_MWD+IFR1+MS+SagFORMATION TOP DETAILSTVDPathTVDssPathMDPathFormation3451.00 3366.00 5708.46 P3_A43943.00 3858.00 6688.38 P3_A114089.00 4004.00 6925.65 P4_B24130.00 4045.00 6986.37 P5_B34206.00 4121.00 7093.87 P5_B4X4231.00 4146.00 7127.98 P5_B44399.00 4314.00 7344.63 P5_B5REFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: KU 44-08, True NorthVertical (TVD) Reference:RKB As-Stake @ 85.00usft (HEC 147)Measured Depth Reference: RKB As-Stake @ 85.00usft (HEC 147)Calculation Method:Minimum CurvatureProject:Kenai Gas FieldSite:KGF 41-18 PadWell:Plan: KU 44-08Wellbore:KU 44-08Design:KU 44-08 wp06aKenai Gas FieldKGF 41-18 PadPlan: KU 44-08KU 44-08KU 44-08 wp06a6.023CASING DETAILSTVD TVDSS MD Size Name98.00 13.00 98.00 20 20"1500.35 1415.35 1780.00 9-5/8 9 5/8" x 12 1/4"4528.47 4443.47 7500.00 5-1/2 5 1/2" x 6 3/4"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 500.00 6.00 82.75 499.63 1.32 10.38 3.00 82.75 10.46 Start Dir 4º/100' : 500' MD, 499.63'TVD4 800.00 18.00 82.75 792.54 9.18 72.14 4.00 0.00 72.72 Start Dir 5º/100' : 800' MD, 792.54'TVD5 1644.57 60.23 82.76 1433.10 74.87 588.82 5.00 0.01 593.56 End Dir : 1644.57' MD, 1433.1' TVD6 6532.57 60.23 82.76 3860.20 609.92 4797.79 0.00 0.00 4836.40 Start Dir 3º/100' : 6532.57' MD, 3860.2'TVD7 6540.18 60.00 82.76 3864.00 610.76 4804.34 3.00 178.98 4843.00 Pippin wp04 tgt18 7500.00 31.21 82.76 4528.47 696.28 5477.53 3.00 180.00 5521.60 Total Depth : 7500' MD, 4528.47' TVD -1600-1200-800-40004008001200160020002400South(-)/North(+) (600 usft/in)0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600West(-)/East(+) (600 usft/in)Pippin wp04 tgt120"9 5/8" x 12 1/4"5 1/2" x 6 3/4"2505 0 0750 1 0 0 0 1 2 5 0 1 5 0 0 1 7 5 0 2 0 0 0 2 2 5 0 2 5 0 0 2 7 5 0 3 0 0 0 3 2 5 0 3 5 0 0 3 7 5 0 4 0 0 0 4 2 5 0 4 5 0 04528 KU 44-08 wp06aStart Dir 3º/100' : 300' MD, 300'TVDStart Dir 4º/100' : 500' MD, 499.63'TVDStart Dir 5º/100' : 800' MD, 792.54'TVDEnd Dir : 1644.57' MD, 1433.1' TVDStart Dir 3º/100' : 6532.57' MD, 3860.2'TVDTotal Depth : 7500' MD, 4528.47' TVDProject: Kenai Gas FieldSite: KGF 41-18 PadWell: Plan: KU 44-08Wellbore: KU 44-08Plan: KU 44-08 wp06aWELL DETAILS: Plan: KU 44-0867.00+N/-S +E/-W NorthingEastingLatittude Longitude0.000.00 2356295.748 275450.195 60° 26' 38.066 N 151° 14' 36.221 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: KU 44-08, True NorthVertical (TVD) Reference:RKB As-Stake @ 85.00usft (HEC 147)Measured Depth Reference:RKB As-Stake @ 85.00usft (HEC 147)Calculation Method:Minimum CurvatureCASING DETAILSTVD TVDSS MD Size Name98.00 13.00 98.00 20 20"1500.35 1415.35 1780.00 9-5/8 9 5/8" x 12 1/4"4528.47 4443.47 7500.00 5-1/2 5 1/2" x 6 3/4" -4670467933140018672333280032673733South(-)/North(+) (700 usft/in)-933 -467 0 467 933 1400 1867 2333 2800 3267 3733 4200 4667 5133West(-)/East(+) (700 usft/in)250500750100012501500175020002250250027503000325035003750400042504500475050005250550057506000625065006750700072507500775080008250850087509000925095009748KBU 32-07 WP1.02505 0 0750100012501500175020002250250027503000325035003750400042504500475050005250550057506000625065006750700072507500775080008183KBU 32-0825050075010001250150017502000225025002750300032503500375040004250450047505000525055005750600062506500675070007250750077508000825085008648KBU 41-18X2505007 5 0100012501500175020002250250027503000 3250350037504000425045004750500052505500575 0600062506500675070007250750077507916KBU 11-17X2505007501000125015001750200022502500275030003250350037504000425045004750500052505 5 0 05750600062506500675070007250750077508000825085008750900092509301KBU 43-07Y2505007501000125015001750200022502500275030003250350037504000425045004750500052505500575060006250650067507000725075007743KBU 14-820"9 5/8" x 12 1/4"5 1/2" x 6 3/4"2505 0 0750 1 0 0 0 1 2 5 0 1 5 0 0 1 7 5 0 2 0 0 0 2 2 5 0 2 5 0 0 2 7 5 0 3 0 0 0 3 2 5 0 3 5 0 0 3 7 5 0 4 0 0 0 4 2 5 0 4 5 0 04528 KU 44-08 wp06aProject: Kenai Gas FieldSite: KGF 41-18 PadWell: Plan: KU 44-08Wellbore: KU 44-08Plan: KU 44-08 wp06aWELL DETAILS: Plan: KU 44-0867.00+N/-S +E/-W NorthingEastingLatittude Longitude0.000.00 2356295.748 275450.195 60° 26' 38.066 N 151° 14' 36.221 W-1000100200South(-)/North(+) (150 usft/in)-200 -100 0 100 200West(-)/East(+) (150 usft/in)2505007501000125015001750200022502500275030003250KBU 32-07 WP1.02505 0 0750100012501500KBU 32-08250500750100012501500175020002250250027503000KBU 41-18X2505007 5 01000125015001750 20002250250027503000KBU 11-17X100012501500KBU 43-07Y2505007501000125015001750200022502500KBU 14-820"2505 0 0 7 5 0 1 0 0 0 KU 44-08 wp06a ' # ( ) " # * +,- * . / / .0)#. 12 !"#"#$ # % &'( #)*+,- -3 . / -0123 0 4 1- *% &'( #)*+,- 4 2 * 5 2# 1 )( $ -.( ' 1 5 )(-.( 67,*+8 #- 0 467,*0 41010- 9 ! $ :5) :: ) % ( ". " 3. ) 4 23 63 $# 03 #) ;: #) #) <( .=>>;/ 7 >'/ 7(/ 7,' (6/6 ( / <7/?>'(60 '<?(665 / / " 3. 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"./&/% "2%& "*%&// "200&%0 &.*""2%&1 )'(-")".+)'(-")".+)'(-")".+ "*&%, *%& "0.&" *.& *"&%"*%& )'(-")".+)'(-")".+)'(-")".+ "*&%, "0&0 "0.&% ",&0 ."&*"."0&01 )'(-")".+)'(-")".+)'(-")".+ "&,/ *& "%&,/ 0,%&- /*&/-*&1 )'(-/)*3)'(-/)*3)'(-/)*3 "%&00 --&00 ""&. --*&.* %%&..0--&001 )'(-/)*3)'(-/)*3)'(-/)*3 "0&". %*%& ""&/- %,"&" --&0%%*%& )'(-/)*3)'(-/)*3)'(-/)*3 0&- "2& %&- "2.&%. /"&""%"2&1 )!"#6% '(/)*)"-4)'(/)*)'(/)*4 "%.&%. /& "%%&-, /& %"&/-/&1 ) '(/)*)"-4)'(/)*)'(/)*4 "%.&*" /%& "%%&-- /*& -.&0"%/%& ) '(/)*)"-4)'(/)*)'(/)*4 *&/, *%& "&" *-0&*/ //&"*%&1 ) *%&'!!#$#'!!#$() 1 *2@1 *2 0A% 0@".& "2*& '(--).0 /564!"!6 ! 7"2*& *2%& '(--).0 /564!"!6 ! 7 8 9 :;)& 9 <&1 9 9 $ &1 = $#> $) ?& 7 << & 9 97689819 : 9 8& 0.001.503.004.50Separation Factor0 450 900 1350 1800 2250 2700 3150 3600 4050 4500 4950 5400 5850 6300 6750 7200 7650Measured DepthNo-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: KU 44-08 NAD 1927 (NADCON CONUS)Alaska Zone 0467.00+N/-S +E/-W Northing EastingLatittudeLongitude0.000.00 2356295.748 275450.195 60° 26' 38.066 N151° 14' 36.221 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: KU 44-08, True NorthVertical (TVD) Reference:RKB As-Stake @ 85.00usft (HEC 147)Measured Depth Reference:RKB As-Stake @ 85.00usft (HEC 147)Calculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-09-15T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool3_MWD+IFR1+MS+Sag18.00170.00KU 44-08 wp06a (KU 44-08)170.007500.00KU 44-08 wp06a (KU 44-08)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 DepthKBU 32-07 WP1.0KBU 32-08KBU 11-17XKBU 14-8GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference18.00 To 7500.00Project: Kenai Gas FieldSite: KGF 41-18 PadWell: Plan: KU 44-08Wellbore: KU 44-08Plan: KU 44-08 wp06aLadder / S.F. PlotsCASING DETAILSTVD TVDSS MD Size Name98.00 13.00 98.00 20 20"1500.35 1415.35 1780.00 9-5/8 9 5/8" x 12 1/4"4528.47 4443.47 7500.00 5-1/2 5 1/2" x 6 3/4" 1 Carlisle, Samantha J (CED) From:Joseph Engel <jengel@hilcorp.com> Sent:Tuesday, November 3, 2020 3:47 PM To:Schwartz, Guy L (CED) Cc:Frank Roach Subject:HAK KU 44-08 (PTD: TBD) Surface Casing Depth Follow Up Flag:Follow up Flag Status:Flagged Guy– IreviewedtheperforationintervalsoftheoffsetKenaiG&IwellswithrespecttothesurfacecasingsetdepthofKU44Ͳ 08. Weareplanningtosetthesurfaceat1780’MD/1500’TVD,whichissimilartothesurfacecasingdepthsoftheG&I wellsalso.TheG&Iperforationintervalsarewellbelow44Ͳ08surfacecasingdepth.Seebelow. Alsobelowisavisualizationofthe3G&Iwellsand44Ͳ08. Letmeknowifyouhaveanyotherquestions. Thankyouforyourtime. ͲJoe 2 Joe Engel | Drilling Engineer | Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 | Anchorage | AK | 99503 Office: 907.777.8395 | Cell: 805.235.6265 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Carlisle, Samantha J (CED) From:Cody Dinger <cdinger@hilcorp.com> Sent:Tuesday, October 6, 2020 8:05 AM To:Boyer, David L (CED); Davies, Stephen F (CED) Subject:KU 44-08 directional plan Attachments:KU 44-08 wp06a_GEO.TXT; KU 44-08 wp06a_GIS.TXT; KU 44-08 wp06a.txt Steve/David, AttachedisthedirectionalplanforKU44Ͳ08,justsentthepermitapplicationtoSamantha. Thankyou! CodyDinger HilcorpAlaska,LLC DrillingTech 907Ͳ777Ͳ8389 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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. X X Sterling Undefined 220-068 KU 44-08 Kenai Gas X WELL PERMIT CHECKLISTCompanyHilcorp Alaska, LLCWell Name:KENAI UNIT 44-08Initial Class/TypeDEV / PENDGeoArea820Unit51120On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2200680KENAI, STERLING UPPER UNDF GAS - 448555NA1 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 sNA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes18 Conductor string providedYes 20" conductor set at 120 ft19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgYes 5 5" liner will be fully cemented. … tieback to surface after cemented.21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes BTC caculation are provided… all meet industry standards.23 Casing designs adequate for C, T, B & permafrostYes Rig has steel pits.. All drilling waste will go to KGF G&I24 Adequate tankage or reserve pitNA grassroots well.25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedNA Diverter is waived per 20 AAC 25.035(h)(2)… several wells on pad.27 If diverter required, does it meet regulationsYes Max form pressure= 1947 ppg (8.3 ppg EMW) will drill with 9-10 ppg mud28 Drilling fluid program schematic & equip list adequateYes Rig 147 has 11" 5000 psi BOPE29 BOPEs, do they meet regulationYes MASP= 1494 psi (will test BOPE tot 3500 psi)30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes Sundry is required to run completion and perforate well.32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableNA34 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]ApprDLBDate10/6/2020ApprGLSDate11/3/2020ApprDLBDate11/3/2020AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJMP11/5/2020dts 11/4/2020JLC 11/4/2020