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221-047
Hilcorp Alaska, LLC Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907/777-8547 September 29, 2023 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Milne Point Conductor Annulus Corrosion Inhibitor Treatments 6/9 to 9/27/2023 Dear Mr. Rixse, Enclosed please a copy of a spreadsheet with a list of thirteen Milne Point wells that were treated with corrosion inhibiting casing filler in the surface casing by conductor annulus. The heavier than water “grease-like” filler displaces water to prevent external casing corrosion that could result in a surface casing leak. The attached spreadsheets include the well names, field, API and PTD numbers, treatment dates and volumes. If you have any additional questions, please contact me at 907-777-8406 or dhorner@hilcorp.com. Sincerely, Darci Horner Regulatory Tech Hilcorp Alaska, LLC Digitally signed by Darci Horner (c-100048) DN: cn=Darci Horner (c-100048) Date: 2023.09.29 09:45:20 - 08'00' Darci Horner (c-100048) Well Field API PTD Initial Top of Cement (ft.) Volume of Cement Pumped (bbls) Final Top of Cement (ft.) Cement Pump Date Corrosion Inhibitor Fill Volume (gal) Final CI Top (ft.) Corrosion Inhibitor Treatment Date Comments MPB-35 MPU 50029237240000 2220850 14' 0 14' N/A 50 surface 9/27/2023 Drilled Sept/Oct 2022. MPB-39 MPU 50029237470000 2230120 1'6" 0 1'6" N/A 10 surface 6/10/2023 Drilled Mar 2023. MPI-20 MPU 50029236790000 2200490 10' 1 1 7/2/2023 5 surface 9/27/2023 Completed Apr 8, 2021. MPI-29 MPU 50029237080000 2220060 6' 0.5 3 7/2/2023 15 surfce 9/27/2023 Drilled in March 2022. Completeted on 4/30/22. MPL-60 MPU 50029236780000 2200480 1' 0 1' N/A 10 surface 6/26/2023 Drilled in 2020. MPL-62 MPU 50029236850000 2200590 1' 0 1' N/A 10 surface 6/26/2023 Drilled in 2020. MPM-13 MPU 50029236380000 2190870 20' 3.5 2' 8/2/2023 10 surface 9/27/2023 Drilled in 2019. MPM-27 MPU 50029237160000 2220490 2' 0 2' N/A 20 surface 6/11/2023 Monobore. Drilled June 2022. MPM-30 MPU 50029237300000 2221180 1' 0 1' N/A 10 surface 6/11/2023 Drilled in Oct 2022. MPM-43 MPU 50029236710000 2200200 1' 0 1' N/A 10 surface 6/11/2023 Drilled in 2020. MPM-62 MPU 50029237440000 2230060 1' 0 1' N/A 10 surface 6/11/2023 Completed May 2023. MPS-45 MPU 50029236930000 2210420 1' 0 1' N/A 10 surface 6/12/2023 Drilled in June 2021. MPS-47 MPU 50029236960000 2210470 4' 0 4' N/A 20 surface 6/12/2023 Drilled in August 2021. Notes: The 4" conductor outlets are any where from 1 to 3' down from the top of the conductor Surface Casing by Conductor Annulus Cement Top Job and Fill Coat Corrosion Inhibitor (CI) Applications Cement to surface means cement is up to the 4" outlets below the wellhead. From the 4" outlets up to the top of conductor was filled with Fill Coat #7 Initial top of cement footage measurement was taken from the 4" outlet down to the TOC RBDMS JSB 100323 MPS-47 MPU 50029236960000 2210470 4'0 4'N/A 20 surface 6/12/2023 Drilled in August 2021. JLC 3/15/2023 RBDMS JSB 032023 1 Regg, James B (OGC) From:Taylor Wellman <twellman@hilcorp.com> Sent:Tuesday, February 28, 2023 12:15 PM To:Rixse, Melvin G (OGC); Regg, James B (OGC) Cc:Alaska NS - Wells Foreman Subject:MPU S-47 (PTD 221-047) CTU #9 BOPE Closure Attachments:RE: [EXTERNAL] RE: CTU #9 Weekly BOPE Test Delay Categories:Blue Category Gentlemen, During the coil tubing operations with CTU #9 on well MPU S‐47 (PTD 221‐047) the BOP’s were actuated to cut the coil tubing and secure the well in order to repair a broken injector. This is the same instance and well that was reported from our Wells Foreman (attached email) but includes the information from Industry Guidance Bulletin 10‐003A. Date, Time of BOPE Use: 02/28/2023, 00:03 Well/Location/PTD Number: MPU, S‐47, PTD 221‐047 Rig Name: CTU #9 Operator Contact: Nick Fraizer, Wells Forman, Hilcorp Alaska, 907‐670‐3330 Operations Summary, including events leading up to BOPE use: The injector for CTU #9 failed yesterday and could not be repaired while in the air. To continue pulling the remaining 1,545’ of coil tubing from the well, the failed injector must be replaced with a new injector. This required the closure of the slip and pipe rams to secure the coil. The well was then killed with produced water. Once the coil was secured and the well was confirmed to have 0 psi, the lower set of blind shear rams were utilized to cut the coil to allow the removal of the failed injector. The upper set of blind shear rams were also closed once the coil had been removed from the BOP. BOPE Used: CTU #9 BOPE, Pipe Rams, Slips and Lower Blind Shear Ram Reason for the BOPE Use: To allow for the well to be secured for the removal of the injector to be repaired. Actions Taken/To Be Taken: From attached email. 1.Install new BOP Stack #2 on top of BOP Stack #1 which is currently on the well 2.Test BOP #2 (anticipate doing this late tonight/early tomorrow morning) 3.Confirm pressures are still at 0psi below BOP #1 4.Load well with KWF if necessary (pending step 3) 5.Make up fishing tools 6.Make up lubricator to BOP #2 7.Open upper set of blind shear rams on BOP #1 8.RIH and latch the coil stub 9.Open slip and pipe rams on BOP #1 10.POH w/coil tubing 11.Secure well. Rig Down CTU #9. Date Used BOPE Retested (if not retested, describe why): Once the coil tubing is removed from the well and well is secured with the tree valves, the used BOPE will be removed and sent to the Schlumberger yard for complete redress and retest. Operations will continue with the next set of BOPE that is in the normal 45 day rotation of BOPE’s as per standard. Thank you and please contact us if additional information is needed, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Milne Point Unit S-47PTD 2210470 jbr 2 Taylor Taylor Wellman Hilcorp Alaska, LLC – Ops Engineer: Milne Point Office: (907) 777‐8449 Cell: (907) 947‐9533 Email: twellman@hilcorp.com 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. DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23696-00-00Well Name/No. MILNE PT UNIT S-47Completion Status1-OILCompletion Date8/20/2021Permit to Drill2210470Operator Hilcorp Alaska, LLCMD13950TVD4092Current Status1-OIL11/30/2021UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:ROP, AGR, ABG, DGR, EWR, ADR MD & TVDNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF8/25/20216300 13912 Electronic Data Set, Filename: MPU S-47 ADR Quadrants All Curves.las35577EDDigital DataDF8/25/2021 Electronic File: MPU S-47 Geosteering End of Well Report.docx35577EDDigital DataDF8/25/2021 Electronic File: MPU S-47 Geosteering End of Well Report.pdf35577EDDigital DataDF8/25/2021 Electronic File: MPU S-47 Geosteering log.emf35577EDDigital DataDF8/25/2021 Electronic File: MPU S-47 Geosteering log.pdf35577EDDigital DataDF8/25/2021 Electronic File: MPU S-47 Geosteering Log150.tif35577EDDigital DataDF8/25/2021 Electronic File: MPU S-47 Geosteering Log300.tif35577EDDigital DataDF8/25/2021 Electronic File: MPU S-47 Post-Well Geosteering X-Section Summary.pdf35577EDDigital DataDF8/25/2021 Electronic File: MPU S-47 Post-Well Geosteering X-Section Summary.pptx35577EDDigital DataDF8/25/2021 Electronic File: MPU_S-47_Geosteering.dlis35577EDDigital DataDF8/25/2021 Electronic File: MPU_S-47_Geosteering.ver35577EDDigital Data0 0 2210470 MILNE PT UNIT S-47 LOG HEADERS35577LogLog Header Scans0 0 2210470 MILNE PT UNIT S-47 PB1 LOG HEADERS35578LogLog Header ScansDF8/25/20216300 12302 Electronic Data Set, Filename: MPU S-47PB1 ADR Quadrants All Curves.las35578EDDigital DataDF8/25/2021 Electronic File: MPU_S-47PB1_Geosteering.dlis35578EDDigital DataDF8/25/2021 Electronic File: MPU_S-47PB1_Geosteering.ver35578EDDigital DataTuesday, November 30, 2021AOGCCPage 1 of 4 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23696-00-00Well Name/No. MILNE PT UNIT S-47Completion Status1-OILCompletion Date8/20/2021Permit to Drill2210470Operator Hilcorp Alaska, LLCMD13950TVD4092Current Status1-OIL11/30/2021UICNoDF8/25/202195 13950 Electronic Data Set, Filename: MPU S-47 LWD FInal.las35579EDDigital DataDF8/25/20216300 13912 Electronic Data Set, Filename: MPU S-47 ADR Quadrants All Curves.las35579EDDigital DataDF8/25/2021 Electronic File: MPU S-47 LWD Final MD.cgm35579EDDigital DataDF8/25/2021 Electronic File: MPU S-47 LWD Final TVD.cgm35579EDDigital DataDF8/25/2021 Electronic File: MPU S-47_Definitive Survey Report.pdf35579EDDigital DataDF8/25/2021 Electronic File: MPU S-47_Definitive Survey Report.txt35579EDDigital DataDF8/25/2021 Electronic File: MPU S-47_GIS.txt35579EDDigital DataDF8/25/2021 Electronic File: MPU S-47_Plan.pdf35579EDDigital DataDF8/25/2021 Electronic File: MPU S-47_Surveys.xlsx35579EDDigital DataDF8/25/2021 Electronic File: MPU S-47_VSec.pdf35579EDDigital DataDF8/25/2021 Electronic File: MPU S-47 LWD Final MD.emf35579EDDigital DataDF8/25/2021 Electronic File: MPU S-47 LWD Final TVD.emf35579EDDigital DataDF8/25/2021 Electronic File: MPU_S-47_Geosteering.dlis35579EDDigital DataDF8/25/2021 Electronic File: MPU_S-47_Geosteering.ver35579EDDigital DataDF8/25/2021 Electronic File: MPU S-47 LWD Final MD.pdf35579EDDigital DataDF8/25/2021 Electronic File: MPU S-47 LWD Final TVD.pdf35579EDDigital DataDF8/25/2021 Electronic File: MPU S-47 LWD Final MD.tif35579EDDigital DataDF8/25/2021 Electronic File: MPU S-47 LWD Final TVD.tif35579EDDigital DataDF8/25/2021 Electronic File: EMFView3_1.zip35579EDDigital DataDF8/25/2021 Electronic File: Readme.txt35579EDDigital Data0 0 2210470 MILNE PT UNIT S-47 LOG HEADERS35579LogLog Header ScansDF8/25/202195 12340 Electronic Data Set, Filename: MPU S-47PB1 LWD FInal.las35580EDDigital DataDF8/25/20216300 12302 Electronic Data Set, Filename: MPU S-47PB1 ADR Quadrants All Curves.las35580EDDigital DataDF8/25/2021 Electronic File: MPU S-47PB1 LWD Final MD.cgm35580EDDigital DataTuesday, November 30, 2021AOGCCPage 2 of 4MPU S-47PB1LWD FInal.lasMPU S-47 LWD FInal.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23696-00-00Well Name/No. MILNE PT UNIT S-47Completion Status1-OILCompletion Date8/20/2021Permit to Drill2210470Operator Hilcorp Alaska, LLCMD13950TVD4092Current Status1-OIL11/30/2021UICNoDF8/25/2021 Electronic File: MPU S-47PB1 LWD Final TVD.cgm35580EDDigital DataDF8/25/2021 Electronic File: MPU S-47PB1_Definitive Survey Report.pdf35580EDDigital DataDF8/25/2021 Electronic File: MPU S-47PB1_Definitive Survey Report.txt35580EDDigital DataDF8/25/2021 Electronic File: MPU S-47PB1_GIS.txt35580EDDigital DataDF8/25/2021 Electronic File: MPU S-47 PB1LWD Final TVD.emf35580EDDigital DataDF8/25/2021 Electronic File: MPU S-47PB1 LWD Final MD.emf35580EDDigital DataDF8/25/2021 Electronic File: MPU_S-47PB1_Geosteering.dlis35580EDDigital DataDF8/25/2021 Electronic File: MPU_S-47PB1_Geosteering.ver35580EDDigital DataDF8/25/2021 Electronic File: MPU S-47PB1 LWD Final MD.pdf35580EDDigital DataDF8/25/2021 Electronic File: MPU S-47PB1 LWD Final TVD.pdf35580EDDigital DataDF8/25/2021 Electronic File: MPU S-47PB1 LWD Final MD.tif35580EDDigital DataDF8/25/2021 Electronic File: MPU S-47PB1 LWD Final TVD.tif35580EDDigital DataDF8/25/2021 Electronic File: EMFView3_1.zip35580EDDigital DataDF8/25/2021 Electronic File: Readme.txt35580EDDigital Data0 0 2210470 MILNE PT UNIT S-47 PB1 LOG HEADERS35580LogLog Header ScansDF10/19/20213500 5239 Electronic Data Set, Filename: MPU_S-47_LDL_22SEP21_down120.las35833EDDigital DataDF10/19/20213498 5238 Electronic Data Set, Filename: MPU_S-47_LDL_22SEP21_down60.las35833EDDigital DataDF10/19/20215232 3496 Electronic Data Set, Filename: MPU_S-47_LDL_22SEP21_static.las35833EDDigital DataDF10/19/2021 Electronic File: MPU_S-47_LDL_22SEP21.pdf35833EDDigital DataDF10/19/2021 Electronic File: MPU_S-47_LDL_22SEP21_img.tiff35833EDDigital Data0 0 2210470 MILNE PT UNIT S-47 LOG HEADERS35833LogLog Header ScansTuesday, November 30, 2021AOGCCPage 3 of 4 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23696-00-00Well Name/No. MILNE PT UNIT S-47Completion Status1-OILCompletion Date8/20/2021Permit to Drill2210470Operator Hilcorp Alaska, LLCMD13950TVD4092Current Status1-OIL11/30/2021UICNoWell 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:8/20/2021Release Date:7/15/2021Tuesday, November 30, 2021AOGCCPage 4 of 4M. Guhl11/30/2021 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 37.8' BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22.Logs Obtained: 23. BOTTOM 20" X-52 110' L-80 2,073' L-80 3,941' 7" L-80 3,933' 4-1/2" L-80 4,092' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 9-5/8"12-1/4" ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, Uncemented TiebackTieback TUBING RECORD Uncemented Screen Liner 6,183'4-1/2" 12.6# L-80 SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 6,163' 13,950' Stg 2 L - 803 sx / T - 270 sx 3,933' 44" 13.5# Surface 2,532' Stg 1 L - 500 sx / T - 400sx 8-1/2" 18.5 yds Concrete STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 8/20/2021 3179' FSL, 692' FEL, Sec. 12, T12N, R10E, UM, AK 2226' FNL, 1578' FEL, Sec. 12, T12N, R10E, UM, AK 221-047 Milne Point Field / Schrader Bluff Oil Pool 64.58' 13,948' / 4,092' HOLE SIZE AMOUNT PULLED 50-029-23696-00-00 MPU S-47 565320 5999842 1476' FSL, 1358' FWL, Sec. 12, T12N, R10E, UM, AK CEMENTING RECORD 5998112 SETTING DEPTH TVD 6004945 BOTTOM TOP Surface Surface CASING WT. PER FT.GRADE 26# 562105 559109 TOP SETTING DEPTH MD Surface Surface Per 20 AAC 25.283 (i)(2) attach electronic information 40# 6,170' 2,073' Surface DEPTH SET (MD) 5,164' / 3,723' PACKER SET (MD/TVD) 129.5# 47# 110' 2,532' 6,330' Gas-Oil Ratio:Choke Size:Water-Bbl: PRODUCTION TEST Not on Production Date of Test: Flow Tubing Oil-Bbl: suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A ***Please see Schematic for Details*** ROP, AGR, ABG, DGR, EWR, ADR MD & TVD Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 8/15/2021 8/2/2021 ADL 380109 01-001 2,172' / 1,816' N/AN/A None 13,950' / 4,092' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 11:19 am, Oct 21, 2021 RBDMS HEW 9/2/2021 Completion Date 8/20/2021 HEW GMGR21OCT2021SFD 10/25/2021 DSR-10/21/21 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD 40' 40' 2212' 1856' Top of Productive Interval 6236' 3938' 1615' 1447' 2644' 2148' 4627' 3460' 6047' 3922' 6236' 3938' 10789' 3956' 11235' 4016' 11515' 4045' 11735' 4062' 11991' 4085' SB NB 11991' 4085' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Joe Lastufka Contact Email:joseph.lastufka@hilcorp.com Authorized Contact Phone: 777-8400 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Schrader Bluff NB Schrader Bluff NC Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top Schrader Bluff NA SV 5 SV 1 This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Schrader Bluff OA Formation at total depth: Ugnu LA3 LOT / FIT Data Sheet, Drilling and Completion Reports, Definitive Directional Surveys, Wellbore Schematic Signature w/Date: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. INSTRUCTIONS The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Schrader Bluff NA (Fault) Schrader Bluff NB Schrader Bluff NF Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 10.21.2021Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.10.21 08:30:50 -08'00' Monty M Myers _____________________________________________________________________________________ Revised By: JNL 9/2/2021 SCHEMATIC Milne Point Unit Well: MPU S-47 Last Completed: 8/20/2021 PTD: 50-029-23696-00-00 Plugback Detail KOP: 11,900’ MD / 4,076’ TVD TD: 12,340’ MD / 4,059’ TVD GENERAL WELL INFO API: 50-029-23696-00-00 Completion Date: 8/20/2021 TD =13,950’(MD) / TD =4,092’ (TVD) 5 20” Orig. KB Elev.: 64.58’ / GL Elev.: 37.8’ 7” 4 11 9-5/8” 1 2 3 See Screen Liner Detail PBTD =13,948’(MD) / PBTD = 4,092’ (TVD) 9-5/8” ‘ES’ Cementer @ 2,390’ 4-1/2” Shoe @ 13,948’ 9 10 6 8 7 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 129.5 / X52 / Weld N/A Surface 110’ N/A 9-5/8" Surface 47/ L-80 / TXP 8.681 Surface 2,532’ 0.0732 9-5/8” Surface 40 / L-80 / TXP 8.835 2,532’ 6,330’ 0.0758 7” Tieback 26 / L-80 / TXP 6.276 Surface 6,170’ 0.0383 4-1/2” Liner 13.5 / L-80 / Hyd 625 3.920 6,163’ 13,950’ 0.0149 TUBING DETAIL 4-1/2" Tubing 12.6# / L-80 / H521 3.958 Surface 6,183’ 0.0152 OPEN HOLE / CEMENT DETAIL 44” 18.5 yards concrete 12-1/4"Stg 1 – Lead – 500 sx / Tail – 400 sx Stg 2 – Lead – 803 sx / Tail – 270 sx 8-1/2” Cementless Screen Liner WELL INCLINATION DETAIL KOP @ 300’ 90° Hole Angle = @ 6100’ MD TREE & WELLHEAD Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing Wellhead FMC 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs JEWELRY DETAIL No. Top MD Item ID 1 22’ 11” x 4-1/2” TCII Tubing Hanger 3.958” 2 5,091’ Baker Gauge Carrier 3.958” 3 5,098’ Haliburton X-Line Sliding Sleeve (opens down) 3.958” 4 5,104’ Baker Ported Sub 3.958” 5 5,164’ Baker Premier Packer 3.860” 6 5,236’ XN Nipple, 3.813” Packing Bore, 3.725” No Go 3.725” 7 6,153’ WLEG – Bottom @ 6,183’ 3.958” 8 6,160’ Bullet Seals (TBSA), Mule Shoe (4-1” Holes) 6.180” 9 6,163’ SLZXP Liner Top Packer (3,933’ TVD) 6.160” 10 6,184’ 7” H563 x 4.5” TSH 625 XO 3.800” 11 13,948’ Shoe 4-1/2” LINER 250ђ SCREEN DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 104 6354’ 3941’ 10688’ 3943’ 33 11956’ 4081’ 13329’ 4075’ 9 13535’ 4080’ 13908’ 4092’ TD: 12,340’ MD / 4,059’ TVD KOP: 11,900’ MD / 4,076’ TVD CASING AND LEAK-OFF FRACTURE TESTS Well Name:MPU S-47 Date:8/10/2021 Csg Size/Wt/Grade: 9.625 40#/47# L-80 Supervisor:B Anderson / O Amend Csg Setting Depth:6,325 3,939 TVD Mud Weight:9.05 ppg LOT / FIT Press =604 psi LOT / FIT =12.00 ppg Hole Depth =6330 md Fluid Pumped=1.0 Bbls Volume Back =0.5 bbls Estimated Pump Output:0.062 Barrels/Stroke LOT / FIT DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here ->219 ->035 ->441 ->8136 ->692 ->16 322 ->8163 ->24 503 ->10 239 ->32 716 ->12 314 ->40 976 ->14 385 ->48 1248 ->16 440 ->56 1536 ->18 504 ->64 1814 ->20 554 ->72 2105 ->22 614 ->80 2403 ->24 ->84 2552 ->26 ->86 2625 ->28 -> Enter Holding Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here ->0606 ->02625 ->1569 ->52593 ->2552 ->10 2586 ->3539 ->15 2580 ->4530 ->20 2576 ->5522 ->25 2573 ->6515 ->30 2573 ->7509 -> ->8502 -> ->9497 -> ->10 490 -> -> -> -> -> -> -> 2 4 6 8 10 12 1416 1820 22 0 8 16 24 32 40 48 56 64 72 80 84 86 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 0 102030405060708090100Pressure (psi)Strokes (# of) LOT / FIT DATA CASING TEST DATA 606569552539530522515509502497490 2625 2593 2586 2580 2576 2573 2573 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 0 5 10 15 20 25 30Pressure (psi)Time (Minutes) LOT / FIT DATA CASING TEST DATA Activity Date Ops Summary 8/1/2021 PJSM. Rig down on MPU S-46. Bridle up, unplug derrick lights, remove derrick pins and scope down derrick. PJSM. Blow down water and rig down inner-connects. Pick up exterior stairs, move cuttings box, unplug electrical plug boards, move brake trailer and enviro-vac. Jack up gen and pipe shed mods. Hook up trucks and begin separating mods. Separate gen mod and remove back tires. Move pit mod, pipe shed and cattle chute. Begin walking sub off of MPU S-46. Walk sub off of MPU S-46 over to MPU S-47 and set. Spot and set cattle chute, pipe shed, mud mod and gen mod. Finish changing out rear tires (8) on gen mod. Replace drag chain bearings. Set diverter T on S-47 and stage wellhead equipment behind well. Pull mats from around S-46. Spot and set break trailer and enviro-vac. Spot Beyond choke. Set cuttings tank. Plug in and swap from cold starts to gen power at 21:00 hrs. Set stairs, landings and walkways. Hook up inner-connects. Scope up cattle chute and bring air system online. Scope up derrick and bridle down. Continue to work on drag chain bearings. Begin working on rig acceptance checklist. Work on rig acceptance checklist. Set stack on diverter T, install bolts and line up. Torque all flanges. Install bell nipple, knife valve and diverter line and torque up all flanges. SIMOPS: continue to work on drag chain bearings. finish up stuffing boxes and clamps on Mud Pump #2. 8/2/2021 Continue to work rig acceptance checklist. Finish tq bell nipple, knife valve and diverter line. C/O psi switch on TDS. Continue to work on drag chain bearings. Function test Mud Pump #1 and #2. G/L = 26.78'. Annular = 11.60' C/O saver sub, install and function test hyd elevators, TDS (good). Finish welding in pits. Install mousehole and close annular with 500 psi. Perform walkthrough. Rig accepted @ 10:00 hrs 8/2/2021. Prep pipeshed. PJSM, M/U and rack back 98 stds 5" NC50, 19.5# S-135 drill pipe. M/U and rack back w/ jars 9 stds of 5" NC50 HWDP 49.3#, S-135. Weld up baffles in hotwell tank for boilers. Sim Ops - Dress shakers, prep pits for surface. Load 290 bbls spud mud in pits. Tag on last stand @ 53' Perform Diverter test w/ 5" DP. Annular closed = 9 sec, Knife open = 5 sec, Koomey drawdown - Initial = 3000, Drawdown = 2000 psi, 200 psi inc = 17 sec, Full charge = 52 sec. Witness waived by AOGCC rep Guy Cook. Test gas alarms and pit sensors. Cut & Slip drill line. PJSM. MU jt of pipe and hang blocks. Cut and slip 11 wraps (69') of drill line. Check drawworks brakes. Torque deadman mounting bolts (225 ft-lbs) and deadman clamp bolts (80 ft-lbs). Service top drive, blocks, crown, IBOP, spinners, iron roughneck and rig floor equipment. Check oil level in TD and extend frame welds. PJSM for making up BHA. Mobilize 3rd party tools to rig floor. rig up tongs for making up 12-1/4" cleanout assembly. Make up 12-1/4" Kymera bit, 1.5° motor, XO and stand of 5" HWDP per DD. PJSM. Fill surface equipment, lines, and stack with water. Verify no leaks. Verify bull plug on divert line is out and no leaks. Pressure test surface equipment and lines to 3000 psi and verify no leaks. Wash down and tag ice plug at 55' MD. Wash through plug and continue to bottom at 400 gpm, 200 psi. Tag bottom of conductor at 107' MD from rig floor. Drill ahead F/ 107' - T/ 220' MD per DD. 450 gpm, 540 psi, 40 rpm, 1.6k Tor, 3-6k WOB, 70% R/F, 43k up, 43k dn, 43k rot. Pull out of the hole F/200' MD to surface with 12-1/2" cleanout assembly, racking back 3 stands of 5" HWDP. Make up lift sub, pick up and inspect bit - good. PJSM. Make up 12-1/2" drilling assembly with smart tools per DD / MWD / GYRO. Pick up GWD, DM, EWR-M5, top stabilizer and TM collar. Obtain rig floor offsets. Upload to MWD tools per MWD. Make up (2) Non-mag flex collars, and XO to HWDP per DD / MWD / GYRO. Continue drilling per DD F/ 220' - T/ 278' MD: 450 GPM, 990 psi, 8k WOB, 40 RPM, 2k Tq on, 1k Tq off, 72% R/F, 53 up, 53 dn, 53 rot. Daily disposal to G&I: 114 bbl. Total disposal to G&I: 114 bbl. Daily H2O from A-Pad 630. Total H2O from A-Pad: 630. Daily H2O from S-Pad Creek: 0 bbl. Total H2O from S-Pad Creek: 0 bbl. Daily Metal: 0 lbs. Total Metal: 0 lbs. Daily Fluid Loss: 0 bbl. Total Fluid Loss Surface: 0 bbl. 8/3/2021 Continue slide drilling 12-1/4" surface F/ 278' - T/ 774' MD (766' TVD). 496' total = 83' AROP. 450 GPM, 1240 psi, 8-14k WOB, 40-60 RPM, 3k Tq on, 1k Tq off, 72% R/F, 71 up, 70 dn, 70 rot. KOP @ 220' MD, Clean MWD svy's @ 658' MD. Mode switch MWD / Shut off GWD. 8.8 MW w/ 285 vis. Continue slide drilling 12- 1/4" surface F/774' - T/ 1365' MD (1272' TVD). 591' total = 99' AROP. 450 GPM, 1420 psi, 8-14k WOB, 60 RPM, 5k Tq on, 4k Tq off, 75% R/F, 81 up, 76 dn, 77 rot. Relax vis to ~160-200. B/R full stands. Continue drill as per WP08. Continue slide drilling 12-1/4" surface F/ 1365' - T/ 1918' MD (1652' TVD). 553' total = 92.2' AROP. 475 GPM, 1560 psi, 5-15k WOB, 60 RPM, 7.5k Tq on, 5k Tq off, 80% R/F, 91 up, 69 dn, 78 rot. 9.1 ppg MW, 177 Vis. B/R full stands. Continue drill as per WP08. Continue drilling 12-1/4" surface F/ 1918' - T/ 2550' MD (2084' TVD) per WP08. 632' total = 105.3' AROP. 475 GPM, 1440 psi, 1-6k WOB, 60 RPM, 5-6k Tq on, 5k Tq off, 80% R/F, 106 up, 73 dn, 87 rot. 9.1 ppg MW, 10.1 ppg ECD, Max gas 259u, B/R full stands. Base Permafrost at 2211' MD (1856' TVD). Daily drilling hours: 12.47 - 7.10 Sliding hours, 5.37 Rotating hours. Distance from WP08: Total 8.13', 7.17' High, 3.84'. Right. Daily disposal to G&I: 1083 bbl. Total disposal to G&I: 1197 bbl. Daily H2O from A-Pad 1060. Total H2O from A-Pad: 1690. Daily H2O from S-Pad Creek: 0 bbl. Total H2O from S-Pad Creek: 0 bbl. Daily Metal: 0 lbs. Total Metal: 0 lbs. Daily Fluid Loss: 0 bbl. Total Fluid Loss Surface: 0 bbl. Total Fluid Loss Production: 0 bbl. 8/4/2021 Continue drilling 12-1/4" surface F/ 2550' - T/ 3125' MD (2472' TVD) per WP08. 575' total = 115' AROP. 500 GPM, 1590 psi, 4-10k WOB, 80 RPM, 6-7k Tq on, 5-6k Tq off, 57% R/F, 111 up, 73 dn, 92 rot. 9.1 ppg MW, 10.3 ppg ECD, Max gas 309u, B/R full stands. Change out liner, swab and wear plate on Mud Pump #1, Pod #3 Slide/ Rot 12.25" Surface Hole F/ 3,125' to 3,800' MD (2,935' TVD) Total 675’ (AROP 112.5’) 500 GPM, 1,630 psi 80 RPM, TRQ on 9-10k, TRQ off 8k, F/O 66%, WOB 5-15k. ECD 9.9. Max Gas 176u. P/U 128K, SLK 83K, ROT 102K. Back ream full stand. Start directional 4°/100 at 3825' MD. Slide/ Rot 12.25" Surface Hole F/ 3,800' to 4,310' MD (3,271' TVD) Total 510’ (AROP 85’) 500 GPM, 1,675 psi 80 RPM, TRQ on 10-12k, TRQ off 9k, F/O 57%, W OB 5-15k. ECD 9.9. Max Gas 85u. P/U 138K, SLK 86K, ROT 105K. Back ream full stand. Cont directional 4°/100. Slide/ Rot 12.25" Surface Hole F/ 4,310' to 4,778' MD (3,542' TVD) Total 468’ (AROP 78’) 500 GPM, 1,760 psi 80 RPM, TRQ on 10-12k, TRQ off 10k, F/O 59%, WOB 7-15k. ECD 10.1. Max Gas 230u. P/U 148K, SLK 85K, ROT 110K. Back ream full stand. Cont directional 4°/100. Distance to WP08: 7.14', 1.46' High, 6.99' Low. ROT Hrs: 7.36. SLD Hrs: 5.15. Daily disposal to G&I: 1026 bbl. Total disposal to G&I: 2223 bbl. Daily H2O from A-Pad 1140 bbl. Total H2O from A-Pad: 2830 bbl. Daily Metal: 0 lbs. Total Metal: 0 lbs. Daily Fluid Loss: 0 bbl. Total Fluid Loss Surface: 0 bbl. 8/5/2021 Slide/ Rot 12.25"" Surface Hole F/ 4,778' to 5158' MD (3,721' TVD) Total 380’ (AROP 63.3’) 500 GPM, 1,860 psi, 80 RPM, TRQ on 7-15k, TRQ off 11k, F/O 61%, WOB 7-15k. ECD 9.9. Max Gas 364u. P/U 154K, SLK 88K, ROT 111K. Back ream full stand.. Cont directional 4°/100." Went to Gen power 11:30 Slide/ Rot 12.25" Surface Hole F/ 5,158' to 5,600' MD (3,858' TVD) Total 442’ (AROP 73.7’) 500 GPM, 1,630 psi 80 RPM, TRQ on 13.5k, TRQ off 12.5k, F/O 63%, WOB 5-15k. ECD 9.9. Max Gas 420u. P/U 154K, SLK 86K, ROT 111K. Back ream full stand. Cont directional 4°/100. Back on High line power 13:30 Slide/ Rot 12.25" Surface Hole F/ 5,600' to 5,895' MD (3,918' TVD) Total 295’ (AROP 64.2’) 500 GPM, 1,780 psi 80 RPM, TRQ on 15-17k, TRQ off 13k, F/O 62%, WOB 5-15k. ECD 9.9. Max Gas 439u. P/U 158K, SLK 82K, ROT 109K. Back ream full stand.. End directional 4°/100 5,647' MD. Pump tangent F/ 5,647' to 5,810' MD. Cont directional 4°/100 F/ 5,810' MD. Slide/ Rot 12.25" Surface Hole F/ 5,895' to TD 6,330' MD (3,939' TVD) Total 435’ (AROP 72.5’) 500 GPM, 1,710 psi 60-80 RPM, TRQ on 15-17k, TRQ off 13-16k, F/O 61%, WOB 9-21k. ECD 10.1. Max Gas 280u. P/U 158K, SLK 77K, ROT 108K. Back ream full stand. Perform final survey. Close approach S-24 CC 30.97' at 6,060' MD. Distance to WP08: 24.6', 23.44' Low, 7.49' Left. ROT Hrs: 5.91. SLD Hrs: 8.88 Daily disposal to G&I: 1373 bbl. Total disposal to G&I: 3596 bbl. Daily H2O from A-Pad 2370 bbl. Total H2O from A-Pad: 4200 bbl. Daily Metal: 0 lbs. Total Metal: 0 lbs. Daily Fluid Loss: 0 bbl. Total Fluid Loss Surface: 0 bbl. 8/2/2021Spud Date: Well Name: Field: County/State: MP S-47 Milne Point Hilcorp Energy Company Composite Report , Alaska 50-029-23696-00-00API #: 8/6/2021 Circulate hole clean at TD. Backream F/6330' - T/ 6178' MD, racking back a stand at each bottoms up. Pump total of 2x bottoms up. 500 gpm, 1625 psi, 60 rpm, 14- 15k Tq, Pump nut plug sweep at 6178' MD, reciprocating 68' T/ 6110' MD. 500 gpm, 1550 psi, Sweep back on time w/ 10% increase in returns. Monitor well for 10 min: static. Run in the hole on elevators to TD at 6330' MD - no fill on bottom. Backream out of the hole F/ 6330' MD - T/ 5,300' MD. 500 gpm 1650 psi 60 rpm trq 12k. Max gas 13u. f/o 55%. Pull speed 40 ft/min or as hole dictates. pu 161k slk 96k rot 113k. Lost 8 bbls PJSM BROOH F/ 5,300' to 1,900' MD. 500 gpm 1650 psi 60 rpm trq 12k max gas 79u. F/O 55%. Pull speed 40 ft/min or as hole dictates. P/U 161k SLK 96k ROT 113k. Obtain BU two stands prior to permafrost at 2,211' MD 1,856' TVD. Hole did not unload. BROOH F/ 1,900' to 664' MD. 500 gpm 1050 psi 60 rpm trq 5k max gas 38u. F/O 55%. Pull speed 40 ft/min or as hole dictates. P/U 72k SLK 63k ROT 68k. Cont BROOH F/ 664’ to 342’ MD 375 gpm 550-700 psi 35 rpm trq 2-9.5k torque limiter set at 9.5k. Pull speed 2-15 ft/min as hole dictates. Encountered moderate gravel with no packing off observed and intermittent torque stalls. Rack back 5" HWDP & Jars. Lost 12 bbls for trip. POOH on elevators F/ 342’ L/D BHA. L/D NM FC, Down load MWD. Cont L/D BHA Top Stab showed excessive wear on bit side. L/D TM, (slight wear) EWR, DM, GWD. Well static. PJSM Cont L/D 1.5° Motor and 12.25" Hybrid K5M633 Bit. PDC Grade 2-3-WT-T-X-1-CT-TD. Cone Grade 1-1-NO- A -F--1-NO-TD Clean and clean rig floor of X/O's, DM and 12.25" bit. R/D 5" Hydraulic elevators and jet flow line. PJSM R/U Weatherford 9.625" handling Equip, power tongs, bail ext, 9.625" elevators and Volant. PJSM P/U M/U Baker Loc 9.625" shoe track, drop bypass valve as per Halliburton Rep. Check Floats, good. RIH 9.625" 40# TCP BTC Csg installing centralizers as per tally to 1,396' MD. Use Best O Life Trq 23k. Fill every 5 jnts top off every 10. Running Speed 40-60 ft/min. P/U 74k SLK 63k. Lost 12 bbl Daily disposal to G&I: 803 bbl. Total disposal to G&I: 4399 bbl. Daily H2O from A-Pad 900 bbl. Total H2O from A-Pad: 5100 bbl. Daily Metal: 0 lbs. Total Metal: 0 lbs. Daily Fluid Loss: 20 bbl. Total Fluid Loss Surface: 20 bbl. 8/7/2021 Continue to run in the hole with 9-5/8, 40#/47#, L-80 TXP BTC surface casing per tally. Tag on depth at 6330' MD, 4' in on Jt #166. Pick up to planned setting depth on 6325' MD and lay down jt #166. 330k up, 90k dn. Ran 95 jts of 40#, 61 jts of 47#, 82 Centralizers. Lost 15 bbls. Establish Circ stage up F/ 2 bpm to 6 bpm 250 psi Rot Rec 6,328' to 6,281' MD. Set Trq stall 15k 1-2 rpm while moving pipe. Cond mud. P/U 330k SLK 90k. SIMOPS L/D Weatherford power tongs, remove bail ext and elevators. No losses observed. PJSM Shut down pumps monitor well for 30 min, static. Remove 20' section of 16" Diverter line and let Halliburton cementers pass. Install 20' section diverter. Well static. Est Rot/ Rec 6,328' to 6,281' MD without issue. Stage up 2-6 bpm 125 psi. Trq stall set 15k 1-2 rpm while moving. SIMOPS Halliburton R/U Equip. Prep pits for cement job. Dynamic loss 1-3 bph. PJSM Shut down. Break out of Volant to check connection. Blow down top drive. R/U cement line to Volant. Clean out gravel F/ possum belly for over board line. R/U H2O to cementers. Rot/ Rec 6,328' to 6,281' MD circ 6 bpm 360 psi through cement line. Prime cementers W/ H2O. R/U data cable for Halliburton computer in dog house. PJSM W/ all personnel for cement job. Halliburton prime lines W/ H2O and attempt to PT. Trouble shoot lines and rig floor valves. Halliburton replaced pop off valve and retest, fail. Found 6 bad valve rubbers in Halliburton pump F/ previous acid job. Cont Rot/ Rec 6,328' to 6,281' MD circ 6 bpm 360 Halliburton replaced rubbers on pump valves due to previous acid job. Cont Rot/ Rec 6,328' to 6,281' MD circ 6 bpm 360 psi. PJSM, Wet lines w/ 5 bbls H2O (HES) and P/T low kick out 911 low/ 4,190 high. Rot & Rec F/ 6,328' to 6,281' 1-2 RPM Trq stall set at 15K, Rot while moving. Pump 1st stage cement job as follows: 52 bbls 10 ppg Tuned spacer w/ 4# red dye & 5 lb/bbl poly flake (1st 10 bbls) 1.8 bpm, 80 psi. Drop bypass plug. Mix and pump 209 bbls 12# lead cement. Pump 82 bbls 15.8# tail cement. Drop shutoff plug. Displace w/ 20 bbls H2O (HES) 5 bpm 267 psi then turn over to rig. Rig disp w/ 258.5 bbls 9.5 ppg spud mud, 7 bpm, ICP 361 psi for 150 bbls away, reduced rate to 6 bpm ICP 374 psi, FCP 270 psi. Stop Rot & Rec string 150 bbls into displacement, set at 6,325’ MD W/ 270K string WT. HES disp 80 bbls 9.4 ppg spacer, 5 bpm 280 psi. Rig disp 105 bbls 9.5# spud mud 6 bpm, ICP 588 psi FCP 833 psi. Reduced rate last 20 bbls to 3 bpm, FCP 681 PSI. Attempt to bump plug at 04:50. Press up to 1200 PSI with 471.9 bbls actual / 463.5 bbls calculated leaving 1 bbl in shoe track. Pressure bled down to 680 psi in 2 min, attempt to bump plug again at 3 bpm 1,239 psi. Pressure bled down F/ 1,239 psi to 134 psi over 12 min. Bleed off pressure and check floats, appear to be holding. Attempted to seat plug again at 3 bpm to 1,500 psi observed flow from well. Discission was made to drop free falling open plug to ES. Lost 8 bbls for cement job. Daily disposal to G&I: 765 bbl. Total disposal to G&I: 5164 bbl. Daily H2O from A-Pad 100 bbl. Total H2O from A-Pad: 5200 bbl. Daily Metal: 0 lbs. Total Metal: 0 lbs. Daily Fluid Loss: 93 bbl. Total Fluid Loss Surface: 113 bbl. 8/8/2021 Free fall plug landed on ES W/O issue. Pump .5 bpm caught pressure right away. Cont press up to 720 psi shifting ES open. Stage pumps up to 6 bpm 400 psi 350 bbls (2.33X Calc BU) into Circ saw poly flake and contaminated mud at surface. Reduced rate 2 bpm dumping over board. Staged pumps back up to 6 bpm 350 psi. After 5 BU shut down disconnect koomey lines from knife valve and flush stack W/ black H2O. stage pumps back up to 6 bpm 350 psi. Cont circ WOC. Cont Circ through ES' 6 bpm 310 psi R/F 43%. WOC No losses. PJSM, Wet lines w/ 5 bbls H2O (HES) Pump 2nd stage cement job as follows: 60 bbls 10 ppg Tuned spacer w/ 4# red dye & 5 lb/bbl poly flake (1st 10 bbls). ArticCem 412 bbls 10.7 ppg Lead cmt, 2.883 yld, (803 sx) 4.6 bpm, 412 psi. 180 bbls into cement saw poly flak at shaker. At 264 bbls into cement saw spacer at shakers. At 390 bbls into cement saw 10.55 ppg cement at shakers. Total lead 412 bbls (10.7 ppg). Pump Premium G cement 58 bbls 15.8 ppg Tail cmt, 1.17 yld, (270 sx) 4.4 bpm, 531 psi. Drop closing plug. Displace w/ 20 bbls H2O (HES) 6.3 bpm 443 psi then turn over to rig. Rig disp w/ 156.5 bbls / Calc 155.3 bbls 9.5 ppg spud mud, 7 bpm ICP 310 psi FCP 667 psi, reduce rate 6 bpm 140 bbls away 654 psi. Reduced rate last 15 bbls to 3 bpm, ICP 475 psi FCP 480 PSI. ES Cementer shifted shut at 1,300 PSI. Held 1,846 psi for 5 minutes, check plug - good. CIP 19:27 hrs. Lost 21 bbls during cement job. Dumped 333 bbls of green cement. PJSM Unsting Volant and blow down cement lines. Install 9.625" elevators. Remove bushing. PJSM Drain stack and flush W/ black H2O 3X working Annular. Remove mouse hole. Flush cement line W/ black H2O. Break Diverter line by cutting box and in cellar. Hook up bridge cranes , remove stack chains. Leave Diverter Tee and starter head 4 bolted. Remove air in flow box boot. Lift stack, center 9.625" csg in conductor as per NOS reps onsite. Suck out 9.625" landing joint. Set emergency slips W/ 120k. Cut 9.625" csg. (28.71') Set stack off to side and dress 9.625" csg as per NOS. L/D old test plug. P/U split bushings. L/D master bushings. Remove conductor 4" valves and cap. PJSM 4 bolt diverter Tee. Install trip nipple and johnny whack stack W/ black H2O. Drain stack and pull trip nipple. Rack back stack to pedestal. Send out Diverter Tee and speed head. Pull bell nipple F/ stack and install RCD head. PJSM Install slip lock well head and trq to engage seals as per NOS Rep onsite. PT seal 500 psi low 5 min, 3,800 psi high 15 min. Orientate and install tubing spool as per NOS rep. Install test plug. Daily disposal to G&I: 1901 bbl. Total disposal to G&I: 7065 bbl. Daily H2O F/ A-Pad 640 bbl. Total H2O A-Pad: 5840 bbl. Daily H2O F/ S-Pad: 740 bbl. Total H2O S-Pad: 740 bbl. Daily Metal: 0 lbs. Total Metal: 0 lbs. Daily Fluid Loss: 29 bbl. Total Fluid Loss Surface: 142 bbl. 8/9/2021 PJSM. Install DSA and set stack on wellhead. Torque all flanges and install turnbuckles. Install drip pan and beyond MPD 4" hardline. Rig up choke and kill lines, drain hoses and hole fill lines. Install Koomy lines and energize Koomy. SIMOPS: Continue to clean pits and replace drag chain bearing. RKBS: LL - 24.25', ULD - 21.60', LPR - 19.59', Blinds - 16.4', UPR - 14.65', Annular - 12.50' PJSM Fill and pump through MPD lines. PT 250/ 1,300 psi, good. Bleed off and pull test cap. PJSM Center BOP and install trip nipple. Tighten chain binders and install mouse hole. PJSM P/U M/U 5" test jnt, 2 ea 5" TIW, 5" Dart & side entry. Flodd surface lines and purge air. Attempt shell test, Mezz kill failed. Greased and rested good. SIMOPS take on 290 bbls 8.9 ppg BaradrilN to pits. PJSM Perform BOPE test W/ 5" & 4.5" to 250 PSI low and 3,000 PSI high for 5 Min. Tested Choke Manifold 1-15, 5" Dart, 2 ea 5" TIW, Upper and lower IBOP, Mez Kill (F/P), HCR and manual Choke and Kill, Super Choke and manual to 1,600 PSI, Upper and lower VRB Rams (2.875" X 5.5") Blind Rams & Annular. Test H2S 10-20 ppm, LEL 20-40%, PVT high/ low level alarms. Checked PVT sensors and return flow. Koomey draw drown Initial System 3,000 PSI, Manifold 1,450 PSI, Annular 1,350 PSI, after System 1,500 PSI, Man 1,550 PSI, Annular 1,490 PSI. 200 PSI increase 25 Sec, full charge 91 sec. Nitrogen 6 bottle average 2,304 PSI. Witnessed by AOGCC Lou Laubenstien. F/P Mezz Kill rebuilt valve W/ now O Rings and wear plate. PJSM Break down TIW, Dart, side entry and top drive test sub. Blow down choke manifold and kill line. PJSM Remove test plug and install wear bushing (38" Ln X 10.75" OD X 9" ID) RILDS 4 ea. PJSM P/U M/.U RR 8.5" XR-CPS Tricone (TFA 0.9419) (Grade 1-1-WT-A-E-I-NO) 6.75" StrataForce Lobe 6.7-6 stg 1.5° Motor as per DD. Cont RIH 5" HWDP and 6.5" HydraJar to 587.81' MD. PJSM Cont single in hole W/ 5" 19.5# S-135 NC50 F/ 587.81' to 2,367'' MD. Drift F/ Skate 3.125" OD. Overboard all returns. P/U 93k SLK 69k Wash down F/ 2367' to tag ES plug at 2,395.5' MD W/ 2 k, 410 gpm, 700 psi. Drill Plug F/ 2,395.5' to 2,396' MD 410 gpm 700 psi 50 rpm Trq 5k WOB 2k. Over board clabber mud at BU. See black rubber at shakers. P/U 96k SLK 69k ROT 81k PJSM Cont drill ES F/ 2,396' to 2,397.5' MD 400-450 gpm 675 psi 50 rpm Trq 4-5k WOB 2k. Seeing black and red rubber at shakers. Ream down to 2,431' MD., ream through ES 2X and W/O pumps or rotation, no issues or drag. P/U 100k SLK 72k ROT 81k PJSM Cont single in hole W/ 5" 19.5# S-135 NC50 F/ 2,431' to 6,151'' MD. Drift F/ Skate 3.125" OD. Overboard all returns. P/U 160k SLK 70k Wash and ream F/ 6,151' to 6,170' MD 3 bpm 475 psi at 6,170' MD no ROT saw Press spike. Increased rate to 450 gpm 1,190 psi 40 rpm Trq 12-14k reamed down 6,170' to 6,183' MD W/ 4-5k WOB. P/U 160k SLK 70k ROT 102k Rot Rec F/ 6,175 to 6,115' MD CBU 450 gpm, 825 psi 40 rpm Trq 14-15k. Dumping and treating clabbered up mud. Daily disposal to G&I: 437 bbl. Total disposal to G&I: 7502 bbl. Daily H2O F/ A-Pad 260 bbl. Total H2O A-Pad: 61000 bbl. Daily H2O F/ S-Pad: 0 bbl. Total H2O S-Pad: 740 bbl. Daily Metal: 0 lbs. Total Metal: 0 lbs. Daily Fluid Loss: 0 bbl. Total Production loss: 0 bbl. Total Surface loss: 142 bbl. 8/10/2021 Pressure test 9-5/8" surface casing to 2500 psi for 30 charted min - good test. Lost 52 psi total: 45 psi over first 15 min, 7 psi over the second 15 min. pumped 4 bbls / bled back 4 bbls. Blow down lines and rig down test equipment. Drill cement, shoe track and 20' of new hole F/ 6181' - T/ 6350' MD: 450 gpm, 1200 psi, 5-9k WOB, 40 rpm, 14k Tq on, 14-15k Tq off, 155k up, 80k dn, 108k rot. Drilled Baffle @ 6205' MD, Float @ 6245' MD, and Shoe @ 6328' MD. Reamed each 2x and tripped through w/o pumps or rotation - no issues. Good indications of cement in shoe track and good cement at bottoms up. Displace well to 8.9 ppg BaraDril-N: 35 bbls 155 Vis Spacer followed by 8.9 ppg BaraDril-N. 450 gpm, 985 psi, 60 rpm, 13-14k Tq, Reciprocate pipe 50' during circulation. Rotated through shoe track 3x during circulation w/o issues. MW in/out = 9.05 ppg after displacement. Obtain SPR. Rig up and Perform FIT: 9.05 ppg MW, 3939' TVD, 604 psi = 12.0 ppg EMW. Pumped 1 bbl / bled back 0.5 bbl Pull out of the hole with 8-1/2" Cleanout assy. F/ 6304' MD to 587' MD. No losses. P/U 153k SLK 87k PJSM L/D all 5" HWDP and Jars. Milk motor and break off 12.25" Tri Cone. L/.D Bit and 1.5° Motor as per DD. Bit grade 1-1-WT-A-E-I-NO-BHA PJSM Bring BHA components to rig floor. P/U M/U 8.5" PDC Bit SK616M-J1D (TFA 0.9020) , 8.5" NRP and 8.5" GeoPilot 7600 XL , 6.75" ADR, 8.375" ILS, 6.75" DGR, 6.75" PWD, 6.75" DM, 6.75" TM HOC and upload MWD. M/U 8.375" Integral Blade, 6.75" FS (non ported-plunger), 6.75" NM FC, 6.75" FS (non ported-plunger), 6.75" NM FC, (Corrosion Ring) 2 ea 5" HWDP, 6.5" SLB Hydra Jars & 1 ea 5" HWDP 279.63' MD. Shallow pulse test 400 gpm, 530 psi F/O 55%. P/U 48k SLK 50k. Drift HWDP 2.75" OD. PJSM Single in hole BHA 3 W/ 5" 19.5# S-135 D.P. F/ 279' to 1,838' MD. P/U 64k SLK 58k. Drift 3.125" OD. No losses. PJSM Single in hole BHA 3 W/ 5" 19.5# S-135 D.P. F/ 1,838' to 2,504' MD. (70 Jnts) P/U 64k SLK 58k. Drift 3.125" OD. No losses. PJSM Cont RIH BHA 3 5" D.P. F/ derrick F/ 2,504' to 6,256' MD P/U 145k SLK 88k. No losses. PJSM Drain stack and remove trip nipple. Install RCD Bearing on stand. RIH and set RCD Bearing, install grey clamp and tighten as per Beyond rep onsite. Install bowl saver and hang curtain around drip pan. Circ through MPD Equip, no leaks. PJSM Hang blocks. Cut 9 wraps (57') ACCUM TM 20575, 2,035' left on drum. Perform monthly sheave wobble inspection. Cont Circ 450 gpm 1,100 psi. Service rig. Grease and service top drive, spinners, blocks, drawworks and iron roughneck. Daily disposal to G&I: 985 bbl. Total disposal to G&I: 8487 bbl. Daily H2O F/ A-Pad 380 bbl. Total H2O A-Pad: 3480 bbl. Daily H2O F/ S-Pad: 0 bbl. Total H2O S-Pad: 740 bbl. Daily Metal: 0 lbs. Total Metal: 0 lbs. Daily Fluid Loss: 0 bbl. Total Production loss: 0 bbl. Total Surface loss: 142 bbl. 8/11/2021 PJSM RIH W/ 5" D.P. F/ derrick F/ 6,256' to 6,350' MD. Established parameters prior to existing shoe 450 gpm 1,100 pdi 80 rpm Trq 10-11k ECD 10.9 EMW, Drill 8.5" Production Hole F/ 6,350' to 6,954' MD (3,930' TVD) Total 604’ (AROP 109.8’) 475 gpm/ MPD 473, 1,310 psi, 120 RPM, TRQ on 13-14k, TRQ off 12-13k, WOB 4-10k. ECD 10.2. Max Gas 1,744u. P/U 147k, SLK 71k, ROT 97k. MPD 100% open. Back ream full stand. Start turn 2°/100 at 6,451' MD. Ungulate in NB as per Geo. Drill 8.5" Production Hole F/ 6,954' to 7,653' MD (3,910' TVD) Total 699’ (AROP 116.5’) 450 gpm/ MPD 454, 1,270 psi, 120 RPM, TRQ on 13.5k, TRQ off 14k, WOB 4-14k. ECD 10.23. Max Gas 1,662u. P/U 145k, SLK 69k, ROT 99k. MPD 100% open. Back ream full stand.. Drill 8.5" Production Hole F/ 7,653' to 8,290' MD (3,908' TVD) Total 638’ (AROP 106.4’) 525 gpm/ MPD 528, 1,640 psi, 120 RPM, TRQ on 13k, TRQ off 14k, WOB 4-14k. ECD 10.41. Max Gas 1,934u. P/U 139k, SLK 69k, ROT 101k. MPD 100% open. Back ream full stand. Spot check well W/ MPD at connections. Drill 8.5" Production Hole F/ 8,290' to 9,179' MD (3,910' TVD) Total 889’ (AROP 148.2’) 525 gpm/ MPD 527, 1,720 psi, 120 RPM, TRQ on 15-16k, TRQ off 14-15k, WOB 4-10k. ECD 10.5. Max Gas 1,645u. P/U 140k, SLK 68k, ROT 98k. MPD 100% open. Back ream full stand. End turn 2°/100 at 8,559' MD. Distance to WP08: 17.74', 10.10' High 10.74' Right No Faults. 8 concretions for a total thickness of 38' (1.4% of the lateral). Footage NB Sand 2,675' Daily disposal to G&I: 533 bbl. Total disposal to G&I: 9020 bbl. Daily H2O F/ A- Pad 0 bbl. Total H2O A-Pad: 3480 bbl. Daily H2O F/ S-Pad: 710 bbl. Total H2O S-Pad: 1450 bbl. Daily Metal: 10 lbs. Total Metal: 10 lbs. Daily Fluid Loss: 0 bbl. Total Production loss: 0 bbl. Total Surface loss: 142 bbl. 8/12/2021 Drill 8.5" Production Hole F/ 9,179' to 9,877' MD (3,918' TVD) Total 698’ (AROP 116.4’) 525 gpm/ MPD 525, 1,850 psi, 120 RPM, TRQ on 13-14k, TRQ off 12- 13k, WOB 4-10k. ECD 10.5. Max Gas 1,063u. P/U 140k, SLK 68k, ROT 98k. MPD 100% open. Back ream full stand. Troubleshooting a different sound coming from shaker #1, both shakers showed severe cracks around welds on shaker beds and motor supports. Baseline measurements were taken as reference to continue drilling to TD. Turn 2°/100 at 9,156' MD. Drop 1.5°/100 at 9,406' MD. Drop 0.26°/100 at 9,606' MD Drill 8.5" Production Hole F/ 9,877' to 10,700' MD (3,965' TVD) Total 823’ (AROP 137.2’) 525 gpm/ MPD 525, 1,950 psi, 120 RPM, TRQ on 19k, TRQ off 18k, WOB 4k. ECD 10.9. Max Gas 1,160u. P/U 157k, SLK 57k, ROT 100k. MPD 100% open. Back ream 30'. Cont drop 0.26°/100 at 9,606' MD Drill 8.5" Production Hole F/ 10,700' to 10,894' MD (3,960' TVD) Total 194’ (AROP 64.7’) 525 gpm/ MPD 522, 1,980 psi, 120 RPM, TRQ on 21.5k, TRQ off 17k, WOB 11k. ECD 10.9. Max Gas 1,102u. P/U 155k, SLK 61k, ROT 96k. MPD 100% open. Back ream 30'. Close approach S-32 CC 18.52' @ 10,760' MD. Shaker #1 welds and cracks to severe to cont drilling. Decision was made to POOH to shoe to make repairs on shakers. Cont drop 0.26°/100 at 9,606' MD exit NB Sand at 10,695' MD due to upcoming fault ~130 DTW. Obtain final survey Inc 82.07° Azi 341.46°, send Geo home position. PJSM Monitor well 10 min, static. Shut in MPD 5 min, static. BROOH CBU 2X F/ 10,894' to 10,769' MD using only Shaker #2. Cont BROOH 40-60 ft min F/ 10,769' to 10,515' MD. Pull on elevators W/ Beyond MPD trip schedule holding 140 psi dynamic & 0 psi static F/ 10,515' to 10,081' MD 60 ft/min pulled tight 30k over 3X decision was made to Cont BROOH. Cont BROOH F/ 10,081' to 9,626' MD 60 ft/min 450 gpm/ mpd 448 1,560 psi 120 RPM Trq 15k Max Gas 29u ECD 10.4 P/U 161k SLK 67k ROT 104k. PJSM Cont BROOH F/ 9,626' to 6,254' MD 60-70 ft/min 450 gpm/ mpd 400 1,175 psi 120 RPM Trq 7-8k Max Gas 22u ECD 10.1 P/U 129k SLK 86k ROT 102k. MPD 100% open. Lost 27 bbl for trip. Pulled through shoe on elevators, clean. NES Welder on location at 03:30. SIMOPS Welder pull leads and prep for welding shaker 1. PJSM Rot Res F/ 6,254' to 6,187' MD CBU 450 gpm/ mpd 450 1,180 psi 60 RPM Trq 5k Max Gas 94u ECD 9.88 P/U 129k SLK 86k ROT 102k. Shut in well with MPD and monitor will working on shakers. SIMOPS Cont prep, lay fire blankets, ply wood, inspect welds. Top off pits W/ mud from Vac truck. PJSM Initiate Hot Work Permit W/ constant LEL monitoring. Lock and tag out shaker motors. Fill TT W/ H2O. Check ventilation. Welder grind out cracks and welding on shaker 1. Distance to WP08: 16.86', 12.74' Low 11.04' Left No Faults. 14 concretions for a total thickness of 65' (1.4% of the lateral). Footage NB Sand 4,370'. Out of NB Sand: 199'. Total: 4569' Daily disposal to G&I: 570 bbl. Total disposal to G&I: 9590 bbl. Daily H2O F/ A-Pad 260 bbl. Total H2O A-Pad: 3740 bbl. Daily H2O F/ S-Pad: 410 bbl. Total H2O S-Pad: 1840 bbl. Daily Metal: 5 lbs. Total Metal: 15 lbs. Daily Fluid Loss: 0 bbl. Total Production loss: 0 bbl. Total Surface loss: 142 bbl. 8/13/2021 Continue welding repairs on both shaker beds. Weld up severe cracks around broken welds around cross support for shaker motors. Shaker #1 showed most damage. Shaker #2 showed similar damage but less severe. Allow welded areas to cool to touch. Monitor well via MPD during repairs. Offload trip tanks and pill pits. Remove fire blankets and plywood from around shakers. Run both shakers then re-inspect for cracks (good). Dress both shakers w/ 170's. Open MPD (0 psi). PJSM RIH F/ 6,248' to 10,831' MD. Noticed ~7k excess drag RIH no issue getting to bottom. Fill drill string 8,539'MD. Washed down F/ 10,831' to 10894' MD. 450 gpm/ MPD 455 1,680 psi 100 rpm Trq 10.5k No fill. Do losses for trip. Drill 8.5" Production Hole F/ 10,894' to 11,278' MD (4,022' TVD) Total 384’ (AROP 96’) 525 gpm/ MPD 523, 2,140 psi, 120 RPM, TRQ on 16.5k, TRQ off 17k, WOB 12.5k. ECD 11.18. Max Gas 793u. P/U 149k, SLK 60k, ROT 99k. MPD 100% open. Back ream 60'. SIMOPS Grind and paint jeep tires. Drill 8.5" Production Hole F/ 11,278' to 11,737' MD (4,061' TVD) Total 459’ (AROP 114.75’) 525 gpm/ MPD 523, 2,147 psi, 120 RPM, TRQ on 17.7k, TRQ off 18k, WOB 5.5-6k. ECD 11.32. Max Gas 975u. P/U 152k, SLK 52k, ROT 101k. MPD 100% open. Back ream 60'. SIMOPS Grind and paint jeep tires. At 11,737’ MD encountered complete loss in returns. Lined up on kill and filled hole with immediate returns. Closed kill and circ down string establishing circ at 120 gpm/ MPD 117 365 psi ROT 20 RPM Trq 14.5-15.5K. Initial loss of 25 bbls. Dynamic loss rate 30-40 bph slowing to 15-20 bph. ROT REC F/ 11,735’ to 11,711’ MD Stage pumps up to 150 gpm/ MPD 146 443 psi ROT 20 rpm Trq 14.5-15.5K. Build 60 bbl LCM Pill (BaraCarb 50 20 ppb, 25 10 ppb, 5 20 ppb). Stage pumps up to 180 gpm/MPD 171 500 PSI 20 RPM Trq 16.5k, 215 gpm/ MPD 202 590 psi. Take on 100 bbls old mud to pits. Increase ROT 40 rpm TRQ 18.2k. Pump 30 bbls of LCM Pill. 84 gpm/ MPD 82 305 psi. Fault #1 at 11,299' MD throw 137 DTW. Entered NB Sand at ~11,521' MD. Avoided entering wet sand. Distance to WP08: 26.83', 26.59' Low 3.52' Left Fault #1 at 11,299' MD throw 137' DTW. 14 concretions for a total thickness of 65' (1.2% of the lateral). Footage NB Sand 4,370'. Out of NB Sand: 1,040'. Total: 5410' Daily disposal to G&I: 338 bbl. Total disposal to G&I: 9928 bbl. Daily H2O F/ A-Pad 0 bbl. Total H2O A-Pad: 3740 bbl. Daily H2O F/ S-Pad: 440 bbl. Total H2O S-Pad: 2280 bbl. Daily Metal: 4 lbs. Total Metal: 19 lbs. Daily Fluid Loss: 0 bbl. Total Production loss: 0 bbl. Total Surface loss: 142 bbl. 8/14/2021 Pump 30 bbls LCM pill (60 ppb) while staging up from 3 bpm to 10 bpm. Losses had slowed from 65% returns to 86% returns by the time pill exited bit. Higher RPM's (+80) seemed to induce higher loss rate. Rot/Recip while pumping pill 80 rpm, 18.5k tq, 10 bpm, 1548 psi, 86-89% returns. Drlg 8.5" lateral F/ 11737' - T/ 11911' MD (4077' TVD). 400 gpm, 1450 psi, 6-11k wob, 24u BGG. 165k up, 58k dn, 99k rot. Observed breathing @ connections. Shut in first connection after drilling continued and saw 194 psi. Bled off from 164 gpm to 75 gpm over 3 min and continue to trend down. Circulate and condition @ 11911' MD while waiting on orders from town. 400 gpm, 1475 psi, 20 rpm, . Saw significant losses while conditioning @ rpm's in excess of 20 (returns fluctuated from 50% to 90% but stabilized @ end of cleanup cycle. Discussion with geos, the fault crossing 11,299’ md is very questionable. With no fault at 11,299’ md, looks like we crossed into OA sand at 11,521’ md, then crossed the fault at ~11,750’ md (DTW). Decision made to drill up in section to better identify location and possibly reaquire NB sand. Drill at 92°. Drlg 8.5" lateral F/ 11911' - T/ 11974' MD building up to 93.2° Inc as per Geo to require sand. 400 gpm, 1450 psi, 11-16k wob, 80 rpm, 17-29k tq on, 18k tq off. B/R full stands. Max gas 510u, 165k up, 60k dn, 99k rot. Drill 8.5" Production Hole F/ 11,974' to 12,340' MD (4,058' TVD) Total 364’ (AROP 60.7’) 450 gpm/ MPD 436, 1,825 psi, 120 RPM, TRQ on 19k, TRQ off 18k, WOB 13k. ECD 11.27. Max Gas 436u. P/U 154k, SLK 35k, ROT 97k. MPD 100% open. Back ream 60'. Dynamic losses slowing to 3-5 bph. Seeing ballooning at connections with pumps off. Return flow trending down. Geo thinks NB Sand is below us. Decision was made to perform open hole side track at ~11,900' MD. Get final surveys. PJSM BROOH F/ 12,340' to 11,900' MD 450 gpm/ MPD 420, 1,650 psi, 120 RPM, TRQ 18k, Max Gas 26u P/U 151k SLK 56k ROT 107k Pull 60/ft min. No losses. Perform side track operations F/ 11,900' to 11,930' MD 450 gpm/ MPD 435, 1,730 psi, 140 RPM, TRQ 18k, WOB 2k. ECD 11.2. Max Gas 436u. P/U 152k, SLK 52k, ROT 99k. Set GeoPilot to 100% deflection at 165°R, trough at 150 ft/hr 3X with ABI showing good separation from mother bore. 1st pass drop 0.1°, 2nd pass 0.4°, 3rd pass 0.4° inc. F/11,930' to 11,976' MD Time drilling 10 ft/hr stage up rate as ABI's showed separation. Ream through side track point 2X. Drill 8.5" Production Hole F/ 11,976' to 12,167' MD (4,095' TVD) Total 191’ (AROP 95.5’) 450 gpm/ MPD 441, 1,780 psi, 120 RPM, TRQ on 15.5k, TRQ off 17k, WOB 11k. ECD 11.18. Max Gas 125u. P/U 151k, SLK 54k, ROT 100k. MPD 100% open. Back ream 60'. Cont seeing ballooning at connections. Intermittent dynamic losses 1-5 bph. Drill 8.5" Production Hole F/ 12,167' to 12,800' MD (4,094' TVD) Total 633’ (AROP 105.5’) 450 gpm/ MPD 415, 1,775 psi, 120 RPM, TRQ on 17-18k, TRQ off 16-17k, WOB 5-15k. ECD 11.1. Max Gas 457u. P/U 162k, SLK 43k, ROT 101k. MPD 100% open. Back ream 60'. In NB Sand targeting 91° inc. AT ~12,287' MD dynamic loss increased to 15-25 bph, return flow 92%. Cont ballooning at connections. Lost ~144 bbls. Close approach S-21 at 12,425' MD 44.14' CC SF 0.16 Distance to WP08: 30.85', 27.76' Low 13.46' Right. Side Track 12,340' to 11,900' MD total 440'. Fault #1 at 11,735' MD throw 160' DTW. 16 concretions for a total thickness of 86' (1.3% of the lateral). Footage NB Sand 5,047'. Out of NB Sand: 1,328'. Total: 6,375' Daily disposal to G&I: 399 bbl. Total disposal to G&I: 10327 bbl. Daily H2O F/ A-Pad 0 bbl. Total H2O A-Pad: 3740 bbl. Daily H2O F/ S- Pad: 670 bbl. Total H2O S-Pad: 2950 bbl. Daily Metal: 2 lbs. Total Metal: 17 lbs. Daily Fluid Loss: 220 bbl. Total Production loss: 220 bbl. Total Surface loss: 142 bbl. 8/15/2021 Drill 8.5" Production Hole F/ 12800' to 13360' MD (4,073' TVD) Total 560’ (AROP 94’) 450 gpm/ MPD 415, 1860 psi, 100 RPM, TRQ on 18k, TRQ off 17k, WOB 5- 15k. ECD 11.1. Max Gas 368u. P/U 165k, SLK 35k, ROT 102k. MPD 100% open. Back ream 60'. Lost dn wt @ 12864' MD. Appeared to fault and drill out top of NB @ 13330' MD. Drop in section to reacquire NB w/ target 85° Inc. Drill 8.5" Production Hole F/ 13360' to 13636' MD (4,095' TVD) Total 266’ (AROP 44’) 450 gpm/ MPD 431, 1950 psi, 80-100 RPM, TRQ on 17k, TRQ off 16k, WOB 4-23k. ECD 11.2. Max Gas 336u. P/U 165k, SLK 35k, ROT 98k. MPD 100% open. Back ream 60'. Reacquire good sand @ ~13550' field assessment. Drill 8.5" Production Hole F/ 13,636' to 13,900' MD (4,091' TVD) Total 264’ (AROP 44’) 400 gpm/ MPD 350, 1666 psi, 80-100 RPM, TRQ on 23k, TRQ off 17.5k, WOB 4-23k. ECD 11.0. Max Gas 277u. P/U 175k, SLK 35k, ROT 101k. MPD 100% open. Back ream 60'. At 13,817’ MD encountered loss rate increase to ~80 bph reduce flow to 400 gpm/ MPD 350 1,750 psi 87% returns. Pump 30 bbl 50 ppb LCM (BaraCarb 50 20 ppb, 25 10 ppb, 5 20 ppb) pill 310 gpm/ MPD 305 98% return. Cont drilling at 400 gpm/ MPD 350 1,660 psi 80 rpm Trq 10.5k ECD 11.05 Max Gas 277u 87% returns, 80-90 bph dynamic losses. No significate change with LCM pill. Cont drilling W/ 400 gpm/ MPD 360 1,690 psi 90% returns, Dynamic losses slowing to ~60 bph. Drilling slowed to 10-20 ROP. At last connection 13,881’ MD initial flow pumps off 400 gpm slowing to 77 gpm after 5 min 22 bbls back. Cont to see ballooning. .Initial loss 80% in returns slowly increase to 96% returns. Lost 244 bbls for tour. Drill 8.5" Production Hole F/ 13,900' to TD as per Geo 13,950' MD (4,091' TVD) Total 50’ (AROP 34’) 400 gpm/ MPD 384, 1650 psi, 80 RPM, TRQ on 19-22k, TRQ off 20k, WOB 12-23k. ECD 11.0 Max Gas 48u. P/U 176k, SLK 35k, ROT 101k. MPD 100% open. Return flow 97% Dynamic loss ~25 bph. SPR. Obtain final survey 89.94 inc 344.84 Azi PJSM Rot Rec F/ 13,950 to 13,877' MD CBU 4X Pump tandem sweeps 40 bbl Low Vis/ Wt 31 Vis 8.6 ppg, 40 bbl High Vis/ Wt 100 Vis 10.0 ppg. 400 gpm/ MPD 380, 1610 psi, 80 RPM, TRQ 19-20k, ECD 10.9 Max Gas 193u. P/U 176k, SLK 35k, ROT 101k. MPD 100% open. Sweeps return on time 0% increase at shakers. SIMOPS Isolate to Pit 1-4 and prep for displacement. Empty Pit 5 and build SAPP Pills. Take on 9.1 ppg QuickDril to pit 5. Distance to WP08: 20.62', 20.58' Low 1.32' Right Side Track 12,340' to 11,900' MD total 440'. Fault #1 at 11,735' MD throw 160' DTW. 16 concretions for a total thickness of 86' (1.3% of the lateral). Footage NB Sand 5,047'. Out of NB Sand: 1,328'. Total: 6,375' Daily disposal to G&I: 399 bbl. Total disposal to G&I: 10726 bbl. Daily H2O F/ A-Pad 280 bbl. Total H2O A-Pad: 4020 bbl. Daily H2O F/ S-Pad: 610 bbl. Total H2O S-Pad: 3560 bbl. Daily Metal: 5 lbs. Total Metal: 26 lbs. Daily Fluid Loss: 435 bbl. Total Production loss: 655 bbl. Total Surface loss: 142 bbl. 8/16/2021 Continue Circulate and condition mud @ TD 13950' MD. Rot/Recip 400 gpm, 1610 psi, 80 rpm, 19.5k tq. ~95% returns (20-25 bph dynamic loss rate). 193u max gas. 10.9 ECD with 9.25 MW. Obtain passing 250u PST. Shut down and monitor well Bled back 15 bbl over 10 min trending from 150 gpm, to 15 gpm PJSM, Pump 3x 40 bbl Sapp pills (8.4 MW, 27 Vis) w/ 50 bbl spacers between. Chase Sapp pills with 9.1 MW lubricated brine (Quikdril / 2% lubes). 400 GPM, 1080 psi, 40 rpm, 16k tq. ~55u BGG. 175k up with mud, 165k up with brine. No dn wt with either fluid. 3-4k drop in tq. L/D 5' dp pup. Drop 2.39" OD steel drift (no wire). Begin BROOH F/ 13950' - T/ 10350' @ 20-30 fpm. Tripped back down @ ST point 1x stand and confirm junction clean via ABI (~85° Inc) with 5k minor bobbles. ~93%-96% returns. 400-450 gpm, 40-100 rpm. Minor stalls @ 15k around loss zone @ 11740' BROOH F/ 10,350' to 6,638' MD 450 gpm/ mpd 438 1,020 psi 120 rpm Trq 5k Max Gas 151u. ECD 9.98 P/U 118k SLK 91k ROT 101k. Pull speed 35-40 ft/min as hole dictates. Minimal dynamic losses. Lost 20 bbls for tour. Cont BROOH F/ 6,638' to 6,563' MD 450 gpm/ mpd 438 1,010 psi 120 rpm Trq 5k Pull speed 35-40 ft/min. Minimal dynamic losses 1-2 bph. Pull 5 stands on elevators F/ 6,563' to 6,235' MD BHA pulled clean through shoe (6,325'). P/U 118k SLK 92K. Rot Rec F/ 6,235' to 6,175' MD stage pumps up to 525 gpm / mpd 518 1,300 psi 40 rpm Trq 4.9k Max Gas 19u ECD 9.84 Pump 32 bbl 200+ High Vis sweep CBU 2X. Sweep back on time W/ 5% increase. Obtain passing 250u PST.. Monitor well 10 min, static. Shut in MPD 5 min, no Press. PJSM Remove RCD Bearing as per Beyond rep onsite. Drain stack monitor well. Undo grey clamp and center RCD bearing and pull to rig floor. Install bearing stripper tool. Strip off bearing. install trip nipple. Prep for laying down D.P. PJSM Pump dry job. POOH L/D 5" D.P. F/ 6,175' to 5,308' MD. Separate out D.P. for Cat 5 inspection. Lost 1 bbl. Daily disposal to G&I: 187 bbl. Total disposal to G&I: 12604 bbl. Daily H2O F/ A-Pad 0 bbl. Total H2O A-Pad: 4020 bbl. Daily H2O F/ S-Pad: 380 bbl. Total H2O S-Pad: 3940 bbl. Daily Metal: 1 lbs. Total Metal: 27 lbs. Daily Fluid Loss: 20 bbl. Total Completion loss: 20 bbl. Total Production loss: 766 bbl. 8/17/2021 Continue POOH laying down 5" dp F/ 5308' - T/ 279' MD. 16 bbl total loss for trip. 75k up, 58k dn @ 5308' MD. POOH F/ 279' - T/ surface. L/D 5" HWDP w/ jars. Retrieve steel drift @ FS. L/D flex DCs. Download MWD. L/D MWD, RSS. Bit grade 1,2,BT,S,X,I,NO,TD. Retrieve corrosion ring from Flex DC.s Clean and clear rig floor. L/D BHA tools. Load and prep shed w/ 4.5" liner as per tally. Mob 40 stop rings and centralizers to rig floor. R/U Weatherford 4.5" casing equipment. PJSM, M/U eccentric blank shoe jt.Run 4.5" 625, 13.5# 250u screen completion F/ surface - T/ 1994' MD as per tally. 9.6k tq on connections. Floating stop ring and centralizer on blank joints. Cont RIH 4.5" 625, 13.5# 250u screen completion F/ 1,994 to 7,761' MD as per tally. 9.6k tq on connections. Floating stop ring and centralizer on blank joints. P/U 100k SLK 76k. Lost 8 bbls for trip. Used 40 Centralizers and rings. Left 17 screens and 14 slicks. PJSM C/O Elevators and L/D Power Tongs. P/U M/U 7" SLZXP (HST 7 ea 1/2" pins 2,093 psi, Dog Sub 9 ea pins, HRD-E 6 ea pins 2,856 psi) and install 2 3/8" Ball shear out assy. M/U SLZXP to 4.5" Liner as per Baker Rep onsite. RIH 1 stand to 7,864' MD. Pump through 3 bpm 80 psi, Rot rpm/ Trq 10/7k, 15/7.5, 20/7.5k. P/U 101k, SLK 80k, ROT 90k. Run speed 70-90 ft/min. PJSM Convey 4.5" Liner W/ 5" 19.5# S-135 D.P. F/ Derrick F/ 7,864' to 9,200' MD. P/U 110k SLK 81k Run speed 70-90 ft/min. PJSM Convey 4.5" Liner W/ 5" 19.5# S-135 D.P. F/ Derrick F/ 9,200' to 13,950' MD. Tag 10k 13,950' P/U 147k SLK 77k Run speed 40-70 ft/min. Lost 10 bbls. PJSM P/U break stand and drop 1.25" OD Phenolic Ball. M/U Stand RIH tag 13,950' MD 10k. P/U to string WT 147k. Pump at 4 bpm 250 psi, slow rate to 2 bpm 140 psi at 950 stks. Ball on seat 28 bbls early. Cont press up observed shear at 2,200 psi saw pusher tool activate cont press up to 2,475 psi hold for 2 min. Slacked off set down 41k. Cont press up Neutralizer at 2,800 psi, released from HRD-E and shear out valve opened at 3,500 psi. Bleed remainin g press. P/U check release 120k broke over, released from SLZXP. TOL at 6,162' MD. PJSM R/U test Equip. Flood choke and kill lines. Shut in Annular. PT SLZXP to 1,500 psi for 10 min on chart, good. R/D test Equip. Pumped 2.4 bbl, bled 2.0 bbl. PJSM Rack back 1 stand to 13,890' MD. CBU 455 gpm 940 psi F/O 53% Max Gas 22u. P/U 120k Monitor well 10 min, static. Pump 25 bbl 10 ppg corrosion inhibited dry job. Blow down. Daily disposal to G&I: 114 bbl. Total disposal to G&I: 12718 bbl. Daily H2O F/ A-Pad 0 bbl. Total H2O A-Pad: 4020 bbl. Daily H2O F/ S-Pad: 120 bbl. Total H2O S-Pad: 4060 bbl. Daily Metal: 0 lbs. Total Metal: 27 lbs. Daily Fluid Loss: 91 bbl. Total Completion loss: 142 bbl. Total Production loss: 808 bbl. 8/18/2021 PJSM, POOH L/D 5" dp F/ 6090' - T/ surface. L/D liner running tool as per BOT rep. Found 1" aluminum debris wedged in running tool. Appears to have come from shoe track. 5.3 bbl loss for trip. RIH with remaining 5" dp out of derrick T/ 1972' MD. 66k up, 56k dn. 5 bbl loss. 1-2 bph static loss rate. Swap to completion AFE @ 12:00 hrs 8/18/2021. See completions report for details. Daily disposal to G&I: 257 bbl. Total disposal to G&I: 12975 bbl. Daily H2O F/ A-Pad 0 bbl. Total H2O A-Pad: 4020 bbl. Daily H2O F/ S-Pad: 140 bbl. Total H2O S-Pad: 4200 bbl. Daily Metal: 0 lbs. Total Metal: 27 lbs. Daily Fluid Loss: 34 bbl. Total Surface loss:142 bbl. Total Production loss: 842 bbl. Activity Date Ops Summary 8/18/2021 Cut and Slip drilling line @ 1972' MD. Service traveling equipment. Grease and service IR, Tongs and inspect brakes on drawworks. 1.5 bph static loss rate.,POOH laying down 5" dp from 1972' to surface (all dp laid down).,Pull wear bushing. Set test plug. Close blind rams and change out upper pipe rams to 7" fixed body. Test rams 250/3000 psi w/ 5 min hold on each. R/D test Equip L/D test jt.,Mobilize 7” handling equipment to rig floor. R/U Weatherford double stack Power Tongs. M/U XO to FOSV. Service Pipe Skate.,P/U M/U 7" Seal Assy RIH w/ 7" 26# L-80 TXP BTC to 6177’ MD, No-Go out 6' deep from tieback tally. Tq to optimal 14,750 lb/ft. Running speed 90 ft/min. Lost 14 bbls.,Space out, L/D jt #154, 153 and 152. Install 9.72' & 9.81’ pup jts below jt #152. M/U hanger and landing jt. S/O landing out on hanger with 55k on hanger (94k dn, 140k up). 2.47' off NoGo, Seal depth 6174.53' MD. WellHead Rep verify Hanger landed. R/U to reverse circulate. Reduce annular psi to 600 psi and close same. Pressure up on annulus to 275 psi, strip up until psi dump to locate 1" ports on seal assy.,Reverse circulate 7"x9-5/8" with 290 bbls 9.2 CI brine. 6 BPM, 360 psi. Losses @ 5 BPH. Daily disposal to G&I: 257 bbl. Total disposal to G&I: 12975 bbl. Daily H2O F/ A-Pad 0 bbl. Total H2O A-Pad: 4020 bbl. Daily H2O F/ S-Pad: 140 bbl. Total H2O S-Pad: 4200 bbl. Daily Metal: 0 lbs. Total Metal: 27 lbs. Daily Fluid Loss: 34 bbl. Total Surface loss: 142 bbl. Total Production loss: 842 bbl. 8/19/2021 Continue reverse circulate 9.2 CI brine & diesel 7" x 9-5/8" annulus. 344 bbls CI brine, 60 bbls diesel. 4 bpm, 390 psi. Shut in annulus psi 260. Strip down and landout 7" hanger w/ 59k string wt on hanger. Drain stack, L/D landing joint. Install 7" packoff and RILDS. Test void 500/5000 psi (good). L/D Mousehole.,Test 9- 5/8" x 7" annulus to 1000 psi w/ 30 min hold. Chart and record same. Test good. 1.3 bbls pumped, 1.2 bbls bled back. 1090 initial, 1038 @ 15 min, 1010 psi final. R/D test equipment.,C/O upper pipe rams to 2-7/8" x 5-1/2" VBR's. R/U and test same 250/3000 with 5 min hold on each. Chart and record same. R/D test equipment.,Load remaining 4.5" jewelry in shed for upper completion. Mob casing equipment to floor and R/U Weatherford YT's, d ouble stack power tongs and slips. Mandrel equipment (4.5" good). M/U XO on FOSV. ~1.5 bph static loss rate.,PJSM, M/U 4.5" 521, 12.6#, L-80 Cut jt full mule shoe and RIH T/ 1078' MD. M/U XN (3.813" packing bore w/ 3.725" NO GO). M/U BOT premier production packer as per BOT rep. M/U XO w/ FOSV and monitor well via trip tank.,Wait on Centrilift equipment. Mobilize Tech wire spool and sheaves to Rig floor. R/U Tech Wire. SimOps: .Adjust pipe skate, fill pill pit with warm water, work on EAMs,M/U Ported Sub, Sliding Sleeve & Gauge as per tally t/ 1102’ MD. Install sensor and tech wire to Gauge as per Centrilift rep onsite. Cont RIH w/ 4.5" 12.6# L-80 W521 f/ 1102' to 6184.61' MD. Tag 1.11’ in on Jt #152 w/ 5k. Install 1 cannon clamp every other connection f/ jt #26 t/ surface. Test tech wire every 1,000'. Tq W521 t/ 4,700 ft/lb. Lost 16 bbls total while running tubing.,PJSM L/D Jts #152,151 & 150. Space out w/ 9.27' & 2.67’ pup jts. P/U Jt #150. C/O Elevators to 5" & P/U 5" D.P. M/U X/O and Hanger. Terminate Tech wire and test, good. Land Hanger w/ shoe at 6182.57' – 2.04' off NoGo. P/U 87k, SO 63k. Wt in hanger = 28k. RILDS. 63 total Cannon Clamps ran.,PJSM Set BPV as per NOS. Clear rig floor of Weatherford & Centrilift tools and Equip. M/U Stack washing tool and flush Stack.,Daily disposal to G&I: 932 bbl. Total disposal to G&I: 13907 bbl. Daily H2O F/ A-Pad 0 bbl. Total H2O A-Pad: 4020 bbl. Daily H2O F/ S-Pad: 0 bbl. Total H2O S-Pad: 4200 bbl. Daily Metal: 0 lbs. Total Metal: 27 lbs. Daily Fluid Loss: 32 bbl. Total Surface loss: 142 bbl. Total Production loss: 874 bbl. 8/20/2021 Flush BOP's and associated equipment @ 15 bpm, 30 rpm with w/ heated soap water reciprocating thru stack with Johnny Whacker. Went on Gen Power @ 07:00 hrs.,PJSM, Bleed down koomey. N/D RCD, drip pan, choke and kill lines. Remove koomey lines. N/D BOP's and rack back same on stump. Continue cleaning pits. Load shed with 114 jts 5" NC50 drill pipe. Inspect #2 MP.,N/U tubing adapter with dry hole tree. Final check on Tek wire (test good). 1718 psi bottom hole, 73.6° F btm hole. Test void 500/5000 psi w/ 5/10 min hold (test good).,LRS Freeze protect 4-1/2" x 7" annulus bullheading 44 bbls diesel @ 2 bpm, 500 psi. Freeze protect 4.5" tbg bullheading 35 bbls diesel @ 1 bpm, 600 psi.,R/U 1502 riser system with 1-7/8" ball and rod loading on top of closed master valve. Rig up lines to pump down 4-1/2” tbg and 4.5" x 7" IA. Rig up test equipment to monitor pressures both sides. Put 500 psi test on surface equipment - Good.,Drop ball and rod and free fall for 5 min. Line up pumo on 4-1/2” tbg and pressure up to 2800 psi, 1.3 bbls pumped. Observe 4.5" x 7" IA pressure increasing from initial 300 psi to 700 psi in 2 min and Tbg pressure decrease f/ 2800 psi t/ 2400 psi. Pressure Tbg back up to 2800 psi. and hold with rolling pumps (1-15 stks/min). IA pressure continue increasing to 2300 psi in 5 min. Total 3.03 bbls pumped.,Bleed down IA and then tubing to initial 300 psi. Rig up surface lines to eliminate any possibility of comm through surface equip. Pressure up to 3500 psi on Tbg and hold with rolling pumps. Tbg and IA equalize at 3500 psi, 7.9 bbls pumped. Shut pumps down and shut in Tbg and IA, monitor pressure for 30 min on chart. Pressure hold indicating good packer set. Discuss options with town engineer, decision made to RDMO.,Bleed 4.5" x 7" IA down to 0 psi, Bleed 4.5” Tbg down to 400 psi. R/D test equip. Blow down and rig down HP lines and 1502 components. Install tree cap with gauge. 4.5" & 4.5" x 7" IA equalized with final reading of 300 psi each. SimOps: Continue cleaning pits, Continue MP #1 inspection.,Prep Rig floor for move. Bridle Up. Finish cleaning pits. Break interconnect lines other than air, steam, water. Blow down water and steam. Break apart interconnects. Rig released @ 00:00,Refer to MPU S-39 for details. Daily disposal to G&I: 206 bbl. Total disposal to G&I: 14113 bbl. Daily H2O F/ A-Pad 0 bbl. Total H2O A-Pad: 4020 bbl. Daily H2O F/ S-Pad: 150 bbl. Total H2O S-Pad: 4350 bbl. Daily Metal: 0 lbs. Total Metal: 27 lbs. Daily Fluid Loss: 5 bbl. Total Surface loss: 142 bbl. Total Production loss: 879 bbl. 50-029-23696-00-00API #: Well Name: Field: County/State: MP S-47 Milne Point Hilcorp Energy Company Composite Report , Alaska 8/2/2021Spud Date: TD Shoe Depth: PBTD: No. Jts. Returned RKB RKB to BHF RKB to THF Jts. 2 3 92 3 58 X Yes No X Yes No 7.8 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface? Yes X No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: Casing (Or Liner) Detail Float Shoe 9.625 CSG RKB 10 3/4 SECOND STAGEHES Returns to surf Rotate Csg Recip Csg Ft. Min. PPG9.5 Shoe @ 6325 FC @ Top of Liner6,241.00 Floats Held 21 763 333 430 H2O CASING RECORD County State Alaska Supv.B Anderson / O Amend Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.MP S-47 Date Run 7-Aug-21 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top TCP BTC Innovex 1.56 6,325.00 6,323.44 2,348.11 2,373.14 25.03 9 5/8 47.0 L-80 TCP BTC Tenaris Csg Wt. On Hook:280,000 Type Float Collar:Standard No. Hrs to Run:13.5 8.34 5 0 10 10.7 412 4.5 100 267 Bump Plug?FIRST STAGE10Tuned spacer w/ 4# red dye & 5 lb/bbl poly 52 15.8 443 4.4 8.34 6.3 20/20 20/20 1239 0 HES 15.8 88 Bump press Circ to surface off ES Bump Plug? Yes 2,390 2390 6,325.006,330.00 CEMENTING REPORT Csg Wt. On Slips:120,000 Spud Mud Tuned spacer w/ 4# red dye 803 2.88 Stage Collar @ 60 Bump press 100 333 ES Closure OK 58 12 205 26.78 RKB to CHF Type of Shoe:Standard Casing Crew:Weatherford No. Jts. Delivered 169 No. Jts. Run 155 14 Length Measurements W/O Threads Ftg. Delivered 6,760.00 Ftg. Run 6,200.00 Ftg. Returned 560.00 Ftg. Cut Jt.28.71 Ftg. Balance www.wellez.net WellEz Information Management LLC ver_04818br 3.1 ArcticCem Type Shoe Jnt 2 ea 10' F/ end, 1 ea 2 nd & 3rd jnt, 1 ea F/ jnt 4 to 26, every other jnt F/ 28 to 52, 5 before and 5 after ES, 3 / 11 160 82 C 9 /8 12 1/ / 12 9.625 CSG 9 5/8 40.0 L-80 TCP BTC Tenaris 81.01 6,323.44 6,242.43 Float Collar 10 3/4 TCP BTC Innovex 1.30 6,242.43 6,241.13 9.625 CSG 9 5/8 40.0 L-80 TCP BTC Tenaris 39.64 6,241.13 6,201.49 Baffle Adapter 10 3/4 TCP BTC Halliburton 1.43 6,201.49 6,200.06 9.625 CSG 9 5/8 40.0 L-80 TCP BTC Tenaris 3,667.77 6,200.06 2,532.29 9.625 Cgs 9 5/8 47.0 L-80 TCP BTC Tenaris 121.23 2,532.29 2,411.06 Pup 9 5/8 40.0 L-80 TCP BTC Tenaris 17.10 2,411.06 2,393.96 ES Cementer 11 3/4 TCP BTC Halliburton 3.72 2,393.96 2,390.24 Pup 9 5/8 40.0 L-80 TCP BTC Tenaris 17.10 2,390.24 2,373.14 Type I II 500 2.35 Premium G 400 1.15 4 Premium G 270 1.17 0 H2O 'HILQLWLYH6XUYH\5HSRUW $XJXVW +LOFRUS$ODVND//& 0LOQH3RLQW 03W63DG 0386 3URMHFW &RPSDQ\ /RFDO&RRUGLQDWH5HIHUHQFH 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B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ B0:',)5066DJ 352-(&7('WR7' $SSURYHG%\ &KHFNHG%\ 'DWH 30 &203$66%XLOG (3DJH Chelsea Wright Digitally signed by Chelsea Wright Date: 2021.08.16 10:15:57 -08'00' Benjamin Hand Digitally signed by Benjamin Hand Date: 2021.08.17 13:41:27 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/19/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU S-47 (PTD 221-047) Leak Detect Log 09/22/2021 Please include current contact information if different from above. 37' (6HW Received By: 10/19/2021 By Abby Bell at 12:58 pm, Oct 19, 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 by signing and returning one copy of this transmittal or fax to 907 564-4422. Received By: Date: Date: 8/25/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU S-47 + MPU S-47PB1 (PTD 221-047) FINAL LWD FORMATION EVALUATION LOGS (08/03/2021 to 08/16/2021) x ROP, AGR, DGR, ABG, EWR-M5, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Survey SFTP Transfer – Main Folders: Subfolders: Please include current contact information if different from above. 37' (6HW eceived By: 08/30/2021 By Abby Bell at 3:30 pm, Aug 25, 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 by signing and returning one copy of this transmittal or fax to 907 564-4422. Received By: Date: Date: 8/25/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU S-47 + MPU S-47PB1 (PTD 221-047) FINAL LWD FORMATION EVALUATION LOGS (08/03/2021 to 08/16/2021) x ROP, AGR, DGR, ABG, EWR-M5, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Survey SFTP Transfer – Main Folders: Subfolders: Please include current contact information if different from above. 37' (6HW Received By: 08/30/2021 By Abby Bell at 3:30 pm, Aug 25, 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 by signing and returning one copy of this transmittal or fax to 907 564-4422. Received By: Date: Date: 08/25/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU S-47 + MPU S-47PB1 (PTD 221-047) FINAL EOW REPORT – GEOSTEERING LOGS (08/10/2021 to 08/16/2021) SFTP Transfer - Data Folders: Please include current contact information if different from above. 37' (6HW Received By: 08/30/2021 By Abby Bell at 3:29 pm, Aug 25, 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 by signing and returning one copy of this transmittal or fax to 907 564-4422. Received By: Date: Date: 08/25/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU S-47 + MPU S-47PB1 (PTD 221-047) FINAL EOW REPORT – GEOSTEERING LOGS (08/10/2021 to 08/16/2021) SFTP Transfer - Data Folders: Please include current contact information if different from above. 37' (6HW Received By: 08/30/2021 By Abby Bell at 3:29 pm, Aug 25, 2021 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, Inc. 3800 Centerpoint Drive, Suite 400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU S-47 Hilcorp Alaska, LLC Permit to Drill Number: 221-047 Surface Location: 3179' FSL, 692' FEL, Sec. 12, T12N, R10E, UM, AK Bottomhole Location: 1261' FNL, 1853' FEL, Sec. 12, T12N, R10E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced 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 July, 2021. Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.15 10:51:26 -08'00' 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: 14,973' TVD: 4,064' 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): 64.3'15.Distance to Nearest Well Open Surface: x-565320 y- 5999842 Zone- 4 37.8' to Same Pool:50' 16.Deviated wells: Kickoff depth: 300 feet 17.Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD Driven 20" 129.5# X-52 80' 80' Surface Surface 118' 118' 47# L-80 TXP 2,500' Surface Surface 2,500' 2,053' 40# L-80 TXP 3,612' 2,500' 2,053' 6,112' 3,916' Tieback 7" 26# L-80 TXP 5,962' Surface Surface 5,962' 3,910' 8-1/2" 4-1/2" 13.5# L-80 Hyd 625 9,011' 5,962' 3,910' 14,973' 4,064' 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: Nathan Sperry Monty Myers Contact Email:nathan.sperry@hilcorp.com Drilling Manager Contact Phone:777-8450 Date: Permit to Drill API Number: Permit Approval Number: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: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7/11/2021 1,358' 12-1/4" 9-5/8" 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): Uncemented Tieback Uncemented Screen Liner Effect. Depth MD (ft): Effect. Depth TVD (ft): Authorized Title: Authorized Signature: Production Liner Intermediate Authorized Name: Conductor/Structural LengthCasing Cement Volume MDSize Plugs (measured): (including stage data) Stg 1 L - 1063 ft3 / T - 458 ft3 2560 18. Casing Program: Top - Setting Depth - BottomSpecifications 1723 Total Depth MD (ft): Total Depth TVD (ft): 22224484 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Stg 2 L - 1935 ft3 / T - 313 ft3 1382 1538' FSL, 1590' FWL, Sec. 12, T12N, R10E, UM, AK 1261' FNL, 1853' FEL, Sec. 12, T12N, R10E, UM, AK 01-001 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 Hilcorp Alaska, LLC 3179' FSL, 692' FEL, Sec. 12, T12N, R10E, UM, AK ADL 380109 MPU S-47 Milne Point Field Schrader Bluff Oil Pool Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. o o o o Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 6.21.2021 By Samantha Carlisle at 12:48 pm, Jun 21, 2021 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.06.21 12:40:15 -08'00' Monty M Myers DSR-6/21/21 50-029-23696-00-00 MGR08JUL2021 * BOPE test to 3000 psi. Annular to 2500 psi. * Approved to remove 20' section of diverter while circulating overbalance fluid at surface hole TD to move in cementing equipment. Line to be replaced before cementing or tripping. 221-047 SFD 6/21/2021 JLC 7/15/2021 7/15/21 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.15 10:50:37 -08'00' Milne Point Unit (MPU) S-47 Drilling Program Version 1 6/9/2021 Table of Contents 1.0 Well Summary ........................................................................................................................... 2 2.0 Management of Change Information ........................................................................................ 3 3.0 Tubular Program:...................................................................................................................... 4 4.0 Drill Pipe Information: .............................................................................................................. 4 5.0 Internal Reporting Requirements ............................................................................................. 5 6.0 Planned Wellbore Schematic ..................................................................................................... 6 7.0 Drilling / Completion Summary ................................................................................................ 7 8.0 Mandatory Regulatory Compliance / Notifications .................................................................. 8 9.0 R/U and Preparatory Work ..................................................................................................... 10 10.0 N/U 13-5/8” 5M Diverter System ............................................................................................. 11 11.0 Drill 12-1/4” Hole Section ........................................................................................................ 13 12.0 Run 9-5/8” Surface Casing ...................................................................................................... 16 13.0 Cement 9-5/8” Surface Casing ................................................................................................. 22 14.0 ND Diverter, NU BOPE, & Test .............................................................................................. 27 15.0 Drill 8-1/2” Hole Section .......................................................................................................... 28 16.0 Run 4-1/2” Screened Liner ...................................................................................................... 33 17.0 Run 7” Tieback ........................................................................................................................ 37 18.0 Run Upper Completion – Jet Pump ........................................................................................ 40 19.0 Innovation Rig Diverter Schematic ......................................................................................... 42 20.0 Innovation Rig BOP Schematic ............................................................................................... 43 21.0 Wellhead Schematic ................................................................................................................. 44 22.0 Days Vs Depth .......................................................................................................................... 45 23.0 Formation Tops & Information............................................................................................... 46 24.0 Anticipated Drilling Hazards .................................................................................................. 48 25.0 Innovation Rig Layout ............................................................................................................. 52 26.0 FIT Procedure .......................................................................................................................... 53 27.0 Innovation Rig Choke Manifold Schematic ............................................................................ 54 28.0 Casing Design ........................................................................................................................... 55 29.0 8-1/2” Hole Section MASP ....................................................................................................... 56 30.0 Spider Plot (NAD 27) (Governmental Sections) ...................................................................... 57 31.0 Surface Plat (As Built) (NAD 27) ............................................................................................. 58 Page 2 Milne Point Unit S-47 SB Producer Drilling Procedure 1.0 Well Summary Well MPU S-47 Pad Milne Point “S” Pad Planned Completion Type Jet pump on 4-1/2 tubing Target Reservoir(s) Schrader Bluff NB Sand Planned Well TD, MD / TVD 14,973’ MD / 4,064’ TVD PBTD, MD / TVD 14,973’ MD / 4,064’ TVD Surface Location (Governmental) 2101' FNL, 692' FEL, Sec 12, T12N, R10E, UM, AK Surface Location (NAD 27) X= 565320, Y=5999842 Top of Productive Horizon (Governmental)1358' FSL, 1590' FWL, Sec 12, T12N, R10E, UM, AK TPH Location (NAD 27) X= 562339, Y=5997996 BHL (Governmental) 1261' FNL, 1853' FEL, Sec 2, T12N, R10E, UM, AK BHL (NAD 27) X= 558825, Y=6005908 AFE Number AFE Drilling Days 17 AFE Completion Days 4 Maximum Anticipated Pressure (Surface) 1382 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1723 psig Work String 5” 19.5# S-135 NC 50 Innovation KB Elevation above MSL: 26.5 ft + 37.8 ft = 64.3 ft GL Elevation above MSL: 37.8 ft BOP Equipment 13-5/8” x 5M Annular, (3) ea 13-5/8” x 5M Rams Page 3 Milne Point Unit S-47 SB Producer Drilling Procedure 2.0 Management of Change Information Page 4 Milne Point Unit S-47 SB Producer Drilling Procedure 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” 19.25”---X-52Weld 12-1/4”9-5/8” 8.835”8.679”10.625”40 L-80 TXP 5,750 3,090 916 9-5/8” 8.681”8.525”10.625”47 L-80 TXP 6,870 4,750 1,086 Tieback 7” 6.276 6.151 7.656 26 L-80 TXP 7,240 5,410 604 8-1/2”4-1/2” Screens 3.920 3.795 4.714 13.5 L-80 Hydril 625 9,020 8,540 279 4.0 Drill Pipe Information: Hole Section OD (in) ID (in)TJ ID (in) TJ OD (in) Wt (#/ft) Grade Conn M/U (Min) M/U (Max) Tension (k-lbs) Surface & Production 5”4.276”3.25” 6.625”19.5 S-135 DS50 36,100 43,100 560klb 5”4.276”3.25” 6.625”19.5 S-135 NC50 30,730 34,136 560klb All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 5 Milne Point Unit S-47 SB Producer Drilling Procedure 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. 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. x Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Afternoon Updates x Submit a short operations update each work day to pmazzolini@hilcorp.com, mmyers@hilcorp, nathan.sperry@hilcorp.com, jengel@hilcorp.com and joseph.lastufka@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. 5.4 EHS Incident Reporting x Health and Safety: Notify EHS field coordinator. x Environmental: Drilling Environmental Coordinator x Notify Drilling Manager & Drilling Engineer on all incidents 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 nathan.sperry@hilcorp.com and joseph.lastufka@hilcorp.com 5.6 Casing and Cement report x Send casing and cement report for each string of casing to mmyers@hilcorp.com nathan.sperry@hilcorp.com and joseph.lastufka@hilcorp.com 5.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmyers@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 jengel@hilcorp.com Drilling Engineer Nate Sperry 907.777.8450 907.301.8996 nathan.sperry@hilcorp.com Completion Engineer David Gorm 907.777.8333 505.215.2819 dgorm@hilcorp.com Geologist John Salsbury 907.777.8481 907.350.1088 jsalsbury@hilcorp.com Reservoir Engineer Reid Edwards 907.777.8421 907.250.5081 reedwards@hilcorp.com Drilling Env. Coordinator Keegan Fleming 907.777.8477 907.350.9439 kfleming@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 cajones@hilcorp.com Drilling Tech Joe Lastufka 907.777.8400 907.227.8496 Joseph.Lastufka@hilcorp.com Page 6 Milne Point Unit S-47 SB Producer Drilling Procedure 6.0 Planned Wellbore Schematic Page 7 Milne Point Unit S-47 SB Producer Drilling Procedure 7.0 Drilling / Completion Summary MPU S-47 is a grassroots producer planned to be drilled in the Schrader Bluff NB sand. S-47 is part of a multi well program targeting the Schrader Bluff sand on S-pad The directional plan is a catenary well path with 12-1/4” hole and 9-5/8” surface casing set into the top of the Schrader Bluff NB sand. An 8-1/2” lateral section will be drilled. A 4-1/2” liner will be run in the open hole section and the well will be produced with a jet pump. The Innovation Rig will be used to drill and complete the wellbore. Drilling operations are expected to commence approximately July 11, 2021, pending rig schedule. Surface casing will be run to 6,112’ MD / 3,916’ TVD and cemented to surface via a 2 stage primary cement job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed, necessary remedial action will then be discussed with AOGCC authorities. All cuttings & mud generated during drilling operations will be hauled to the Milne Point “B” pad G&I facility. General sequence of operations: 1. MIRU Innovation Rig to well site 2. N/U & Test 13-5/8” Diverter and 16” diverter line 3. Drill 12-1/4” hole to TD of surface hole section. Run and cement 9-5/8” surface casing 4. N/D diverter, N/U wellhead, NU 13-5/8” 5M BOP & Test 5. Drill 8-1/2” lateral to well TD 6. Run 4-1/2” production liner 7. Run 7” tieback 8. Run Upper Completion 9. N/D BOP, N/U Tree, RDMO Reservoir Evaluation Plan: 1. Surface hole: No mud logging. On Site geologist. LWD: GR + Res 2. Production Hole: No mud logging. On site geologist. LWD: GR + ADR (For geo-steering) Page 8 Milne Point Unit S-47 SB Producer Drilling Procedure 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the all applicable AOGCC regulations, specific regulations are listed below. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. x BOPs shall be tested at (2) week intervals during the drilling and completion of MPU S-47. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. x The initial test of BOP equipment will be to 250/3,000 psi & subsequent tests of the BOP equipment will be to 250/3,000 psi for 5/5 min (annular to 50% rated WP, 2,500 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 or control fluid flow from the well bore, AOGCC is to be notified and we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. 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”. o Ensure the diverter vent line is at least 75’ away from potential ignition sources x Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. x Casing pressure test criteria in 20 AAC 25.030 (e) Casing and Cementing,“A casing pressure test must be performed if BOPE is to be installed on a casing. The casing must be tested to hold a minimum surface pressure equal to 50 percent of the casing internal yield pressure. The test pressure must show stabilizing pressure and may not decline more than 10 percent within 30 minutes. The results of this test and any subsequent tests of the casing must be recorded as required by 20 AAC 25.070(1)”. AOGCC Regulation Variance Requests: x Hilcorp requests a variance to remove a 20’ section of vent line after drilling and running 9-5/8” casing to surface TD. The section would be removed after circulating a minimum of 1.5X BU in order to move cement equipment to the west side of the pad. The section will be re-installed prior to cementing. While the section is removed, we will continue to pump at minimum rate. At no time will underbalanced fluids be pumped into the well while the section is removed. Page 9 Milne Point Unit S-47 SB Producer Drilling Procedure Summary of Innovation BOP Equipment & Test Requirements Hole Section Equipment Test Pressure (psi) 12-1/4”x 13-5/8” 5M CTI Annular BOP w/ 16” diverter line Function Test Only 8-1/2” x 13-5/8” x 5M Control Technology Inc Annular BOP x 13-5/8” x 5M Control Technology Inc Double Gate o Blind ram in btm cavity x Mud cross w/ 3” x 5M side outlets x 13-5/8” x 5M Control Technology Single ram x 3-1/8” x 5M Choke Line x 3-1/8” x 5M Kill line x 3-1/8” x 5M Choke manifold x Standpipe, floor valves, etc Initial Test: 250/3,000 Subsequent Tests: 250/3,000 Primary closing unit: Control Technology Inc. (CTI), 6 station, 3,000 psi, 220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an electric triplex pump on a different electrical circuit and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: 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. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Email:jim.regg@alaska.gov Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Email:Victoria.loepp@alaska.gov Mel Rixse / Petroleum Engineer / (O): 907-793-1231 / (C): 907-223-3605 / Email:melvin.rixse@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 Milne Point Unit S-47 SB Producer Drilling Procedure 9.0 R/U and Preparatory Work 9.1 S-47 will utilize a newly set 20” conductor on S-pad. Ensure to review attached surface plat and make sure rig is over appropriate conductor. 9.2 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.3 Install landing ring. 9.4 Insure (2) 4” nipples are installed on opposite sides of the conductor with ball valves on each. 9.5 Level pad and ensure enough room for layout of rig footprint and R/U. 9.6 Rig mat footprint of rig. 9.7 MIRU Innovation. Ensure rig is centered over conductor to prevent any wear to BOPE or wellhead. 9.8 Mud loggers WILL NOT be used on either hole section. 9.9 Mix spud mud for 12-1/4” surface hole section. Ensure mud temperatures are cool (<80qF). 9.10 Ensure 5” liners in mud pumps. x White Star Quattro 1,300 HP mud pumps are rated at 4,097 psi, 381 gpm @ 140 spm @ 96.5% volumetric efficiency. Page 11 Milne Point Unit S-47 SB Producer Drilling Procedure 10.0 N/U 13-5/8” 5M Diverter System 10.1 N/U 13-5/8” CTI BOP stack in diverter configuration (Diverter Schematic attached to program). x N/U 20” x 13-5/8” DSA x N/U 13 5/8”, 5M diverter “T”. x NU Knife gate & 16” diverter line. x Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). x Diverter line must be 75 ft from nearest ignition source x Place drip berm at the end of diverter line. x Utilized extensions if needed. 10.2 Notify AOGCC. Function test diverter. x Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. x Ensure that the annular closes in less than 30 seconds (API Standard 64 3rd edition March 2018 section 12.6.2 for packing element ID less than or equal to 20”) 10.3 Ensure to set up a clearly marked “warning zone” is established on each side and ahead of the vent line tip. “Warning Zone” must include: x A prohibition on vehicle parking x A prohibition on ignition sources or running equipment x A prohibition on staged equipment or materials x Restriction of traffic to essential foot or vehicle traffic only. 24 hour notice. Page 12 Milne Point Unit S-47 SB Producer Drilling Procedure 10.4 Rig & Diverter Orientation: x May change on location NOTE Page 13 Milne Point Unit S-47 SB Producer Drilling Procedure 11.0 Drill 12-1/4” Hole Section 11.1 P/U 12-1/4” directional drilling assembly: 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 Consider running a UBHO sub for wireline gyro.GWD will be the primary gyro tool. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. x Drill string will be 5” 19.5# S-135. x Run a solid float in the surface hole section. 11.2 Begin drilling out from 20” conductor at reduced flow rates to avoid broaching the conductor. x Consider using a trash bit to clean out conductor to mitigate potential damage from debris in conductor. 11.3 Drill 12-1/4” hole section to section TD, in the Schrader NB sand. Confirm this setting depth with the Geologist and Drilling Engineer while drilling the well. x Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. x Efforts should be made to minimize dog legs in the surface hole. Keep DLS < 6 deg / 100. x Hold a safety meeting with rig crews to discuss: x Conductor broaching ops and mitigation procedures. x Well control procedures and rig evacuation x Flow rates, hole cleaning, mud cooling, etc. x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Keep mud as cool as possible to keep from washing out permafrost. x Pump at 400-600 gpm. Monitor shakers closely to ensure shaker screens and return lines can handle the flow rate. x Ensure to not out drill hole cleaning capacity, perform clean up cycles or reduce ROP if packoffs, increase in pump pressure or changes in hookload are seen x Slow in/out of slips and while tripping to keep swab and surge pressures low x Ensure shakers are functioning properly. Check for holes in screens on connections. x Have the flowline jets hooked up and be ready to jet the flowline at the first sign of pea gravel, clay balling or packing off. x Adjust MW and viscosity as necessary to maintain hole stability, ensure MW is at a 9.2 minimum at TD (pending MW increase due to hydrates). x Perform wireline gyros until clean MWD surveys are seen. Take MWD surveys every stand drilled. x Be prepared for gas hydrates. In MPU they have been encountered typically around 2,100- 2,400’ TVD (just below permafrost). Be prepared for hydrates: x Gas hydrates can be identified by the gas detector and a decrease in MW or ECD x Monitor returns for hydrates, checking pressurized & non-pressurized scales Page 14 Milne Point Unit S-47 SB Producer Drilling Procedure x Do not stop to circulate out gas hydrates – this will only exacerbate the problem by washing out additional permafrost. Attempt to control drill (150 fph MAX) through the zone completely and efficiently to mitigate the hydrate issue. Flowrates can also be reduced to prevent mud from belching over the bell nipple. x Gas hydrates are not a gas sand, once a hydrate is disturbed the gas will come out of the well. MW will not control gas hydrates, but will affect how gas breaks out at surface. x Take MWD and GWD surveys every stand until magnetic interference cleans up. After MWD surveys show clean magnetics, only take MWD surveys. x Surface Hole AC: x There are no wells with a clearance factor of <1.0 11.4 12-1/4” hole mud program summary: x Density: Weighting material to be used for the hole section will be barite. Additional barite or spike fluid will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg and TD with 9.2+ ppg. Depth Interval MW (ppg) Surface – Base Permafrost 8.9+ Base Permafrost - TD 9.2+ (For Hydrates if need based on offset wells) MW can be cut once ~500’ below hydrate zone x PVT System: 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. x Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. x Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM (10 ppb total) BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. x Wellbore and mud stability:Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high-clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5 – 9.0 range with caustic soda. Daily additions of ALDACIDE G / X-CIDE 207 MUST be made to control bacterial action. x Casing Running:Reduce system YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what YP value they have targeted). Page 15 Milne Point Unit S-47 SB Producer Drilling Procedure System Type:8.8 – 9.2 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Section Density Viscosity Plastic Viscosity Yield Point API FL pH Temp Surface 8.8 –9.8 75-175 20 - 40 25-45 <10 8.5 –9.0 70 F System Formulation: Gel + FW spud mud Product Concentration Fresh Water soda Ash AQUAGEL caustic soda BARAZAN D+ BAROID 41 PAC-L /DEXTRID LT ALDACIDE G 0.905 bbl 0.5 ppb 15 - 20 ppb 0.1 ppb (8.5 – 9.0 pH) as needed as required for 8.8 – 9.2 ppg if required for <10 FL 0.1 ppb 11.5 At TD; PU 2-3 stands off bottom to avoid washing out the hole at TD, CBU, pump tandem sweeps and drop viscosity. 11.6 RIH to bottom, proceed to BROOH to HWDP x Pump at full drill rate (400-600 gpm), and maximize rotation. x Pull slowly, 5 – 10 ft / minute, adjust as dictated by hole conditions x Monitor well for any signs of packing off or losses. x Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. x If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.7 TOOH and LD BHA 11.8 No open hole logging program planned. Page 16 Milne Point Unit S-47 SB Producer Drilling Procedure 12.0 Run 9-5/8” Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 9-5/8” casing running equipment (CRT & Tongs) x Ensure 9-5/8” TXP x DS50 XO on rig floor and M/U to FOSV. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x R/U of CRT if hole conditions require. x R/U a fill up tool to fill casing while running if the CRT is not used. x Ensure all casing has been drifted to 8.75” on the location prior to running. x Top 2,000’ of casing 47# drift 8.525” 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 120’ shoe track assembly consisting of: 9-5/8” Float Shoe 1 joint – 9-5/8” TXP, 2 Centralizers 10’ from each end w/ stop rings 1 joint –9-5/8” TXP, 1 Centralizer mid joint w/ stop ring 9-5/8” Float Collar w/ Stage Cementer Bypass Baffle ‘Top Hat’ 1 joint –9-5/8” TXP, 1 Centralizer mid joint with stop ring 9-5/8” HES Baffle Adaptor x Ensure bypass baffle is correctly installed on top of float collar. x Ensure proper operation of float equipment while picking up. x Ensure to record S/N’s of all float equipment and stage tool components. This end up. Bypass Baffle 2500' Page 17 Milne Point Unit S-47 SB Producer Drilling Procedure 12.5 Float equipment and Stage tool equipment drawings: Page 18 Milne Point Unit S-47 SB Producer Drilling Procedure 12.6 Continue running 9-5/8” surface casing x Fill casing while running using fill up line on rig floor. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x Centralization: x 1 centralizer every joint to ~ 1000’ MD from shoe x 1 centralizer every 2 joints to ~2,000’ above shoe (Top of Lowest Ugnu) x Verify depth of lowest Ugnu water sand for isolation with Geologist x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. x Any packing off while running casing should be treated as a major problem. It is preferable to POH with casing and condition hole than to risk not getting cement returns to surface. 12.7 Install the Halliburton Type H ES-II Stage tool so that it is positioned at least 100’ TVD below the permafrost (~ 2,500’ MD). x Install centralizers over couplings on 5 joints below and 5 joints above stage tool. x Do not place tongs on ES cementer, this can cause damaged to the tool. x Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3300 psi. 9-5/8” 40# L-80 TXP Make-Up Torques: Casing OD Minimum Optimum Maximum 9-5/8”18,860 ft-lbs 20,960 ft-lbs 23,060 ft-lbs 9-5/8” 47# L-80 TXP MUT: Casing OD Minimum Optimum Maximum 9-5/8”21,440 ft-lbs 2,3820 ft-lbs 26,200 ft-lbs Page 19 Milne Point Unit S-47 SB Producer Drilling Procedure Page 20 Milne Point Unit S-47 SB Producer Drilling Procedure 12.8 Continue running 9-5/8” surface casing x Centralizers: 1 centralizer every 3rd joint to 200’ from surface x Fill casing while running using fill up line on rig floor. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x Centralization: o 1 centralizer every 2 joints to base of conductor 12.9 The last 2,000’ of 9-5/8” will be 47#, from 2,000’ to Surface x Ensure drifted to 8.525” 2500'2500' Page 21 Milne Point Unit S-47 SB Producer Drilling Procedure 12.10 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.11 Slow in and out of slips. 12.12 P/U landing joint and M/U to casing string. Position the casing shoe +/- 10’ from TD. Strap the landing joint prior to the casing job and mark the joint at (1) ft intervals to use as a reference when getting the casing on depth. 12.13 Lower casing to setting depth. Confirm measurements. 12.14 Have slips staged in cellar, along with necessary equipment for the operation. 12.15 Circulate and condition mud through CRT. Reduce YP to < 20 to help ensure success of cement job. Ensure adequate amounts of cold M/U water are available to achieve this. If possible reciprocate casing string while conditioning mud. Page 22 Milne Point Unit S-47 SB Producer Drilling Procedure 13.0 Cement 9-5/8” Surface Casing 13.1 Hold a pre-job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. x How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. x Which pumps will be utilized for displacement, and how fluid will be fed to displacement pump. x Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. x Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses x Review test reports and ensure pump times are acceptable. x Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 13.4 R/U cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 13.5 Fill surface cement lines with water and pressure test. 13.6 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug (flexible bypass plug) – HEC rep to witness. Mix and pump cement per below calculations for the 1st stage, confirm actual cement volumes with cementer after TD is reached. 13.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead & tail, TOC brought to stage tool. Estimated 1st Stage Total Cement Volume: 394 sx 452 sx Page 23 Milne Point Unit S-47 SB Producer Drilling Procedure Cement Slurry Design (1st Stage Cement Job): 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets “sticky”, cease pipe reciprocation and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. x Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very accurate using 0.0625 bps (5” liners) for the Quattro pump output. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: 5,992’ x .0758 bpf = 449.1 bbls 80 bbls of tuned spacer to be left behind stage tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, ±4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. 13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held, this is to ensure the stage tool is not prematurely opened. Lead Slurry Tail Slurry Density 12.0 lb/gal 15.8 lb/gal Yield 2.35 ft3/sk 1.16 ft3/sk Mix Water 13.92 gal/sk 4.98 gal/sk (2500' * .0732) + (3492' * .0758) = 447.7 bbls Page 24 Milne Point Unit S-47 SB Producer Drilling Procedure 13.16 Increase pressure to 3,300 psi to open circulating ports in stage collar. Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface and volume pumped to see the returns. Circulate until YP < 20 again in preparation for the 2nd stage of the cement job. 13.17 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker bypass line to the cuttings tank. Have black water available and vac trucks ready to assist. Ensure to flush out any rig components, hard lines and BOP stack that may have come in contact with the cement. Page 25 Milne Point Unit S-47 SB Producer Drilling Procedure Second Stage Surface Cement Job: 13.18 Prepare for the 2 nd stage as necessary. Circulate until first stage reaches sufficient compressive strength. Try to maintain flow rate through stage tool until 2nd stage is ready. Hold pre-job safety meeting. x Past wells have seen pressure increase while circulating through stage tool after reduced rate 13.19 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 13.20 Fill surface lines with water and pressure test. 13.21 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.22 Mix and pump cmt per below recipe for the 2 nd stage. 13.23 Cement volume based on annular volume + open hole excess (200% for lead and 100% for tail). Job will consist of lead & tail, TOC brought to surface. However cement will continue to be pumped until clean spacer is observed at surface. Estimated 2nd Stage Total Cement Volume: Cement Slurry Design (2nd stage cement job): Lead Slurry Tail Slurry System Permafrost L G Density 10.7 lb/gal 15.8 lb/gal Yield 4.41 ft3/sk 1.17 ft3/sk Mixed Water 22.02 gal/sk 5.08 gal/sk 268 sx 439 sx Page 26 Milne Point Unit S-47 SB Producer Drilling Procedure 13.24 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail. 13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. 13.26 Displacement calculation: 2500’ x 0.0758 bpf = 190 bbls mud 13.27 Monitor returns closely while displacing cement. Adjust pump rate if necessary. Wellhead side outlet valve in cellar can be opened to take returns to cellar if required. Be prepared to pump out fluid from cellar. Have black water available to retard setting of cement. 13.28 Decide ahead of time what will be done with cement returns once they are at surface. We should circulate approximately 100 - 150 bbls of cement slurry to surface. 13.29 Land closing plug on stage collar and pressure up to 1,000 – 1,500 psi to ensure stage tool closes. Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool has closed. Slips will be set as per plan to allow full annulus for returns during surface cement job. Set slips. 13.30 Make initial cut on 9-5/8” final joint. L/D cut joint. Make final cut on 9-5/8”. Dress off stump. Install 9-5/8” wellhead. If transition nipple is welded on, allow to cool as per schedule. Ensure to report the following on wellez: 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 nathan.sperry@hilcorp.com and joseph.lastufka@hilcorp.com This will be included with the EOW documentation that goes to the AOGCC. 2500' * 0.0732 = 183 bbls Page 27 Milne Point Unit S-47 SB Producer Drilling Procedure 14.0 ND Diverter, NU BOPE, & Test 14.1 ND the diverter T, knife gate, diverter line & NU 11” x 13-5/8” 5M casing spool. 14.2 NU 13-5/8” x 5M BOP as follows: x BOP configuration from top down: 13-5/8” x 5M annular / 13-5/8” x 5M double gate / 13- 5/8” x 5M mud cross / 13-5/8” x 5M single gate x Double gate ram should be dressed with 2-7/8” x 5-1/2” VBRs in top cavity,blind ram in bottom cavity. x Single ram can be dressed with 2-7/8” x 5-1/2” VBRs or 5” solid body rams x NU bell nipple, install flowline. x Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to mud cross). x Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual valve 14.3 RU MPD RCD and related equipment 14.4 Run 5” BOP test plug 14.5 Test BOP to 250/3,000 psi for 5/5 min. Test annular to 250/2,500 psi for 5/5 min. x Test with 5” test joint and test VBR’s with 3-1/2” test joint x Confirm test pressures with PTD x Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug x Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 14.6 RD BOP test equipment 14.7 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.8 Mix 8.9 ppg Baradrill-N fluid for production hole. 14.9 Set wearbushing in wellhead. 14.10 If needed, rack back as much 5” DP in derrick as possible to be used while drilling the hole section. 14.11 Ensure 5” liners in mud pumps. 24 hour notice to AOGCC. Page 28 Milne Point Unit S-47 SB Producer Drilling Procedure 15.0 Drill 8-1/2” Hole Section 15.1 MU 8-1/2” Cleanout BHA (Milltooth Bit & 1.22° PDM) 15.2 TIH w/ 8-1/2” cleanout BHA to stage tool. Note depth TOC tagged on AM report. Drill out stage tool. 15.3 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 15.4 RU and test casing to 2,500 psi / 30 min. Ensure to record volume / pressure (every ¼ bbl) and plot on FIT graph. AOGCC reg is 50% of burst = 5,750 / 2 = ~2,875 psi, but max test pressure on the well is 2,500 psi as per AOGCC. Document incremental volume pumped (and subsequent pressure) and volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 15.5 Drill out shoe track and 20’ of new formation. 15.6 CBU and condition mud for FIT. 15.7 Conduct FIT to 12.0 ppg EMW. Chart Test. Ensure test is recorded on same chart as FIT. Document incremental volume pumped (and subsequent pressure) and volume returned. 15.8 POOH and LD cleanout BHA 15.9 PU 8-1/2” directional BHA. x Ensure BHA components have been inspected previously. x Drift and caliper all components before MU. 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 Ensure MWD is RU and operational. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. x Drill string will be 5” 19.5# S-135 DS50 & NC50. x Run a ported float in the production hole section. Schrader Bluff Bit Jetting Guidelines Formation Jetting TFA NB 6 x 14 0.902 OA 6 x 13 0.778 OB 6 x 13 0.778 Casing test and FIT digital data to AOGCC for review. Page 29 Milne Point Unit S-47 SB Producer Drilling Procedure 15.10 8-1/2” hole section mud program summary: x Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. x Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. x Rheology: Keep viscosifier additions to an absolute minimum (N-VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8.5 (hole diameter) for sufficient hole cleaning x Run the centrifuge continuously while drilling the production hole, this will help with solids removal. x Dump and dilute as necessary to keep drilled solids to an absolute minimum. x MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, & Toolpusher office. System Type:8.9 – 9.5 ppg Baradrill-N drilling fluid Properties: Interval Density PV YP LSYP Total Solids MBT HPH T Hardness Production 8.9-9.5 15-25 - ALAP 15 - 30 4-6 <10% <8 <11.0 <100 System Formulation: Product Concentration Water KCL KOH N-VIS DEXTRID LT BARACARB 5 BARACARB 25 BARACARB 50 BARACOR 700 BARASCAV D X-CIDE 207 0.955 bbl 11 ppb 0.1 ppb 1.0 – 1.5 ppb 5 ppb 4 ppb 4 ppb 2 ppb 1.0 ppb 0.5 ppb 0.015 ppb Page 30 Milne Point Unit S-47 SB Producer Drilling Procedure 15.11 TIH with 8-1/2” directional assembly to bottom 15.12 Install MPD RCD 15.13 Displace wellbore to 8.9 ppg Baradrill-N drilling fluid 15.14 Begin drilling 8-1/2” hole section, on-bottom staging technique: x Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8K. x Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations x If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to PU off bottom and restart on bottom staging technique. If stick slip continues, consider adding 0.5% lubes 15.14 Drill 8-1/2” hole section to section TD per Geologist and Drilling Engineer. x Flow Rate: 350-550 GPM, target min. AV’s 200 ft/min, 385 GPM x RPM: 120+ x Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly wet to maximize solids removal efficiency. Check for holes in screens on every connection. x Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low x Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection x Monitor Torque and Drag with pumps on every 5 stands x Monitor ECD, pump pressure & hookload trends for hole cleaning indication x Surveys can be taken more frequently if deemed necessary. x Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. x Use ADR to stay in section. Reservoir plan is to stay in NB sand. x Limit maximum instantaneous ROP to < 250 FPH. The sands will drill faster than this, but when concretions are hit when drilling this fast, cutter damage can occur. x Target ROP is as fast as we can clean the hole without having to backream connections x Schrader Bluff NB Concretions: 4-6% Historically x MPD will be utilized to monitor pressure build up on connections. x 8-1/2” Lateral A/C: x S-27L1 has a clearance factor of 0.790. S-27L1 is a long term shut-in Schrader producer that will remain shut-in. There is no HSE risk due to a collision. x S-32 is a long term shut-in Schrader producer with a clearance factor of 0.590. There is no HSE risk associated with a collision. S-32 is scheduled to be P&A’d with cement. x S-34L2 has a separation factor of 0.826. S-34L2 will be P&A’d prior to drilling S- 47. There is no HSE risk due to a collision. x S-35/35PB2 has a separation factor of 0.243. This was a Schrader Bluff producer that will be shut-in and scheduled for a reservoir P&A. There is no HSE risk due to a collision. Page 31 Milne Point Unit S-47 SB Producer Drilling Procedure 15.15 Reference:Halliburton has a procedure for Schrader OH sidetracks based on lessons learned and best practices. Ensure the DD is referencing their procedure. x Patience is key! Getting kicked off too quickly might have been the cause of failed liner runs on past wells. x If a known fault is coming up, put a slight “kick-off ramp” in wellbore ahead of the fault so we have a nice place to low side. x Attempt to lowside in a fast drilling interval where the wellbore is headed up. x Orient TF to low side and dig a trough with high flowrates for the first 30 feet, working string back and forth. Trough for approximately 30 minutes. x Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. 15.16 At TD, CBU at least 4 times at 200 ft/min AV (385+ GPM) and rotation (120+ RPM). Pump tandem sweeps if needed x Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent stream, circulate more if necessary x If seepage losses are seen while drilling, consider reducing MW at TD to 9.0 ppg minimum 15.17 Mix and pump 40 bbl 10 ppb SAPP pill. Line up to a closed loop system and circulate three SAP pills with 50 bbl in between. Displace out SAP pills. Monitor shakers for returns of mud filter cake and calcium carbonate. Circulate the well clean. Losses during the cleanup of the wellbore are a good indication that the mud filter cake is being removed, including an increase in the loss rate. 15.18 Displace 1.5 OH + liner volume with viscosified brine. x Proposed brine blend (same as used on M-16, aiming for an 8 on the 6 RPM reading) - KCl: 7.1ppb for 2% NaCl: 60.9ppg for 9.4ppg Lotorq: 1.5% Lube 776: 1.5% Soda Ash: as needed for 9.5pH Busan 1060: 0.42ppb Flo-Vis Plus: 1.25ppb x Monitor well for loss rate and contact Drilling Engineer and/or Ops Engineer if further discussion needed prior to BROOH. Assure brine is overbalanced to pore pressure. Page 32 Milne Point Unit S-47 SB Producer Drilling Procedure 15.19 BROOH with the drilling assembly to the 9-5/8” casing shoe x Circulate at full drill rate (less if losses are seen, 350 GPM minimum). x Rotate at maximum RPM that can be sustained. x Pulling speed 5 – 10 min/stand (slip to slip time, not including connections), adjust as dictated by hole conditions x If backreaming operations are commenced, continue backreaming to the shoe 15.20 If abnormal pressure has been observed in the lateral, utilize MPD to close on connections while BROOH. 15.21 CBU minimum two times at 9-5/8” shoe and clean casing with high vis sweeps. 15.22 Monitor well for flow/pressure build up with MPD. Increase fluid weight if necessary. x Wellbore breathing has been seen on past MPU SB wells. Perform extended flow checks to determine if the well is breathing, treat all flow as an influx until proven otherwise. 15.23 POOH and LD BHA. 15.24 Continue to POOH and stand back BHA if possible. Rabbit DP on TOOH, ensure rabbit diameter is sufficient for future ball drops. Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any additional logging runs conducted. Page 33 Milne Point Unit S-47 SB Producer Drilling Procedure 16.0 Run 4-1/2” Screened Liner 16.1 Well control preparedness: In the event of an influx of formation fluids while running the 4- 1/2” screened liner, the following well control response procedure will be followed: x P/U & M/U the 5” safety joint (with 4-1/2” crossover installed on bottom, TIW valve in open position on top, 4-1/2” handling joint above TIW). This joint shall be fully M/U and available prior to running the first joint of 4-1/2” Predrilled liner. x Slack off and with 5” DP across the BOP, shut in ram or annular on 5” DP. Close TIW. x Proceed with well kill operations. 16.2 R/U 4-1/2” liner running equipment. x Ensure 4-1/2” 13.5# Hydril 625 x DS-50 crossover is on rig floor and M/U to FOSV. x Ensure all casing has been drifted on the deck prior to running. x Be sure to count the total # of joints on the deck before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 16.3 Run 4-1/2” screened production liner x Use API Modified or “Best O Life 2000 AG”thread compound. Dope pin end only w/ paint brush. Wipe off excess. x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Run round nose float shoe on bottom. x 4-1/2” screened liner will auto –fill x 4-1/2” Liner will be centralized with 1/joint free floating x If needed, install swell packers as per the lower completion tally. x Remove protective packaging on swell packers just prior to picking up x Do not place tongs or slips on the packer element 4-1/2” 13.5# L-80 Hydril 625 Torque OD Minimum Optimum Maximum 4-1/2 8,000 ft-lbs 9,600 ft-lbs 12,800 ft-lbs Page 34 Milne Point Unit S-47 SB Producer Drilling Procedure Page 35 Milne Point Unit S-47 SB Producer Drilling Procedure 16.6. Ensure to run enough liner to provide for approx 150’ overlap inside 9-5/8” casing. Ensure hanger/pkr will not be set in a 9-5/8” connection. x AOGCC regulations require a minimum 100’ overlap between the inner and outer strings as per 20 AAC 25.030(d)(6). Do not place liner hanger/packer across 9-5/8” connection. 16.7. Before picking up Baker SLZXP liner hanger / packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 16.8. M/U Baker SLZXP liner top packer to 4-1/2” liner. 16.9. Note: PU, SO, ROT and torque of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 16.10. RIH with liner no faster than 30 ft/min – this is to prevent buckling the liner and drill string and weight transfer to get liner to bottom with minimal rotation. Watch displacement carefully and avoid surging the hole or buckling the liner. Slow down running speed if necessary. x Ensure 5” DP/HWDP has been drifted x There is no inner string planned to be run, as opposed to previous wells. The DP should auto fill. Monitor FL and if filling is required due to losses/surging. 16.11. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + SO depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 16.12. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, & 20 RPM. 16.13. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.14. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.15. Rig up to pump down the work string with the rig pumps. 16.16. Break circulation. Begin circulating at ~1 BPM and monitor pump pressures. Do not exceed 1,600 psi while circulating.Pusher tool is set at 2,100 psi with 5% shear screws but it should be discussed before exceeding 1,600 psi. Note all losses. Confirm all pressures with Baker 16.17. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. Page 36 Milne Point Unit S-47 SB Producer Drilling Procedure 16.18. Shut down pumps. Drop setting ball (ball seat now located in HRDE setting tool and not at the WIV) down the workstring and pump slowly (1-2 BPM). Slow pump before the ball seats. Do not allow ball to slam into ball seat. 16.19. Continue pressuring up to 2,700 psi to set the SLZXP liner hanger/packer. Hold for 5 minutes. Slack off 20K lbs on the SZXP liner hanger/packer to ensure the HRDE setting tool is in compression for release from the SLZXP liner hanger/packer. Continue pressuring up 4,500 psi to release the HRDE running tool. 16.20. Bleed DP pressure to 0 psi. Pick up to expose rotating dog sub and set down 50K without pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20 RPM and set down 50K again. 16.21. PU to neutral weight, close BOP and test annulus to 1,500 psi for 10 minutes charted. 16.22. Bleed off pressure and open BOPE. Pickup to verify that the HRD setting tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. 16.23. PU pulling running tool free of the packer and displace with at max rate to wash the liner top. Pump sweeps as needed. 16.24. POOH. LD and inspect running tools. If setting of liner hanger/packer proceeded as planned, LD DP on the TOOH. Note: Once running tool is LD, swap to the completion AFE. Page 37 Milne Point Unit S-47 SB Producer Drilling Procedure 17.0 Run 7” Tieback 17.1 RU and pull wear bushing. Get an accurate measurement of RKB to tubing hanger load shoulder to be used for tie-back space out calculation. Install 7” solid body casing rams in the upper ram cavity. RU testing equipment. PT to 250/3,000 psi with 7” test joint. RD testing equipment. 17.2 RU 7” casing handling equipment. x Ensure XO to DP made up to FOSV and ready on rig floor. x Rig up computer torque monitoring service. x String should stay full while running, RU fill up line and check as appropriate. 17.3 PU 7” tieback seal assembly and set in rotary table. Ensure 7” seal assembly has (4) 1” holes above the first seal. These holes will be used to spot diesel freeze protect in the 9-5/8” x 7” annulus. 17.4 MU first joint of 7” to seal assy. 17.6 Run 7”, 26#, L-80 TXP tieback to position seal assembly two joints above tieback sleeve. Record PU and SO weights. 7”, 26#, L-80, TXP =Casing OD Torque (Min) Torque (Opt)Torque (Max)Torque (Operating) 7”13,280 ft-lbs 14,750 ft-lbs 16,230 ft-lbs 20,000 ft-lbs Page 38 Milne Point Unit S-47 SB Producer Drilling Procedure Page 39 Milne Point Unit S-47 SB Producer Drilling Procedure 17.7 MU 7” to DP crossover. 17.8 MU stand of DP to string, and MU top drive. 17.9 Break circulation at 1 BPM and begin lowering string. 17.10 Note seal assembly entering tieback sleeve with a pressure increase, stop pumping and bleed off pressure. Leave standpipe bleed off valve open. 17.11 Continue lowering string and land out on no-go. Set down 5 – 10K and mark the pipe as “NO- GO DEPTH”. 17.12 PU string & remove unnecessary 7” joints. 17.13 Space out with pups as needed to leave the no-go 1 ft above fully no-go position when the casing hanger is landed. Ensure one full joint is below the casing hanger. 17.14 PU and MU the 7” casing hanger. 17.15 Ensure circulation is possible through 7” string. 17.16 RU and circulation corrosion inhibited brine in the 9-5/8” x 7” annulus. 17.17 With seals stabbed into tieback sleeve, spot diesel freeze protection from 2,500’ TVD to surface in 9-5/8” x 7” annulus by reverse circulating through the holes in the seal assembly. Ensure annular pressure are limited to prevent collapse of the 7” casing (verify collapse pressure of 7” tieback seal assembly). 17.18 SO and land hanger. Confirm hanger has seated properly in wellhead. Make note of actual weight on hanger on morning report. 17.19 Back out the landing joint. MU packoff running tool and install packoff on bottom of landing joint. Set casing hanger packoff and RILDS. PT void to 3,000 psi for 10 minutes. 17.20 RD casing running tools. 17.21 PT 9-5/8” x 7” annulus to 1,000 psi for 30 minutes charted. Page 40 Milne Point Unit S-47 SB Producer Drilling Procedure 18.0 Run Upper Completion – Jet Pump 18.1 RU to run 4-1/2”, 12.6#, L-80 Hydril 521 tubing. x Ensure wear bushing is pulled. x Ensure 4-1/2”, L-80, 13.5#, Hydril 521 x XT-39 crossover is on rig floor and M/U to FOSV. x Ensure all tubing has been drifted in the pipe shed prior to running. x Be sure to count the total # of joints in the pipe shed before running. x Keep hole covered while RU casing tools. x Record OD’s, ID’s, lengths, SN’s of all components with vendor & model info. x Monitor displacement from wellbore while RIH. 18.2 PU, MU and RH with the following 4-1/2” JP completion (confirm tally with Operations Engineer): x WLEG/Mule shoe x XX joints, 4-1/2”, 12.6#, L-80, H521 x Crossover Pup, 4-1/2” TXPM Box x 4-1/2” H521 Pin x Nipple, 3.813” XN profile (3.750” no-go), 4-1/2”, TXPM (RHC plug body installed) x Crossover Pup, 4-1/2”, H521 Box x 4-1/2”, TXP Pin x 1 joint, 4-1/2”, 12.6#, L-80, H521 x Crossover Pup, 4-1/2” TC-II Box x 4-1/2” H521 Pin x Retrievable Packer, Baker, 4-1/2”, 12.6#, L-80, TC-II x Crossover Pup, 4-1/2”, H521 Box x 4-1/2”, TC-II Pin x 1 joint, 4-1/2”, 12.6#, L-80, H521 x Pup joint, 4-1/2”, 12.6#, L-80, H521 x Crossover, 4-1/2”, EUE 8rd Box x 4-1/2”, H521 Pin x Ported Pressure Sub, 4-1/2”, 12.6#, L-80, EUE 8rd x Crossover, 4-1/2”, H521 Box x 4-1/2”, EUE 8rd Pin x Sliding Sleeve, 4-1/2”, 12.6#, L-80 Hydril 521 x Crossover, 4-1/2”, EUE 8rd Box x 4-1/2”, H521 Pin x Gauge Carrier, 4-1/2”, 12.6#, L-80, EUE 8rd x Crossover, 4-1/2”, H521 Box x 4-1/2”, EUE 8rd Pin x Pup joint, 4-1/2”, 12.6#, L-80, H521 x XXX joints, 4-1/2”, 12.6#, L-80, H521 18.3 PU and MU the 4-1/2” tubing hanger. Make final splice of the TEC wire and ensure any unsued control line ports are dummied off. Page 41 Milne Point Unit S-47 SB Producer Drilling Procedure 18.4 Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. 18.5 Land the tubing hanger and RILDS. Lay down the landing joint. 18.6 Install 4” HP BPV. ND BOP. Install the plug off tool. 18.7 NU the tubing head adapter and NU the tree. 18.8 PT the tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 18.9 Pull the plug off tool and BPV. 18.10 Reverse circulate the well over to corrosion inhibited source water follow by diesel freeze protect to 2,500’ MD. 18.11 Drop the ball & rod. 18.12 Pressure up on the tubing to 3,500 psi to set the packer. PT the tubing to 3,500 psi for 30 minutes (charted). 18.13 Bleed the tubing pressure to 2,000 psi and PT the IA to 3,500 psi for 30 minutes (charted). Bleed both the IA and tubing to 0 psi. 18.14 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 18.15 RDMO Innovation Page 42 Milne Point Unit S-47 SB Producer Drilling Procedure 19.0 Innovation Rig Diverter Schematic Page 43 Milne Point Unit S-47 SB Producer Drilling Procedure 20.0 Innovation Rig BOP Schematic Page 44 Milne Point Unit S-47 SB Producer Drilling Procedure 21.0 Wellhead Schematic Page 45 Milne Point Unit S-47 SB Producer Drilling Procedure 22.0 Days Vs Depth Page 46 Milne Point Unit S-47 SB Producer Drilling Procedure 23.0 Formation Tops & Information Page 47 Milne Point Unit S-47 SB Producer Drilling Procedure Page 48 Milne Point Unit S-47 SB Producer Drilling Procedure 24.0 Anticipated Drilling Hazards 12-1/4” Hole Section: Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates Gas hydrates are generally not seen on S-pad. They were reported between 1000’ and 2000’ MD on S- 15 (2002). Remember that hydrate gas behaves differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates, but can help control the breakout at surface. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non-pressurized mud scale. The non-pressurized scale will reflect the actual mud cut weight. Isolate/dump contaminated fluid to remove hydrates from the system. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECD’s to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPM’s when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti-Collison: There are no known wells with a clearance factory <1.0. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Well Specific A/C: x There are no wells with a clearance factor of <1.0 Wellbore stability (Permafrost, running sands and gravel, conductor broaching): Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations between surge and swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. Page 49 Milne Point Unit S-47 SB Producer Drilling Procedure H2S: Treat every hole section as though it has the potential for H2S. MPU S-pad is not known for H2S. Three samples containing H2S have been captured. S-08 had 50 ppm measured in 2012. S-12 had 28.9 ppm measured in 2012. S-39 had 2 ppm measured in 2014. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 50 Milne Point Unit S-47 SB Producer Drilling Procedure 8-1/2” Hole Section: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of > 300 gpm Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: There are no planned fault crossings for S-47. H2S: Treat every hole section as though it has the potential for H2S. MPU S-pad is not known for H2S. Three samples containing H2S have been captured. S-08 had 50 ppm measured in 2012. S-12 had 28.9 ppm measured in 2012. S-39 had 2 ppm measured in 2014. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: Reservoir pressures are expected to be normal. Utilize MPD to mitigate any abnormal pressure seen. Anti-Collision Take directional surveys every stand, take additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic interference with another well. Reference A/C report in directional plan. Well Specific AC: x S-27L1 has a clearance factor of 0.790. S-27L1 is a long term shut-in Schrader producer that will remain shut-in. There is no HSE risk due to a collision. x S-32 is a long term shut-in Schrader producer with a clearance factor of 0.590. There is no HSE risk associated with a collision. S-32 is scheduled to be P&A’d with cement. x S-34L2 has a separation factor of 0.826. S-34L2 will be P&A’d prior to drilling S- 47. There is no HSE risk due to a collision. Page 51 Milne Point Unit S-47 SB Producer Drilling Procedure x S-35/35PB2 has a separation factor of 0.243. This was a Schrader Bluff producer that will be shut-in and scheduled for a reservoir P&A. There is no HSE risk due to a collision. MPU S-21 - See email attached at end of this PTD. (page 133) MPU S-24 - See email attached at end of this PTD. (page 133) Page 52 Milne Point Unit S-47 SB Producer Drilling Procedure 25.0 Innovation Rig Layout Page 53 Milne Point Unit S-47 SB Producer Drilling Procedure 26.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Ensure that casing test and subsequent FIT tests are recorded on the same chart. Document incremental volume pumped and returned during test. Page 54 Milne Point Unit S-47 SB Producer Drilling Procedure 27.0 Innovation Rig Choke Manifold Schematic Page 55 Milne Point Unit S-47 SB Producer Drilling Procedure 28.0 Casing Design Page 56 Milne Point Unit S-47 SB Producer Drilling Procedure 29.0 8-1/2” Hole Section MASP Page 57 Milne Point Unit S-47 SB Producer Drilling Procedure 30.0 Spider Plot (NAD 27) (Governmental Sections) Page 58 Milne Point Unit S-47 SB Producer Drilling Procedure 31.0 Surface Plat (As Built) (NAD 27) !""# Superceded on successive Report (following) 06001200180024003000360042004800True Vertical Depth (1200 usft/in)-2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000Vertical Section at 330.00° (1200 usft/in)MPU S-47 wp05 CP1MPU S-47 wp05 HeelMPU S-47 wp05 CP2MPU S-47 wp05 CP3MPU S-47 wp07 Tangent9 5/8" x 12 1/4"4 1/2" x 8 1/2"500100015002000250030003500400045005000550060006500 7000 7 500 8000 8500 90009500100001050011000115001200012500 1300013500140001450014973 MPU S-47 wp07Start Dir 3º/100' : 250' MD, 250'TVDStart Dir 4º/100' : 550' MD, 548.77'TVDStart Dir 4º/100' : 800' MD, 791.03'TVDEnd Dir : 1545.8' MD, 1409.28' TVDStart Dir 4º/100' : 3830.76' MD, 2951.13'TVDBegin Pump TangentEnd Dir : 5660.38' MD, 3862.56' TVDStart Dir 4º/100' : 5810.38' MD, 3889.9'TVDEnd Pump TangentEnd Dir : 6112.11' MD, 3915.96' TVDStart Dir 2º/100' : 6460.45' MD, 3912.43'TVDEnd Dir : 8546.11' MD, 3888.77' TVDStart Dir 2º/100' : 9109.71' MD, 3887.35'TVDEnd Dir : 9470.72' MD, 3896.62' TVDStart Dir 2º/100' : 11716.41' MD, 4032.92'TVDEnd Dir : 12500.68' MD, 4065.3' TVDStart Dir 2º/100' : 12532.62' MD, 4065.08'TVDEnd Dir : 13343.07' MD, 4062.59' TVDTotal Depth : 14973.07' MD, 4064.3' TVDBPRFUG3 CoalUG2 CoalLA3LA1UG MAUG MBUG MCUG MDUG MESB_NB (target)Hilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: MPU S-4737.80+N/-S +E/-W NorthingEastingLatittude Longitude0.00 0.005999842.08 565319.63 70° 24' 36.081 N 149° 28' 5.262 WSURVEY PROGRAMDate: 2021-02-04T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool26.50 650.00 MPU S-47 wp07 (MPU S-47) 3_Gyro-GC_Csg650.00 6112.00 MPU S-47 wp07 (MPU S-47) 3_MWD+IFR2+MS+Sag6112.00 14973.07 MPU S-47 wp07 (MPU S-47) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSTVDPath TVDssPath MDPath Formation1866.02 1801.72 2222.68 BPRF2893.51 2829.21 3745.37 UG3 Coal3146.08 3081.78 4122.27 UG2 Coal3481.46 3417.16 4668.40 LA33557.29 3492.99 4810.06 LA13718.03 3653.73 5162.63 UG MA3756.03 3691.73 5264.56 UG MB3773.10 3708.80 5314.40 UG MC3804.76 3740.46 5416.11 UG MD3873.32 3809.02 5719.42 UG ME3914.21 3849.91 6020.83 SB_NB (target)3925.50 3861.20 9946.48 SB NAREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU S-47, True NorthVertical (TVD) Reference:MPU S-47 As-built RKB @ 64.30usftMeasured Depth Reference: MPU S-47 As-built RKB @ 64.30usftCalculation Method:Minimum CurvatureProject:Milne PointSite:M Pt S PadWell:Plan: MPU S-47Wellbore:MPU S-47Design:MPU S-47 wp07CASING DETAILSTVD TVDSS MD SizeName3915.96 3851.66 6112.11 9-5/8 9 5/8" x 12 1/4"4064.30 4000.00 14973.07 4-1/2 4 1/2" x 8 1/2"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 26.50 0.00 0.00 26.50 0.00 0.00 0.00 0.00 0.002 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 250' MD, 250'TVD3 550.00 9.00 200.00 548.77 -22.10 -8.04 3.00 200.00 -15.11 Start Dir 4º/100' : 550' MD, 548.77'TVD4 800.00 19.00 200.00 791.03 -78.86 -28.70 4.00 0.00 -53.94 Start Dir 4º/100' : 800' MD, 791.03'TVD5 1545.80 47.56 217.25 1409.28 -419.74 -241.64 4.00 26.10 -242.69 End Dir : 1545.8' MD, 1409.28' TVD6 3830.76 47.56 217.25 2951.13 -1762.07 -1262.37 0.00 0.00 -894.81 Start Dir 4º/100' : 3830.76' MD, 2951.13'TVD7 5660.38 79.50 294.00 3862.56 -1961.51 -2692.72 4.00 88.95 -352.36 MPU S-47 wp07 Tangent Begin Pump Tangent8 5810.38 79.50 294.00 3889.90 -1901.53 -2827.46 0.00 0.00 -233.04 Start Dir 4º/100' : 5810.38' MD, 3889.9'TVD9 6112.11 90.58 298.81 3915.96 -1767.99 -3096.15 4.00 23.65 16.95 End Dir : 6112.11' MD, 3915.96' TVD10 6460.45 90.58 298.81 3912.43 -1600.12 -3401.36 0.00 0.00 314.93 Start Dir 2º/100' : 6460.45' MD, 3912.43'TVD11 7120.14 91.00 312.00 3903.30 -1218.81 -3937.81 2.00 88.09 913.39 MPU S-47 wp05 CP112 8546.11 90.14 340.51 3888.77 -45.35 -4721.73 2.00 91.54 2321.59 End Dir : 8546.11' MD, 3888.77' TVD13 9109.71 90.14 340.51 3887.35 485.96 -4909.78 0.00 0.00 2875.74 Start Dir 2º/100' : 9109.71' MD, 3887.35'TVD14 9406.34 87.56 345.85 3893.30 769.71 -4995.57 2.00 115.86 3164.37 MPU S-47 wp05 CP215 9470.72 86.52 346.61 3896.62 832.15 -5010.87 2.00 143.86 3226.10 End Dir : 9470.72' MD, 3896.62' TVD16 11716.41 86.52 346.61 4032.92 3012.78 -5529.94 0.00 0.00 5374.11 Start Dir 2º/100' : 11716.41' MD, 4032.92'TVD17 12146.93 87.00 338.00 4057.30 3421.88 -5660.46 2.00 -87.06 5793.66 MPU S-47 wp05 CP318 12500.68 90.41 331.80 4065.30 3741.93 -5810.41 2.00 -61.30 6145.81 End Dir : 12500.68' MD, 4065.3' TVD19 12532.62 90.41 331.80 4065.08 3770.08 -5825.50 0.00 0.00 6177.74 Start Dir 2º/100' : 12532.62' MD, 4065.08'TVD20 13343.07 89.94 348.00 4062.59 4528.62 -6103.10 2.00 91.62 6973.45 End Dir : 13343.07' MD, 4062.59' TVD21 14973.07 89.94 348.00 4064.30 6123.00 -6442.00 0.00 0.00 8523.67 Total Depth : 14973.07' MD, 4064.3' TVDSuperceded -2250 -1800 -1350 -900 -450 0 450 900 1350 1800 2250 2700 3150 3600 4050 4500 4950 5400 5850 6300 South(-)/North(+) (900 usft/in)-6300 -5850 -5400 -4950 -4500 -4050 -3600 -3150 -2700 -2250 -1800 -1350 -900 -450 0 West(-)/East(+) (900 usft/in) MPU S-47 wp07 Tangent MPU S-47 wp05 CP3 MPU S-47 wp05 CP2 MPU S-47 wp05 Heel MPU S-47 wp05 CP1 9 5/8" x 12 1/4" 4 1/2" x 8 1/2" 250 500750 1000 1250 1500 175 0 2000 2250 2500 275 0 3 0 0 0 3250350037504 0 0 0 4 0 6 4 MPU S-47 wp07 Start Dir 3º/100' : 250' MD, 250'TVD Start Dir 4º/100' : 550' MD, 548.77'TVD Start Dir 4º/100' : 800' MD, 791.03'TVD End Dir : 1545.8' MD, 1409.28' TVD Start Dir 4º/100' : 3830.76' MD, 2951.13'TVD End Dir : 5660.38' MD, 3862.56' TVD Begin Pump Tangent Start Dir 4º/100' : 5810.38' MD, 3889.9'TVD End Pump Tangent End Dir : 6112.11' MD, 3915.96' TVD Start Dir 2º/100' : 6460.45' MD, 3912.43'TVD End Dir : 8546.11' MD, 3888.77' TVD Start Dir 2º/100' : 9109.71' MD, 3887.35'TVD End Dir : 9470.72' MD, 3896.62' TVD Start Dir 2º/100' : 11716.41' MD, 4032.92'TVD End Dir : 12500.68' MD, 4065.3' TVD Start Dir 2º/100' : 12532.62' MD, 4065.08'TVD End Dir : 13343.07' MD, 4062.59' TVD Total Depth : 14973.07' MD, 4064.3' TVD CASING DETAILS TVD TVDSS MD Size Name 3915.96 3851.66 6112.11 9-5/8 9 5/8" x 12 1/4" 4064.30 4000.00 14973.07 4-1/2 4 1/2" x 8 1/2" Project: Milne Point Site: M Pt S Pad Well: Plan: MPU S-47 Wellbore: MPU S-47 Plan: MPU S-47 wp07 WELL DETAILS: Plan: MPU S-47 37.80 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 5999842.08 565319.63 70° 24' 36.081 N 149° 28' 5.262 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: MPU S-47, True North Vertical (TVD) Reference: MPU S-47 As-built RKB @ 64.30usft Measured Depth Reference:MPU S-47 As-built RKB @ 64.30usft Calculation Method:Minimum Curvature Superceded -2250 -1800 -1350 -900 -450 0 450 900 1350 1800 2250 2700 3150 3600 4050 4500 4950 5400 5850 6300 South(-)/North(+) (900 usft/in)-6300 -5850 -5400 -4950 -4500 -4050 -3600 -3150 -2700 -2250 -1800 -1350 -900 -450 0 West(-)/East(+) (900 usft/in) 250500750 1000 1250 1500 1750 2000 2250 2500 2750 3 0 0 03 250350037504 0 0 0 MPU S-46i wp08 250 5007 5 0 1 0 0 01 2 5 0 1 5 0 0 1 7 5 0 2 0 0 0 2 25 0 2 5 0 0 2 7 5 0 3 0 0 0 32 5 0 35003750MPU S-48i wp04 47505000525055005 7 5 0 60006250650067506893MPH-06 MPH-17 MPU S-203 37503648MPU S-203PB1MPU S-203PB2 37503573MPU S-202 wp10 - as-built updates 2250250027503000325035003750 3649MPS-22 37504000MPU S-56PB1 4 0 0 0 MPU S-44i wp06 17502000225025002750300032503500375040004204MPS-30 MPS-27L1 37504000MPS-27 1750200022502500275030003250350037503911MPS-27PB1 20002250250027503000325035003750400042504417MPS-21 3250350037504 0 0 0 MPU S-45 4 0 0 0 3969MPS-24PB2 3882MPS-24 MPS-25L1 200022502500275030003250350037504000MPS-25 2 2 5 0 250027503000325035003750400042504271MPS-26 2000225025002750300032503500375040004175MPS-14 1500175020002250250027503000325035003750MPS-32 MPS-34L2 MPS-34L1 1500175020002250250027503000325035003750MPS-34 4 1 2 8 MPS-35PB2 MPS-35 1250150017502000225025002750300032503500MPS-35PB1 2 0 0 022 50250027503000325035003750400042504256MPS-31 9 5/8" x 12 1/4" 4 1/2" x 8 1/2" 250 500750 1000 1250 1500 1 750 200 0 2250 2500 2750 3 0 0 0 3250350037504 0 0 0 4 0 6 4 MPU S-47 wp07 Project: Milne Point Site: M Pt S Pad Well: Plan: MPU S-47 Wellbore: MPU S-47 Plan: MPU S-47 wp07 Superceded $ # % & " # ' ()* ' + + , -&# . !"#$%&' ( * / )' *, *+,- * . * ' !"#$%&' ( 0 . 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"#$%$ )*' + , '-() &./ 01112#32400*13*5-$6#7*3284#1627038/.' () ! "#$ "9 :;<#3* & ( 303 &3 ')3 = 030; 15 ! 3> &&! 3 +5 3 &4?@ ?; >A B5 !( & C&( B B Superceded & ! "#$" ! "#$%$ /4 "/94 "'(< ')- &. '- &.5 - &.< ') &> ! 3> &&! 3 +5 3 & 4 ( 303 &3 ')3 )*' + , '-() &.&'( " ! "#$" ! "#$" ! "#$%$ ')- &. ; /( !" "" # " "" "" !" "" # " "" "" "" # " "" !" "" !" "" "" $ $ "" $ $ # " "" $ $ !" "" !" "" "" % % "" "" # " "" !" "" !" "" # " "" "" % % !" "" % % # " "" % % "" Superceded & ! "#$" ! "#$%$ /4 "/94 "'(< ')- &. '- &.5 - &.< ') &> ! 3> &&! 3 +5 3 & 4 ( 303 &3 ')3 )*' + , '-() &.&'( " ! "#$" ! "#$" ! "#$%$ ')- &. ; /( $ $ !" "" $ $ # " "" $ $ "" !" "" # " "" "" !" "" # " "" "" !" "" # " "" "" !" "" # " "" "" % % !" "" % % # " "" % % "" % % !" "" % % # " "" % % "" !" "" # " "" "" $ $ !" "" $ $ # " "" $ $ "" $ $ !" "" $ $ # " "" $ $ "" Superceded & ! "#$" ! "#$%$ /4 "/94 "'(< ')- &. '- &.5 - &.< ') &> ! 3> &&! 3 +5 3 & 4 ( 303 &3 ')3 )*' + , '-() &.&'( " ! "#$" ! "#$" ! "#$%$ ')- &. ; /( !" "" # " "" "" !" "" # " "" "" !" "" # " "" "" $ $ !" "" $ $ # " "" $ $ "" $ $ !" "" $ $ # " "" $ $ "" !" "" # " "" ""& & & !" ""& & & # " ""& & & ""& & $& $ !" ""& & $& $ # " ""& & $& $ ""& & $& $ !" ""& & $& $ # " ""& & $& $ ""& & & !" ""& & & # " ""& & & "" Superceded & ! "#$" ! "#$%$ /4 "/94 "'(< ')- &. '- &.5 - &.< ') &> ! 3> &&! 3 +5 3 & 4 ( 303 &3 ')3 )*' + , '-() &.&'( " ! "#$" ! "#$" ! "#$%$ ')- &. ; /(& & $& $ # " ""& & $& $ "" '& & & ( !" "" '& & & ( # " "" '& & & ( "" '& & & ( "" '& & & ( !" "" '& & & ( !" "" '& & & ( # " "" '& & & ( "" '& & & ( !" "" '& & & ( # " "" '& & & ( "" '& & & ( !" "" '& & & ( # " "" '& & & ( "" > - &.B- &. , D , B & ( )* ) "+ & ( ),!-. /- - + & ( ),!-. /- - + Superceded & ! "#$" ! "#$%$# " 0" """1 2* " "3 1 " 4( "" 1 "" "1 5 " 6!" $( 5 "78!" $( 5 "# " 9!" $( ""3" +3 " 4( ( 4 " " "( 1 1" +3 010 1 2 1 03 Superceded 0.001.002.003.004.00Separation Factor0 325 650 975 1300 1625 1950 2275 2600 2925 3250 3575 3900 4225 4550 4875 5200 5525 5850 6175Measured Depth (650 usft/in)No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU S-47 NAD 1927 (NADCON CONUS)Alaska Zone 0437.80+N/-S+E/-W Northing Easting LatittudeLongitude0.000.005999842.08 565319.63 70° 24' 36.081 N 149° 28' 5.262 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU S-47, True NorthVertical (TVD) Reference:MPU S-47 As-built RKB @ 64.30usftMeasured Depth Reference:MPU S-47 As-built RKB @ 64.30usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2021-02-04T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 650.00 MPU S-47 wp07 (MPU S-47) 3_Gyro-GC_Csg650.00 6112.00 MPU S-47 wp07 (MPU S-47) 3_MWD+IFR2+MS+Sag6112.00 14973.07 MPU S-47 wp07 (MPU S-47) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 325 650 975 1300 1625 1950 2275 2600 2925 3250 3575 3900 4225 4550 4875 5200 5525 5850 6175Measured Depth (650 usft/in)MPU S-46i wp08MPU S-201 wp07MPU S-48i wp04MPS-43MPU S-56PB1MPU S-44i wp06MPU S-45MPS-24MPS-41NO GLOBAL FILTER: Using user defined selection & filtering criteria26.50 To 6112.00Project: Milne PointSite: M Pt S PadWell: Plan: MPU S-47Wellbore: MPU S-47Plan: MPU S-47 wp07Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name3915.96 3851.66 6112.11 9-5/8 9 5/8" x 12 1/4"4064.30 4000.00 14973.07 4-1/2 4 1/2" x 8 1/2"Superceded ! "#$ ! "#$ ! "#$%$&'( " ! "#$" ! "#$" ! "#$%$ )*' + , '-() &./ 01112#32400*13*5-$6#7*3284#1627038/.' () ! "#$ "9 :;<#3* & ( 3#1$*3$ &3 ')3 = 030; 15 ! 3> &&! 3 +5 3 &4?@ ?; >A B5 !( & C&( B B Superceded & ! "#$" ! "#$%$ /4 "/94 "'(< ')- &. '- &.5 - &.< ') &> ! 3> &&! 3 +5 3 & 4 ( 3#1$*3$ &3 ')3 )*' + , '-() &.&'( " ! "#$" ! "#$" ! "#$%$ ')- &. ; /( ! "" ! "" # " ! "" ! $" ! "" ! "" # " ! "" ! $" ! "" #30*3"3#21#1323#*$*3>> A " 3*2#$3"*30103#3$0#$3'> A " # " ! "" ! "" ! $" ! "" 23$*$3"31$2*3#2311*$3>> A " % % ! "" ! $" ! "" # " ! "" ! "" & & ! $" ! "" & & # " ! "" & & ! "" ! "" ! $" ! "" # " ! "" ! "" & �"3*2$#3$321230'> A " & &03#3"#302$23#3$23>> A " Superceded & ! "#$" ! "#$%$ /4 "/94 "'(< ')- &. '- &.5 - &.< ') &> ! 3> &&! 3 +5 3 & 4 ( 3#1$*3$ &3 ')3 )*' + , '-() &.&'( " ! "#$" ! "#$" ! "#$%$ ')- &. ; /( & &0303"#312$3$3$135 > A " ! "" # " ! "" ! $" ! "" ! $" ! "" # " ! "" ! "" 03$*$3"*32#0#31301$*$3>> A " ##31$23#0"13$12#*32#3$23#0'> A " ! $" ! "" # " ! "" ! "" & & ! $" ! "" & & # " ! "" & & ! "" & &$#30#03#0"#3$21332*0#03#0'> A " & &$30#0*$3"323#32#0*$3>> A " $30##130"2031#0323#*##130>> A " #3##03"3#*$3#3*0#035 > A " % % ! $" ! "" % % # " ! "" % % ! "" % %$30##130"230#0323#*##130>> A " % %#3##03"3#*$3#3*##035 > A "' ' ' # " ! ""' ' ' ! ""' ' %' % # " ! ""' ' %' % ! $" ! ""' ' %' % ! ""' ' %' % # " ! "" Superceded & ! "#$" ! "#$%$ /4 "/94 "'(< ')- &. '- &.5 - &.< ') &> ! 3> &&! 3 +5 3 & 4 ( 3#1$*3$ &3 ')3 )*' + , '-() &.&'( " ! "#$" ! "#$" ! "#$%$ ')- &. ; /(' ' %' % ! "" !(' ' ' ) ! "" !(' ' ' ) # " ! "" !(' ' ' ) ! "" !(' ' ' ) ! "" !(' ' ' ) # " ! "" !(' ' ' ) ! "" > - &.B- &. , D , B ' ) *+ * ", ' ) *- $. / 0. . , ' ) *- $. / 0. . ,# " 1 " """2 3+ !!" !"4 2 " !5 )! "" 2 ""! "2 6 " ! 7 $" !%)! 6 "89$" !%)! 6 "# " !:$" !%)!! ""4" ,4 !" !5 )!) 5 ! " " ! ! ") 2 2"!,4!1 21 2 3 2 1 4 Superceded 0.001.002.003.004.00Separation Factor6175 6650 7125 7600 8075 8550 9025 9500 9975 10450 10925 11400 11875 12350 12825 13300 13775 14250 14725 15200Measured Depth (950 usft/in)MPH-17MPU S-203MPU S-203PB1MPU S-203PB2MPU S-202 wp10 - as-built updatesMPS-22MPS-30MPS-27L1MPS-27MPS-21MPS-24MPS-25L1MPS-25MPS-14MPS-32MPS-34L2MPS-34L1MPS-34MPS-35PB2MPS-35MPS-35PB1MPH-11MPS-31No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU S-47 NAD 1927 (NADCON CONUS)Alaska Zone 0437.80+N/-S +E/-W Northing Easting LatittudeLongitude0.000.005999842.08 565319.63 70° 24' 36.081 N 149° 28' 5.262 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU S-47, True NorthVertical (TVD) Reference:MPU S-47 As-built RKB @ 64.30usftMeasured Depth Reference:MPU S-47 As-built RKB @ 64.30usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2021-02-04T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 650.00 MPU S-47 wp07 (MPU S-47) 3_Gyro-GC_Csg650.00 6112.00 MPU S-47 wp07 (MPU S-47) 3_MWD+IFR2+MS+Sag6112.00 14973.07 MPU S-47 wp07 (MPU S-47) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)6175 6650 7125 7600 8075 8550 9025 9500 9975 10450 10925 11400 11875 12350 12825 13300 13775 14250 14725 15200Measured Depth (950 usft/in)MPH-17MPS-27L1MPS-27MPS-24NO GLOBAL FILTER: Using user defined selection & filtering criteria6112.00 To 14973.07Project: Milne PointSite: M Pt S PadWell: Plan: MPU S-47Wellbore: MPU S-47Plan: MPU S-47 wp07CASING DETAILSTVD TVDSS MD Size Name3915.96 3851.66 6112.11 9-5/8 9 5/8" x 12 1/4"4064.30 4000.00 14973.07 4-1/2 4 1/2" x 8 1/2"Ladder / S.F. PlotsSuperceded !""# Superceded 06001200180024003000360042004800True Vertical Depth (1200 usft/in)-2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000Vertical Section at 330.00° (1200 usft/in)MPU S-47 wp05 CP1MPU S-47 wp05 HeelMPU S-47 wp05 CP2MPU S-47 wp05 CP3MPU S-47 wp07 Tangent9 5/8" x 12 1/4"4 1/2" x 8 1/2"500100015002000250030003500400045005000550060006500 7000 7 500 8000 8500 90009500100001050011000115001200012500 1300013500140001450014973 MPU S-47 wp07Start Dir 3º/100' : 250' MD, 250'TVDStart Dir 4º/100' : 550' MD, 548.77'TVDStart Dir 4º/100' : 800' MD, 791.03'TVDEnd Dir : 1545.8' MD, 1409.28' TVDStart Dir 4º/100' : 3830.76' MD, 2951.13'TVDBegin Pump TangentEnd Dir : 5660.38' MD, 3862.56' TVDStart Dir 4º/100' : 5810.38' MD, 3889.9'TVDEnd Pump TangentEnd Dir : 6112.11' MD, 3915.96' TVDStart Dir 2º/100' : 6460.45' MD, 3912.43'TVDEnd Dir : 8546.11' MD, 3888.77' TVDStart Dir 2º/100' : 9109.71' MD, 3887.35'TVDEnd Dir : 9470.72' MD, 3896.62' TVDStart Dir 2º/100' : 11716.41' MD, 4032.92'TVDEnd Dir : 12500.68' MD, 4065.3' TVDStart Dir 2º/100' : 12532.62' MD, 4065.08'TVDEnd Dir : 13343.07' MD, 4062.59' TVDTotal Depth : 14973.07' MD, 4064.3' TVDBPRFUG3 CoalUG2 CoalLA3LA1UG MAUG MBUG MCUG MDUG MESB_NB (target)Hilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: MPU S-4737.80+N/-S +E/-W NorthingEastingLatittude Longitude0.00 0.005999842.08 565319.63 70° 24' 36.081 N 149° 28' 5.262 WSURVEY PROGRAMDate: 2021-02-04T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool26.50 650.00 MPU S-47 wp07 (MPU S-47) 3_Gyro-GC_Csg650.00 6112.00 MPU S-47 wp07 (MPU S-47) 3_MWD+IFR2+MS+Sag6112.00 14973.07 MPU S-47 wp07 (MPU S-47) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSTVDPath TVDssPath MDPath Formation1866.02 1801.72 2222.68 BPRF2893.51 2829.21 3745.37 UG3 Coal3146.08 3081.78 4122.27 UG2 Coal3481.46 3417.16 4668.40 LA33557.29 3492.99 4810.06 LA13718.03 3653.73 5162.63 UG MA3756.03 3691.73 5264.56 UG MB3773.10 3708.80 5314.40 UG MC3804.76 3740.46 5416.11 UG MD3873.32 3809.02 5719.42 UG ME3914.21 3849.91 6020.83 SB_NB (target)3925.50 3861.20 9946.48 SB NAREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU S-47, True NorthVertical (TVD) Reference:MPU S-47 As-built RKB @ 64.30usftMeasured Depth Reference: MPU S-47 As-built RKB @ 64.30usftCalculation Method:Minimum CurvatureProject:Milne PointSite:M Pt S PadWell:Plan: MPU S-47Wellbore:MPU S-47Design:MPU S-47 wp07CASING DETAILSTVD TVDSS MD SizeName3915.96 3851.66 6112.11 9-5/8 9 5/8" x 12 1/4"4064.30 4000.00 14973.07 4-1/2 4 1/2" x 8 1/2"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 26.50 0.00 0.00 26.50 0.00 0.00 0.00 0.00 0.002 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 250' MD, 250'TVD3 550.00 9.00 200.00 548.77 -22.10 -8.04 3.00 200.00 -15.11 Start Dir 4º/100' : 550' MD, 548.77'TVD4 800.00 19.00 200.00 791.03 -78.86 -28.70 4.00 0.00 -53.94 Start Dir 4º/100' : 800' MD, 791.03'TVD5 1545.80 47.56 217.25 1409.28 -419.74 -241.64 4.00 26.10 -242.69 End Dir : 1545.8' MD, 1409.28' TVD6 3830.76 47.56 217.25 2951.13 -1762.07 -1262.37 0.00 0.00 -894.81 Start Dir 4º/100' : 3830.76' MD, 2951.13'TVD7 5660.38 79.50 294.00 3862.56 -1961.51 -2692.72 4.00 88.95 -352.36 MPU S-47 wp07 Tangent Begin Pump Tangent8 5810.38 79.50 294.00 3889.90 -1901.53 -2827.46 0.00 0.00 -233.04 Start Dir 4º/100' : 5810.38' MD, 3889.9'TVD9 6112.11 90.58 298.81 3915.96 -1767.99 -3096.15 4.00 23.65 16.95 End Dir : 6112.11' MD, 3915.96' TVD10 6460.45 90.58 298.81 3912.43 -1600.12 -3401.36 0.00 0.00 314.93 Start Dir 2º/100' : 6460.45' MD, 3912.43'TVD11 7120.14 91.00 312.00 3903.30 -1218.81 -3937.81 2.00 88.09 913.39 MPU S-47 wp05 CP112 8546.11 90.14 340.51 3888.77 -45.35 -4721.73 2.00 91.54 2321.59 End Dir : 8546.11' MD, 3888.77' TVD13 9109.71 90.14 340.51 3887.35 485.96 -4909.78 0.00 0.00 2875.74 Start Dir 2º/100' : 9109.71' MD, 3887.35'TVD14 9406.34 87.56 345.85 3893.30 769.71 -4995.57 2.00 115.86 3164.37 MPU S-47 wp05 CP215 9470.72 86.52 346.61 3896.62 832.15 -5010.87 2.00 143.86 3226.10 End Dir : 9470.72' MD, 3896.62' TVD16 11716.41 86.52 346.61 4032.92 3012.78 -5529.94 0.00 0.00 5374.11 Start Dir 2º/100' : 11716.41' MD, 4032.92'TVD17 12146.93 87.00 338.00 4057.30 3421.88 -5660.46 2.00 -87.06 5793.66 MPU S-47 wp05 CP318 12500.68 90.41 331.80 4065.30 3741.93 -5810.41 2.00 -61.30 6145.81 End Dir : 12500.68' MD, 4065.3' TVD19 12532.62 90.41 331.80 4065.08 3770.08 -5825.50 0.00 0.00 6177.74 Start Dir 2º/100' : 12532.62' MD, 4065.08'TVD20 13343.07 89.94 348.00 4062.59 4528.62 -6103.10 2.00 91.62 6973.45 End Dir : 13343.07' MD, 4062.59' TVD21 14973.07 89.94 348.00 4064.30 6123.00 -6442.00 0.00 0.00 8523.67 Total Depth : 14973.07' MD, 4064.3' TVDSuperceded -2250 -1800 -1350 -900 -450 0 450 900 1350 1800 2250 2700 3150 3600 4050 4500 4950 5400 5850 6300 South(-)/North(+) (900 usft/in)-6300 -5850 -5400 -4950 -4500 -4050 -3600 -3150 -2700 -2250 -1800 -1350 -900 -450 0 West(-)/East(+) (900 usft/in) MPU S-47 wp07 Tangent MPU S-47 wp05 CP3 MPU S-47 wp05 CP2 MPU S-47 wp05 Heel MPU S-47 wp05 CP1 9 5/8" x 12 1/4" 4 1/2" x 8 1/2" 250 500750 1000 1250 1500 175 0 2000 2250 2500 275 0 3 0 0 0 3250350037504 0 0 0 4 0 6 4 MPU S-47 wp07 Start Dir 3º/100' : 250' MD, 250'TVD Start Dir 4º/100' : 550' MD, 548.77'TVD Start Dir 4º/100' : 800' MD, 791.03'TVD End Dir : 1545.8' MD, 1409.28' TVD Start Dir 4º/100' : 3830.76' MD, 2951.13'TVD End Dir : 5660.38' MD, 3862.56' TVD Begin Pump Tangent Start Dir 4º/100' : 5810.38' MD, 3889.9'TVD End Pump Tangent End Dir : 6112.11' MD, 3915.96' TVD Start Dir 2º/100' : 6460.45' MD, 3912.43'TVD End Dir : 8546.11' MD, 3888.77' TVD Start Dir 2º/100' : 9109.71' MD, 3887.35'TVD End Dir : 9470.72' MD, 3896.62' TVD Start Dir 2º/100' : 11716.41' MD, 4032.92'TVD End Dir : 12500.68' MD, 4065.3' TVD Start Dir 2º/100' : 12532.62' MD, 4065.08'TVD End Dir : 13343.07' MD, 4062.59' TVD Total Depth : 14973.07' MD, 4064.3' TVD CASING DETAILS TVD TVDSS MD Size Name 3915.96 3851.66 6112.11 9-5/8 9 5/8" x 12 1/4" 4064.30 4000.00 14973.07 4-1/2 4 1/2" x 8 1/2" Project: Milne Point Site: M Pt S Pad Well: Plan: MPU S-47 Wellbore: MPU S-47 Plan: MPU S-47 wp07 WELL DETAILS: Plan: MPU S-47 37.80 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 5999842.08 565319.63 70° 24' 36.081 N 149° 28' 5.262 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: MPU S-47, True North Vertical (TVD) Reference: MPU S-47 As-built RKB @ 64.30usft Measured Depth Reference:MPU S-47 As-built RKB @ 64.30usft Calculation Method:Minimum Curvature Superceded -2250 -1800 -1350 -900 -450 0 450 900 1350 1800 2250 2700 3150 3600 4050 4500 4950 5400 5850 6300 South(-)/North(+) (900 usft/in)-6300 -5850 -5400 -4950 -4500 -4050 -3600 -3150 -2700 -2250 -1800 -1350 -900 -450 0 West(-)/East(+) (900 usft/in) 250500750 1000 1250 1500 1750 2000 2250 2500 2750 3 0 0 03 250350037504 0 0 0 MPU S-46i wp08 250 5007 5 0 1 0 0 01 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 32 5 0 35003750MPU S-48i wp04 47505000525055005 7 5 0 60006250650067506893MPH-06 MPH-17 MPU S-203 37503648MPU S-203PB1MPU S-203PB2 37503573MPU S-202 wp10 - as-built updates 2250250027503000325035003750 3649MPS-22 37504000MPU S-56PB1 4 0 0 0 MPU S-44i wp06 17502000225025002750300032503500375040004204MPS-30 MPS-27L1 37504000MPS-27 1750200022502500275030003250350037503911MPS-27PB1 20002250250027503000325035003750400042504417MPS-21 3250350037504 0 0 0 MPU S-45 4 0 0 0 3969MPS-24PB2 3882MPS-24 MPS-25L1 200022502500275030003250350037504000MPS-25 2 2 5 0 250027503000325035003750400042504271MPS-26 2000225025002750300032503500375040004175MPS-14 1500175020002250250027503000325035003750MPS-32 MPS-34L2 MPS-34L1 1500175020002250250027503000325035003750MPS-34 4 1 2 8 MPS-35PB2 MPS-35 1250150017502000225025002750300032503500MPS-35PB1 2 0 0 022 50250027503000325035003750400042504256MPS-31 9 5/8" x 12 1/4" 4 1/2" x 8 1/2" 250 500750 1000 1250 1500 1 750 200 0 2250 2500 2750 3 0 0 0 3250350037504 0 0 0 4 0 6 4 MPU S-47 wp07 Project: Milne Point Site: M Pt S Pad Well: Plan: MPU S-47 Wellbore: MPU S-47 Plan: MPU S-47 wp07 Superceded $ # % & " # ' ()* ' + + , -&# . !"#$%&' ( * / )' *, *+,- * . * ' !"#$%&' ( 0 . 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"#$%$ )*' + , '-() &./ 01112#32400*13*5-$6#7*3284#1627038/.' () ! "#$ "9 :;<#3* & ( 303 &3 ')3 = 030; 15 ! 3> &&! 3 +5 3 &4?@ ?; >A B5 !( & C&( B B Superceded & ! "#$" ! "#$%$ /4 "/94 "'(< ')- &. '- &.5 - &.< ') &> ! 3> &&! 3 +5 3 & 4 ( 303 &3 ')3 )*' + , '-() &.&'( " ! "#$" ! "#$" ! "#$%$ ')- &. ; /( !" "" # " "" "" !" "" # " "" "" "" # " "" !" "" !" "" "" $ $ "" $ $ # " "" $ $ !" "" !" "" "" % % "" "" # " "" !" "" !" "" # " "" "" % % !" "" % % # " "" % % "" Superceded & ! "#$" ! "#$%$ /4 "/94 "'(< ')- &. '- &.5 - &.< ') &> ! 3> &&! 3 +5 3 & 4 ( 303 &3 ')3 )*' + , '-() &.&'( " ! "#$" ! "#$" ! "#$%$ ')- &. ; /( $ $ !" "" $ $ # " "" $ $ "" !" "" # " "" "" !" "" # " "" "" !" "" # " "" "" !" "" # " "" "" % % !" "" % % # " "" % % "" % % !" "" % % # " "" % % "" !" "" # " "" "" $ $ !" "" $ $ # " "" $ $ "" $ $ !" "" $ $ # " "" $ $ "" Superceded & ! "#$" ! "#$%$ /4 "/94 "'(< ')- &. '- &.5 - &.< ') &> ! 3> &&! 3 +5 3 & 4 ( 303 &3 ')3 )*' + , '-() &.&'( " ! "#$" ! "#$" ! "#$%$ ')- &. ; /( !" "" # " "" "" !" "" # " "" "" !" "" # " "" "" $ $ !" "" $ $ # " "" $ $ "" $ $ !" "" $ $ # " "" $ $ "" !" "" # " "" ""& & & !" ""& & & # " ""& & & ""& & $& $ !" ""& & $& $ # " ""& & $& $ ""& & $& $ !" ""& & $& $ # " ""& & $& $ ""& & & !" ""& & & # " ""& & & "" Superceded & ! "#$" ! "#$%$ /4 "/94 "'(< ')- &. '- &.5 - &.< ') &> ! 3> &&! 3 +5 3 & 4 ( 303 &3 ')3 )*' + , '-() &.&'( " ! "#$" ! "#$" ! "#$%$ ')- &. ; /(& & $& $ # " ""& & $& $ "" '& & & ( !" "" '& & & ( # " "" '& & & ( "" '& & & ( "" '& & & ( !" "" '& & & ( !" "" '& & & ( # " "" '& & & ( "" '& & & ( !" "" '& & & ( # " "" '& & & ( "" '& & & ( !" "" '& & & ( # " "" '& & & ( "" > - &.B- &. , D , B & ( )* ) "+ & ( ),!-. /- - + & ( ),!-. /- - + Superceded & ! "#$" ! "#$%$# " 0" """1 2* " "3 1 " 4( "" 1 "" "1 5 " 6!" $( 5 "78!" $( 5 "# " 9!" $( ""3" +3 " 4( ( 4 " " "( 1 1" +3 010 1 2 1 03 Superceded 0.001.002.003.004.00Separation Factor0 325 650 975 1300 1625 1950 2275 2600 2925 3250 3575 3900 4225 4550 4875 5200 5525 5850 6175Measured Depth (650 usft/in)No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU S-47 NAD 1927 (NADCON CONUS)Alaska Zone 0437.80+N/-S+E/-W Northing Easting LatittudeLongitude0.000.005999842.08 565319.63 70° 24' 36.081 N 149° 28' 5.262 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU S-47, True NorthVertical (TVD) Reference:MPU S-47 As-built RKB @ 64.30usftMeasured Depth Reference:MPU S-47 As-built RKB @ 64.30usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2021-02-04T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 650.00 MPU S-47 wp07 (MPU S-47) 3_Gyro-GC_Csg650.00 6112.00 MPU S-47 wp07 (MPU S-47) 3_MWD+IFR2+MS+Sag6112.00 14973.07 MPU S-47 wp07 (MPU S-47) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 325 650 975 1300 1625 1950 2275 2600 2925 3250 3575 3900 4225 4550 4875 5200 5525 5850 6175Measured Depth (650 usft/in)MPU S-46i wp08MPU S-201 wp07MPU S-48i wp04MPS-43MPU S-56PB1MPU S-44i wp06MPU S-45MPS-24MPS-41NO GLOBAL FILTER: Using user defined selection & filtering criteria26.50 To 6112.00Project: Milne PointSite: M Pt S PadWell: Plan: MPU S-47Wellbore: MPU S-47Plan: MPU S-47 wp07Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name3915.96 3851.66 6112.11 9-5/8 9 5/8" x 12 1/4"4064.30 4000.00 14973.07 4-1/2 4 1/2" x 8 1/2"Superceded ! "#$ ! "#$ ! "#$%$&'( " ! "#$" ! "#$" ! "#$%$ )*' + , '-() &./ 01112#32400*13*5-$6#7*3284#1627038/.' () ! "#$ "9 :;<#3* & ( 3#1$*3$ &3 ')3 = 030; 15 ! 3> &&! 3 +5 3 &4?@ ?; >A B5 !( & C&( B B Superceded & ! "#$" ! "#$%$ /4 "/94 "'(< ')- &. '- &.5 - &.< ') &> ! 3> &&! 3 +5 3 & 4 ( 3#1$*3$ &3 ')3 )*' + , '-() &.&'( " ! "#$" ! "#$" ! "#$%$ ')- &. ; /( ! "" ! "" # " ! "" ! $" ! "" ! "" # " ! "" ! $" ! "" #30*3"3#21#1323#*$*3>> A " 3*2#$3"*30103#3$0#$3'> A " # " ! "" ! "" ! $" ! "" 23$*$3"31$2*3#2311*$3>> A " % % ! "" ! $" ! "" # " ! "" ! "" & & ! $" ! "" & & # " ! "" & & ! "" ! "" ! $" ! "" # " ! "" ! "" & �"3*2$#3$321230'> A " & &03#3"#302$23#3$23>> A " Superceded & ! "#$" ! "#$%$ /4 "/94 "'(< ')- &. '- &.5 - &.< ') &> ! 3> &&! 3 +5 3 & 4 ( 3#1$*3$ &3 ')3 )*' + , '-() &.&'( " ! "#$" ! "#$" ! "#$%$ ')- &. ; /( & &0303"#312$3$3$135 > A " ! "" # " ! "" ! $" ! "" ! $" ! "" # " ! "" ! "" 03$*$3"*32#0#31301$*$3>> A " ##31$23#0"13$12#*32#3$23#0'> A " ! $" ! "" # " ! "" ! "" & & ! $" ! "" & & # " ! "" & & ! "" & &$#30#03#0"#3$21332*0#03#0'> A " & &$30#0*$3"323#32#0*$3>> A " $30##130"2031#0323#*##130>> A " #3##03"3#*$3#3*0#035 > A " % % ! $" ! "" % % # " ! "" % % ! "" % %$30##130"230#0323#*##130>> A " % %#3##03"3#*$3#3*##035 > A "' ' ' # " ! ""' ' ' ! ""' ' %' % # " ! ""' ' %' % ! $" ! ""' ' %' % ! ""' ' %' % # " ! "" Superceded & ! "#$" ! "#$%$ /4 "/94 "'(< ')- &. '- &.5 - &.< ') &> ! 3> &&! 3 +5 3 & 4 ( 3#1$*3$ &3 ')3 )*' + , '-() &.&'( " ! "#$" ! "#$" ! "#$%$ ')- &. ; /(' ' %' % ! "" !(' ' ' ) ! "" !(' ' ' ) # " ! "" !(' ' ' ) ! "" !(' ' ' ) ! "" !(' ' ' ) # " ! "" !(' ' ' ) ! "" > - &.B- &. , D , B ' ) *+ * ", ' ) *- $. / 0. . , ' ) *- $. / 0. . ,# " 1 " """2 3+ !!" !"4 2 " !5 )! "" 2 ""! "2 6 " ! 7 $" !%)! 6 "89$" !%)! 6 "# " !:$" !%)!! ""4" ,4 !" !5 )!) 5 ! " " ! ! ") 2 2"!,4!121 2 3 2 14 Superceded 0.001.002.003.004.00Separation Factor6175 6650 7125 7600 8075 8550 9025 9500 9975 10450 10925 11400 11875 12350 12825 13300 13775 14250 14725 15200Measured Depth (950 usft/in)MPH-17MPU S-203MPU S-203PB1MPU S-203PB2MPU S-202 wp10 - as-built updatesMPS-22MPS-30MPS-27L1MPS-27MPS-21MPS-24MPS-25L1MPS-25MPS-14MPS-32MPS-34L2MPS-34L1MPS-34MPS-35PB2MPS-35MPS-35PB1MPH-11MPS-31No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU S-47 NAD 1927 (NADCON CONUS)Alaska Zone 0437.80+N/-S +E/-W Northing Easting LatittudeLongitude0.000.005999842.08 565319.63 70° 24' 36.081 N 149° 28' 5.262 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU S-47, True NorthVertical (TVD) Reference:MPU S-47 As-built RKB @ 64.30usftMeasured Depth Reference:MPU S-47 As-built RKB @ 64.30usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2021-02-04T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 650.00 MPU S-47 wp07 (MPU S-47) 3_Gyro-GC_Csg650.00 6112.00 MPU S-47 wp07 (MPU S-47) 3_MWD+IFR2+MS+Sag6112.00 14973.07 MPU S-47 wp07 (MPU S-47) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)6175 6650 7125 7600 8075 8550 9025 9500 9975 10450 10925 11400 11875 12350 12825 13300 13775 14250 14725 15200Measured Depth (950 usft/in)MPH-17MPS-27L1MPS-27MPS-24NO GLOBAL FILTER: Using user defined selection & filtering criteria6112.00 To 14973.07Project: Milne PointSite: M Pt S PadWell: Plan: MPU S-47Wellbore: MPU S-47Plan: MPU S-47 wp07CASING DETAILSTVD TVDSS MD Size Name3915.96 3851.66 6112.11 9-5/8 9 5/8" x 12 1/4"4064.30 4000.00 14973.07 4-1/2 4 1/2" x 8 1/2"Ladder / S.F. PlotsSuperceded !""# 06001200180024003000360042004800True Vertical Depth (1200 usft/in)-2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000Vertical Section at 330.00° (1200 usft/in)MPU S-47 wp05 CP1MPU S-47 wp05 HeelMPU S-47 wp05 CP2MPU S-47 wp05 CP3MPU S-47 wp07 Tangent9 5/8" x 12 1/4"4 1/2" x 8 1/2"500100015002000250030003500400045005000550060006500 7000 7 500 8000 8500 90009500100001050011000115001200012500 1300013500140001450014973 MPU S-47 wp07Start Dir 3º/100' : 250' MD, 250'TVDStart Dir 4º/100' : 550' MD, 548.77'TVDStart Dir 4º/100' : 800' MD, 791.03'TVDEnd Dir : 1545.8' MD, 1409.28' TVDStart Dir 4º/100' : 3830.76' MD, 2951.13'TVDBegin Pump TangentEnd Dir : 5660.38' MD, 3862.56' TVDStart Dir 4º/100' : 5810.38' MD, 3889.9'TVDEnd Pump TangentEnd Dir : 6112.11' MD, 3915.96' TVDStart Dir 2º/100' : 6460.45' MD, 3912.43'TVDEnd Dir : 8546.11' MD, 3888.77' TVDStart Dir 2º/100' : 9109.71' MD, 3887.35'TVDEnd Dir : 9470.72' MD, 3896.62' TVDStart Dir 2º/100' : 11716.41' MD, 4032.92'TVDEnd Dir : 12500.68' MD, 4065.3' TVDStart Dir 2º/100' : 12532.62' MD, 4065.08'TVDEnd Dir : 13343.07' MD, 4062.59' TVDTotal Depth : 14973.07' MD, 4064.3' TVDBPRFUG3 CoalUG2 CoalLA3LA1UG MAUG MBUG MCUG MDUG MESB_NB (target)Hilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: MPU S-4737.80+N/-S +E/-W NorthingEastingLatittude Longitude0.00 0.005999842.08 565319.63 70° 24' 36.081 N 149° 28' 5.262 WSURVEY PROGRAMDate: 2021-02-04T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool26.50 650.00 MPU S-47 wp07 (MPU S-47) 3_Gyro-GC_Csg650.00 6112.00 MPU S-47 wp07 (MPU S-47) 3_MWD+IFR2+MS+Sag6112.00 14973.07 MPU S-47 wp07 (MPU S-47) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSTVDPath TVDssPath MDPath Formation1866.02 1801.72 2222.68 BPRF2893.51 2829.21 3745.37 UG3 Coal3146.08 3081.78 4122.27 UG2 Coal3481.46 3417.16 4668.40 LA33557.29 3492.99 4810.06 LA13718.03 3653.73 5162.63 UG MA3756.03 3691.73 5264.56 UG MB3773.10 3708.80 5314.40 UG MC3804.76 3740.46 5416.11 UG MD3873.32 3809.02 5719.42 UG ME3914.21 3849.91 6020.83 SB_NB (target)3925.50 3861.20 9946.48 SB NAREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU S-47, True NorthVertical (TVD) Reference:MPU S-47 As-built RKB @ 64.30usftMeasured Depth Reference: MPU S-47 As-built RKB @ 64.30usftCalculation Method:Minimum CurvatureProject:Milne PointSite:M Pt S PadWell:Plan: MPU S-47Wellbore:MPU S-47Design:MPU S-47 wp07CASING DETAILSTVD TVDSS MD SizeName3915.96 3851.66 6112.11 9-5/8 9 5/8" x 12 1/4"4064.30 4000.00 14973.07 4-1/2 4 1/2" x 8 1/2"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 26.50 0.00 0.00 26.50 0.00 0.00 0.00 0.00 0.002 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 250' MD, 250'TVD3 550.00 9.00 200.00 548.77 -22.10 -8.04 3.00 200.00 -15.11 Start Dir 4º/100' : 550' MD, 548.77'TVD4 800.00 19.00 200.00 791.03 -78.86 -28.70 4.00 0.00 -53.94 Start Dir 4º/100' : 800' MD, 791.03'TVD5 1545.80 47.56 217.25 1409.28 -419.74 -241.64 4.00 26.10 -242.69 End Dir : 1545.8' MD, 1409.28' TVD6 3830.76 47.56 217.25 2951.13 -1762.07 -1262.37 0.00 0.00 -894.81 Start Dir 4º/100' : 3830.76' MD, 2951.13'TVD7 5660.38 79.50 294.00 3862.56 -1961.51 -2692.72 4.00 88.95 -352.36 MPU S-47 wp07 Tangent Begin Pump Tangent8 5810.38 79.50 294.00 3889.90 -1901.53 -2827.46 0.00 0.00 -233.04 Start Dir 4º/100' : 5810.38' MD, 3889.9'TVD9 6112.11 90.58 298.81 3915.96 -1767.99 -3096.15 4.00 23.65 16.95 End Dir : 6112.11' MD, 3915.96' TVD10 6460.45 90.58 298.81 3912.43 -1600.12 -3401.36 0.00 0.00 314.93 Start Dir 2º/100' : 6460.45' MD, 3912.43'TVD11 7120.14 91.00 312.00 3903.30 -1218.81 -3937.81 2.00 88.09 913.39 MPU S-47 wp05 CP112 8546.11 90.14 340.51 3888.77 -45.35 -4721.73 2.00 91.54 2321.59 End Dir : 8546.11' MD, 3888.77' TVD13 9109.71 90.14 340.51 3887.35 485.96 -4909.78 0.00 0.00 2875.74 Start Dir 2º/100' : 9109.71' MD, 3887.35'TVD14 9406.34 87.56 345.85 3893.30 769.71 -4995.57 2.00 115.86 3164.37 MPU S-47 wp05 CP215 9470.72 86.52 346.61 3896.62 832.15 -5010.87 2.00 143.86 3226.10 End Dir : 9470.72' MD, 3896.62' TVD16 11716.41 86.52 346.61 4032.92 3012.78 -5529.94 0.00 0.00 5374.11 Start Dir 2º/100' : 11716.41' MD, 4032.92'TVD17 12146.93 87.00 338.00 4057.30 3421.88 -5660.46 2.00 -87.06 5793.66 MPU S-47 wp05 CP318 12500.68 90.41 331.80 4065.30 3741.93 -5810.41 2.00 -61.30 6145.81 End Dir : 12500.68' MD, 4065.3' TVD19 12532.62 90.41 331.80 4065.08 3770.08 -5825.50 0.00 0.00 6177.74 Start Dir 2º/100' : 12532.62' MD, 4065.08'TVD20 13343.07 89.94 348.00 4062.59 4528.62 -6103.10 2.00 91.62 6973.45 End Dir : 13343.07' MD, 4062.59' TVD21 14973.07 89.94 348.00 4064.30 6123.00 -6442.00 0.00 0.00 8523.67 Total Depth : 14973.07' MD, 4064.3' TVD -2250 -1800 -1350 -900 -450 0 450 900 1350 1800 2250 2700 3150 3600 4050 4500 4950 5400 5850 6300 South(-)/North(+) (900 usft/in)-6300 -5850 -5400 -4950 -4500 -4050 -3600 -3150 -2700 -2250 -1800 -1350 -900 -450 0 West(-)/East(+) (900 usft/in) MPU S-47 wp07 Tangent MPU S-47 wp05 CP3 MPU S-47 wp05 CP2 MPU S-47 wp05 Heel MPU S-47 wp05 CP1 9 5/8" x 12 1/4" 4 1/2" x 8 1/2" 250 500750 1000 1250 1500 175 0 2000 2250 2500 275 0 3 0 0 0 3250350037504 0 0 0 4 0 6 4 MPU S-47 wp07 Start Dir 3º/100' : 250' MD, 250'TVD Start Dir 4º/100' : 550' MD, 548.77'TVD Start Dir 4º/100' : 800' MD, 791.03'TVD End Dir : 1545.8' MD, 1409.28' TVD Start Dir 4º/100' : 3830.76' MD, 2951.13'TVD End Dir : 5660.38' MD, 3862.56' TVD Begin Pump Tangent Start Dir 4º/100' : 5810.38' MD, 3889.9'TVD End Pump Tangent End Dir : 6112.11' MD, 3915.96' TVD Start Dir 2º/100' : 6460.45' MD, 3912.43'TVD End Dir : 8546.11' MD, 3888.77' TVD Start Dir 2º/100' : 9109.71' MD, 3887.35'TVD End Dir : 9470.72' MD, 3896.62' TVD Start Dir 2º/100' : 11716.41' MD, 4032.92'TVD End Dir : 12500.68' MD, 4065.3' TVD Start Dir 2º/100' : 12532.62' MD, 4065.08'TVD End Dir : 13343.07' MD, 4062.59' TVD Total Depth : 14973.07' MD, 4064.3' TVD CASING DETAILS TVD TVDSS MD Size Name 3915.96 3851.66 6112.11 9-5/8 9 5/8" x 12 1/4" 4064.30 4000.00 14973.07 4-1/2 4 1/2" x 8 1/2" Project: Milne Point Site: M Pt S Pad Well: Plan: MPU S-47 Wellbore: MPU S-47 Plan: MPU S-47 wp07 WELL DETAILS: Plan: MPU S-47 37.80 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 5999842.08 565319.63 70° 24' 36.081 N 149° 28' 5.262 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: MPU S-47, True North Vertical (TVD) Reference: MPU S-47 As-built RKB @ 64.30usft Measured Depth Reference:MPU S-47 As-built RKB @ 64.30usft Calculation Method:Minimum Curvature -2250 -1800 -1350 -900 -450 0 450 900 1350 1800 2250 2700 3150 3600 4050 4500 4950 5400 5850 6300 South(-)/North(+) (900 usft/in)-6300 -5850 -5400 -4950 -4500 -4050 -3600 -3150 -2700 -2250 -1800 -1350 -900 -450 0 West(-)/East(+) (900 usft/in) 250500750 1000 1250 1500 1750 2000 2250 2500 2750 3 0 0 03 250350037504 0 0 0 MPU S-46i wp08 250 5007 5 0 1 0 0 01 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 35003750MPU S-48i wp04 47505000525055005 7 5 0 60006250650067506893MPH-06 MPH-17 MPU S-203 37503648MPU S-203PB1MPU S-203PB2 37503573MPU S-202 wp10 - as-built updates 2250250027503000325035003750 3649MPS-22 37504000MPU S-56PB1 4 0 0 0 MPU S-44i wp06 17502000225025002750300032503500375040004204MPS-30 MPS-27L1 37504000MPS-27 1750200022502500275030003250350037503911MPS-27PB1 20002250250027503000325035003750400042504417MPS-21 3250350037504 0 0 0 MPU S-45 4 0 0 0 3969MPS-24PB2 3882MPS-24 MPS-25L1 200022502500275030003250350037504000MPS-25 2 2 5 0 250027503000325035003750400042504271MPS-26 2000225025002750300032503500375040004175MPS-14 1500175020002250250027503000325035003750MPS-32 MPS-34L2 MPS-34L1 1500175020002250250027503000325035003750MPS-34 4 1 2 8 MPS-35PB2 MPS-35 1250150017502000225025002750300032503500MPS-35PB1 2 0 0 022 50250027503000325035003750400042504256MPS-31 9 5/8" x 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"#$%$ )*' + , '-() &./ 01112#32400*13*5-$6#7*3284#1627038/.' () ! "#$ "9 :;<#3* & ( 303 &3 ')3 = 030; 15 ! 3> &&! 3 +5 3 &4?@ ?; >A B5 !( & C&( B B & ! "#$" ! "#$%$ /4 "/94 "'(< ')- &. '- &.5 - &.< ') &> ! 3> &&! 3 +5 3 & 4 ( 303 &3 ')3 )*' + , '-() &.&'( " ! "#$" ! "#$" ! "#$%$ ')- &. ; /( !" "" # " "" "" !" "" # " "" "" "" # " "" !" "" !" "" "" $ $ "" $ $ # " "" $ $ !" "" !" "" "" % % "" "" # " "" !" "" !" "" # " "" "" % % !" "" % % # " "" % % "" & ! "#$" ! "#$%$ /4 "/94 "'(< ')- &. '- &.5 - &.< ') &> ! 3> &&! 3 +5 3 & 4 ( 303 &3 ')3 )*' + , '-() &.&'( " ! "#$" ! "#$" ! "#$%$ ')- &. ; /( $ $ !" "" $ $ # " "" $ $ "" !" "" # " "" "" !" "" # " "" "" !" "" # " "" "" !" "" # " "" "" % % !" "" % % # " "" % % "" % % !" "" % % # " "" % % "" !" "" # " "" "" $ $ !" "" $ $ # " "" $ $ "" $ $ !" "" $ $ # " "" $ $ "" & ! "#$" ! "#$%$ /4 "/94 "'(< ')- &. '- &.5 - &.< ') &> ! 3> &&! 3 +5 3 & 4 ( 303 &3 ')3 )*' + , '-() &.&'( " ! "#$" ! "#$" ! "#$%$ ')- &. ; /( !" "" # " "" "" !" "" # " "" "" !" 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"#$%$# " 0" """1 2* " "3 1 " 4( "" 1 "" "1 5 " 6!" $( 5 "78!" $( 5 "# " 9!" $( ""3" +3 " 4( ( 4 " " "( 1 1" +3 010 1 2 1 03 0.001.002.003.004.00Separation Factor0 325 650 975 1300 1625 1950 2275 2600 2925 3250 3575 3900 4225 4550 4875 5200 5525 5850 6175Measured Depth (650 usft/in)No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU S-47 NAD 1927 (NADCON CONUS)Alaska Zone 0437.80+N/-S+E/-W Northing Easting LatittudeLongitude0.000.005999842.08 565319.63 70° 24' 36.081 N 149° 28' 5.262 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU S-47, True NorthVertical (TVD) Reference:MPU S-47 As-built RKB @ 64.30usftMeasured Depth Reference:MPU S-47 As-built RKB @ 64.30usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2021-02-04T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 650.00 MPU S-47 wp07 (MPU S-47) 3_Gyro-GC_Csg650.00 6112.00 MPU S-47 wp07 (MPU S-47) 3_MWD+IFR2+MS+Sag6112.00 14973.07 MPU S-47 wp07 (MPU S-47) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 325 650 975 1300 1625 1950 2275 2600 2925 3250 3575 3900 4225 4550 4875 5200 5525 5850 6175Measured Depth (650 usft/in)MPU S-46i wp08MPU S-201 wp07MPU S-48i wp04MPS-43MPU S-56PB1MPU S-44i wp06MPU S-45MPS-24MPS-41NO GLOBAL FILTER: Using user defined selection & filtering criteria26.50 To 6112.00Project: Milne PointSite: M Pt S PadWell: Plan: MPU S-47Wellbore: MPU S-47Plan: MPU S-47 wp07Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name3915.96 3851.66 6112.11 9-5/8 9 5/8" x 12 1/4"4064.30 4000.00 14973.07 4-1/2 4 1/2" x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�"3*2$#3$321230'> A " & &03#3"#302$23#3$23>> A " & ! "#$" ! "#$%$ /4 "/94 "'(< ')- &. '- &.5 - &.< ') &> ! 3> &&! 3 +5 3 & 4 ( 3#1$*3$ &3 ')3 )*' + , '-() &.&'( " ! "#$" ! "#$" ! "#$%$ ')- &. ; /( & &0303"#312$3$3$135 > A " ! "" # " ! "" ! $" ! "" ! $" ! 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") 2 2"!,4!1 21 2 3 2 1 4 0.001.002.003.004.00Separation Factor6175 6650 7125 7600 8075 8550 9025 9500 9975 10450 10925 11400 11875 12350 12825 13300 13775 14250 14725 15200Measured Depth (950 usft/in)MPH-17MPU S-203MPU S-203PB1MPU S-203PB2MPU S-202 wp10 - as-built updatesMPS-22MPS-30MPS-27L1MPS-27MPS-21MPS-24MPS-25L1MPS-25MPS-14MPS-32MPS-34L2MPS-34L1MPS-34MPS-35PB2MPS-35MPS-35PB1MPH-11MPS-31No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU S-47 NAD 1927 (NADCON CONUS)Alaska Zone 0437.80+N/-S +E/-W Northing Easting LatittudeLongitude0.000.005999842.08 565319.63 70° 24' 36.081 N 149° 28' 5.262 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU S-47, True NorthVertical (TVD) Reference:MPU S-47 As-built RKB @ 64.30usftMeasured Depth Reference:MPU S-47 As-built RKB @ 64.30usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2021-02-04T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 650.00 MPU S-47 wp07 (MPU S-47) 3_Gyro-GC_Csg650.00 6112.00 MPU S-47 wp07 (MPU S-47) 3_MWD+IFR2+MS+Sag6112.00 14973.07 MPU S-47 wp07 (MPU S-47) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)6175 6650 7125 7600 8075 8550 9025 9500 9975 10450 10925 11400 11875 12350 12825 13300 13775 14250 14725 15200Measured Depth (950 usft/in)MPH-17MPS-27L1MPS-27MPS-24NO GLOBAL FILTER: Using user defined selection & filtering criteria6112.00 To 14973.07Project: Milne PointSite: M Pt S PadWell: Plan: MPU S-47Wellbore: MPU S-47Plan: MPU S-47 wp07CASING DETAILSTVD TVDSS MD Size Name3915.96 3851.66 6112.11 9-5/8 9 5/8" x 12 1/4"4064.30 4000.00 14973.07 4-1/2 4 1/2" x 8 1/2"Ladder / S.F. 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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. 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