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Home My WebLink About222-025DATA SUBMITTAL COMPLIANCE REPORT API No. 50-883-20030-02-00Well Name/No. N COOK INLET UNIT A-10B Completion Status 1-GASCompletion Date 8/21/2022 Permit to Drill 2220250 Operator Hilcorp Alaska, LLC MD 6271 TVD 5449 Current Status 1-GAS 4/24/2023 UIC No Well Log Information: Digital Med/Frmt ReceivedStart Stop OH / CH Comments Log Media Run No Electr Dataset Number Name Interval List of Logs Obtained:CBL 8-16-22, LWD NoNo YesMud Log Samples Directional Survey REQUIRED INFORMATION (from Master Well Data/Logs) DATA INFORMATION Log/ Data Type Log Scale DF 7/25/20223040 6271 Electronic Data Set, Filename: NCIU A-10B LWD FInal.las 36826ED Digital Data DF 7/25/2022 Electronic File: NCIU A-10B LWD Final MD.cgm36826EDDigital Data DF 7/25/2022 Electronic File: NCIU A-10B LWD Final TVD.cgm36826EDDigital Data DF 7/25/2022 Electronic File: NCIU A-10B - Definitive Survey Report.pdf 36826ED Digital Data DF 7/25/2022 Electronic File: NCIU A-10B - Final Surveys.xlsx36826EDDigital Data DF 7/25/2022 Electronic File: NCIU A-10B_DSR Actual_Plan.pdf 36826ED Digital Data DF 7/25/2022 Electronic File: NCIU A-10B_DSR Actual_VSec.pdf 36826ED Digital Data DF 7/25/2022 Electronic File: NCIU A-10B_DSR.txt36826EDDigital Data DF 7/25/2022 Electronic File: NCIU A-10B_DSR_GIS.txt36826EDDigital Data DF 7/25/2022 Electronic File: NCIU A-10B LWD Final MD.emf36826EDDigital Data DF 7/25/2022 Electronic File: NCIU A-10B LWD Final TVD.emf36826EDDigital Data DF 7/25/2022 Electronic File: NCIU A-10B LWD Final MD.pdf36826EDDigital Data DF 7/25/2022 Electronic File: NCIU A-10B LWD Final TVD.pdf36826EDDigital Data DF 7/25/2022 Electronic File: NCIU A-10B LWD Final MD.tif36826EDDigital Data DF 7/25/2022 Electronic File: NCIU A-10B LWD Final TVD.tif36826EDDigital Data DF 9/22/2022741 461 Electronic Data Set, Filename: NCI_A- 10B_RBT_16AUG22_FreePipe.las 37032ED Digital Data DF 9/22/20226166 2600 Electronic Data Set, Filename: NCI_A- 10B_RBT_16AUG22_MainPass.las 37032ED Digital Data Monday, April 24, 2023AOGCCPage 1 of 3 NCIU A-10B LWD FInal.las DATA SUBMITTAL COMPLIANCE REPORT API No. 50-883-20030-02-00Well Name/No. N COOK INLET UNIT A-10B Completion Status 1-GASCompletion Date 8/21/2022 Permit to Drill 2220250 Operator Hilcorp Alaska, LLC MD 6271 TVD 5449 Current Status 1-GAS 4/24/2023 UIC No Well Cores/Samples Information: ReceivedStart Stop Comments Total Boxes Sample Set NumberName Interval INFORMATION RECEIVED Completion Report Production Test Information Geologic Markers/Tops Y Y / NA Y Comments: Mud Logs, Image Files, Digital Data Composite Logs, Image, Data Files Cuttings Samples Y / NA Y Y / NA Directional / Inclination Data Mechanical Integrity Test Information Daily Operations Summary Y Y / NA Y Core Chips Core Photographs Laboratory Analyses Y / NA Y / NA Y / NA COMPLIANCE HISTORY Date CommentsDescription Completion Date:8/21/2022 Release Date:5/18/2022 DF 9/22/2022 Electronic File: NCI_A-10B_RBT_16AUG22.pdf37032EDDigital Data DF 9/22/2022 Electronic File: NCI_A- 10B_RBT_16AUG22_FreePipe.dlis 37032ED Digital Data DF 9/22/2022 Electronic File: NCI_A- 10B_RBT_16AUG22_img.tiff 37032ED Digital Data DF 9/22/2022 Electronic File: NCI_A- 10B_RBT_16AUG22_MainPass.dlis 37032ED Digital Data DF 11/9/20226168 5634 Electronic Data Set, Filename: NCI_A- 10B_Perf_23-Aug-2022_(3921).las 37248ED Digital Data DF 11/9/2022 Electronic File: NCI_A-10B_Perf_23-Aug- 2022_(3921).pdf 37248ED Digital Data Monday, April 24, 2023AOGCCPage 2 of 3 DATA SUBMITTAL COMPLIANCE REPORT API No. 50-883-20030-02-00Well Name/No. N COOK INLET UNIT A-10B Completion Status 1-GASCompletion Date 8/21/2022 Permit to Drill 2220250 Operator Hilcorp Alaska, LLC MD 6271 TVD 5449 Current Status 1-GAS 4/24/2023 UIC No Compliance Reviewed By:Date: Monday, April 24, 2023AOGCCPage 3 of 3 M. Guhl 4/24/2023 Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/8/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221108 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# IRU 241-01 502832018400 221076 8/14/2022 AK E-Line GPT/Plug/Perf IRU 241-01 502832018400 221076 8/31/2022 AK E-Line GPT/Plug/Perf IRU 41-01 502832008800 192109 9/9/2022 AK E-Line GR/Perf IRU 241-01 502832018400 221076 8/25/2022 AK E-Line Perf IRU 241-01 502832018400 221076 8/22/2022 AK E-Line Plug/GR MPU S-34 500292317100 203130 9/4/2022 AK E-Line Cut Tubing NCI A-09A 508832002901 222024 8/20/2022 AK E-Line Perf NCI A-10B 508832003002 222025 8/23/2022 AK E-Line Perf Please include current contact information if different from above. T37244 T37244 T37245 T37244 T37244 T37246 T37247 T37248NCI A-10B 508832003002 222025 8/23/2022 AK E-Line Perf Kayla Junke Digitally signed by Kayla Junke Date: 2022.11.09 11:47:34 -09'00' David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/21/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20220921 Well API #PTD #Log Date Log Company Log Type AOGCC Eset # HVB B-16A 50231200400100 222070 8/5/2022 YellowJacket CBL Paxton 6 50133207070000 222054 7/23/2022 AK E-Line CBL NCIU A-09A 50883200290100 222024 8/6/2022 AK E-Line CBL NCIU A-11A 50883200310200 222013 8/15/2022 Halliburton CBL NCIU A-10B 50883200300200 222025 8/16/2022 Halliburton CBL Please include current contact information if different from above. T37029 T37031 T37030 T37033 T37032NCIU A-10B 50883200300200 222025 8/16/2022 Halliburton CBL Kayla Junke Digitally signed by Kayla Junke Date: 2022.09.22 13:28:56 -08'00' 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): North Cook Inlet Unit GL: N/A BF: N/A 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 4-1/2" L-80 5,447' 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 Rate241 July 10, 2022 July 5, 2022 ADL 17589 N/A N/A 3,042' MD / 2,718' TVD101 374' MD / 374' TVD 6,271' MD / 5,449' TVD CBL 8-16-22, Logging While Drilling Logs Sr Res EngSr Pet GeoSr Pet Eng N/A N/A Oil-Bbl: Water-Bbl: 004909 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/A4909 Flowing *** Please see attached schematic for perforation detail *** 0 Water-Bbl: PRODUCTION TEST 8/21/2022 Date of Test: 11 9/3/2022 24 Flow Tubing 0 12.6# 6,269' Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information DEPTH SET (MD) 2,847' MD / 2,583' TVD PACKER SET (MD/TVD) CASING WT. PER FT.GRADE 333746 334201 TOP SETTING DEPTH MD 2,847' SETTING DEPTH TVD 2588376 BOTTOM TOP 2,583' 20 bbls HOLE SIZE AMOUNT PULLED 50-883-20030-02-00 NCIU A-10B 332044 2586673 141' FSL, 2314' FEL, Sec 31, T12N, R9W, SM, AK CEMENTING RECORD 2588096 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 8/21/2022 1306' FNL, 1026' FWL, Sec 6, T11N, R9W, SM, AK 428' FSL, 1863' FEL, Sec 31, T12N, R9W, SM, AK 222-025 / 322-439 / 322-409 Tertiary System Gas Pool 126.6' 6,182' MD / 5,374' TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 6-3/4" 595 sx 2,854'4-1/2" Tieback SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment RECEIVED by James Brooks at 7:50 am, 9/9/2022 Completed 8/21/2022 JSB RBDMS JSB 091522 G G Development SFD 11/14/2022WCB 4/24/23 222-025 / 322-439 / 322-409 NCIU A-10B DSR-9/16/22 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A Top of Productive Interval 5224' Bel A 4557' 5220' 4554' 5317' 4636' 5520' 4809' 5640' 4912' 5769' 5022' 5956' 5182' 6069' 5278' 6135' 5334' Bel H 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Contact Email:cdinger@hilcorp.com Authorized Contact Phone: 777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: Bel D Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Report. 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 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 Bel H Bel E Bel B Bel C Bel A This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 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 Bel F Bel G Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 9.8.2022Digitally 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: 2022.09.08 15:54:26 -08'00' Monty M Myers Updated by CJD 09-8-22 SCHEMATIC North Cook Inlet Unit Tyonek Platform Well: NCI A-10B PTD: 222-025 API:50-883-20030-02-00 Completed: 8/21/2022 Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) 30”27”Surf 366’ 16”62.5 H-40 15.062”Surf 631’ 10-3/4”40.5 & 45.5 J-55 BTC 9.950”Surf 1,911’ 7-5/8”29.7 L-80 BTC 6.87”Surf 3,042’ 4-1/2”12.6 L-80 JFE 3.958”2,844’6,267’ 4-1/2”12.6 L-80 IBT-M 3.958”Surf 2,854’ Notes: Short joints (10’) of 4-1/2” casing @ 4,275’, 5,292’ RA Tag @ 5,250’& 5,722’ Jewelry Detail Item Depth MD Depth TVD ID OD Description 1 374’374’3.812”6.600”Baker S-5 TRSSSV 2 2,847’2,583’3.940”6.390”Baker ZXP liner hanger, Seals & packer assy. PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status Bel-A Upper 5,224’5,236’4,557’4,568’12 08/23/22 Open Bel-A Lower 5,287’5,305’4,611’4,626’18 08/23/22 Open Bel-B Upper 1 5,346’5,352’4,661’4,666’6 08/23/22 Open Bel-B Upper 2 5,359’5,365’4,672’4,677’6 08/23/22 Open Bel-B Mid 5,416’5,436’4,721’4,738’20 08/23/22 Open Bel-B Lower 5,455’5,465’4,754’4,763’10 08/23/22 Open Bel-C Mid 5,581’5,595’4,861’4,874’14 08/23/22 Open Bel-C Lower 1 5,608’5,612’4,885’4,888’4 08/22/22 Open Bel-C Lower 2 5,625’5,630’4,899’4,904’5 08/22/22 Open Bel-D Upper 5,640’5,645’4,912’4,916’5 08/22/22 Open Bel-D Mid 5,712’5,717’4,974’4,978’5 08/22/22 Open Bel-D Lower 5,733’5,743’4,992’5,000’10 08/22/22 Open Bel-E Upper 5,779’5,799’5,031’5,048’20 08/22/22 Open Bel-E Mid 5,890’5,896’5,125’5,130’6 08/22/22 Open Bel-E Lower 5,927’5,945’5,157’5,172’18 08/21/22 Open Bel-F Mid 6,002’6,007’5,221’5,225’5 08/21/22 Open Bel-F Lower 6,052’6,064’5,263’5,273’12 08/21/22 Open Bel-G Mid 6,107’6,117’5,310’5,319’10 08/21/22 Open Bel-G Lower 6,124’6,130’5,325’5,330’6 08/21/22 Open Activity Date Ops Summary 7/3/2022 Secure drill package to sub structure. Rig welder working on stairs, handrails to safe out the rig. (note: Tested A-09A tree w/Vault rep. against TWC to 5k psi f/5min. on chart-good).;Drill holes in skid rails and secure sub structure t/deck. Remove dry hole tree from A-10B and cut grating to fit tbg spool LDS. Work boat.;N/U 9" x 11" 5k tbg spool, 13-5/8" 5m riser and DSA, 13-5/8" 5m BOP's and bell nipple. Install TT fill up line, bleed off line and pollution pan and torque same. Cont. t/work boat.;Measure flow line for fitting to shaker tank and fit same. Pressure up Koomey unit and function test BOP's.;P/u 4.5 test jt and m/u lower test plug, R/U test pump, floor valve and dart. Fill stack with h2o. Pressure test w/lower test plug in 11" 3m x 9" 3m Csg spool t/250-3k psi f/5min. -charted. Cont. test BOP's.;Inlet Water Used Today (bbl): 0 Inlet Water Used Cumulative (bbl): 0 Discharge Today (bbl): 0 Discharge Cumulative (bbl): 0 Daily down hole loss (bbl): 0 Total down hole loss (bbl): 0 7/4/2022 Grease choke manifold, fill annulus w/h2o. Flush through choke/kill lines and manifold w/same. Attempt t/test 11-3m x 9-3m csg head t/250-3k psi numerous times, no success. R/D test line, B/O test jt f/test plug and Top drive.;Pull test jt to the floor and observe leak on connection, re-tighten same. RIH and screw into test plug and re-test w/annular t/250-3k psi f/5min. on chart-good.;Cont. t/test 13-5/8" 5m BOP, choke manifold and floor valves w/4" and 4.5" test jts 250low/3000 psi high f/5min. -charted as per AOGCC/Hilcorp policy. Perform Accumulator draw down and function test f/drillers emergency remote panel.;R/D test equipment, install MWD transducer in derrick on stand pipe goose neck.;Pick up clean out assy w/Wellbore Integrity Rep. and RIH t/3000’, attempt t/Kelly up-top drive die retainer not holding-die pushing up.;Pull damaged die retainer plates and fabricate new. inspect grabber blocks and dies.;Inlet Water Used Today (bbl): 78 (Used for rinse of RCRA-empty tank) Inlet Water Used Cumulative (bbl): 78 Discharge Today (bbl): 78 (Rinse volume from RCRA-empty tank) Discharge Cumulative (bbl): 78 Daily down hole loss (bbl): 0 Total down hole loss (bbl): 0 7/5/2022 Kelly up top drive and tag CIBP at 3059' with 10K down.;Displace well to 9.2 ppg LSND 4 bpm, 300 psi while reciprocating string. Flush choke lines, choke manifold and kill line.;Close annular and pressure test 7-5/8" casing to 2500 psi for 30 charted min. Good test.;Pump dry job and pull out of the hole, racking back DP and HWDP. Lay out mills and casing scraper - look good.;Hold PJSM with rig crew, WIS rep, MWD and DD for picking up whipstock assembly. Make up mills and MWD and shallow test - good. Make up slide to mills and and run in the hole. Tag tight spot at 145'.;Discuss options and review 7-5/8" casing run information. Pull out of the hole with whipstock. When pulling whipstock shear bolt pin, observed that the pin was not fully in the groove pushing mills 1/8" further out from slide. Lay out slide assembly and remove shear bolt and replace with new.;Make up whipstock with new shear pin and TIH, tag top of CIBP @3065'. Orient whipstock @84deg ROHS w/Haliburton DD. Set whipstock @3063'DPM As per WIS Rep.. P/O wt-92k, S/O wt-87k.;Mill window f/3042' TOW t/3043' as per WIS @250gpm, 750psi, 100rpm, 4-5k trq, 2-3k wob, P/U wt-92k, S/O wt-87k, rot wt-90k.;Cont. mill window f/3043' t/3052' BOW and 20ft new hole 3074'md as per WIS @265gpm, 805psi, 109rpm, 6k trq, 2-3k wob, P/U wt-92k, S/O wt-87k, rot wt-90k.;Circulate and condition mud 9.1ppg in/out.;Perform FIT t/930psi for a 15.7ppg, 1.5bbls pumped w/1.5bbls returned.;Annulus pressure: OA=0, IA=50psi, @2330hrs.;Inlet Water Used Today (bbl): 0 Inlet Water Used Cumulative (bbl): 78 Discharge Today (bbl): 0 Discharge Cumulative (bbl): 78 Daily down hole loss (bbl): 0 Total down hole loss (bbl): 0 7/6/2022 Pump dry job, POOH w/mill assy f/3041' t/surface.;L/D 6-3/4" mill assy and MWD.;P/U Johnny Whacker (flush tool), flush stack, well head and choke/kill line. L/D Flush tool.;Clean and clear rig floor of WIS tools, simop- service rig, c/o die blocks on top drive with set machined dwn 1/4".;M/U 6-3/4" drilling assy-BHA #2, t/519 and shallow pulse test-good. TIH t/3040', monitoring displacement on TT. Orient tool face 84ROHS and pass through window -no issues.;Attempt t/Kelly up, stand riding on the back of the 3.5" bell guide, causing pipe handler t/rotate with top drive. Remove 3.5" bell guide and replace w/5" bell guide. Had to widen counter sink hole to accommodate new machine die blocks. RIH f/3040 t/3074'.;Drill rat hole f/BHA f/3074' t/3345', as per Haliburton DD/wp03. 272gpm, 1150psi, 80rpm, 3k trq, 2-3k wob, p/u 88k, s/o 75k, rot 85k. Back ream connection full stand, sweeps as needed.;Get SPR's, Circ. B/U 270gpm, 1150 psi, 50rpm, 3k trq, p/u 88k, s/o 75k, rot 85k.;Monitor well for flow-good, POOH f/3345' t/surface.;P/U BHA#3.;casing pressure @2330hrs OA=0psi, IA=50psi Metal recovered: Today: 65.5 (includes milling operations) Cumulative: 65.5;Inlet Water Used Today (bbl): 6 Inlet Water Used Cumulative (bbl): 84 Discharge Today (bbl): 18 Discharge Cumulative (bbl): 96 Daily down hole loss (bbl): 0 Total down hole loss (bbl): 0 n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: NCIU A-10B North Cook Inlet Unit Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00034 NCIU A-10B Drilling Spud Date: Kelly up top drive and tag CIBP at 3059' with 10K down. p g tag top of CIBP @3065'. Orientyy p whipstock @84deg ROHS w/Haliburton DD. Set whipstock @3063'DPM A POOH w/mill assy f/3041' t/surface.;L/D 6-3/4" mill assy a ;Mill window f/3042' TOW t/3043' gp @ Milled window. FIT to 15.7 ppg. My calc is 15.6 ppg. -WCB p ;Cont. mill window f/3043' t/3052' pg t/3074'.;Drill rat hole f/BHA f/3074' t/3345', p ;Perform FIT t/930psi for a 15.7ppg, BOW and 20ft new hole 3074'md 7/7/2022 MU BHA #3, plug in and upload to MWD tools. Perform shallow pulse test and install source.;Run in the hole with BHA #3, monitor well with trip tank - proper displacement. Filling pipe every 20 stands. MW 9.2 ppg in/out.;Drill 6-3/4" hole per DD and wp03 F/ 3345' T/ 3710', 254gpm, 1300psi, 80rpm, 3-4k trq, 3-7k wob, p/u=105k, s/o=90k, rot=95k.;Drill 6-3/4" hole per DD and wp03 F/ 3710' T/ 4819', 254gpm, 1180psi, 6.3 flow, 80rpm, 3-4k trq, 3-7k wob, p/u=105k, s/o=90k, rot=95k.;Metal collected: Today: 29, Cumulative: 94.5 Csg pressures @2330hrs: OA=5psi, IA=50psi Distance to wp03: 6.31, projected to bit: 4.72 high, 4.19 left.;Inlet Water Used Today: 16 Inlet Water Used Cumulative: 100 Discharge Today: 49 Discharge Cumulative: 145 Daily down hole loss: 0 Total down hole loss: 0 7/8/2022 Drill 6-3/4" hole per DD and wp03 F/ 3970' T/ 4346'. 376 ft at 47.0 ft/hr ave ROP 80 RPM, 5-7K TOR, 4-7K WOB, 250 GPM, 1250 PSI 125K up, 95K dn, 100k rot. Backream each connection 2x.;Circulate high-vis sweep and monitor well for 10 min (static) prior to performing short trip back to 7-5/8" casing window.;Short trip F/ 4346' T/ 3030' on elevators. No issues pulling through open hole or through window with BHA. Monitor well with trip tank, hole taking proper fill.;Service top drive, blocks, drawworks and rig floor equipment.;Run in the hole on elevators F/ 3030' T/4346', monitoring displacement on the TT., Wash dwn last 30' t/btm.;Drill/Slide as per wp03/DD f/4346' t/4573' @ 250gpm,1150psi, 8.9flow, 80rpm, 4-5k trq, p/u=110k, s/o=95k, rot=100k. Sweep hole every 500' or as needed, back ream x2 ea. std.;Drill/Slide as per wp03/DD f/4573' T/4819' @ 255gpm,1386psi, 9.9 flow, 80rpm, 6-7k trq, p/u=113k, s/o=97k, rot=102k. Sweep hole every 500' or as needed, back ream x2 ea. std.;Csg pressure @23:45hrs: OA=0psi, IA=54psi Metal Recovery #'s: Today-5.5#, Cumulative-100# Distance to wp03: 6.31, projected to bit: 4.72 high, 4.19 left.;Inlet Water Used Today: 39 Inlet Water Used Cumulative: 139 Discharge Today: 133 Discharge Cumulative: 279 Daily down hole loss: 0 Total down hole loss: 0 7/9/2022 Drill/Slide 6-3/4" hole per DD and wp03 F/ 4819' T/ 5104'. - 285' at 47.5 fph ave ROP. PU 120K, SO 95K, ROT 100K. 250 GPM, 1300 PSI, 80 RPM, 6-7K TOR, 3- 7K WOB Backream each stand 2x. Pump High vis sweeps every 500'. MW in/out = 9.2 ppg/9.2 ppg Max gas = 71 units.;Drill/Slide 6-3/4" hole per DD and wp03 F/ 5104' T/ 5385'. - 281' at 46.8 fph ave ROP. PU 135K, SO 100K, ROT 110K. 250 GPM, 1483 PSI, 80 RPM, 6-8K TOR, 3-6K WOB Backream each stand 2x. Pump High vis sweeps every 500'. MW in/out = 9.2 ppg/9.2 ppg Max gas = 96 units.;Circulate hole clean with high-vis sweep. Get SPR's: @5385'md/4660'tvd, 9.2ppg, pmp#1=20spm/250psi, 30spm/350psi, 40spm/500psi pmp#2=20spm/230psi, 30spm/340psi, 40spm/480psi.;Short trip-monitor well f/10min.-good. POOH f/5385' t/4067', monitoring fill on the TT.. P/U=195k break over wt., no other issues.;Cont. short trip, RIH f/4067' t/5385', monitoring fill on the TT. Wash down last std, no issues.;Drill/Slide 6-3/4" hole per DD and wp03 F/ 5385' T/ 5670', 250gpm, 1575psi, 83rpm, 8.5 flow, 7.5-8k trq, p/u=138, s/o=103k, rot=113k. Backream each stand 2x. Pump High vis sweeps every 500'.;Metals Recovery (lbs.): Today: 5, Cumulative: 105 Distance to wp03: 5.61 Projected to bit: 0.23Low, 5.6 Right Annulus pressures @2330hrs: OA=0psi, IA=50psi;Inlet Water Used Today: 93 Inlet Water Used Cumulative: 232 Discharge Today: 93 Discharge Cumulative: 372 Daily down hole loss: 0 Total down hole loss: 0 7/10/2022 Drill/Slide 6-3/4" hole per DD and wp03 F/ 5670' T/ 5874'. - 204' at 34.0 fph ave ROP. PU 150K, SO 95K, ROT 100K. 250 GPM, 1780 PSI, 80 RPM, 7-8K TOR, 3- 7K WOB Backream each stand 2x. MW in/out = 9.1 ppg/9.2 ppg Max gas = 35 units.;Drill/Slide 6-3/4" hole per DD and wp03 F/ 5874' T/ 6138'. - 264' at 44.0 fph ave ROP. PU 150K, SO 100K, ROT 120K. 250 GPM, 1750 PSI, 80 RPM, 7-8K TOR, 3-7K WOB Backream each stand 2x. Pumping sweeps every 500 ft. MW in/out = 9.1+ ppg/9.2 ppg Max gas = 75 units.;Drill/Slide 6-3/4" hole per DD and wp03 F/ 6138' T/ 6271' TD - 133' at 44.0 fph ave ROP. PU 150K, SO 100K, ROT 120K. 247 GPM, 1780 PSI, 60 RPM, 5-7K TOR, 5-15K WOB.;Pump 20bbl hi-vis sweep at TD, 254gpm, 1450psi, 50rpm, 6-7k trq, rotate and reciprocate, no lag on strokes 5-10% increase in flow upon return, no visible cutting increase.;Wiper Trip- Monitor well, fill Trip Tank. POOH f/6271' t/3031', monitoring fill on the trip tank. No issues.;Service Rig.;RIH f/3031' t/6271', monitoring displacement on the trip tank. No issues.;Metals Recovery (lbs): Today: 10, Cumulative: 115 Annulus pressures: OA=0psi, IA= Distance to wp03: 5.06' Projected to bit: 3.24' low, 3.88' left;Inlet Water Used Today: 386 Inlet Water Used Cumulative: 618 Discharge Today: 221 Discharge Cumulative: 593 Daily down hole loss: 0 Total down hole loss: 0 TD'd @6271'. -WCB y ppg ;Drill 6-3/4" hole per DD and wp03 F/ 3710' T/ 4819', p ;Drill 6-3/4" hole per DD and wp03 F/ 3345' T/ 3710', p ;Drill/Slide 6-3/4" hole per DD and wp03 F/ 6138' T/ 6271' ;Drill/Slide 6-3/4" hole per DD and wp03 F/ 5874' T/ 6138'. Drill 6-3/4" hole per DD and wp03 F/ 3970' T/ 4346'. Drill/Slide 6-3/4" hole per DD and wp03 F/ 4819' T/ 5104'. units.;Drill/Slide 6-3/4" hole per DD and wp03 F/ 5104' T/ 5385'. Drill/Slide 6-3/4" hole per DD and wp03 F/ 5670' T/ 5874'. g ;Drill/Slide 6-3/4" hole per DD and wp03 F/ 5385' T/ 5670', 7/11/2022 Cont. to circ. 25bbl sweep around (40#/bbl walnut-marker) @250gpm, 1720psi, 50rpm, 5-7k trq, no lag on sweep/stks. Hole clean.;Gather SPR's @6271'TD/5449'tvd, 9.2ppg Pmp#1= 20spm/300psi, 30spm/440psi, 40spm/625psi Pmp#2= 20spm/300psi, 30spm, 450psi, 40spm/625psi.;Flow check-static, pmp slug and POOH f/6271' t/3040', monitor well @ csg window-static. Cont. POOH t/578', monitoring fill on the TT.;Rack back Flex DC and HWDP t/113', Unload radio-active sources, down load data and L/D smart tools, as per Haliburton DD/MWD Reps.;Clean and clear rig floor, adjust brake bands and c/o guide roller on Draw works.;R/U Hydraulic power tongs, 4.5" handling tools and equipment w/Parker Csg. P/U cement head and install xo's and pup jt, L/D same. R/U cement hose's, chicksan and manifold.;Wait on crane to unload boat, P/U centralizers, M/U floor valve on xo's for 4.5" liner. Fuel Csg unit.;Pre-job, P/U 4.5" 12.6 L-80 shoe track as per Baker Rep., baker lock same and check floats-good. RIH w/4.5" 12.6# L-80 JFEBear liner t/1648' monitoring displacement on TT and filling csg on the fly.;Cont. RIH w/4.5" liner t/3378'. filling on the fly and monitoring displacement on the TT.;C/O handling equipment t/3.5" and P/U Baker ZXP liner hanger as per Baker Rep., C/O handling equipment back to 4" and Kelly up on 1std and run ZXP in the hole 60'+-.;Circulate 1.5 string volumes @ 260gpm and 365psi.;Metals Recovery (lbs): Today: 0, Cumulative: 115 Annulus pressures@ 2345hrs: OA=0psi, IA=50psi Distance to wp03: 5.06' Projected to bit: 3.24'low, 3.88' left;Inlet Water Used Today: 0 Inlet Water Used Cumulative: 618 Discharge Today: 237 Discharge Cumulative: 829 Daily down hole loss: 0 Total down hole loss: 0 7/12/2022 RIH w/ 4-1/2" 12.6# L-80 JFEBear Casing on 4" DP t/ 6265' @ 2 min a stand;P/up cmt head and 15' space out pup. Brk circ and stage up rate . Tag btm @ 7271' w/ 5k. Up 140K Dn 95k;Circ and condition @ 5 bpm @ 515 psi while reciprocating pipe . Up 140k DN 95k;Hold PJSM. Halliburton Flush cmt line with water to shaker tank and brk circ w/5 bbl water ahead . PT lines 1380L 5078H ok. Halliburton mix and pumped 30 bbl @ 10.5 ppg tuned spacer @ 2 bpm @ 250 psi. Mix and pump 129 bbls 595 sx of 15.3 ppg cmt @ 4bpm @ 550 psi. Drop dart and Halliburton;and launch same w/ 10 bbls water. Displaced w/ 9.2 ppg mud @ 5 bpm @ 1566 psi Bump plug 1/2 bbl late and pressured up t/ 2021 psi. CIP @ 16:44 hrs. reciprocated pipe up to displacement where pipe became sticky w/38 bbls lost during cmt job. Chk floats good;Set dn 50k and pressure up to 3000 psi w/ good indication of packer shear w/ top @ 2848' test back side t/ 1065 psi 5 min ok;L/dn cmt head and lines;Pressure up and pull out and circ clean @ 494 gpm @ 825 psi w/ 111 bbls of contaminated and strung-out spacer and cmt back, estimate ~20 bbls cement back to surface;Pooh f/ 2848' chk and l/dn liner running tool ok;Clean and clear rig floor service rig;P/up and m/up baker 6.5" polish mill and trip in the hole to 2846', monitoring well with trip tank.;Tag top of liner at 2846' with polish mill. Polish PBR per Baker rep, 1.5 bpm, 75 psi, 10 rpm, 3k torque. Pick up out of PBR and circulate bottoms up, 7 bpm, 300 psi and perform 15 min flow check - static.;Pooh f/ 2846' and lay down polish mills. Break off 15' pup from bottom of cement head and lay both back to deck.;Pull wear bushing.;Rig up and test 4-1/2" liner. Purge air from stack, close blind rams. Troubleshoot pumps - unable to maintain prime. Move fluid in pits. PT liner to 2100 psi for 30 charted min - good test.;Rig up to run 4-1/2" IBT upper completion.;Metals Recovery (lbs): Today: 0, Cumulative: 115 Annulus pressures@ 2345hrs: OA=0psi, IA=50psi Distance to wp03: 5.06' Projected to bit: 3.24'low, 3.88' left;Inlet Water Used Today: 0 Inlet Water Used Cumulative: 618 Discharge Today: 237 Discharge Cumulative: 829 Daily down hole loss: 0 Total down hole loss: 0 7/13/2022 P/u and Run BOT 5.75" 17# bullet seal assy on 4-1/2" 12.6# L-80 IBTM upper completion. t/ 2472' confirm pipe count. p/up baker S-5 BXCE 9Cr-IMO 80ksi MYS 4-1/2" IBT SSSV Install control line and test same t/ 5000 psi ok w/ opening pressure @2200 psi.;Continue p/up 4-1/2" completion t/ 2846' and no go out. Space out and install pup and P/up m/up dress hanger and test control line 5000 psi ok rih t/ 2828' R/up to circ.;Pump high vis sweep and chg well over to Raw sea water @ 430 gpm @ 343 psi. Pump and chg well over to inhibited drill water and R/dn tbg handling equipment.;Pump out stack and land hanger w/ 70k (blocks @ 45k) 1.71' off no go @ 2846'.;Perform M.I.T pump dn tbg and pressure up t/ 2050 psi on chart for 30 min w/ annulus open good. pump dn annulus and pressure up to 1600 psi on chart for 30 min w/ tbg open Good.;Terminate SSSV control line with Pollard. Lay down landing assembly. Install TWC.;Nipple down bell nipple and pollution pan. Disconnect fill up line and bleed off line. Nipple down 13-5/8 BOPE stack and set back. Nipple down 3-5/8" high pressure riser.;Nipple up tree per Vault wellhead rep. Pressure test hanger void to 5000 psi for 15 min - good test. Pressure test tree to 250/5000 psi for 5/10 min - good test.;Rig down prep to skid rig to A-11A. g g g ;Tag top of liner at 2846' with polish mill. Polish PBR per Baker rep, p@ p circ clean @ 494 gpm @ 825 psi w/ 111 bbls of contaminated and strung-out spacer and cmt back, estimate ~20 bbls cement back to surface; pgppp Halliburton mix and pumped 30 bbl @ 10.5 ppg tuned spacer @ 2 bpm @ 250 psi.p p @ ppg p@p@p Mix and pump 129 bbls 595 sx of 15.3 ppg cmt @ 4bpm @ 550 psi. Drop dart and Halliburton;and launch same w/ 10 bbls water. Displaced w/ 9.2 ppg mud @ 5 pp bpm @ 1566 psi Bump plug 1/ Running liner in hole. -WCB Tag btm Liner set. ~20bbls cement returned. Tagged top of liner @2846'. -WCB P/u and Run BOT 5.75" 17# bullet seal assy on 4-1/2" 12.6# L-80 IBTM upper completion. RIH w/ 4-1/2" 12.6# L-80 JFEBear Casing on 4" DP t/ 6265' / pp pp ;Continue p/up 4-1/2" completion t/ 2846' and no go out. gggqpp ;Perform M.I.T pump dn tbg and pressure up t/ 2050 psi on chart for 30 min w/ annulus open good. Upper completion run. Passing MIT-T and MIT-IA. -WCB P/U 4.5" 12.6 L-80 g j shoe track as per Baker Rep., baker lock same and check floats-good. RIH w/4.5" 12.6# L-80 JFEBear liner t/1648' monitoring displacement on TT and filling csg pp g gpg on the fly.;Cont. RIH w/4.5" liner t/3378'. filling on the fly and monitoring displacement on the TT.;C/O handling equipment t/3.5" and P/U Baker ZXP liner hanger y as per Baker Rep., y w/38 @ bbls lost during cmt job. Chk floats good; p@ p ppg g pump dn annulus and(@) g@ pressure up to 1600 psi on chart for 30 min w/ tbg open Good. pp pp@ pppp pressure up to 3000 psi w/ good indication of packer shear wppg p /2 bbl late pp / Activity Date Ops Summary 8/5/2022 Complete PJSM,& PTW, MIRU Eline, string line, rehead, PT lube 200L/2500H (Pass) RIH with 3.7 GR tool string. Tag at 2861'. COuld not pass. POOH, PU small tool string RIH with small tool string and sat down at 2861 again. POOH and Rig down. 8/16/2022 Morning safety meeting. PTW. Move BOPs and riser over to A-10B. PU injector head and lubricator. MU BHA -2.88"x.75' CTC, 2.88"x1.25' DFCV, 2.88"x6.5' BiDi jars, 2.88"x2.13' Disco, 2.88"x1.2' Circ sub, 2.875"x12.7' motor, 3.70"x1.5'. OAL - 26'. Function test BOP rams. Pressure test 250 psi low / 3500 psi high. Open well and RIH. Dry tag at 2865'.,PUH 20'. Bring on pump at 1.3 bpm. RIH and start milling. Seeing some motor work and stacking weight between 2865'-3000'. Upped pump rate to 1.5 bpm and milled to 3300'. Back-reamed to 2860' and shut down pump. Dry drifted and tagged at 6158'. Circulate bottoms up and POOH.,Unstab from the well. Break down milling BHA. MU HES memory CBL tools below YJ MHA. OAL - 28'. Open well and RIH. Begin logging from 6150' to 2650' at 45 fpm. POOH. Breakdown BHA, and verify CBL data - good data. Cement top estimated to be near LTP @ 2844'. Lay down lubricator and injector head. Install night cap on BOPs. SDFN. 8/17/2022 Morning safety meeting. PTW. Pickup injector head and lubricator. MU 3.72" JSN BHA. OAL - 6'. Pressure test to 250 psi and 3000 psi. RIH to 6150'. Pump nitrogen at 1200 scfm. Initial OTT volume was 10 bbls, expecting 126 bbls back (includes coil volume + wellbore volume). Final OTT strap was 133 bbls. Total volume removed from CT and well - 123 bbls. POOH. Secure tree.,Start demobilizing SLB CTU. Breakdown and rack iron, collect hoses and sensor/control lines, breakdown lubricator and stack BOPs, and prep all equipment to load out on 2 boats coming tonight.,Load out the Sovereign with equipment headed for Rig Tenders. Load Titan with equipment headed to the Steelhead. 8/21/2022 Morning safety meeting. PTW. Move riser, wireline valves and lubricator over to A-10B. Re-head EL wire. MU 2-7/8" x 6' HSC gun. Pressure test to 1500 psi. WHP is 309 psi. Confirm SSSV is pressured up.,Arm and RIH with 2-7/8" x 6' gun. Pull correlation log. Send to town, on depth. Perforate the Beluga G lower from 6124'-6130'. POOH. Gun was clean and dry. All shots fired. Pressures - 309 psi - no change.,MU 2-7/8" x 10' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga G mid from 6107'-6117'. POOH. Gun was clean and dry. All shots fired. Pressures - 306 - no change.,MU 2-7/8" x 12' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Bled WHP to 200 psi, shut in and WHP contniued to fall. Perforate the Beluga F Lower from 6052'- 6064'. POOH. Gun was clean and dry. All shots fired. Pressures - 148, 143, 140, 135.,MU 2-7/8" x 5' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga F mid from 6002'-6007'. POOH. Gun was clean and dry. All shots fired. Pressures - 103, 103, 104, 105.,MU 2-7/8" x 18' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga E Lower from 5927'-5945'. POOH. Gun was clean and dry. All shots fired. Pressures - 114, 115, 117, 118.,Lay down lubricator. Install night cap. SDFN. Walk the worksite on the Spartan Rig 151 for Gyro/whipstock work early tomorrow morning. Position Little Blackie EL unit. Re-head. Confirm Gyro tool communication. 8/22/2022 Morning safety meeting. PTW. Check in with the 151 Rig. They will be needing an EL crew around noon today. Standby for the crane to unload a boat and move some piping. Well is currently flowing at 550 mcf and 57 psi.,MU 2-7/8" x 6' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga E mid from 5890-5896'. POOH. Gun was clean and dry. All shots fired. Pressures - 57 psi - no change.,MU 2-7/8" x 20' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga E upper from 5779-5799'. POOH. Gun was clean and dry. All shots fired. Pressures - 58 psi - no change.,MU 2-7/8" x 10' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga D lower from 5733'-5743'. POOH. Gun was clean and dry. All shots fired. Pressures - 62 psi - no change.,MU 2-7/8" x 5' gun. Arm and RIH. Pull correlation log. Send to town, make 1' shift per Geo. Perforate the Beluga D mid from 5712'- 5717'. POOH. Gun was wet. All shots fired. Pressures - 59, 59, 58, 86. Pressure and rate stabilized at 1594 mcf and 118 psi.,MU 2-7/8" x 5' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga D upper from 5640'-5645'. POOH. Gun was wet. All shots fired. Pressures - 123, 121, 117, 171. Pressure and rate stabilized at 1343 mcf and 163 psi.,MU 2-7/8" x 5' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga C Lower 2 from 5625'-5630'. POOH. Gun was wet. All shots fired. Pressures - 160, 160, 164, 186. Pressure and rate stabilized at 1390 mcf and 166 psi.,MU 2-7/8" x 4' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga C Lower 1 from 5608'-5612'. POOH. Gun was . All shots fired. Pressures - 163, 163, 163, 186. Pressure and rate stabilized at 1370 mcf and 173 psi.,Lay down lubricator. Install night cap. Re-head. SDFN. 8/23/2022 AK E-line conduct JSA, review crane operations, approve PTW. Well flowing ~ 1.85 MM scfm @ 155 psi. Perforate with well flowing.,MU 2-7/8" x 14' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga C Mid from 5581'-5595'. POOH. Bull plug was a little wet with small amount of sand. All shots fired. Shoot well flowing at Pressure = 155 psi, increased to 560 psi after shooting.,MU 2-7/8" x 10' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga B Lower from 5455-5465'. POOH. Bull plug was dry. All shots fired. Shoot well flowing at Pressure = 565 psi, no change after shooting.,MU 2-7/8" x 20' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga B Mid from 5416-5436'. POOH. Bull plug was dry. All shots fired. Shoot well flowing at Pressure = 554 psi, no change after shooting.,MU 2-7/8" x 6' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga B Upper 2 from 5359-5365'. POOH. Bull plug was dry. All shots fired. Shoot well flowing at Pressure = 550 psi, no change after shooting.,MU 2-7/8" x 6' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga B Upper 1 from 5346-5352'. POOH. Bull plug was dry. All shots fired. Shoot well flowing at Pressure = 544 psi, no change after shooting.,MU 2-7/8" x 18' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga A Lower from 5287-5305'. POOH. Bull plug was dry. All shots fired. Shoot well flowing at Pressure = 527 psi, no change after shooting.,MU 2-7/8" x 12' gun. Arm and RIH. Pull correlation log. Send to town, on depth. Perforate the Beluga A Upper from 5224-5236'. POOH. Bull plug was dry. All shots fired. Shoot well flowing at Pressure = 520 psi, no change after shooting.,Laydown lubricator and remove wireline valves from tree. Install tree cap and secure well. Hand well over to production with well flowing. MU X-over and wireline valves to A-11A. Re-head E-line. SDFN. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: NCIU A-10B North Cook Inlet Unit Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00034 NCIU A-10B Completion Spud Date: MIRU Eline, g Perforate the Beluga B Upper 1 from 5346-5352'. g p Perforate the Beluga A Lower from 5287-5305'. g p Perforate the Beluga B Lower from 5455-5465'. POOH. y Perforate the Beluga E Lower from 5927'-5945'. g Tag at 2861'. COuld not pass. y Perforate the Beluga D mid from 5712'- 5717'. POOH. yg Perforate the Beluga B Upper 2 from 5359-5365'. Perforate theg@ Beluga C Mid from 5581'-5595'. gg Perforate the Beluga F Lower from 6052'- 6064'. Perforate the Beluga E pp g mid from 5890-5896'. Coil cleared wellbore w/N2. -WCB CBL shows TOC @~3040. -WCB Perforate the Beluga C Lower 2 from 5625'-5630'. y Perforate the Beluga F mid from 6002'-6007'. y Perforate the Beluga E upper from 5779-5799'. y Perforate the Beluga G mid from 6107'-6117'. gp Perforate the Beluga G lower fromp 6124'-6130'. POOH. yg g Well is currently flowing at 550 mcf and 57 psi. g RIH with small tool string and sat down at 2861 again. POOH g Perforate the Beluga A Upper from 5224-5236'. RIH to 6150'. Pumpgy g pj p pp nitrogen at 1200 scfm. Initial OTT volume was 10 bbls, expecting 126 bbls back (includes coil volume + wellbore volume). Final OTT strap was 133 bbls. Totalg volume removed from CT and well - 123 bbls. POOH. Perforate the Beluga C Lower 1 from 5608'-5612'. g Perforate the Beluga B Mid from 5416-5436'. EL couldn't get down - tagged 2861'. -WCB y Perforate the Beluga D lower from 5733'-5743'. Openjppgp well and RIH. Dry tag at 2865'.,PUH 20'. Bring on pump at 1.3 bpm. RIH and start milling. Seeing some motor work and stacking weight between 2865'-3000'. yg g p p p g g Upped pump rate to 1.5 bpm and milled to 3300'. Back-reamed to 2860' and shut down pump. Dry drifted and tagged at 6158'. Re-head EL wire. Perforate the Beluga D upper from 5640'-5645'. p Begin logging from 6150' togy p 2650' at 45 fpm. POOH. Breakdown BHA, and verify CBL data - good data. Cement top estimated to be near LTP @ 2844'. gp Pressure and rate stabilized at 1370 mcf and 173 psi. ! !" !"#$ %&& '() *) #+ ) ,- ) ) .) ./) ! 0 +)"## !$!%&'(') 1) !/)*+, 0 ) !$!%&'(') ) - + 0 *) 2 *) '( 03) * *) . /&0123 4 /&01 **4 5 6 "- 7-. 778 . .' 1 +) +) 41) 1) 546#. 56# '" . ) ( ( & 9:' '0)(0 ))& 66(0 ( . +4)0)() (9 ';6<)9(:) 9 ;9'<96(' 0- ./ 789 :+ 1 7,9 * 1 789 ! 0+*01 !=="& && 0> >& && 9( : 0)(:/ 99 &9('9'69):6 ' )-) +) 1 ! ( + - ) :*7,-9 7 9 56# 7 9 789 546#. 7 9 ,; )9)()) 9 (/0 ( ( 9)()) :* 7 9 '1* ,* 7./9 , 7 9 0>'>& && )?=+?7, )'=@A 7B )()) 9)()) & :=1 4 9>/>& : )?!C#= &)= AC# # 77 (') / :(') **$2++ 2 /> >/'/ )?"- "@>6A!=="8 & /'('0 ) :(6) **$2++ 1 :>'>& ) )?"-, D, 7 6"@>6A!=="8E 3 , 7() 96( ' &&9(' "-, D, 7141 !4 '>&:>& && 0 7 9 ! 789 < 789 546#. 7 9 56# 7 9 ,- 7 9 ,- 7 9 0 1 79 0 41 79 - 79 786=9 ,* 9)()) ( ( 9)()) ( ( 0)() & 9:' '0)(0 ))& 66(0 ( ( 2C2 )()) (&) ))'(:6 )()) ( / ( 6&)() & 9:' '0)(: ))& 66() (6' ( ) )?=+?7,14 9)()) ()& ))(00 9)()) () (6&'(0 & 9:' '06( & ))& 66( ) (/ ( : )?=+?7,14 & )()) ()0 )&'(:9 & )()) (90 () 0'(0 & 9:' '06(&: ))& 6)(:: (& (& )?=+?7,14 &9)()) ()0 )&'(9 &9)()) (:6 (6:&'(0 & 9:' '06(99 ))& 6)(0 ( (' )?=+?7,14 ) )()) ()/ )&6(&& ) )()) ( ('00'(0 & 9:' '06(:) ))& 6)(9& ( 9 (: )?=+?7,14 )9)()) (): )&6(9 )9)()) (): (:'&&'(0 & 9:' '09( ))& 6)()) ( & (& )?=+?7,14 6 )()) (6 )&:(06 6 )()& ('0 ( 9&0'('/ & 9:' '09()/ ))& 6)(6 ( : (&6 )?=+?7,14 69)()) (6& )6 (0 69)()& (// (&)&'('/ & 9:' '09(0& ))& 6&(// (0 ()& )?=+?7,14 9 )()) (6 )9:(:) 9 )()& &()9 (&0)0'('/ & 9:' '0'( 0 ))& 6&(/) (&0 (6/ )?=+?7,14 99)()) ()0 '(6 99)()& &('/ (&'6&'('/ & 9:' '0'(6 ))& 6&(/9 () (0 )?=+?7,14 '() *) #+ ) ,- ) ) .) ./) ! 0 +)"## !$!%&'(') 1) !/)*+, 0 ) !$!%&'(') ) - + 0 7 9 ! 789 < 789 546#. 7 9 56# 7 9 ,- 7 9 ,- 7 9 0 1 79 0 41 79 - 79 786=9 ,* ' )()) ('9 )9(0 ' )()& )( : ( 060'('/ & 9:' '0'(: ))& 6)(6 (09 ( )?=+?7,14 '9)()) (9) 9'(96 '9)() )('0 ()99&'(': & 9:' '00()/ ))& 6)(:0 (/ &( 6 )?=+?7,14 0 )()) )(6: 99(69 0 )(&' 6(/ (6'90'(') & 9:' '0:(9/ ))& 69(0 )(/ 6(&& )?=+?7,14 09)()) 9(0' ):(&) 09)( 0(0) 6(&''&'(60 & 9:' ':(): ))& 6:(96 9(&/ :(: )?=+?7,14 : )()) :( ) &'(:/ : &(0) &(:& 0()/'0'( & 9:' ':'(6& ))& 9(09 9(&0 )(:& )?=+?7,14 :9)()) /() &:(): :9&(0 /(6) (:'0&9(96 & 9:' '/&(/: ))& 99() &(&6 & ('0 )?=+?7,14 / )()) /(:0 )&(:) / (6/ &'(9& 9( 0006(:' & 9:' 0 ( ))& 9/('& &( : &:(6 )?=+?7,14 /9)()) (6/ )6()9 /9 (0 ))(:: /(/':&6( 0 & 9:' 0 0(&/ ))& '6(' ()9 )'(:6 )?=+?7,14 )()) (: )6(&6 ///(0' 6(:' &9(6 :0)() & 9:' 09(& ))& 0 (0 &('& 6'( / )?=+?7,14 9)()) )(/ ))(9: 6:(90 9 (:6 )(6)/&(/6 & 9:' 0&6( / ))& 0'()6 &(0/ 9'(6) )?=+?7,14 (') 6(09 )'( /9(66 ' (6 ):( /':(: & 9:' 0))(99 ))& :)(6 )(69 '0(') )?!C#=1&4 '9(') '(&9 )&( 90( 06(9/ 60(') ) (6: & 9:' 060(' ))& /&(:0 &(:: :)(/0 )?!C#=1&4 &9'(') /( )&( &6)(:) /0(/' '&(&) 0(& & 9:' 00 (09 ))& 0(: )( & ( ) )?!C#=1&4 )9 (') &(&9 ) ( ))&( / &9('/ 0:(:' & 9(6' & 9:' 0/:(&6 ))& &6(:6 &(9 6 (6 )?!C#=1&4 66&(') &)(09 )&( 60( : 99(:6 /0( & &/ (69 & 9:' :&:(& ))& 6)(6) &(:6 0)(9 )?!C#=1&4 9)9(') &'( )9( 9 (69 ::(6) :('6 )06(:& & 9:' :' ()/ ))& '9(9& &(00 & (:& )?!C#=1&4 '&0(') &'(9 &/( 9:)(/: &&&(/ 6 (' 690()9 & 9:' :/6(99 ))& :0(9) &(/) &6/(&9 )?!C#=1&4 0&&(') &'( ) ( ''/(: &9/(6: ' (:6 96&(99 & 9:' /) (: ))& & :(09 (0 &::()9 )?!C#=1&4 :0(') &6(9 )&( 099( &/6(&& :(0 '&:(60 & 9:' /'9(&6 ))& &) ( (:& )&'(6& )?!C#=1&4 / :(') &6(/: )&( :)0(09 )&'(9& & (:: 0(& & 9:' //0(&6 ))& &9 (06 (9) )'&(66 )?!C#=1&4 & /'('0 &)(09 6()' & /( )::('6 &60(/' ::&(60 & 9:0 9:('/ ))& &/0(0& &(9 6)0()' )?"-1)4 & 90(& &9(99 60( ) & '6(& 6 '('/ &'9(90 /)0(6/ & 9:0 0'(6: ))& )9(9/ 6(/ 6'&(6 )?"-1)4 & &:(: &:(&& 6:( & /( ' 6&9(6/ &:'(& //&(6) & 9:0 /6(/: ))& ))'(6 6()/ 6/ (& )?"-1)4 & &:( & ) (/: 6:()0 & 0)(9 669(/: ) /( && 6'(9& & 9:0 9() ))& )9/(' 6(69 9& (/ )?"-1)4 & )6(0& )6('& 6/(6 & &&6(0 6'0(9: )))(: & /0(96 & 9:0 )'(): ))& ):6('/ '( 0 99)(09 )?"-1)4 & 6 )(' )0(96 9 ( & &06(0 6/(6 )'(' & 60(96 & 9:0 9/(9) ))& 6&(:) 6(09 9/ (: )?"-1)4 & 6'6(0) 6 (:0 9&(& & )&(96 99(6 )/('0& /6(/ & 9:0 :)()6 ))& 66)(&6 9(:0 '&:(: )?"-1)4 & 9&0()6 66( 9(:9 & )'0(0 96(66 6&6(/:& &6( 0 & 9:0 & :(/ ))& 60'(/& 9(0 '0( / )?"-1)4 & 9:/(9 60(&' 9('& & 6() 9':(/: 69/(:/& &:6(9 & 9:0 &)9(/) ))& 9&(&) 9( / 09(9' )?"-1)4 & '6/('/ 6/(69 60(/' & 69() 9/:( & 6/6(&& )&6(9 & 9:0 &'6(60 ))& 96'(/' 9(:& 0' (9 )?"-1)4 & 0 (06 6:(:& 66('9 & 6/( : '&/(/ 9&0(9/& )'6(69 & 9:0 &/9(:' ))& 9: (0/ 6(&) : '(9 )?"-1)4 & 00(/' 60(09 6 (:6 & 9)(:& '')(69 99:(' & 6 9(/ & 9:0 )&:(/9 ))& '&(&/ 6(/' :9(0& )?"-1)4 & :)6(&: 60(&6 6(66 & 90)(/) '/:( 9 9::(:)& 660() & 9:0 )')( ))& '6)( ( : :/'(// )?"-1)4 & :/9(9& 6'(9& 6(0& & '9(0/ 0)(6: ':(6/& 6:/(' & 9:0 )/'( ))& '0)(9 (&& /6( / )?"-1)4 & /9'(9/ 6'( & 6(/6 & '9:( 0'6()0 '60(/&& 9)()0 & 9:0 6&:(9' ))& 0 )( 9 (:' /:6('' )?"-1)4 ) :(6) 66(:) 6(': & 0 (6 0/0(& '00(&/& 906(0: & 9:0 6' (/' ))& 0)&(:/ (/9 &:(9 )?"-1)4 ) 96( 69(60 6&(6 & 0&'(6/ :9(/) '/6(:& 9//(:' & 9:0 60/(66 ))& 09 ( 9 &() 9)( ' )?"-, D, 7164 ) '()' 6 (/9 60( / & 00(/6 :6'(&: 0&6('& '69() & 9:0 9 /()9 ))& 0: (6' :(:/ /9(6' )?"-, D, 7164 ) & ('& )0(' 6:( : & :66(/ ::'(9) 0':(/& 0:(&0 & 9:0 96:(/' ))& :&9( 0 )('& 99( )?"-, D, 7164 ) ) )(0) )6(&' 9)(): & /& () /&(' : ():& 0/)('0 & 9:0 9:&(/0 ))& :'0(0' 6(/ & /(' )?"-, D, 7164 '() *) #+ ) ,- ) ) .) ./) ! 0 +)"## !$!%&'(') 1) !/)*+, 0 ) !$!%&'(') ) - + 0 7 9 ! 789 < 789 546#. 7 9 56# 7 9 ,- 7 9 ,- 7 9 0 1 79 0 41 79 - 79 786=9 ,* ) )')(0: )&(9: 99(9 & /0 (6& /6 (6 :)0(&:& :6)(0/ & 9:0 ' (:& ))& :/6(/) )(6 &6&(' )?"-, D, 7164 ) 699(69 )&(&6 9:(&' ) 60(:& /'0(&6 :0:(6&& /&(/ & 9:0 '&:( ' ))& /)'(69 ('9 &/(60 )?"-, D, 7164 ) 99&( : )&(': 9'(:/ ) &/()9 //9( 9 /&&(/) &(0& & 9:0 '99(&) ))& /: ('& (:/ )6&(/: )?"-, D, 7164 ) '69( / )&(: 9:()& ) & 0(:' &(00 /'6() ) :(&) & 9:0 ':()6 ))) &)( (/: )/&(9& )?"-, D, 7164 ) 06 (60 )(0/ ' (9' ) &::(0' 60(6' 0(0/) '&() & 9:0 0 '()/ ))) ''(/0 () 66&(6/ )?"-, D, 7164 ) :)6(/9 )&()6 9/('' ) )':(:) 0&(6' 9(&:) &6&(& & 9:0 0) (09 ))) (: (00 6/&( )?"-, D, 7164 ) /&0()0 )(6' ' (: ) 660(&/ /'(/6 /)(96) )& ('' & 9:0 096('& ))) 9)(6 ( 96 (&9 )?"-, D, 7164 6 & ('/ )(: ' (&0 ) 9&'(09 &(&6 )'( &) 6 (& & 9:0 00:() ))) /'(&) ()0 9::(99 )?"-, D, 7164 6 6(9 )&()& 9/(9& ) ' '(&9 6'(&& 0/( /) 60/('& & 9:0 : &('9 ))) &)/('0 (0 ')0(06 )?"-, D, 7164 6 & /(9& )(: 9/(/ ) ':0( 9 0(66 &&&(&0) 9' (6& & 9:0 :&0(&6 ))) &:)(& (&& ':0(' )?"-, D, 7164 6 ) '(6 )&( ) 9/(&) ) 0'/(9' /0(' &''( 6) '6&(/) & 9:0 :9&()& ))) )&0()6 (/9 0)0()' )?"-, D, 7164 6 6 (') ) (0' 9/(' ) :6/(// &&&() ) :() ) 0&)()' & 9:0 :0'(': ))) )'/(/9 ()' 0:9(/& )?"-, D, 7164 6 6/)(/ ) (9: 9:(/ ) /) (&) &6'(6' )6/(/) : )(' & 9:0 / (6 ))) 6(/ (6& :))( )?"-, D, 7164 6 9/ ( ' ) (09 9:()' 6 &(/) &0(/: )/( ') ::'() & 9:0 /&9()& ))) 69)(6& ()6 ::(' )?"-, D, 7164 6 ':&( )( 0 90(6 6 /(:& &/0( / 6)( 0) /'9(/ & 9:0 /6/(:6 ))) 6/)(0: (') /&:(6/ )?"-, D, 7164 6 00:('/ ) (6) 9:(&: 6 06(/ )&)(6 60&(/6 6:(&: & 9:0 /09(96 ))) 9)'( (: /00(90 )?"-, D, 7164 6 :'/(6: )()9 90(:9 6 &9&(:& )6:( ' 9&(606 &'(/ & 9:0 ///('& ))) 909(/ ( 6 & &)(:& )?"-, D, 7164 6 /'6( ' ) (') ' (' 6 )))(/ )0)(6 996(& 6 & 0(&0 & 9:: &6( ))) ':( (60 & 0&( ) )?"-, D, 7164 9 9:()9 )(& ' (' 6 66(: )/0(&9 9/'(&&6 &::(0 & 9:: 60(9/ ))) '' ()' (' & /(:9 )?"-, D, 7164 9 99(& )(9: 9/(:0 6 6/0(6: 6&&(6' ')/(/&6 )0 (:9 & 9:: 0&(' ))) 0 6(6 (6& & '/(': )?"-, D, 7164 9 &6:('9 )(9) 9/(60 6 900( 660(9 ':&(&6 69 (60 & 9:: /'(&6 ))) 06'(/0 (&) & &:( )?"-, D, 7164 9 )66(0 )(99 9:( ' 6 '9:(/0 60)(& 0&9( :6 9)&()6 & 9:: &('0 ))) 0/ () (00 & &'0(0/ )?"-, D, 7164 9 6)0(/' )(09 90(6) 6 0):()' 6//()& 0''(6'6 '(0) & 9:: 60(: ))) :)&( 9 (6 & )'(): )?"-, D, 7164 9 9&:(&& )()& 90(&: 6 :9(&/ 9&6(0/ : '(&6 '::('' & 9:: 0&( ' ))) :0&(' (6: & )')() )?"-, D, 7164 9 '&&(6 )( ) 9'(:' 6 :/9(:0 99(&/ :60(66 0'/(&6 & 9:: /0(/0 ))) /)(60 (): & 6(0: )?"-, D, 7164 9 00()& )(9) 9'( : 6 /0'(// 90:(9 :::(&6 :9 ()' & 9:: &&6(9/ ))) /96(/) (': & 6' (:) )?"-, D, 7164 9 :&(6& )(0/ 90(06 9 90(/6 ' 9(0' /) ( )6 /)() & 9:: &9(&) ))) //0() (/' & 9 (60 )?"-, D, 7164 9 / /(&/ )(6/ 90( 9 6 (6 '))(& /0&(:99 )(0: & 9:: &00(/0 ))6 6 ()6 (6' & 9' (/0 )?"-, D, 7164 ' 6() )(69 9:()' 9 &&() '9/(9' & 6(09 /6('0 & 9:: ) )(0/ ))6 :&(9: ('/ & ' () )?"-, D, 7164 ' /:(&: )(:9 90(:0 9 ) (69 ':9('9 & 9'(''9 06(:& & 9:: )&/(&0 ))6 &6(/ (9 & '9/(9 )?"-, D, 7164 ' /&(6 )(9: 90()9 9 ):(9 0&(' & /:(669 &96(:: & 9:: )99(0 ))6 '0( ' (6 & 0 :() )?"-, D, 7164 ' &&9(' )(66 90( & 9 6 /(:& 0&(9' & )( )9 &:)(/ & 9:: )'6()' ))6 :(0: ('0 & 0&9(99 )?"-, D, 7164 ' &0( )(66 90( & 9 66:(99 0)6(69 & )&(:/9 )&(/& & 9:: )0'(/' ))6 & (:& ( & 06/( .*F2+2+ 8!A8!A A Benjamin Hand Digitally signed by Benjamin Hand Date: 2022.07.18 14:03:30 -08'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2022.07.18 14:27:35 -08'00' TD Shoe Depth: PBTD: No. Jts. Returned RKB RKB to BHF RKB to THF Jts. 1 1 1 1 1 1 1 8 1 10 1 1 23 1 33 1 Yes X No X Yes No Fluid Description: Liner hanger Info (Make/Model):Liner top Packer?:X Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type:Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type:Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? Yes X No Reciprocated?X Yes No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Full Joint 4.5" JFE-Bear L-80 12.6# With Centrali Full Joint 4.5" JFE-Bear L-80 12.6# With Centrali Casing (Or Liner) Detail Round Nose Float Shoe Short pup 4.5" JFE-Bear Full Joint 4.5" JFE-Bear L-80 12.6# w/ RA tag 5L-80 Rotate Csg Recip Csg Ft. Min. PPG9.2 Shoe @ 6269 FC @ Top of Liner 28476,224.00 Floats Held2100 LSND CASING RECORD County State Alaska Supv.Brett Anderson Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.NCIU A-10B Date Run 12-Jul-22 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top BTC Baker 1.80 6,269.00 6,267.20 5,250.11 4,285.34 9.82 5,301.96 5,292.13 5,292.134 1/2 12.6 L-80 JFE-Bear 42.02 JFE-Bear 4 1/2 12.6 L-80 JFE-Bear 5,250.11 JFE-Bear Baker 43.43 4 1/2 12.6 4 1/2 12.6 L-80 HRD-E ZXP Liner Top Pkr 6 5/8 L-80 2,890.20 964.77 L-80 JFE-Bear Short pup 4.5" JFE-Bear 4 1/2 12.6 L-80 JFE-Bear 4,285.34 4,275.52 1,385.33 4,275.52 2,890.20 9.82 Csg Wt. On Hook:140,000 Type Float Collar:Baker Float Collar No. Hrs to Run:13 9.2 5 1578 FI R S T S T A G E 10.5Tuned Spacer 30 82.6/81.1 2021 20 Halliburton 15.3 129 Bump press cement to surface Bump Plug? 16:44 7/12/2022 2,846 6,269.006,271.00 6,181.00 CEMENTING REPORT Csg Wt. On Slips:95,000 LSND 2,846.77 54.67 RKB to CHF 52.48 Type of Shoe:Round Nose Float Casing Crew:Parker Wellbore No. Jts. Delivered 88 No. Jts. Run 74 14 Length Measurements W/O Threads Ftg. Delivered Ftg. Run Ftg. Returned Ftg. Cut Jt. Ftg. Balance Baker ZXP www.wellez.net WellEz Information Management LLC ver_04818br 5 1 free-floating each joint Full Joint 4.5" BTC L-80 12.6# w/Centralizer 4 1/2 12.6 L-80 BTC 41.29 6,267.20 6,225.91 Float Collar 5 L-80 BTC Baker 1.49 6,225.91 6,224.42 Full Joint 4.5" BTC L-80 12.6# w/Centralizer 4 1/2 12.6 L-80 BTC 40.80 6,224.42 6,183.62 Landing Collar 5 L-80 BTC Baker 1.07 6,183.62 6,182.55 Full Joint 4.5" BTC L-80 12.6# w/Centralizer 4 1/2 12.6 L-80 BTC 41.41 6,182.55 6,141.14 XO Joint JFEBear to BTC 4 1/2 12.6 L-80 JFE-Bear 41.19 6,141.14 6,099.95 Full Joint 4.5" JFE-Bear L-80 12.6# With Centrali 4 1/2 12.6 L-80 JFE-Bear 335.69 6,099.95 5,764.26 Full Joint 4.5" JFE-Bear L-80 12.6# w/ RA tag 4 1/2 12.6 L-80 JFE-Bear 41.85 5,764.26 5,722.41 Full Joint 4.5" JFE-Bear L-80 12.6# With Centrali 4 1/2 12.6 L-80 JFE-Bear 420.46 5,722.41 6,301.96 Cement 595 1.24 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. From:McLellan, Bryan J (OGC) To:Chad Helgeson Cc:Donna Ambruz Subject:RE: NCIU A-10B PTD# 222-025 cement Bond Log Date:Wednesday, August 17, 2022 2:48:00 PM Chad Approval granted to proceed with perforating per Sundry 322-439 Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Wednesday, August 17, 2022 2:22 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: NCIU A-10B PTD# 222-025 cement Bond Log Bryan, Please find attached the cement Bond Log for NCIU A-10B, PTD# 222-025. We did get cement returns after unstinging from the liner top, and the cement looks like it went from top to bottom of the liner on this well, as we expected. Please provide approval to perforate after reviewing the bond log. Chad Helgeson KEN Operations Engineer Hilcorp Alaska LLC chelgeson@hilcorp.com 907-777-8405 (O) 907-229-4824 (C) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. 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ďůĞĞĚĚŽǁŶůŝŶĞƐďĞƚǁĞĞŶǁĞůůĂŶĚEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϲ͘Ϳ KŶĐĞǇŽƵŚĂǀĞĐŽŶĨŝƌŵĞĚůŝŶĞƐĂƌĞďůĞĚĚŽǁŶ͕ŶŽƚƌĂƉƉĞĚƉƌĞƐƐƵƌĞĞǆŝƐƚƐ͕ĂŶĚŶŽŶŝƚƌŽŐĞŶŚĂƐ ĂĐĐƵŵƵůĂƚĞĚďĞŐŝŶƌŝŐĚŽǁŶŽĨůŝŶĞƐĨƌŽŵƚŚĞEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϳ͘Ϳ &ŝŶĂůŝǌĞũŽďůŽŐĂŶĚĚŝƐĐƵƐƐŽƉĞƌĂƚŝŽŶƐǁŝƚŚtĞůůƐŝƚĞDĂŶĂŐĞƌ͘ŽĐƵŵĞŶƚĂŶǇůĞƐƐŽŶƐůĞĂƌŶĞĚ ĂŶĚĐŽŶĨŝƌŵĨŝŶĂůƌĂƚĞƐͬƉƌĞƐƐƵƌĞͬǀŽůƵŵĞƐŽĨƚŚĞũŽďĂŶĚƌĞŵĂŝŶŝŶŐŶŝƚƌŽŐĞŶŝŶƚŚĞƚƌĂŶƐƉŽƌƚ͘ ϭϴ͘Ϳ ZDKEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdĂŶŬ͘ 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. Received By: Date: Date: 07/25/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: NCIA-10B PTD: 222-025 API: 50-883-20030-02-00 FINAL LWD FORMATION EVALUATION LOGS (07/06/2022 to 07/10/20212) x DGR, SLIM EWR-4, ALD, CTN (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Survey SFTP Transfer - Data Folders: Please include current contact information if different from above. 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Chmielowski Date: 2022.07.18 09:14:10 -08'00' 5%'06 -6% tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůůEĂŵĞ͗E/hͲϭϬW/EƵŵďĞƌ͗ϱϬͲϴϴϯͲϮϬϬϯϬͲϬϮͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗WƌŽĚƵĐĞƌ >ĞŐ͗>ĞŐηϮ^ŽƌŶĞƌ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϳͬϭϯͬϮϮ ZŝŐ͗^ƉĂƌƚĂŶϭϱϭ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍ϰϬϯ ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ŽŶŶĂŵďƌƵǌ;ϴϯϬϱͿ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϮϮͲϬϮϱ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶ ;ϵϬϳͿϳϳϳͲϴϰϬϱ;KͿ ;ϵϬϳͿϮϮϵͲϰϴϮϰ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗^ĞĂŶDĐ>ĂƵŐŚůŝŶ ;ϵϬϳͿϮϮϯͲϲϳϴϰ;DͿ Current Bottom Hole Pressure: 2,546 psi @ 5,382 TVD 9.1 ppg current mud weight Maximum Potential Surface Pressure: 2,008 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) ƌŝĞĨtĞůů^ƵŵŵĂƌǇ E/hͲϬϭϬŝƐĂĞůƵŐĂƉƌŽĚƵĐĞƌƚŚĂƚŝƐĐƵƌƌĞŶƚůǇďĞŝŶŐĚƌŝůůĞĚ͘dŚŝƐƐƵŶĚƌǇŝƐƚŽƌƵŶƚƵďŝŶŐǁŝƚŚƚŚĞ ĚƌŝůůŝŶŐƌŝŐĂĨƚĞƌƚŚĞůŝŶĞƌŝƐĐĞŵĞŶƚĞĚŝŶƉůĂĐĞ͘ůůƉƌŽƉŽƐĞ ĚǁŽƌŬǁŝůůďĞǁŝƚŚƚŚĞůŝŶĞƌƐĞƚŝŶƉůĂĐĞ͘ WƌŽĐĞĚƵƌĞ͗ ϭ͘ ΎΎΎdĂŬĞŽǀĞƌŽƉĞƌĂƚŝŽŶƐĨƌŽŵƚŚĞƌŝůůŝŶŐ^ŝĚĞƚƌĂĐŬWƌŽŐƌĂŵWdϮϮϮͲϬϮϱ^ƚĞƉϭϴΎΎΎ Ϯ͘ dĞƐƚKW͛ƐĞǀĞƌǇϭϰĚĂǇƐĐŽŶƚŝŶƵĞĚĨƌŽŵůĂƐƚƚĞƐƚĚĂƚĞ͘ x dĞƐƚƚŽϮϱϬƉƐŝůŽǁͬϯ͕ϱϬϬƉƐŝŚŝŐŚͬϮ͕ϱϬϬƉƐŝĂŶŶƵůĂƌ͘;EŽƚĞ͗EŽƚŝĨǇK'ϰϴŚŽƵƌƐ ŝŶĂĚǀĂŶĐĞŽĨƚĞƐƚƚŽĂůůŽǁƚŚĞŵƚŽǁŝƚŶĞƐƐƚĞƐƚͿ͘ ϯ͘ ŽŵƉůĞƚŝŽŶĨůƵŝĚǁŝůůďĞŝŶŚŝďŝƚĞĚĚƌŝůůǁĂƚĞƌ͘KW͛ƐǁŝůůďĞ ĐůŽƐĞĚĂƐŶĞĞĚĞĚƚŽĐŝƌĐƵůĂƚĞƚŚĞ ǁĞůů͘ ϰ͘ WhϰͲϭͬϮ͟ƐĞĂůĂƐƐĞŵďůǇĂŶĚZ/,ǁͬϰͲϭͬϮ͟/dϭϮ͘ϲηƚƵďŝŶŐ͘ ϱ͘ /ŶƐƚĂůůdZ^^^sĂƉƉƌŽǆŝŵĂƚĞůǇĂƚϯϱϬ͛͘ZhĐŽŶƚƌŽůůŝŶĞƐƉŽŽůĞ ƌĂŶĚŝŶƐƚĂůůƐŝŶŐůĞĐŽŶƚƌŽůůŝŶĞ͘ ϲ͘ EŽͲŐŽƚŝĞďĂĐŬƐĞĂůĂƐƐĞŵďůǇŝŶůŝŶĞƌWZĂŶĚŵĂƌŬƉŝƉĞ͘WhƉƵƉƐƚŽƐƉĂĐĞŽƵƚ͘ ϳ͘ WhŚĂŶŐĞƌĂŶĚƚĞƌŵŝŶĂƚĞĐŽŶƚƌŽůůŝŶĞƚŚƌŽƵŐŚŚĂŶŐĞƌ͘>ĂŶĚƐƚƌ ŝŶŐ͕ŶŽƚĞĚŝƐƚĂŶĐĞŽĨƐĞĂůƐ ĨƌŽŵŶŽͲŐŽ͘ ϴ͘ /ŶƐƚĂůůƉĂĐŬŽĨĨĂŶĚƚĞƐƚŚĂŶŐĞƌǀŽŝĚ͘ ϵ͘ WƌĞƐƐƵƌĞƚĞƐƚĐĂƐŝŶŐƚŽϭ͕ϱϬϬƉƐŝĂŶĚĐŚĂƌƚĨŽƌϯϬŵŝŶ͘ ϭϬ͘ WƌĞƐƐƵƌĞƚĞƐƚƚƵďŝŶŐƚŽϮ͕ϬϬϬƉƐŝĂŶĚĐŚĂƌƚĨŽƌϯϬŵŝŶ͘ ϭϭ͘ /ŶƐƚĂůůWs ϭϮ͘ EKW͕EhdƌĞĞĂŶĚƚĞƐƚ ϭϯ͘ ZDKĂŶĚŵŽǀĞƚŽͲϭϬ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ tĞůů^ĐŚĞŵĂƚŝĐWƌŽƉŽƐĞĚ 0,7,$ WR SVL EMP hƉĚĂƚĞĚǇ͗,ϬϳͬϭϭͬϮϮ WƌŽƉŽƐĞĚ ^ĐŚĞŵĂƚŝĐ EŽƌƚŚŽŽŬ/ŶůĞƚhŶŝƚ dǇŽŶĞŬWůĂƚĨŽƌŵ tĞůů͗E/ͲϭϬ Wd͗ϮϮϮͲϬϮϱ W/͗ϱϬͲϴϴϯͲϮϬϬϯϬͲϬϮͲϬϬ ŽŵƉůĞƚĞĚ͗&ƵƚƵƌĞ -HZHOU\'HWDLO ,WHP 'HSWK 0' 'HSWK 79',' 2' 'HVFULSWLRQ %DNHU21<;5(756669 ¶ ¶ %DNHU=;3OLQHUKDQJHUSDFNHUDVV\ Wd͗цϲ͕ϭϬϮ͛d͗ϲ͕Ϯϳϭ͛ ´ Z<͗D^>сϭϮϲ͘ϲ͛ ϭϬͲϯͬϰ͟ ϰͲϭͬϮ͟ ´:LQGRZ #¶0' ´ E/hͲϭϬ DŽƚŚĞƌďŽƌĞ &DVLQJ 7XELQJ'HWDLO 6,=( :7 *5$'( &211 0,1,' 723 %700' ´ ´ 6XUI ¶ ´ + ´ 6XUI ¶ ´ - %7& ´ 6XUI ¶ ´ / %7& ´ 6XUI ¶ ´ / -)( ´ ¶ ¶¶ ´ / ,%70 ´ 6XUI ¶¶ 1RWHV 6KRUWMRLQWVRI´FDVLQJ#¶¶ 5$7DJ#¶ ¶ 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: North Cook Inlet Field, Tertiary System Gas Pool, NCIU A-10B Hilcorp Alaska, LLC Permit to Drill Number: 222-025 Surface Location: 1306' FNL, 1026' FWL, Sec 6, T11N, R9W, SM, AK Bottomhole Location: 432' FSL, 1852' FEL, Sec 31, T12N, R9W, SM, 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 May, 2022. 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VWRSSLQJDWDSUHGHWHUPLQHGSRLQWVXUIDFHSUHVVXUHLVLQFUHDVHGXQWLOWKHIRUPDWLRQEHJLQVWRWDNHIOXLG DWWKLVSRLQWWKHSUHVVXUHZLOOFRQWLQXHWRULVHEXWDWDVORZHUUDWH7KHV\VWHPLVVKXWLQDQGSUHVVXUH PRQLWRUHGDVZLWKDQ),7 3DJH5HYLVLRQ0DUFK NCI A-10B PTD Rev 0 &KRNH0DQLIROG6FKHPDWLF 3DJH5HYLVLRQ0DUFK NCI A-10B PTD Rev 0 3DJH5HYLVLRQ0DUFK NCI A-10B PTD Rev 0 &DVLQJ'HVLJQ,QIRUPDWLRQ 3DJH5HYLVLRQ0DUFK NCI A-10B PTD Rev 0 ´+ROH6HFWLRQ0$63 3DJH5HYLVLRQ0DUFK NCI A-10B PTD Rev 0 3ORW1$'*RYHUQPHQWDO6HFWLRQV 3DJH5HYLVLRQ0DUFK NCI A-10B PTD Rev 0 6ORW'LDJUDP 3DJH5HYLVLRQ0DUFK NCI A-10B PTD Rev 0 'LUHFWLRQDO3URJUDPZS$WWDFKHGVHSDUDWHO\ 6WDQGDUG3URSRVDO5HSRUW )HEUXDU\ 3ODQ1&,$%ZS +LOFRUS$ODVND//& 1RUWK&RRN,QOHW 1RUWK&RRN,QOHW8QLW 3ODQ1&,8$ 3ODQ1&,$% 2250 2625 3000 3375 3750 4125 4500 4875 5250 5625 6000 6375 6750 7125True Vertical Depth (750 usft/in)0 375 750 1125 1500 1875 2250 2625 3000 3375 3750 4125 4500 4875 5250 5625 Vertical Section at 50.97° (750 usft/in) NCI A-10B wp03 tgt12500300035004000 450050005500600065007000750080008250A-10250030003500400045005000550060006500700075008000 8 5 0 0 8 8 4 0 A-10A 7" TOW 4 1/2" x 6 1/8" 3 5 0 0 4 0 0 0 4 5 0 0 5 0 0 0 5 5 0 0 6 0 0 0 6 2 9 4 NCI A-10B wp03 Start Dir 12º/100' : 3003.33' MD, 2690.72'TVD : 80° RT TF End Dir : 3016.33' MD, 2699.87' TVD Start Dir 5º/100' : 3036.33' MD, 2713.91'TVD End Dir : 3367.04' MD, 2972.85' TVD Total Depth : 6293.94' MD, 5469.7' TVD Top CI 1 Top Beluga B Hilcorp Alaska, LLC Calculation Method:Minimum Curvature Error System:ISCWSA Scan Method: Closest Approach 3D Error Surface: Ellipsoid Separation Warning Method: Error Ratio WELL DETAILS: Plan: NCIU A-10 Water Depth: 101.00 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 2586673.71 332044.17 61° 4' 35.831 N 150° 56' 54.607 W SURVEY PROGRAM Date: 2022-02-04T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 103.33 1053.33 NCIU A-10 2008 Gyro (NCI A-10) 3_Gyro-CT_Csg+Cent 1101.63 1908.63 Copy of N COOK INLET UNIT A-10 Eastman (NCI A-10) 3_CB-Film-GSS 2096.67 3003.33 N COOK INLET UNIT A-10A (NCI A-10A) 3_MWD 3003.33 3403.00 NCI A-10B wp03 (Plan: NCI A-10B) 3_MWD_Interp Azi+Sag 3403.00 6293.94 NCI A-10B wp03 (Plan: NCI A-10B) 3_MWD+AX+Sag FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 3801.63 3675.00 4338.57 Top CI 1 4626.63 4500.00 5305.67 Top Beluga B REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: NCIU A-10, True North Vertical (TVD) Reference:NCI A-10B RKB @ 126.63usft Measured Depth Reference:NCI A-10B RKB @ 126.63usft Calculation Method:Minimum Curvature Project:North Cook Inlet Site:North Cook Inlet Unit Well:Plan: NCIU A-10 Wellbore:Plan: NCI A-10B Design:NCI A-10B wp03 CASING DETAILS TVD TVDSS MD Size Name 2690.72 2564.09 3003.33 7 7" TOW 5469.69 5343.06 6293.94 4-1/2 4 1/2" x 6 1/8" SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 3003.33 45.12 41.74 2690.72 789.23 670.19 0.00 0.00 1017.62 Start Dir 12º/100' : 3003.33' MD, 2690.72'TVD : 80° RT TF 2 3016.33 45.41 43.90 2699.87 796.00 676.46 12.00 80.00 1026.76 End Dir : 3016.33' MD, 2699.87' TVD 3 3036.33 45.41 43.90 2713.91 806.27 686.34 0.00 0.00 1040.90 Start Dir 5º/100' : 3036.33' MD, 2713.91'TVD 4 3367.04 31.45 58.40 2972.85 937.24 842.57 5.00 152.69 1244.74 End Dir : 3367.04' MD, 2972.85' TVD 5 5293.94 31.45 58.40 4616.63 1464.16 1698.91 0.00 0.00 2241.76 NCI A-10B wp03 tgt1 6 6293.94 31.45 58.40 5469.70 1737.61 2143.32 0.00 0.00 2759.19 Total Depth : 6293.94' MD, 5469.7' TVD 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 South(-)/North(+) (400 usft/in)600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 West(-)/East(+) (400 usft/in) NCI A-10B wp03 tgt1 2750 3000 3250 3500 3750 4 00 0 4 2 5 0 4 5 0 0 4 7 5 0 5 0 0 0 52505 5 0 0 5 7 5 0 6 0 0 0 6 2 6 7 A-10 2 5 0 0 2 7 5 0 3 0 0 0 3 2 5 0 3 5 0 0 3 7 5 0 4000 4250 4500 4 7 5 0 5 0 0 0 5 2 5 0 5 5 0 0 5 7 5 0 6 0 0 0 6 2 5 0 6500 6 7 5 0 6 8 9 3 A-10A 4 1/2" 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B0:'$;6DJ(OOLSVHHUURUWHUPVDUHFRUUHODWHGDFURVVVXUYH\WRROWLHRQSRLQWV6HSDUDWLRQLVWKHDFWXDOGLVWDQFHEHWZHHQHOOLSVRLGV&DOFXODWHGHOOLSVHVLQFRUSRUDWHVXUIDFHHUURUV&OHDUDQFH)DFWRU 'LVWDQFH%HWZHHQ3URILOHV'LVWDQFH%HWZHHQ3URILOHV(OOLSVH6HSDUDWLRQ'LVWDQFH%HWZHHQFHQWUHVLVWKHVWUDLJKWOLQHGLVWDQFHEHWZHHQZHOOERUHFHQWUHV$OOVWDWLRQFRRUGLQDWHVZHUHFDOFXODWHGXVLQJWKH0LQLPXP&XUYDWXUHPHWKRG)HEUXDU\ &203$663DJHRI 0.001.002.003.004.00Separation Factor3150 3325 3500 3675 3850 4025 4200 4375 4550 4725 4900 5075 5250 5425 5600 5775 5950 6125 6300Measured Depth (350 usft/in)A-10A-10ANo-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: NCIU A-10 NAD 1927 (NADCON CONUS)Alaska Zone 04Water Depth: 101.00+N/-S +E/-W Northing EastingLatitudeLongitude0.000.002586673.71332044.1761° 4' 35.831 N150° 56' 54.607 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: NCIU A-10, True NorthVertical (TVD) Reference:NCI A-10B RKB @ 126.63usftMeasured Depth Reference:NCI A-10B RKB @ 126.63usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-02-04T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool103.33 1053.33 NCIU A-10 2008 Gyro (NCI A-10) 3_Gyro-CT_Csg+Cent1101.63 1908.63 Copy of N COOK INLET UNIT A-10 Eastman (NCI A-10) 3_CB-Film-GSS2096.67 3003.33 N COOK INLET UNIT A-10A (NCI A-10A) 3_MWD3003.33 3403.00 NCI A-10B wp03 (Plan: NCI A-10B) 3_MWD_Interp Azi+Sag3403.00 6293.94 NCI A-10B wp03 (Plan: NCI A-10B) 3_MWD+AX+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)3150 3325 3500 3675 3850 4025 4200 4375 4550 4725 4900 5075 5250 5425 5600 5775 5950 6125 6300Measured Depth (350 usft/in)A-10GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference3003.33 To 6293.94Project: North Cook InletSite: North Cook Inlet UnitWell: Plan: NCIU A-10Wellbore: Plan: NCI A-10BPlan: NCI A-10B wp03CASING DETAILSTVD TVDSS MD Size Name2690.72 2564.09 3003.33 7 7" TOW5469.69 5343.06 6293.94 4-1/2 4 1/2" x 6 1/8" _____________________________________________________________________________________ Updated by DMA 05-11-22 SCHEMATIC ________________________ Tyonek Platform Well: A-10A Last Completed: 9/5/2003 PTD: 203-075 API: 50-883-20030-01-00____________ CASING DETAIL Size Wt Grade Conn ID Top Btm 30” 120.0 H-40 WELDED 27” 41’ 366’ 16” 62.5 H-40 WELDED 15.062” 41’ 631’ 10-3/4” 40.5 J-55 BTC 10.050” 41’ 1,695’ 10-3/4” 45.5 J-55 BTC 9.950” 1,695’ 1,911’ 7-5/8” 29.7 L-80 BTC 6.875” 44’ 8,830' TUBING DETAIL 4-1/2” 12.6 L-80 IBT-mod 3.958” 4,250’ 7,764’ 3-1/2” 9.3 L-80 IBT-mod 7,765’ 7,972’ GRAVEL PACK 4” 9.5 L-80 IBT-mod 3.548” 4,694’ 7,564’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item A ±3,010’±2,693’ Whipstock (Still to be set by drilling) B 3,036’ 2,704’ CIBP C 4,226’ 3,487’ 6.059 CIBP w/ 27’ of cement (tag @ 4,199’) 1 4,277’ 3,555’ 3.958 5.563 PBR 80-47, 15’ seal travel 2 4,295’ 3,531’ 3.958 Cement Retainer w/ 22ft of cement 6 4,307’ 3,575’ 3.875 6.500 Packer, Baker Premier 7 4,310’ 3,540’ 3.958 CIBP 8 4,665’ 3,817’ 3.813 5.500 Sleeve, Baker CMU Sliding, CLOSED, 9 4,708’ 3,845’ 3.280 4.218 Anchor Latch, Baker S-22 10 4,709’ 3,846’ 4.000 6.490 Packer, Baker SC-2 4,799’ 3,906’ 3.548 4.590 Screen, Bakerweld, .012 ga. 11 5,017’ 4,049’ 3.250 6.490 Packer, Baker SC-1L Multizone 12 5,611’ 4,436’ 3.250 6.490 Packer, Baker SC-1L Multizone 5,672’ 4,436’ 3.548 4.590 Screen, Bakerweld, .012 ga. 13 6,208’ 4,854’ 3.280 4.218 Snap Latch, Baker S-22 14 6,209’ 4,854’ 4.000 6.490 Packer, Baker SC-2 6,293’ 4,915’ 3.548 4.590 Screen, Bakerweld, .012 ga 15 6,716’ 5,230’ 3.250 6.490 Packer, Baker SC-1L Multizone 6,748’ 5,255’ Magna Range Plug (12/2/21) 6,814’ 5,304’ 3.548 4.590 Screen, Bakerweld, .012 ga 16 7,181’ 5,581’ 3.250 6.490 Packer, Baker SC-1L Multizone 7,264’ 5,643’ 3.548 4.590 Screen, Bakerweld, .012 ga 17 7,564’ 5,866’ 3.280 4.218 Snap Latch, Baker S-22B 18 7,565’ 5,866’ 4.000 6.500 Packer, Baker FB-1 Sump Packer 19 7,764’ 6,019’ 3.940 5.375 XO, 4.5 X 3.5 20 7,797’ 6,044’ 2.813 4.250 Nipple, X 21 7,830’ 6,070’ 3.548 5.020 Screen, SLHT Excluder 22 7,938’ 6,153’ 2.813 4.250 Nipple, X 23 7,970’ 6,178’ 2.992 3.800 Wireline Entry Guide Note: 9/3/2003 Three Radioactive (RA) 7-5/8” casing couplings @ 4366’, 5879’ & 7450’ Note: 9/3/2003 Radioactive (RA) collars @ 581’, 6011’, 6396’, 6907’ & 7377’ Note: 07/02/21 – RIH w/ 2-1/8” nozzle for dry tag to 7,970’ RKB Actual Pre-rig 5/11/22 - bjm SCHEMATIC Updated by DMA 05-11-22 Tyonek Platform Well: A-10A Last Completed: 9/5/2003 PTD: 203-075 API: 50-883-20030-01-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Comments Sterling 4,415’ 4,428’ 3,648’ 3,656’ 13’ 9/15/2003 TCP Guns CI-A 4,454’ 4,487’ 3,674’ 3,697’ 33’ 9/15/2003 TCP Guns CI-1 4,805’ 4,905’ 3,910’ 3,976’ 100’ 9/5/2003 Gravel Packed Slots CI-2 4,920’ 5,005’ 3,985’ 4,041’ 85’9/5/2003 Gravel Packed Slots CI-10 5,685’ 5,700’ 4,486’ 4,496’15’ 9/5/2003 Gravel Packed Slots Beluga A 5,894’ 5,914’ 4,629’ 4,643’ 20’ 9/5/2003 Gravel Packed Slots Beluga B 6,090’ 6,105’ 4,769’ 4,779’ 15’9/5/2003 Gravel Packed Slots Beluga C 6,185’ 6,195’ 4,837’ 4,844’ 10’ 9/5/2003 Gravel Packed Slots Beluga D 6,300’ 6,310’ 4,921’ 4,928’ 10’9/5/2003 Gravel Packed Slots Beluga D 6,450’ 6,525’ 5,031’ 5,086’ 75’9/5/2003 Gravel Packed Slots Beluga E 6,646’ 6,665’ 5,177’ 5,191’ 19’9/5/2003 Gravel Packed Slots Beluga F 6,685’ 6,710’ 5,207’ 5,226’ 25’9/5/2003 Gravel Packed Slots Beluga G 6,825’ 6,865’ 5,313’ 5,343’ 40’9/5/2003 Gravel Packed Slots Beluga H 7,010’ 7,028’ 5,452’ 5,466’ 18’ 9/5/2003 Gravel Packed Slots Beluga I 7,165’ 7,175’ 5,569’ 5,577’ 10’ 9/5/2003 Gravel Packed Slots Beluga J 7,270’ 7,280’ 5,647’ 5,655’ 10’ 9/5/2003 Gravel Packed Slots Beluga L 7,425’ 7,450’ 5,762’ 5,781’ 25’9/5/2003 Gravel Packed Slots Beluga M 7,515’ 7,555’ 5,829’ 5,859’ 40’ 9/5/2003 Gravel Packed Slots Beluga P 7,830’ 7,905’ 6,070’ 6,128’ 75’9/5/2003 Gravel Packed Slots 5HYLVHG 75$160,77$//(77(5&+(&./,67 :(//1$0(BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB 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