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Home My WebLink About222-1131a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _0 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): Cannery Loop Unit GL: 19.8' 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 N/A (ft MSL) 22.Logs Obtained: 23. BOTTOM 20" K-55 123' 13-3/8"L-80 1,865' 9-5/8"L-80 3,449' 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 1,953' Surface N/A SIZE DEPTH SET (MD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Surface 3,820' (TOW) Surface 16" Driven Surface 606 sx SETTING DEPTH TVD ACID, FRACTURE, CEMENT SQUEEZE, ETC. TUBING RECORD 417 sx12-1/4" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 12/8/2024 222-113 / 324-602 TOP HOLE SIZE N/A N/A 3,820' MD / 3,449' TVD N/A 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 272452 2388727 50-133-20553-01-00September 25, 2022 LOCI 78-156 CLU 10RDOctober 9, 2022274' FSL, 520' FEL, Sec 7, T5N, R11W, SM, AK 37.8' Beluga Gas Pool ADL 60569 / AD: 391790 8,803' MD / 7,838' TVD 3,820' MD / 3,449' TVD N/A CASING, LINER AND CEMENTING RECORD 1473' FSL, 2381' FWL, Sec 8, T5N, R11W, SM, AK 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, AMOUNT PULLED 275383 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, 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 only if necessary. PACKER SET (MD/TVD) Conductor BOTTOMCASINGWT. PER FT.GRADE CEMENTING RECORD 2389863 Choke Size: Surface Per 20 AAC 25.283 (i)(2) attach electronic information 40#Surface 133# 68# 123' Water-Bbl: PRODUCTION TEST N/A Date of Test:Oil-Bbl: N/A Gas-Oil Ratio: Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl:Water-Bbl:Flow Tubing G s d 1 0 p dB P L s (att Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 4:41 pm, Jan 28, 2025 Abandoned 12/8/2024 JSB RBDMS JSB 013025 xG * * Daily Ops Summary dated 9/25/2022, previous Completion Report dated 2/8/2023, and wellbore schematic drawing contained herein list top window as 4,120' MD / 3,721' TVD. SFD SFD 3/27/2025 ADL DSR-4/7/25 * BJM 5/7/25 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A Top of Productive Interval N/A N/A 8,731' 7,778' 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 Digital Signature with Date:Contact Email:cdinger@hilcorp.com Contact Phone: 907-777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered)FORMATION TESTS 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. 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). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, 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). Authorized Name and Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. INSTRUCTIONS Wellbore Schematic, PreDrill and P&A Reports Authorized Title: Drilling Manager Formation Name at TD: 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. 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; or 90 days after log acquisition, whichever occurs first. Tyonek N Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.01.28 16:18:06 - 09'00' Sean McLaughlin (4311) * Previous Completion Report dated 2/8/2023 lists 8,741' MD / 7,778' TVD. SFD _____________________________________________________________________________________ Updated by CJD 1-28-25 P&A Schematic Cannery Loop Unit – Pad # 1 Well: CLU-10RD P&A’d: 12/8/24 PTD: 222-113 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 133 / K-55 / N/A 18.73 Surf 123' 13-3/8'Surface 68 /L-80/ BTC 12.415 Surf 1,953’ 9-5/8"Intermediate 40 / L-80 / BTC 8.835 Surf 3,820’ (TOW) 7”Liner 26 / L-80 / Vamtop 6.276”3,877’5,921’ 4-1/2”Prod liner 12.6 / L-80 / DWC/C 3.958”5,682’8,801’ TUBING DETAIL 4-1/2"Tieback 12.6 / L-80 / IBT 3.958”Surf 5,678’ JEWELRY DETAIL No Depth Item 1 3,854’9-5/8” CIBP 2 3,920’Flex-lock liner hanger, HRDE ZXPN Liner Top Packer w/ 5.5” PBR 3 5,500’7” CIBP w/ 40ft of cement Tag @ 5460’ MD 4 5,682’5” x 7” ZXP, HRDE Liner Top Packer, w. 5.25” PBR 5 6,110’4-1/2” CIBP with 25ft of cmt (11/2/24) 6 7,300’4-1/2” CIBP w/ 10ft of cmt, TOC @ 7,290’ (3/2/23) 7 7,450’4-1/2” WRP (1.84” OD External Fish neck), w SL catcher sub on top 8 7,985’CIBP w/ 10ft of cmt (6.4 gal) set 11/25/22 ToC 7,975’ 9 8,290’CIBP w/ 25ft of cmt (16 gal) Set 10/30/22 Toc 8,265’ OPEN HOLE / CEMENT DETAIL 8-1/2” 30 bbls spacer followed by 67 bbls of 15.3 ppg, bumped plug. Recovered 30 bbls spacer and 10 bbls of cement. CBL run 9/30/22, shows TOC @ 4,163’ MD 6-1/8”CBL run 10/16/22, shows TOC @ 4,163’ MD RA Tags @ 7,782 & 6,807’ short joints @ 7,292’ & 8,309’ Top CINGSA: 5522’ MD; 4917’ TVD Base CINGSA: 5807’ MD; 5144’ TVD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status UB 4A Lower 6,135’6,149’5,394’5,398’14 03/23/2023 ISOLATED MB 7A Upper 7,330’7,338’6,430’6,437’8 02/03/2023 Isolated MB 7A Mid 7,342’7,347’6,441’6,446’5 02/03/2023 Isolated MB 7A Lower 7,360’7,378’6,458’6,474’18 12/29/2022 Isolated LB 7,501'7,516’6,589'6,603'15’12/03/2022 Isolated LB 1A Upper 7,544’7,557’6,629'6,642'10’11/02/2022 Isolated LB 1A Lower 7,564’7,572’6,648'6,656'8’11/02/2022 Isolated LB 1C Upper 7,588'7,595'6,671'6,677'7'12/03/2022 Isolated LB 1C Lower 7,601'7,608'6,683'6,690'7'12/02/2022 Isolated LB 1D 7,640'7,645'6,720'6,725'5'12/02/2022 Isolated LB 1F Upper 7,683'7,691'6,761'6,768'8'12/02/2022 Isolated LB 1F Mid 7,703'7,708'6,779'6,784'5'12/02/2022 Isolated LB 1F Lower 7,732'7,740'6,807'6,815'8'12/02/2022 Isolated LB 1G Upper 7,764'7,772'6,837'6,845'8'11/28/2022 Isolated LB 1G Lower 7,788’7,796’6,860'6,868'8’10/31/2022 Isolated LB 2 7,821'7,831'6,892'6,901'10'11/28/2022 Isolated LB 2A 7,889'7,898'6,956'6,965'9'11/28/2022 Isolated LB 2B upper 7,911’7,921’6,977'6,987'10’10/31/2022 Isolated LB 2B Mid 7,928’7,934’6,994'6,999'6’10/31/2022 Isolated LB 2B Lower 7,946'7,951'7,011'7,016'5'11/28/2022 Isolated LB 2B 7,996’8,007’7,059'7,069'11’10/31/2022 Isolated LB 3C 8,301’8,311’7,351'7,361'10’10/26/2022 Isolated LB 4B 8,468’8,474’7,513'7,519'10’10/26/2022 Isolated LB 5 Upper 8,613’8,621’7,653'7,661'8’10/26/2022 Isolated LB 5 Mid 8,631’8,636’7,671'7,676'5’10/26/2022 Isolated LB 5 Lower 8,641’8,649’7,681'7,688'8’10/24/2022 Isolated ? See drawing at left. SFD Page 1/1 Well Name: CLU 010RD2 Report Printed: 1/28/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Jobs Actual Start Date:11/1/2024 End Date: Report Number 1 Report Start Date 11/2/2024 Report End Date 11/3/2024 Last 24hr Summary PJSM and sign onto PTW. MIRU YJ Eline Unit. Pressure test to 250/2500 psi, as per Sundry. RIH w/4.5'' CIBP. Set CIBP at 6110'. Tag plug at 6110', log verification of plug tag. POH to surface. Secure well for the night and LD lub. Report Number 2 Report Start Date 11/3/2024 Report End Date 11/4/2024 Last 24hr Summary PJSM/PTW. RIH w/3''x 25' bailer twice to dump bail 25' of cement ontop of CIBP at 6110'. Total of 16gal of cement dumped. RDMO YJ Eline unit. Fill tbg with 66.8bbls of FW, conduct MIT to 2200 psi for 30 min, as per Sundry. Witness waived by Jim Regg. Starting MIT pressure at 2210psi, ending pressure at 2203psi. Bleed off pressure test, download data and send to town/well file. RU Slickline, PT to 250/2500 psi. RIH w/3.5'' blind box, tag TOC at 6083',confirm tag, 27' of cmt ontop of CIBP. POH to surface. RDMO slickline. Winterize tree and secure well. Report Number 3 Report Start Date 11/17/2024 Report End Date 11/18/2024 Last 24hr Summary Held PJSM and approve PTW. Check Well Pressures T/IA/OA 0/0/19, Removed flowline and SSV, blinded off at ground level, Lay out containment, set rig mats and base beam, spot in carrier. Raised and scoped up derrick. Spot in associated equipment. Set BPV, N/d tree installed test sub and N/u 13-5/8” stack. Set work floor. Began working on winterization. Report Number 4 Report Start Date 11/18/2024 Report End Date 11/19/2024 Last 24hr Summary Continue rigging up and making up BOPE. Worked on issues with dragon heater. Continue winterizing R/u and functioned gas detection. Hung winterization around BOP. Continue hooching and getting heat on critical areas. Troubleshoot heaters shutting down. M/u 4-1/2" test joint. P/u and run in w/ 4-1/2" test joint. Fluid pack BOPE, pressure up and look for leaks. Shell test 250/3000 psi, good test. Notify AOGCC rep Brian Bixby. Cont. winterizing while waiting on arrival of state rep. Report Number 5 Report Start Date 11/19/2024 Report End Date 11/20/2024 Last 24hr Summary Test BOPE as per Hilcorp & AOGCC expectations, AOGCC's Brian Bixby witnessed test, all tests 250/3000psi, w/4 1/2" TJ, one FP on choke line connection leak, torque & re-test good, tested PVT & gas alarms. R/D test Eq. blow down. Prep to pull hanger. Pull hanger @ 42k, pull seals moving @ 82k, wt dropped t/74k seals out. Pull hanger to floor. Circulate hole volume clean at 3.3BPM, 83psi. Prep to l/d 4-1/2" production liner. L/d hanger. POOH, l/d 4-1/2" production liner from 5678' to SSSV. Remove banding and 357' SSSV control line. Cont. POOH, L/d tubing to 1265'. Report Number 6 Report Start Date 11/20/2024 Report End Date 11/21/2024 Last 24hr Summary POOH l/d 4 1/2" IBT tubing f/ 1265'- t/ 836'. Issue w/ skate kicker, R/D skate. Continue l/D 4 1/2" completion to surface, tailing out with loader. R/U e-line, RIH w/ 7" CIBP, set @ 5500'. E-line make 3 runs w/35' 4" bailer, dumping a total of 50 gallons of 16ppg cmt on plug @ 5500'. R/U & pt well t/3250psi, stabilized @ 3150psi, 15 min 3150psi, 30 min 3150psi. E-line RIH w/ 5.60" LIB, tagging cement at 5460.5'. Tag and pressure test witnessed by AOGCC inspector Bob Noble. E-line RIH w/ 9.625" CIBP set @ 3854'. R/d e-line. Nipple down BOP, install well cap flange on wellhead. R/d rig support equipment in preparation to be mobilized. Remove accessible berming. Lay over derrick. P/u tools and misc. equipment. Mobilize rig to Happy Valley. Clean location to be ready for Rig 169. Field: Cannery Loop Sundry #: 324-602 State: ALASKA Rig/Service:Permit to Drill (PTD) #:224-135Permit to Drill (PTD) #:222-113 Wellbore API/UWI:50-133-20553-01-00 Page 1/1 Well Name: CLU 010RD2 Report Printed: 1/28/2025WellViewAdmin@hilcorp.com Well Operations Summary Jobs Actual Start Date:12/4/2024 End Date:12/29/2024 Report Number 1 Report Start Date 12/4/2024 Report End Date 12/5/2024 Operation Continue rigging down rigg floor remove top drive from rig floor, spot in crane remove windwalls from pits remove clam shell R/D iron roughneck, install shipping beams in cellar, remove gas buster and BOP Stack from cellar, prep and scope down derrick, continue rigging down modules Prepped and laid derrick over. Lowered Pit roofs. Disconned pason wires, and hydraulic hoses from derrick. Blow down dteam and water lines and disconnected same. R/D MP's 1&2, disconnect electrical lines and roll up. R/D Mud pits. Fold up V-door and rolled up electrical lines. Lay felt liner and rig mats. Finish R/D electrical to dog house, accumulator room, drawworks unit and generators. Scope in and lower drill shack. Report Number 2 Report Start Date 12/5/2024 Report End Date 12/6/2024 Operation Rig movers on location start pulling apart back yard, pull boiler and diesel tank, pull Top Drive HPU, pull pump skids out, pull jig and pit modules out, pull doghouse/water tank, pull gen skid, spot in cranes and pull derrick and draw works, pull sub and pony subs off well and transport to pad, transport cranes, P/U mats and felt and liner, clean location. Spot pony subs over well spot in cranes and set sub and center over well, set draw works and derrick on sub, spot in doghouse/water tank raise doghouse, spot in gen and pit modules, set jig and pump skids, set top drive HPU, raise pit rooves and begin rigging up, raise mast, set boiler and diesel skid, continue hauling and offloading modules and equipment to location, continue rigging up. Install with crane the choke house, centrifuge, BOP, and Mud tank wind walls. Spot in boiler house, Aux fuel tank, gas buster, upright water tank, and cement silo. R/U all power cables and power up generators. R/U Mud pump and mud tank lines, air water steam and diesel lines. Stage up boilers and get up to op pressure and temp. Power up air compressor and send air, steam, water and diesel around the rig. R/U and general house keeping around the rig. Lay felt, liner and rig mat for catwalk. Spool and slip drill line. Install sub winter tarps. Prep to scope the derrick. Report Number 3 Report Start Date 12/6/2024 Report End Date 12/7/2024 Operation Continue Rigging up, R/D camps and office trailers, transport to location, set mats and spot camps, power up and get coms going, insal handi berm around rig, Spot in catwalk and fold over beaver slide, pin lower torque tube, Scope derrick up and pin install t bar and turn buckles on torque tube, pre to P/U top drive, continue building docks and organizing location, work through rig acceptance checklist, fill pits with water and check function, P/U top drive and pin to blocks hook up service loop and kelly hose, test function R/U tongs, and bring up slips, TIW, IBOP, and sub rack. Removed well cap and N/U B section of well head. Stabbed BOP stack and N/U. Install choke and kill lines. Connect accumulator hoses. Attempt to install bell nipple (RKB to high for installation, waiting on welder). Install flow box and flow line. Funtion test BOP-good. Remove trolly beam. Secure stack. Finish building 300 bbl of 6% KCL mud. CCI continue haul misc. loads from gas field. Report Number 4 Report Start Date 12/7/2024 Report End Date 12/8/2024 Operation Grease choke manifold valves and man choke and kill line valves, R/U test equipment, Function test gas alarms, Continue building mud in pits. Shell test stack and lines, tighten flange on choke line and tighten blind ram door, retest blind ram door still leaking, open blind ram door and change seal tighten door back up retest good. Test BOP's with 4.5'' test jt, t/ 250/3000 psi f/ 5 min each, test TIW and Dart, CMV 1-15, auto and man IBOP, HCR and Man choke and kill,Upper lower and blind rams, annular preventer and mez. kill valve, perform drawdown test and test gas alarms, test PVT alarms, Test Man and Electric choke had 1 FP double ball replace and retest good. R/D test equiment, clear floor blow down lines. P/U BHA #1. P/U 5" HWDP single and M/U string mill, casing scraper, bit sub, and taper mill. Single in the hole with 16 jnts of 4.5" HWDP t/ 491'. Cont t/ single in the hole with 24 joints of 4.5" DP t/1294'. Cont t/ single in the hole with 4.5" DP f/1294' to tag CIBP at 3856'. PJSM with rig crew and CCI on displacement. Pump 20 bbl spacer then displace well to 9.0ppg 6% KCL mud system. Blow down top drive. POOH on elevators f/3856' t/3170' Report Number 5 Report Start Date 12/8/2024 Report End Date 12/9/2024 Operation POOH f/ 3170' t/ surface, L/D Scraper BHA as per WIS M/U BHA as per WIS rep and MWD, shallow test tools, M/U whipstock assembly to mills, M/U remaining BHA RIH w/ Whipstock assembly t/ setting depth @ 3847' Orient tool face to 45L and cycle pumps 6 times to Multicycle tool, pressure up t/ 3000 psi and set anchor as per WIS Rep. Set down 30k to ensure set then P/U 65k over to sear bolt. Mill 8.5" window f/3820' t/3825'. 415GPM=1637PSI, 75RPM=8-11K Tq. ROP 1-3'/hr. Pump high vis sweep at 3823' back on time with 50% increase in metal. Cont to mill 8.5" window f/3825' t/3834'. 415GPM=2075PSI, 80RPM=8K Tq. ROP 1-3'/hr. Drill new formation f/3834' t/3843'. 415GPM=1725PSI, 80 RPM=6.9k TQ. 1-2K WOB. MW=9.0 Field: Cannery Loop Sundry #: 224-135 State: ALASKA Rig/Service: HEC 169Permit to Drill (PTD) #:224-135 Wellbore API/UWI:50-133-20553-02-00 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________CANNERY LOOP UNIT 10RD JBR 03/13/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Tested with 4 1/2" Test joint. Flange on Choke line was leaking, Tightened up and passed retest. Precharge Bottles = 1 @ 900psi, 21 @ 1000psi and 2 @ 1050psi. Good Test Test Results TEST DATA Rig Rep:Tyson RentonOperator:Hilcorp Alaska, LLC Operator Rep:Harold Soule Rig Owner/Rig No.:Hilcorp 401 PTD#:2221130 DATE:11/19/2024 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopBDB241121064414 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4 MASP: 1834 Sundry No: 324-602 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 8 PNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8"P #1 Rams 1 2 7/8"x5"P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 4 1/16"P HCR Valves 1 4 1/16"P Kill Line Valves 3 2 1/16,4 1/1 P Check Valve 0 NA BOP Misc 1 Flange FP System Pressure P3000 Pressure After Closure P2050 200 PSI Attained P28 Full Pressure Attained P96 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P6@1600 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P25 #1 Rams P2 #2 Rams P2 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill NA0 9 9 9 9 9999 9 9 Flange on Choke line was leaking Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250220 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 18RD 50133205840100 222033 1/27/2025 AK E-LINE Patch BRU 223-24 50283201830000 221072 1/26/2025 AK E-LINE Perf CLU 10RD 50133205530100 222113 11/2/2024 YELLOWJACKET PLUG GP 03-87 50733204370000 166052 12/16/2024 AK E-LINE Plug/Cement IRU 44-36 50283200890000 193022 1/22/2025 AK E-LINE Perf KU WD-01 50133203450000 181107 10/15/2024 YELLOWJACKET PERF MPI 1-29 50029216690000 186181 1/29/2025 AK E-LINE Perf MPU C-39 50029228490000 197248 1/27/2025 AK E-LINE TubingCut MPU E-20A 50029225610100 204054 2/1/2025 READ CaliperSurvey MPU K-33 50029227290000 196202 2/8/2025 AK E-LINE TubeCut MPU S-08 50029231680000 203123 2/6/2025 AK E-LINE CmtRtr/Punch MRU A-13 50733200770000 168002 2/6/2025 AK E-LINE TubingPunch MRU M-02 50733203890000 187061 1/22/2025 AK E-LINE Perf MRU M-32RD2 50733204620200 217091 2/10/2025 AK E-LINE TubingPunch NCIU A-09 50883200290100 222024 1/31/2025 AK E-LINE Perf NCIU A-16 50883201270000 208098 1/30/2025 AK E-LINE Perf NCIU A-21 50883201990000 224086 1/15/2025 AK E-LINE Plug, Perf NK-41A 50029227780100 197158 1/6/2025 HALLIBURTON Coilflag PAVE 3-1 50029238060000 224140 1/4/2025 YELLOWJACKET CBL PBU P1-13 50029223720000 193074 12/3/2024 HALLIBURTON PPROF PTM P1-07A 50029219960100 204037 12/31/2024 YELLOWJACKET PPROF Please include current contact information if different from above. T40127 T40128 T40129 T40130 T40131 T40132 T40133 T40134 T40135 T40136 T40137 T40138 T40139 T40140 T40141 T40142 T40143 T40144 T40145 T40146 T40147 CLU 10RD 50133205530100 222113 11/2/2024 YELLOWJACKET PLUG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.20 14:09:18 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 7 Township: 5N Range: 11W Meridian: Seward Drilling Rig: n/a Rig Elevation: n/a Total Depth: 8803 ft MD Lease No.: ADL0060569 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 123 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 1953 Feet Csg Cut@ Feet Intermediate: 9 5/8" O.D. Shoe@ 4129 Feet Csg Cut@ Feet Production: 4 1/2" O.D. Shoe@ 8801 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: O.D. Tail@ Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Annulus Bridge plug 5501 ft 5460 ft 8.4 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing IA 3150 3150 3150 OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Harold Soule Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): This plug is for a redrill . Tubing was pulled and plug was set in casing. MIT was performed against the casing. November 21, 2024 Bob Noble Well Bore Plug & Abandonment Cannery Loop Unit 10RD Hilcorp Alaska LLC PTD 2221130; Sundry 324-602 none Test Data: P Casing Removal: rev. 3-24-2022 2024-1120_Plug_Verification_CLU-10RD_bn 9 9 9 9 9 9 999 9 9 9 9 9 9 99 9 9 99 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.11.22 15:18:41 -09'00' From:McLellan, Bryan J (OGC) To:Chad Helgeson Cc:Donna Ambruz; Wade Hudgens Subject:RE: [EXTERNAL] RE: CLU-10RD (PTD#222-113) Sundry # 324-602 plug/cement change request Date:Monday, November 18, 2024 2:04:00 PM Chad, Hilcorp has approval to proceed with the plan as described in your email below dated 11/18/24. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Monday, November 18, 2024 1:49 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Wade Hudgens <Wade.Hudgens@hilcorp.com> Subject: RE: [EXTERNAL] RE: CLU-10RD (PTD#222-113) Sundry # 324-602 plug/cement change request Bryan, While I do not agree that the regulations require a plug with cement in cased pipe to be placed/installed within 50ft of the top of CINGSA Storage Pool, Hilcorp will install this 7” plug as shown on the attached schematic. The proposed plugs: 7” CIBP set @ ~ 5,500ft with 25ft of cement (40.2 gal) dump bailed on plug and pressure tested 3000 psi (plug tagged) – notification for witness already submitted this morning for tomorrow night 9-5/8” CIBP set @ 3,820’ for the base of the whipstock (no cement) Please let us know if this is acceptable path forward as described above. Regards CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Chad Helgeson From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, November 18, 2024 1:18 PM To: Chad Helgeson <chelgeson@hilcorp.com> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: RE: [EXTERNAL] RE: CLU-10RD (PTD#222-113) Sundry # 324-602 plug/cement change request Chad, The plug should be in the 7” liner, <50’ above the top of the CINGSA gas storage pool with at least 25’ of cement dump bailed on top. Please send a proposed diagram Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Friday, November 15, 2024 11:18 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: RE: [EXTERNAL] RE: CLU-10RD (PTD#222-113) Sundry # 324-602 plug/cement change request Bryan, Yes, we need to change the depth of the plug. We will be moving the kickoff point up into the 9-5/8” casing above the 7” liner top. The proposed kickoff point is 100ft above the current 7” liner top @ 3,795’ with 25ft of cement on plug. Attached is the solid pressure test we did on the 4-1/2” plug w/ cement at 6110. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Please let us know if you approve moving the plug supposed to be set in the 7” up to the 9- 5/8”. Attached is a proposed schematic for this operation. Thanks Chad From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, November 14, 2024 5:01 PM To: Chad Helgeson <chelgeson@hilcorp.com> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: [EXTERNAL] RE: CLU-10RD (PTD#222-113) Sundry # 324-602 plug/cement change request Or will this plan change based on revised CLU 10RD2 PTD? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: McLellan, Bryan J (OGC) Sent: Thursday, November 14, 2024 5:00 PM To: Chad Helgeson <chelgeson@hilcorp.com> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: RE: CLU-10RD (PTD#222-113) Sundry # 324-602 plug/cement change request Chad, Hilcorp has approval to make the change to the plug setting requirements in sundry 324-602 as listed below. All other conditions of approval in the original sundry still apply. Thanks 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. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Friday, November 1, 2024 2:18 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: CLU-10RD (PTD#222-113) Sundry # 324-602 plug/cement change request Bryan, As discussed on the phone, Hilcorp is requesting a change to the plug depth request you made on step 15 of the sundry #324-602 to set the CIBP and Cement plug no more than 50’ above the top of the CINGA Pool. We are requesting to move the proposed plug in step 17 to 5025’ and dump bailing 25ft of cement on plug, placing the top of the plug at 5000 for the base of the whip stock. (this plug placement will be 497ft above the top of CINGSA Pool with 25ft of cement on CIBP). Hilcorp will provide 24hr notice for AOGCC to witness pressure test and tag of cement top. Please let us know if this change is approved. Chad Helgeson Operations Engineer Kenai Asset Team 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 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. _____________________________________________________________________________________ Updated by CAH 11-18-24 PROPOSED Rev 1 Cannery Loop Unit – Pad # 1 Well: CLU-10RD Last Completed: 10/12/22 PTD: 222-113 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 133 / K-55 / N/A 18.73 Surf 123' 13-3/8'Surface 68 /L-80/ BTC 12.415 Surf 1,953’ 9-5/8"Intermediate 40 / L-80 / BTC 8.835 Surf 4,120’ (TOW) 7”Liner 26 / L-80 / Vamtop 6.276”3,877’5,921’ 4-1/2”Prod liner 12.6 / L-80 / DWC/C 3.958”5,682’8,801’ TUBING DETAIL 4-1/2"Tieback 12.6 / L-80 / IBT 3.958”Surf 5,678’ JEWELRY DETAIL No Depth Item 1 ±3,820’9-5/8” CIBP for whipstock 2 3,920’Flex-lock liner hanger, HRDE ZXPN Liner Top Packer w/ 5.5” PBR 3 ±5,500’7” CIBP w/ 25ft of cement 4 5,682’5” x 7” ZXP, HRDE Liner Top Packer, w. 5.25” PBR 5 6,110’4-1/2” CIBP with 25ft of cmt (11/2/24) 6 7,300’4-1/2” CIBP w/ 10ft of cmt, TOC @ 7,290’ (3/2/23) 7 7,450’4-1/2” WRP (1.84” OD External Fish neck), w SL catcher sub on top 8 7,985’CIBP w/ 10ft of cmt (6.4 gal) set 11/25/22 ToC 7,975’ 9 8,290’CIBP w/ 25ft of cmt (16 gal) Set 10/30/22 Toc 8,265’ OPEN HOLE / CEMENT DETAIL 8-1/2” 30 bbls spacer followed by 67 bbls of 15.3 ppg, bumped plug. Recovered 30 bbls spacer and 10 bbls of cement. CBL run 9/30/22, shows TOC @ 4,163’ MD 6-1/8”CBL run 10/16/22, shows TOC @ 4,163’ MD RA Tags @ 7,782 & 6,807’ short joints @ 7,292’ & 8,309’ Top CINGSA: 5522’ MD; 4917’ TVD Base CINGSA: 5807’ MD; 5144’ TVD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status UB 4A Lower 6,135’6,149’5,394’5,398’14 03/23/2023 ISOLATED MB 7A Upper 7,330’7,338’6,430’6,437’8 02/03/2023 Isolated MB 7A Mid 7,342’7,347’6,441’6,446’5 02/03/2023 Isolated MB 7A Lower 7,360’7,378’6,458’6,474’18 12/29/2022 Isolated LB 7,501'7,516’6,589'6,603'15’12/03/2022 Isolated LB 1A Upper 7,544’7,557’6,629'6,642'10’11/02/2022 Isolated LB 1A Lower 7,564’7,572’6,648'6,656'8’11/02/2022 Isolated LB 1C Upper 7,588'7,595'6,671'6,677'7'12/03/2022 Isolated LB 1C Lower 7,601'7,608'6,683'6,690'7'12/02/2022 Isolated LB 1D 7,640'7,645'6,720'6,725'5'12/02/2022 Isolated LB 1F Upper 7,683'7,691'6,761'6,768'8'12/02/2022 Isolated LB 1F Mid 7,703'7,708'6,779'6,784'5'12/02/2022 Isolated LB 1F Lower 7,732'7,740'6,807'6,815'8'12/02/2022 Isolated LB 1G Upper 7,764'7,772'6,837'6,845'8'11/28/2022 Isolated LB 1G Lower 7,788’7,796’6,860'6,868'8’10/31/2022 Isolated LB 2 7,821'7,831'6,892'6,901'10'11/28/2022 Isolated LB 2A 7,889'7,898'6,956'6,965'9'11/28/2022 Isolated LB 2B upper 7,911’7,921’6,977'6,987'10’10/31/2022 Isolated LB 2B Mid 7,928’7,934’6,994'6,999'6’10/31/2022 Isolated LB 2B Lower 7,946'7,951'7,011'7,016'5'11/28/2022 Isolated LB 2B 7,996’8,007’7,059'7,069'11’10/31/2022 Isolated LB 3C 8,301’8,311’7,351'7,361'10’10/26/2022 Isolated LB 4B 8,468’8,474’7,513'7,519'10’10/26/2022 Isolated LB 5 Upper 8,613’8,621’7,653'7,661'8’10/26/2022 Isolated LB 5 Mid 8,631’8,636’7,671'7,676'5’10/26/2022 Isolated LB 5 Lower 8,641’8,649’7,681'7,688'8’10/24/2022 Isolated 1 Gluyas, Gavin R (OGC) From:Chad Helgeson <chelgeson@hilcorp.com> Sent:Monday, October 21, 2024 9:05 AM To:Davies, Stephen F (OGC) Cc:McLellan, Bryan J (OGC); Dewhurst, Andrew D (OGC) Subject:RE: [EXTERNAL] CLH 10RD (PTD 222-113, Sundry 324-602) - Question Attachments:CLU-10RD Schematic 10-21-24.pdf Steve, Good catch on that mistake. - The Cement top for the 8-1/2” hole is correct. - The 6-1/8” hole section cement top is at the liner top packer at 5682’. Attached is an updated schematic with that corrected. Chad From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Saturday, October 19, 2024 8:00 AM To: Chad Helgeson <chelgeson@hilcorp.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL] CLH 10RD (PTD 222-113, Sundry 324-602) - Question Chad, While reviewing Hilcorp’s Sundry ApplicaƟon to plug for redrill CLU 10RD, I noƟced the following on both wellbore schemaƟc drawings. To ensure that AOGCC’s records are accurate, could you please check these values? If correcƟons are needed, I can add them to the current applicaƟon. Thanks and Be Well, Steve Davies AOGCC 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 CONFIDENTIALITY NOTICE: This e-mail message, including any aƩachments, contains informaƟon from the Alaska Oil and Gas ConservaƟon Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidenƟal and/or privileged informaƟon. The unauthorized review, use or disclosure of such informaƟon may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov 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. _____________________________________________________________________________________ Updated by CAH 10-21-24 SCHEMATIC Cannery Loop Unit – Pad # 1 Well: CLU-10RD Last Completed: 10/12/22 PTD: 222-113 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 133 / K-55 / N/A 18.73 Surf 123' 13-3/8'Surface 68 /L-80/ BTC 12.415 Surf 1,953’ 9-5/8"Intermediate 40 / L-80 / BTC 8.835 Surf 4,120’ (TOW) 7”Liner 26 / L-80 / Vamtop 6.276”3,877’5,921’ 4-1/2”Prod liner 12.6 / L-80 / DWC/C 3.958”5,682’8,801’ TUBING DETAIL 4-1/2"Tieback 12.6 / L-80 / IBT 3.958”Surf 5,678’ JEWELRY DETAIL No Depth Item 1 357’Baker S-05 TRSSSV w/ 3.813” BX Profile, full open 1,900 psi 2 3,920’Flex-lock liner hanger, HRDE ZXPN Liner Top Packer w/ 5.5” PBR 3 5,682’5” x 7” ZXP, HRDE Liner Top Packer, w. 5.25” PBR 4 7,300’4-1/2” CIBP w/ 10ft of cmt, TOC @ 7,290’ (3/2/23) 5 7,450’4-1/2” WRP (1.84” OD External Fish neck), w SL catcher sub on top 6 7,985’CIBP w/ 10ft of cmt (6.4 gal) set 11/25/22 ToC 7,975’ 7 8,290’CIBP w/ 25ft of cmt (16 gal) Set 10/30/22 Toc 8,265’ OPEN HOLE / CEMENT DETAIL 8-1/2” 30 bbls spacer followed by 67 bbls of 15.3 ppg, bumped plug. Recovered 30 bbls spacer and 10 bbls of cement. CBL run 9/30/22, shows TOC @ 4,163’ MD 6-1/8”CBL run 10/16/22, shows TOC @ 5682’ MD RA Tags @ 7782 & 6807’ short joints @ 7292’ & 8309’ Top CINGSA: 5522’ MD; 4917’ TVD Base CINGSA: 5807’ MD; 5144’ TVD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status UB 4A Lower 6,135’6,149’5,394’5,398’14 03/23/2023 Open MB 7A Upper 7,330’7,338’6,430’6,437’8 02/03/2023 Isolated MB 7A Mid 7,342’7,347’6,441’6,446’5 02/03/2023 Isolated MB 7A Lower 7,360’7,378’6,458’6,474’18 12/29/2022 Isolated LB 7,501'7,516’6,589'6,603'15’12/03/2022 Isolated LB 1A Upper 7,544’7,557’6,629'6,642'10’11/02/2022 Isolated LB 1A Lower 7,564’7,572’6,648'6,656'8’11/02/2022 Isolated LB 1C Upper 7,588'7,595'6,671'6,677'7'12/03/2022 Isolated LB 1C Lower 7,601'7,608'6,683'6,690'7'12/02/2022 Isolated LB 1D 7,640'7,645'6,720'6,725'5'12/02/2022 Isolated LB 1F Upper 7,683'7,691'6,761'6,768'8'12/02/2022 Isolated LB 1F Mid 7,703'7,708'6,779'6,784'5'12/02/2022 Isolated LB 1F Lower 7,732'7,740'6,807'6,815'8'12/02/2022 Isolated LB 1G Upper 7,764'7,772'6,837'6,845'8'11/28/2022 Isolated LB 1G Lower 7,788’7,796’6,860'6,868'8’10/31/2022 Isolated LB 2 7,821'7,831'6,892'6,901'10'11/28/2022 Isolated LB 2A 7,889'7,898'6,956'6,965'9'11/28/2022 Isolated LB 2B upper 7,911’7,921’6,977'6,987'10’10/31/2022 Isolated LB 2B Mid 7,928’7,934’6,994'6,999'6’10/31/2022 Isolated LB 2B Lower 7,946'7,951'7,011'7,016'5'11/28/2022 Isolated LB 2B 7,996’8,007’7,059'7,069'11’10/31/2022 Isolated LB 3C 8,301’8,311’7,351'7,361'10’10/26/2022 Isolated LB 4B 8,468’8,474’7,513'7,519'10’10/26/2022 Isolated LB 5 Upper 8,613’8,621’7,653'7,661'8’10/26/2022 Isolated LB 5 Mid 8,631’8,636’7,671'7,676'5’10/26/2022 Isolated LB 5 Lower 8,641’8,649’7,681'7,688'8’10/24/2022 Isolated 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,803'N/A Casing Collapse Structural Conductor 1,500psi Surface 1,950psi Intermediate 3,090psi Intermediate 5,410psi Production 7,500psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Liner Top Pkrs; Baker S-05 TRSSSV 3,920' MD/3,539' TVD; 5,682' MD/ 5,044' TVD; 357' MD/'TVD 7,838'7,290'6,393' Kenai C.L.U.Beluga Gas 20" 13-3/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Cannery Loop Unit (CLU-10RD)CO 231A Same 5,235'7" ~1,834psi 2,044' See Schematic Length October 23, 2024 8,801'3,119' 4-1/2" 7,837' 5,921' Perforation Depth MD (ft): 4,120 (TOW) 4-1/2" See Attached Schematic 5,750psi 3,060psi 3,450psi 123' 3,721' 123' 1,953' Size 123' 9-5/8"4,129' 1,953' MD Hilcorp Alaska, LLC Proposed Pools: 12.6# L-80 TVD Burst 5,678' 7,230psi 1,865' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE-Hilcorp (formerly ADL 060569), ADL 391790 222-113 50-133-20553-01-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Chad Helgeson, Operations Engineer AOGCC USE ONLY 8,430psi Tubing Grade: chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writte n approval. Authorized Name and Digital Signature with Date: m n P s t _ N 66 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:20 am, Oct 17, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.10.16 16:43:34 - 08'00' Noel Nocas (4361) 324-602 X DSR-10/23/24BJM 10/24/24 SFD 10/19/2024 Plug for Redrill 10-407 BOP test to 3000 psi, annular test to 2500 psi. Place bridge plug and cement no more than 50' above top of CINGSA gas storage pool. Provide 24 hrs notice for AOGCC opportunity to witness pressure test and tag of both cement plugs. X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.25 10:59:19 -08'00'10/25/24 RBDMS JSB 102924 Well Prognosis Well: CLU-10RD 02/01/2022 Well Name: CLU-10RD API Number: 50-133-20553-01-00 Current Status: Shut in Gas Well Permit to Drill Number: 222-113 First Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Second Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Maximum Expected BHP: 2373 psi @ 5394’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure: 1834 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: NA – Prep for Sidetrack, plugging ops only Well Status: Well was sidetracked in 2022, but was not successful and has been shut-in since 2022. Brief Well Summary CLU-10 was drilled in 2005 and completed as an EXCAPE well and frac’d, and in 2012 the original well was plugged back and the well suspended. In 2022 the well was sidetracked, and completed, but was unsuccessful producing commercial volumes of gas. The purpose of this work is to prepare the well for another redrill. Notes Regarding Wellbore Condition x Inclination o Max deviation of 37° @ 5660’ MD o Max DLS of 6.4°/100’ @ 4729’ MD x Fluid in Annulus is 8.4 ppg CI water x CINGSA Top: 5522’ MD (4917’ TVD) x CINGSA Bottom: 5807’ MD (5144’ TVD) Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /2,500 psi high 3. PU 4-1/2” CIBP. RIH and set at 6110’ (collect a log on plug tag). 4. PU Cement bailer and dump 25ft of cement on plug at 6110’. 5. RDMO Eline 6. MIRU 401 workover rig 7. Fill tubing with 8.4 ppg water 8. Install TWC, ND tree, NU BOP 9. Test BOPE ¾ Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. (Notify AOGCC 24 hours in advance of test to allow them to witness test). ¾ If the BOP is used to shut in on the well in a well control situation or if BOP equipment could be compromised, ALL BOP components utilized for well control or compromised must be tested prior to the next trip into the wellbore. ¾ BOPs will be closed as needed to circulate the well during this workover. 10. Pull TWC 11. Pick up on hanger with short joint 12. Circulate well prior to pulling tubing, once tubing is out of the seals 13. Pull and lay down tubing Provide 24 hrs opportunity to witness plug and pressure test and tag of cement top. - bjm Pressure test plug to 2000 psi. -bjm Well Prognosis Well: CLU-10RD 02/01/2022 x Seal assembly and SCSSV sent to Baker for redress/repair to be put back in inventory 14. RU Eline 15. RIH and set 7” CIBP at ~5000’ 16. RDMO Eline 17. Pressure test casing to 2500 psi 18. MIT casing and plug to 3000 psi 19. ND BOP, NU dry hole tree 20. RDMO Rig 401 Attachments: 1) Actual Schematic. 2) Proposed Schematic 3) Rig 401 BOP Diagram 13-5/8” Set a CIBP and cement plug no more than 50' above the top of the CINGSA pool.Pressure test and tag TOC. Provide 24 hr notice for AOGCC opportunity to witness pressure test and tag of cement top.-bjm _____________________________________________________________________________________ Updated by DMA 08-09-23 SCHEMATIC Cannery Loop Unit – Pad # 1 Well: CLU-10RD Last Completed: 10/12/22 PTD: 222-113 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 133 / K-55 / N/A 18.73 Surf 123' 13-3/8'Surface 68 /L-80/ BTC 12.415 Surf 1,953’ 9-5/8"Intermediate 40 / L-80 / BTC 8.835 Surf 4,120’ (TOW) 7”Liner 26 / L-80 / Vamtop 6.276”3,877’5,921’ 4-1/2”Prod liner 12.6 / L-80 / DWC/C 3.958”5,682’8,801’ TUBING DETAIL 4-1/2"Tieback 12.6 / L-80 / IBT 3.958”Surf 5,678’ JEWELRY DETAIL No Depth Item 1 357’Baker S-05 TRSSSV w/ 3.813” BX Profile, full open 1,900 psi 2 3,920’Flex-lock liner hanger, HRDE ZXPN Liner Top Packer w/ 5.5” PBR 3 5,682’5” x 7” ZXP, HRDE Liner Top Packer, w. 5.25” PBR 4 7,300’4-1/2” CIBP w/ 10ft of cmt, TOC @ 7,290’ (3/2/23) 5 7,450’4-1/2” WRP (1.84” OD External Fish neck), w SL catcher sub on top 6 7,985’CIBP w/ 10ft of cmt (6.4 gal) set 11/25/22 ToC 7,975’ 7 8,290’CIBP w/ 25ft of cmt (16 gal) Set 10/30/22 Toc 8,265’ OPEN HOLE / CEMENT DETAIL 8-1/2” 30 bbls spacer followed by 67 bbls of 15.3 ppg, bumped plug. Recovered 30 bbls spacer and 10 bbls of cement. CBL run 9/30/22, shows TOC @ 4,163’ MD 6-1/8”CBL run 10/16/22, shows TOC @ 4,163’ MD RA Tags @ 7,782 & 6,807’ short joints @ 7,292’ & 8,309’ Top CINGSA: 5522’ MD; 4917’ TVD Base CINGSA: 5808’ MD; 5144’ TVD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status UB 4A Lower 6,135’6,149’5,394’5,398’14 03/23/2023 Open MB 7A Upper 7,330’7,338’6,430’6,437’8 02/03/2023 Isolated MB 7A Mid 7,342’7,347’6,441’6,446’5 02/03/2023 Isolated MB 7A Lower 7,360’7,378’6,458’6,474’18 12/29/2022 Isolated LB 7,501'7,516’6,589'6,603'15’12/03/2022 Isolated LB 1A Upper 7,544’7,557’6,629'6,642'10’11/02/2022 Isolated LB 1A Lower 7,564’7,572’6,648'6,656'8’11/02/2022 Isolated LB 1C Upper 7,588'7,595'6,671'6,677'7'12/03/2022 Isolated LB 1C Lower 7,601'7,608'6,683'6,690'7'12/02/2022 Isolated LB 1D 7,640'7,645'6,720'6,725'5'12/02/2022 Isolated LB 1F Upper 7,683'7,691'6,761'6,768'8'12/02/2022 Isolated LB 1F Mid 7,703'7,708'6,779'6,784'5'12/02/2022 Isolated LB 1F Lower 7,732'7,740'6,807'6,815'8'12/02/2022 Isolated LB 1G Upper 7,764'7,772'6,837'6,845'8'11/28/2022 Isolated LB 1G Lower 7,788’7,796’6,860'6,868'8’10/31/2022 Isolated LB 2 7,821'7,831'6,892'6,901'10'11/28/2022 Isolated LB 2A 7,889'7,898'6,956'6,965'9'11/28/2022 Isolated LB 2B upper 7,911’7,921’6,977'6,987'10’10/31/2022 Isolated LB 2B Mid 7,928’7,934’6,994'6,999'6’10/31/2022 Isolated LB 2B Lower 7,946'7,951'7,011'7,016'5'11/28/2022 Isolated LB 2B 7,996’8,007’7,059'7,069'11’10/31/2022 Isolated LB 3C 8,301’8,311’7,351'7,361'10’10/26/2022 Isolated LB 4B 8,468’8,474’7,513'7,519'10’10/26/2022 Isolated LB 5 Upper 8,613’8,621’7,653'7,661'8’10/26/2022 Isolated LB 5 Mid 8,631’8,636’7,671'7,676'5’10/26/2022 Isolated LB 5 Lower 8,641’8,649’7,681'7,688'8’10/24/2022 Isolated _____________________________________________________________________________________ Updated by CAH 10-11-24 PROPOSED Cannery Loop Unit – Pad # 1 Well: CLU-10RD Last Completed: 10/12/22 PTD: 222-113 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 133 / K-55 / N/A 18.73 Surf 123' 13-3/8'Surface 68 /L-80/ BTC 12.415 Surf 1,953’ 9-5/8"Intermediate 40 / L-80 / BTC 8.835 Surf 4,120’ (TOW) 7”Liner 26 / L-80 / Vamtop 6.276”3,877’5,921’ 4-1/2”Prod liner 12.6 / L-80 / DWC/C 3.958”5,682’8,801’ TUBING DETAIL 4-1/2"Tieback 12.6 / L-80 / IBT 3.958”Surf 5,678’ JEWELRY DETAIL No Depth Item 1 3,920’Flex-lock liner hanger, HRDE ZXPN Liner Top Packer w/ 5.5” PBR 2 ±5,000’7” CIBP for whipstock 3 5,682’5” x 7” ZXP, HRDE Liner Top Packer, w. 5.25” PBR 3A ±6,110’4-1/2” CIBP with 25ft of cmt 4 7,300’4-1/2” CIBP w/ 10ft of cmt, TOC @ 7,290’ (3/2/23) 5 7,450’4-1/2” WRP (1.84” OD External Fish neck), w SL catcher sub on top 6 7,985’CIBP w/ 10ft of cmt (6.4 gal) set 11/25/22 ToC 7,975’ 7 8,290’CIBP w/ 25ft of cmt (16 gal) Set 10/30/22 Toc 8,265’ OPEN HOLE / CEMENT DETAIL 8-1/2” 30 bbls spacer followed by 67 bbls of 15.3 ppg, bumped plug. Recovered 30 bbls spacer and 10 bbls of cement. CBL run 9/30/22, shows TOC @ 4,163’ MD 6-1/8”CBL run 10/16/22, shows TOC @ 4,163’ MD RA Tags @ 7,782 & 6,807’ short joints @ 7,292’ & 8,309’ Top CINGSA: 5522’ MD; 4917’ TVD Base CINGSA: 5807’ MD; 5144’ TVD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status UB 4A Lower 6,135’6,149’5,394’5,398’14 03/23/2023 ISOLATED MB 7A Upper 7,330’7,338’6,430’6,437’8 02/03/2023 Isolated MB 7A Mid 7,342’7,347’6,441’6,446’5 02/03/2023 Isolated MB 7A Lower 7,360’7,378’6,458’6,474’18 12/29/2022 Isolated LB 7,501'7,516’6,589'6,603'15’12/03/2022 Isolated LB 1A Upper 7,544’7,557’6,629'6,642'10’11/02/2022 Isolated LB 1A Lower 7,564’7,572’6,648'6,656'8’11/02/2022 Isolated LB 1C Upper 7,588'7,595'6,671'6,677'7'12/03/2022 Isolated LB 1C Lower 7,601'7,608'6,683'6,690'7'12/02/2022 Isolated LB 1D 7,640'7,645'6,720'6,725'5'12/02/2022 Isolated LB 1F Upper 7,683'7,691'6,761'6,768'8'12/02/2022 Isolated LB 1F Mid 7,703'7,708'6,779'6,784'5'12/02/2022 Isolated LB 1F Lower 7,732'7,740'6,807'6,815'8'12/02/2022 Isolated LB 1G Upper 7,764'7,772'6,837'6,845'8'11/28/2022 Isolated LB 1G Lower 7,788’7,796’6,860'6,868'8’10/31/2022 Isolated LB 2 7,821'7,831'6,892'6,901'10'11/28/2022 Isolated LB 2A 7,889'7,898'6,956'6,965'9'11/28/2022 Isolated LB 2B upper 7,911’7,921’6,977'6,987'10’10/31/2022 Isolated LB 2B Mid 7,928’7,934’6,994'6,999'6’10/31/2022 Isolated LB 2B Lower 7,946'7,951'7,011'7,016'5'11/28/2022 Isolated LB 2B 7,996’8,007’7,059'7,069'11’10/31/2022 Isolated LB 3C 8,301’8,311’7,351'7,361'10’10/26/2022 Isolated LB 4B 8,468’8,474’7,513'7,519'10’10/26/2022 Isolated LB 5 Upper 8,613’8,621’7,653'7,661'8’10/26/2022 Isolated LB 5 Mid 8,631’8,636’7,671'7,676'5’10/26/2022 Isolated LB 5 Lower 8,641’8,649’7,681'7,688'8’10/24/2022 Isolated The picture can't be displayed.The picture can't be displayed.The picture can't be displayed.The picture can't be displayed. 13-5/8"Spherical Annular Height: 46" Weight: 12,806 13-5/8"LWS Double BOP Height: 37" Width: 93" Weight 9,900 lbs. TOP RAMS 2-7/8" TO 5-1/2" MULTI- RAMS BOTTOM RAMS BLIND RAMS 13-5/8"Mud Cross W/ 4- 1/16" outlets Height:28.5" Width 31" Dual 4-1/16" Manual Gate valves W/ DSA to 2-1/16" 4-1/16" Manual Gate valve & 4-1/16" HCR W/ DSA to 2-1/16" Full Mud Cross Assy. width w/ valves installed Width: 98.5" Weight: 2200 lbs. Kill side Choke side Height Addition for Ring Gaskets: 0" BOP Total Height: 111.5" BOP Total weight: 24,906 lbs. 13-5/8" 5m BOP Package W/ 4-1/16" Valves Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer SFD 10/19/2024 324-602 SFD 10/19/2024 CLU 10RD 222-113 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: N2 Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,803 feet See Schematic feet true vertical 7,838 feet N/A feet Effective Depth measured 7,290 feet 3920, 5682 feet true vertical 6,393 feet 3539, 5044 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / L-80 5,678' MD 5,041' TVD Liner Top Pkrs 3920, 5682 MD 3539, 5044 TVD Packers and SSSV (type, measured and true vertical depth) Baker S-05 TRSSSV 357' MD 357' MD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: N/A Chad Helgeson, Operations Engineer 323-105 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 19 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 chelgeson@hilcorp.com 907-777-8405 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 123' 000 0 650 65 Intermediate measured TVD 9-5/8" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-113 50-133-20553-01-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEE-Hilcorp (formerly ADL 060569), ADL 391790 Cannery Loop / Beluga Gas Pool Cannery Loop Unit (CLU) 10RD Plugs Junk measured Length Burst Collapse 1,500psi 1,950psi Production 4,129' 3,119' Casing Structural 3,721' 7,837' 4,120 (TOW) 8,801' 123'Conductor Surface Intermediate 20" 13-3/8" 123' 1,953' 2,044' 7" 5,921' 5,235' 7,230psi 5,410psi 3,090psi 7,500psi 3,060psi 3,450psi 5,750psi 8,430psi 1,953' 1,865' PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.12.21 09:28:01 - 09'00' Noel Nocas (4361) By Grace Christianson at 2:12 pm, Dec 21, 2023 SFD 1/2/2024BJM 1/11/24 DSR-1/26/24 RBDMS JSB 122823 Perforate Rig Start Date End Date 3/2/23 12/12/23 Fox N2 pump on location. Open PTW & PJSM. Rig up hardline to the companion valve. PT to 250/3000 psi, pass. WHP @ 65 psi. Come online w/ N2 @ 800 scf/min (12:05 in Scada). See breakover @ 1353 psi @ 90,000 scf (2:04 in scada). Maintain 800 scf/min for 30 min, WHP down to 1265 psi. Shut in N2 @ 117,500 scf (2:35 in scada). Let WHP bleed back. Ops notified us manifold valve is leaking. Shut in flowline valve and install digital gauge (can no longer trend WHP in Scada). Come online w/ N2 pump @ 800 scf/min. Starting scf @ 117,500. Starting pressure= 720 psi, 15 min = 830 psi, 30 min = 898, 45 min = 942, 1 hour = 967. See Breakover @ 968 psi, @ 163,300 scf. Hold rate steady for 10 min @ 800 scf/min. 966 psi at end of 10 min. increase rate to 1800 scf/min (177,600 total pumped). Starting pressure = 966, 15 min = 1166, 30 min = 1305 Increase rate to 2500 scf/min (250,000 scf total pumped) @ 1375 psi. 15 min = 1560 psi, 30 min = 1672, 45 min = 1711. Run out of N2 @ 370,000 scfs. SI well @ 1711 psi. RDMO fox N2. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name CLU-10RD 50-133-20553-01-00 222-113 03/02/2023 - Thursday Yellow Jacket arrive on location. Hold TBT and approve PTW. MIRU Equipment. MU GPT and 4-1/2" CIBP toolstring. PT lubricator to 200 psi low / 2000 psi high. Find fluid level at 7295'. Log across plug setting interval and tie-into previous perf log. Set CIBP at 7300'. Tag plug to confirm set. POOH and log from 6400' to 5770' and send to RE/GEO for upcoming perfs. Add 12' to log. POOH and laydown plug setting toolstring. MU and RIH with 3" x 25' bailer loaded with 6.4 gallons of cement. Dump bail 10' of cement on top of plug at 7300'. TOC = 7290'. MU and RIH with 2-7/8" x 14' perf gun. GR/CCL to top perf = 10.0' Send correlation data to RE/GEO and confirm on depth. Perforate 6135-6149' (UB 4A Lower) Initial pressure = 194 psi, 5, 10, 15 minute pressures = 194 psi. All shots fired. Gun is dry. Bleed well down from 194 psi to 102 psi. No flow. Shut-in well and monitor. RIH with GPT and find fluid level at 7200'. Laydown toolstring and secure well with night cap. 03/03/2023- Friday 03/23/2023 - Thursday PTW, JSA with Yellow jacket E-line crew. Pick up lubricator make up GPT tool string. Stab on well. WHP 105 psi. RIH logging for fluid. Fluid level @ 6758'. Tagged cement top at 7299'. POOH to surface. RIH with CCL and sample bailer down to 7200' and catch water sample. Tagged up at surface. Collect water sample in container. RDMO Yellow Jacket E- line. Move to KBU 11-07. Tagged cement top at 7299'. Dump bail 10' of cement on top of plug at 7300'. TOC = 7290'. Tagged cement 1' above CIBP. Indicates cement was not set or depth control was off. -bjm sundried procedure called for 25' of cement. verified all perfs in the same Beluga Gas Pool so cement is not required -bjm Rig Start Date End Date 3/2/23 12/12/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name CLU-10RD 50-133-20553-01-00 222-113 12/12/2023- Tuesday Reservoir team determined no additional work was needed on this well, at this time, after completing the perfs on CLU- 14. _____________________________________________________________________________________ Updated by DMA 08-09-23 SCHEMATIC Cannery Loop Unit – Pad # 1 Well: CLU-10RD Last Completed: 10/12/22 PTD: 222-113 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 133 / K-55 / N/A 18.73 Surf 123' 13-3/8'Surface 68 /L-80/ BTC 12.415 Surf 1,953’ 9-5/8"Intermediate 40 / L-80 / BTC 8.835 Surf 4,120’ (TOW) 7”Liner 26 / L-80 / Vamtop 6.276”3,877’5,921’ 4-1/2”Prod liner 12.6 / L-80 / DWC/C 3.958”5,682’8,801’ TUBING DETAIL 4-1/2"Tieback 12.6 / L-80 / IBT 3.958”Surf 5,678’ JEWELRY DETAIL No Depth Item 1 357’Baker S-05 TRSSSV w/ 3.813” BX Profile, full open 1,900 psi 2 3,920’Flex-lock liner hanger, HRDE ZXPN Liner Top Packer w/ 5.5” PBR 3 5,682’5” x 7” ZXP, HRDE Liner Top Packer, w. 5.25” PBR 4 7,300’4-1/2” CIBP w/ 10ft of cmt, TOC @ 7,290’ (3/2/23) 5 7,450’4-1/2” WRP (1.84” OD External Fish neck), w SL catcher sub on top 6 7,985’CIBP w/ 10ft of cmt (6.4 gal) set 11/25/22 ToC 7,975’ 7 8,290’CIBP w/ 25ft of cmt (16 gal) Set 10/30/22 Toc 8,265’ OPEN HOLE / CEMENT DETAIL 8-1/2” 30 bbls spacer followed by 67 bbls of 15.3 ppg, bumped plug. Recovered 30 bbls spacer and 10 bbls of cement. CBL run 9/30/22, shows TOC @ 4,163’ MD 6-1/8”CBL run 10/16/22, shows TOC @ 4,163’ MD RA Tags @ 7,782 & 6,807’ short joints @ 7,292’ & 8,309’ Top CINGSA: 5522’ MD; 4917’ TVD Base CINGSA: 5808’ MD; 5144’ TVD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status UB 4A Lower 6,135’6,149’5,394’5,398’14 03/23/2023 Open MB 7A Upper 7,330’7,338’6,430’6,437’8 02/03/2023 Isolated MB 7A Mid 7,342’7,347’6,441’6,446’5 02/03/2023 Isolated MB 7A Lower 7,360’7,378’6,458’6,474’18 12/29/2022 Isolated LB 7,501'7,516’6,589'6,603'15’12/03/2022 Isolated LB 1A Upper 7,544’7,557’6,629'6,642'10’11/02/2022 Isolated LB 1A Lower 7,564’7,572’6,648'6,656'8’11/02/2022 Isolated LB 1C Upper 7,588'7,595'6,671'6,677'7'12/03/2022 Isolated LB 1C Lower 7,601'7,608'6,683'6,690'7'12/02/2022 Isolated LB 1D 7,640'7,645'6,720'6,725'5'12/02/2022 Isolated LB 1F Upper 7,683'7,691'6,761'6,768'8'12/02/2022 Isolated LB 1F Mid 7,703'7,708'6,779'6,784'5'12/02/2022 Isolated LB 1F Lower 7,732'7,740'6,807'6,815'8'12/02/2022 Isolated LB 1G Upper 7,764'7,772'6,837'6,845'8'11/28/2022 Isolated LB 1G Lower 7,788’7,796’6,860'6,868'8’10/31/2022 Isolated LB 2 7,821'7,831'6,892'6,901'10'11/28/2022 Isolated LB 2A 7,889'7,898'6,956'6,965'9'11/28/2022 Isolated LB 2B upper 7,911’7,921’6,977'6,987'10’10/31/2022 Isolated LB 2B Mid 7,928’7,934’6,994'6,999'6’10/31/2022 Isolated LB 2B Lower 7,946'7,951'7,011'7,016'5'11/28/2022 Isolated LB 2B 7,996’8,007’7,059'7,069'11’10/31/2022 Isolated LB 3C 8,301’8,311’7,351'7,361'10’10/26/2022 Isolated LB 4B 8,468’8,474’7,513'7,519'10’10/26/2022 Isolated LB 5 Upper 8,613’8,621’7,653'7,661'8’10/26/2022 Isolated LB 5 Mid 8,631’8,636’7,671'7,676'5’10/26/2022 Isolated LB 5 Lower 8,641’8,649’7,681'7,688'8’10/24/2022 Isolated DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 5 3 - 0 1 - 0 0 We l l N a m e / N o . CA N N E R Y L O O P U N I T 1 0 R D Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 10 / 2 4 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 1 1 3 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 88 0 3 TV D 78 3 8 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No We l l L o g I n f o r m a t i o n : Di g i t a l Me d / F r m t Re c e i v e d St a r t S t o p OH / CH Co m m e n t s Lo g Me d i a Ru n No El e c t r Da t a s e t Nu m b e r Na m e In t e r v a l Li s t o f L o g s O b t a i n e d : CB L s 9 - 3 0 - 2 2 & 1 0 - 1 6 - 2 2 , G P T a n d P e r f L o g s , M u d l o g s , L W D ( A D R , C T N , A L D , P W D D D S R ) No No Ye s Mu d L o g S a m p l e s D i r e c t i o n a l S u r v e y RE Q U I R E D I N F O R M A T I O N (f r o m M a s t e r W e l l D a t a / L o g s ) DA T A I N F O R M A T I O N Lo g / Da t a Ty p e Lo g Sc a l e DF 11 / 8 / 2 0 2 2 40 9 5 8 8 0 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 R D L W D Fi n a l . l a s 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 40 1 0 8 8 0 3 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U - 1 0 R D . l a s 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U 1 0 R D L W D F i n a l M D . c g m 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U 1 0 R D L W D F i n a l T V D . c g m 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D - D e f i n i t i v e S u r v e y Re p o r t . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D _ A c t u a l _ P l a n . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D _ A c t u a l _ V S e c . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D _ D S R . t x t 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D _ D S R _ G I S . t x t 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D _ F i n a l S u r v e y s . x l s x 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U 1 0 R D L W D F i n a l M D . e m f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U 1 0 R D L W D F i n a l T V D . e m f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U 1 0 R D L W D F i n a l M D . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U 1 0 R D L W D F i n a l T V D . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U 1 0 R D L W D F i n a l M D . t i f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U 1 0 R D L W D F i n a l T V D . t i f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D D a i l y R e p o r t s . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D F i n a l W e l l R e p o r t . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D D r i l l i n g D y n a m i c s Lo g M D 2 i n . p d f 37 2 4 0 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 1 o f 8 Su p p l i e d b y Op Su p p l i e d b y Op CL U 1 0 R D L W D Fin al. l as CL U - 1 0 R D . l a s DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 5 3 - 0 1 - 0 0 We l l N a m e / N o . CA N N E R Y L O O P U N I T 1 0 R D Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 10 / 2 4 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 1 1 3 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 88 0 3 TV D 78 3 8 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D D r i l l i n g D y n a m i c s Lo g M D 5 i n . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D D r i l l i n g D y n a m i c s Lo g T V D 2 i n . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D D r i l l i n g D y n a m i c s Lo g T V D 5 i n . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D F o r m a t i o n L o g M D 2i n . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D F o r m a t i o n L o g M D 5i n . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D F o r m a t i o n L o g T V D 2i n . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D F o r m a t i o n L o g T V D 5i n . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D G a s R a t i o L o g M D 2i n . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D G a s R a t i o L o g M D 5i n . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D G a s R a t i o L o g T V D 2i n . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D G a s R a t i o L o g T V D 5i n . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D L W D C o m b o L o g M D 2i n . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D L W D C o m b o L o g M D 5i n . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D L W D C o m b o L o g TV D 2 i n . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D L W D C o m b o L o g TV D 5 i n . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D D r i l l i n g D y n a m i c s Lo g M D 2 i n . t i f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D D r i l l i n g D y n a m i c s Lo g M D 5 i n . t i f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D D r i l l i n g D y n a m i c s Lo g T V D 2 i n . t i f 37 2 4 0 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 2 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 5 3 - 0 1 - 0 0 We l l N a m e / N o . CA N N E R Y L O O P U N I T 1 0 R D Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 10 / 2 4 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 1 1 3 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 88 0 3 TV D 78 3 8 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D D r i l l i n g D y n a m i c s Lo g T V D 5 i n . t i f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D F o r m a t i o n L o g M D 2i n . t i f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D F o r m a t i o n L o g M D 5i n . t i f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D F o r m a t i o n L o g T V D 2i n . t i f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D F o r m a t i o n L o g T V D 5i n . t i f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D G a s R a t i o L o g M D 2i n . t i f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D G a s R a t i o L o g M D 5i n . t i f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D G a s R a t i o L o g T V D 2i n . t i f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D G a s R a t i o L o g T V D 5i n . t i f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D L W D C o m b o L o g M D 2i n . t i f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D L W D C o m b o L o g M D 5i n . t i f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D L W D C o m b o L o g TV D 2 i n . t i f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D L W D C o m b o L o g TV D 5 i n . t i f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 8 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D S h o w R e p o r t s . p d f 37 2 4 0 ED Di g i t a l D a t a DF 11 / 1 7 / 2 0 2 2 58 9 9 3 8 2 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U - 1 0 R D M A I N PA S S F I N A L . l a s 37 2 6 7 ED Di g i t a l D a t a DF 11 / 1 7 / 2 0 2 2 86 8 8 5 1 6 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U - 1 0 R D _ R B T _1 6 O C T 2 2 _ M a i n P a s s . l a s 37 2 6 7 ED Di g i t a l D a t a DF 11 / 1 7 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D C B L L O G F I N A L . p d f 37 2 6 7 ED Di g i t a l D a t a DF 11 / 1 7 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D _ R B T _ 1 6 O C T 2 2 . p d f 37 2 6 7 ED Di g i t a l D a t a DF 11 / 1 7 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D _ R B T _1 6 O C T 2 2 _ i m g . t i f f 37 2 6 7 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 3 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 5 3 - 0 1 - 0 0 We l l N a m e / N o . CA N N E R Y L O O P U N I T 1 0 R D Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 10 / 2 4 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 1 1 3 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 88 0 3 TV D 78 3 8 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No DF 11 / 1 7 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D _ R B T _1 6 O C T 2 2 _ M a i n P a s s . d l i s 37 2 6 7 ED Di g i t a l D a t a DF 12 / 1 6 / 2 0 2 2 86 6 6 7 5 6 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U - 1 0 R D CO R R E C T E D G U N R U N 1 - 8 F T . l a s 37 3 7 7 ED Di g i t a l D a t a DF 12 / 1 6 / 2 0 2 2 86 6 5 7 5 6 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U - 1 0 R D G U N RU N 1 - 8 F T . l a s 37 3 7 7 ED Di g i t a l D a t a DF 12 / 1 6 / 2 0 2 2 86 4 5 7 7 5 3 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U - 1 0 R D L O G OF F B O T T O M . l a s 37 3 7 7 ED Di g i t a l D a t a DF 12 / 1 6 / 2 0 2 2 E l e c t r o n i c F i l e : C L U 1 0 R D G P T - P E R F F I N A L . p d f 37 3 7 7 ED Di g i t a l D a t a DF 12 / 1 6 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D C O R R E C T E D G U N RU N 1 - 8 F T . p d f 37 3 7 7 ED Di g i t a l D a t a DF 12 / 1 6 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D G P T 1 . p d f 37 3 7 7 ED Di g i t a l D a t a DF 12 / 1 6 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D G P T 2 I N H O L E . p d f 37 3 7 7 ED Di g i t a l D a t a DF 12 / 1 6 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D G P T 2 U P H O L E . p d f 37 3 7 7 ED Di g i t a l D a t a DF 12 / 1 6 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D G U N R U N 1 - 8 F T . p d f 37 3 7 7 ED Di g i t a l D a t a DF 12 / 1 6 / 2 0 2 2 E l e c t r o n i c F i l e : C L U - 1 0 R D L O G O F F BO T T O M . p d f 37 3 7 7 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 86 6 6 7 5 6 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U - 1 0 R D CO R R E C T E D G U N R U N 1 - 8 F T . l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 73 7 8 8 1 6 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U - 1 0 R D G P T 1 D O W N P A S S . l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 79 2 9 8 0 4 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U - 1 0 R D G P T AC R O S S P E R F S . l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 82 4 2 7 7 4 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U - 1 0 R D G U N 5 C O R R E L A T I O N P A S S . l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 79 6 7 7 6 1 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U - 1 0 R D G U N 8 C O R R E L A T I O N P A S S . l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 85 9 0 7 6 8 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U - 1 0 R D G U N S 1 A N D 2 C O R R E L A T I O N P A S S . l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 84 7 9 7 7 3 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U - 1 0 R D G U N S 3 A N D 4 C O R R E L A T I O N P A S S . l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 80 2 7 7 7 4 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U - 1 0 R D G U N S 6 A N D 7 C O R R E L A T I O N P A S S . l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 -4 3 7 9 6 3 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 R D G P T 1. l a s 37 4 6 4 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 4 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 5 3 - 0 1 - 0 0 We l l N a m e / N o . CA N N E R Y L O O P U N I T 1 0 R D Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 10 / 2 4 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 1 1 3 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 88 0 3 TV D 78 3 8 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No DF 1/ 2 4 / 2 0 2 3 79 6 1 7 4 1 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 R D G U N 1. l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 79 1 2 7 4 2 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 R D G U N 2. l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 78 6 2 7 4 2 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 R D G U N 3. l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 78 1 1 7 4 3 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 R D G U N 4. l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 77 9 7 7 4 4 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 R D G U N 10 . l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 77 9 4 7 4 4 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 R D G U N 11 . l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 77 9 4 7 4 3 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 R D G U N 5. l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 77 9 1 7 4 4 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 R D G U N 6. l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 77 9 6 7 4 4 0 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 R D G U N 7. l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 77 9 4 7 4 4 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 R D G U N 8. l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 77 9 4 7 4 4 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 R D G U N 9. l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 80 0 8 7 7 2 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 R D P L U G CO R R E L A T I O N . l a s 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U - 1 0 R D G P T 1 D O W N PA S S . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U - 1 0 R D G P T A C R O S S PE R F S . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U - 1 0 R D G U N 5 CO R R E L A T I O N P A S S . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U - 1 0 R D G U N 8 CO R R E L A T I O N P A S S . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U - 1 0 R D G U N S 1 A N D 2 CO R R E L A T I O N P A S S . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U - 1 0 R D G U N S 3 A N D 4 CO R R E L A T I O N P A S S . p d f 37 4 6 4 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 5 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 5 3 - 0 1 - 0 0 We l l N a m e / N o . CA N N E R Y L O O P U N I T 1 0 R D Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 10 / 2 4 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 1 1 3 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 88 0 3 TV D 78 3 8 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U - 1 0 R D G U N S 6 A N D 7 CO R R E L A T I O N P A S S . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U - 1 0 R D P E R F - G P T F I N A L . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 R D G P T 1 . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 R D G P T - P E R F F I N A L . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 R D G U N 1 . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 R D G U N 2 . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 R D G U N 3 . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 R D G U N 4 . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : 1 1 1 7 2 2 C L U 1 0 R D G P T FI N A L . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 R D G U N 1 0 . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 R D G U N 1 1 . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 R D G U N 5 . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 R D G U N 6 . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 R D G U N 7 . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 R D G U N 8 . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 R D G U N 9 . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 R D P E R F F I N A L 1 2 - 2 - 22 . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 R D P L U G CO R R E L A T I O N . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 4 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 R D P L U G F I N A L . p d f 37 4 6 4 ED Di g i t a l D a t a DF 1/ 2 6 / 2 0 2 3 78 0 6 6 7 5 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : CL U _ 1 0 R D _ G P T _ 2 9 - D e c - 2 0 2 2 _ ( 4 1 2 2 ) . l a s 37 4 7 4 ED Di g i t a l D a t a DF 1/ 2 6 / 2 0 2 3 77 9 2 7 2 7 4 E l e c t r o n i c D a t a S e t , F i l e n a m e : CL U _ 1 0 R D _ P l u g _ P e r f _ 2 9 - D e c - 2 0 2 2 _ ( 4 1 2 2 ) . l a s 37 4 7 4 ED Di g i t a l D a t a DF 1/ 2 6 / 2 0 2 3 E l e c t r o n i c F i l e : C L U _ 1 0 R D _ G P T _ P l u g _ P e r f _ 2 9 - De c - 2 0 2 2 _ ( 4 1 2 2 ) . p d f 37 4 7 4 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 64 1 7 5 4 6 3 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 - R D 1 4 ' PE R F C O R R E L A T I O N U B - 4 A L 3 - 2 - 2 3 . l a s 37 5 6 8 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 6 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 5 3 - 0 1 - 0 0 We l l N a m e / N o . CA N N E R Y L O O P U N I T 1 0 R D Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 10 / 2 4 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 1 1 3 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 88 0 3 TV D 78 3 8 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No We l l C o r e s / S a m p l e s I n f o r m a t i o n : Re c e i v e d St a r t S t o p C o m m e n t s To t a l Bo x e s Sa m p l e Se t Nu m b e r Na m e In t e r v a l DF 3/ 2 8 / 2 0 2 3 74 0 9 7 1 4 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 - R D C I B P CO R R E L A T I O N 3 - 2 - 2 3 . l a s 37 5 6 8 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 64 0 8 5 7 5 7 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 - R D CO R R E L A T I O N A C R O S S 6 4 0 0 - 5 7 7 0 ' 3 - 2 - 23 . l a s 37 5 6 8 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 58 4 0 7 2 1 6 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 - R D G P T AF T E R P E R F 3 - 2 - 2 3 . l a s 37 5 6 8 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 75 7 4 0 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 - R D G P T DO W N P A S S 3 - 2 - 2 3 . l a s 37 5 6 8 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 42 0 0 7 2 9 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : C L U 1 0 - R D G P T FL U I D @ 6 7 5 8 ' 3 - 3 - 2 3 . l a s 37 5 6 8 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 64 2 0 5 7 6 9 E l e c t r o n i c D a t a S e t , F i l e n a m e : C O R R E C T E D CL U 1 0 - R D C O R R E L A T I O N A C R O S S 6 4 0 0 - 57 7 0 ' 3 - 2 - 2 3 . l a s 37 5 6 8 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 - R D 1 4 ' P E R F CO R R E L A T I O N U B - 4 A L 3 - 2 - 2 3 . p d f 37 5 6 8 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 - R D C I B P CO R R E L A T I O N 3 - 2 - 2 3 . p d f 37 5 6 8 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 - R D C I B P - P E R F FI N A L . p d f 37 5 6 8 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 - R D C O R R E L A T I O N AC R O S S 6 4 0 0 - 5 7 7 0 ' 3 - 2 - 2 3 . p d f 37 5 6 8 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 - R D G P T A F T E R P E R F 3- 2 - 2 3 . p d f 37 5 6 8 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 - R D G P T D O W N P A S S 3- 2 - 2 3 . p d f 37 5 6 8 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 - R D G P T F I N A L . p d f 37 5 6 8 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 E l e c t r o n i c F i l e : C L U 1 0 - R D G P T F L U I D @ 67 5 8 ' 3 - 3 - 2 3 . p d f 37 5 6 8 ED Di g i t a l D a t a DF 3/ 2 8 / 2 0 2 3 E l e c t r o n i c F i l e : C O R R E C T E D C L U 1 0 - R D CO R R E L A T I O N A C R O S S 6 4 0 0 - 5 7 7 0 ' 3 - 2 - 23 . p d f 37 5 6 8 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 7 o f 8 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 50 - 1 3 3 - 2 0 5 5 3 - 0 1 - 0 0 We l l N a m e / N o . CA N N E R Y L O O P U N I T 1 0 R D Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 10 / 2 4 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 1 1 3 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 88 0 3 TV D 78 3 8 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No IN F O R M A T I O N R E C E I V E D Co m p l e t i o n R e p o r t Pr o d u c t i o n T e s t I n f o r m a t i o n Ge o l o g i c M a r k e r s / T o p s Y Y / N A Y Co m m e n t s : Co m p l i a n c e R e v i e w e d B y : Da t e : Mu d L o g s , I m a g e F i l e s , D i g i t a l D a t a Co m p o s i t e L o g s , I m a g e , D a t a F i l e s Cu t t i n g s S a m p l e s Y / N A Y Y / N A Di r e c t i o n a l / I n c l i n a t i o n D a t a Me c h a n i c a l I n t e g r i t y T e s t I n f o r m a t i o n Da i l y O p e r a t i o n s S u m m a r y Y Y / N A Y Co r e C h i p s Co r e P h o t o g r a p h s La b o r a t o r y A n a l y s e s Y / N A Y / N A Y / N A CO M P L I A N C E H I S T O R Y Da t e C o m m e n t s De s c r i p t i o n Co m p l e t i o n D a t e : 10 / 2 4 / 2 0 2 2 Re l e a s e D a t e : 9/ 2 2 / 2 0 2 2 12 / 1 / 2 0 2 2 41 2 0 8 3 0 3 3 1 8 2 5 Cu t t i n g s Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 8 o f 8 M. G u h l 9 / 2 5 / 2 0 2 3 Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 03/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230328 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 50133205300100 214070 2/18/2023 YELLOW JACKET PLUG BCU 18RD 50133205840100 222033 3/9/2023 YELLOW JACKET PERF CLU 10RD 50133205530100 222113 3/2/2023 YELLOW JACKET PERF-GPT-PLUG KBU 11-07 50133205560000 205165 3/3/2023 YELLOW JACKET PERF KBU 11-07 50133205560000 205165 3/1/2023 YELLOW JACKET PLUG KU 14X-6 50133203420000 181092 3/3/2023 YELLOW JACKET CALIPER-SCBL NCI B-02 50883200900100 197210 3/9/2023 AK E-LINE GPT Perf SRU 224-10 50133101380100 222124 2/15/2023 YELLOW JACKET PLUG TBU D-09RD 50733201310100 181080 2/27/2023 AK E-LINE Plug Punch Please include current contact information if different from above. CLU 10RD 50133205530100 222113 3/2/2023 YELLOW JACKET PERF-GPT-PLUG 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,805'N/A Casing Collapse Structural Conductor 1,500psi Surface 1,950psi Intermediate 3,090psi Intermediate 5,410psi Production 7,500psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Chad Helgeson, Operations Engineer chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: 12.6# L-80 5,678' March 6, 2023 Liner Top Pkrs; Baker S-05 TRSSSV 3,920' MD/3,539' TVD; 5,682' MD/ 5,044' TVD; 357' MD/'TVD See Schematic See Schematic 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE-Hilcorp (formerly ADL 060569), ADL 391790 222-113 50-133-20553-01-00 Cannery Loop Unit N/A Beluga Gas CO 231A Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 CLU-10RD Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 7,840'7,975'7,038'~1,843psi N/A MD 5,750psi 3,060psi 3,450psi 123' 1,865' 3,721' 123' 1,953' 4,120 (TOW) Perforation Depth MD (ft): 2,044' 4-1/2"3,119' 7" 9-5/8"4,129' 20" 13-3/8" 123' 1,953' 7,230psi5,235'5,921' 8,430psi8,801'7,837' m n P s 66 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Meredith Guhl at 7:17 am, Feb 21, 2023 Kenai 323-105 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2023.02.18 07:23:29 -09'00' Dan Marlowe (1267) DSR-2/22/23 8,803' BJM 2/24/23 10-404 7,838'SFD SFD 2/22/2023JLC 2/27/2023 2/27/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.27 12:26:56 -09'00' RBDMS JSB 022823 Well Work Prognosis Well Name: CLU 10RD API Number: 50-133-20553-01-00 Current Status: Gas Producer Rig: Eline Estimated Start Date: 3/6/23 Regulatory Contact: Donna Ambruz (8305) Permit to Drill Number: 222-113 First Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (M) Second Call Engineer: Jake Flora (907) 223-6784 (M) Maximum Expected BHP 2,384’ psi @ 5,420’ TVD Based on 0.44psi/ft gradient Maximum Potential Surface Pressure: 1,843 psi @ 5,420’ TVD Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary Cannery Loop 10RD is a sidetracked gas producer drilled and completed in October 2022. The well has been perforated and has not found commercial gas volumes yet. The zones are all in the Beluga Pool per CO 231A definition. Notes Regarding Wellbore Condition x 4-1/2” monobore completion planned x TRSSSV at ~140-150’ x CINGSA isolated with 7” liner CINGSA Pool bottom – 5,808’ MD (5,144’ TVD) x 4-1/2” WRP set at 7,450’ with catcher sub. SL unable to fish. Procedure: 1. RU E-line, PT lubricator to 2000 psi High/250 psi Low 2. Run GPT and confirm fluid level is below bottom perf, Pressure well up with gas from offset well on pad, or N2 to push fluid below 6200’. 3. Set CIBP at ~7,300’, place 25ft of cement on plug 4. Perforate Beluga Gas sands with 60 deg phased hollow carrier perf guns Pool Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Beluga UB 4A Upper ±6,117’' ±6,122' ±5,394’ ±5,398’ 5’ Beluga UB 4A Lower ±6,135’ ±6,149’ ±5,408’ ±5,420’ 14’ Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. a. Record initial and 5/10/15 minute tubing pressures after firing b. Above perfs will be shot in the Beluga Gas Pool governed by CO 231A 5. Turn well over to Ops for production E-line Procedure (Contingency) 1. If any zone produces sand and/or water or needs isolated: 2. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 2,500 psi High. 3. RIH and set a Casing Patch or set a CIBP above the zone and dump 25’ of cement on top of the plug. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic Agree. SFD 2/22/2023 _____________________________________________________________________________________ Revised By CAH 2-17-23 SCHEMATIC Cannery Loop Unit – Pad # 1 Well: CLU-10RD Last Completed: 10/12/22 PTD: 222-113 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 133 / K-55 / N/A 18.73 Surf 123' 13-3/8'Surface 68 /L-80/ BTC 12.415 Surf 1,953’ 9-5/8"Intermediate 40 / L-80 / BTC 8.835 Surf 4,120’ (TOW) 7”Liner 26 / L-80 / Vamtop 6.276”3,877’5,921’ 4-1/2”Prod liner 12.6 / L-80 / DWC/C 3.958”5,682’8,801’ TUBING DETAIL 4-1/2"Tieback 12.6 / L-80 / IBT 3.958”Surf 5,678’ JEWELRY DETAIL No Depth Item 1 357’Baker S-05 TRSSSV w/ 3.813” BX Profile, full open 1,900 psi 2 3,920’Flex-lock liner hanger, HRDE ZXPN Liner Top Packer w/ 5.5” PBR 3 5,682’5” x 7” ZXP, HRDE Liner Top Packer, w. 5.25” PBR 3A 7,450’4-1/2” WRP (1.84” OD External Fish neck), w SL catcher sub on top 4 7,985’CIBP w/ 10ft of cmt (6.4 gal) set 11/25/22 ToC 7,975’ 5 8,290’CIBP w/ 25ft of cmt (16 gal) Set 10/30/22 Toc 8,265’ OPEN HOLE / CEMENT DETAIL 8-1/2” 30 bbls spacer followed by 67 bbls of 15.3 ppg, bumped plug. Recovered 30 bbls spacer and 10 bbls of cement. CBL run 9/30/22, shows TOC @ 4,163’ MD 6-1/8”CBL run 10/16/22, shows TOC @ 4,163’ MD RA Tags @ 7,782 & 6,807’ short joints @ 7,292’ & 8,309’ Top CINGSA: 5522’ MD; 4917’ TVD Base CINGSA: 5808’ MD; 5144’ TVD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status MB 7A Upper 7,330’7,338’6,430’6,437’8 2/3/23 Open MB 7A Mid 7,342’7,347’6,441’6,446’5 2/3/23 Open MB 7A Lower 7,360’7,378’6,458’6,474’18 12/29/22 Open LB 7,501'7,516’6,589'6,603'15’12/3/2022 Temp plug LB 1A Upper 7,544’7,557’6,629'6,642'10’11/2/2022 Temp plug LB 1A Lower 7,564’7,572’6,648'6,656'8’11/2/2022 Temp plug LB 1C Upper 7,588'7,595'6,671'6,677'7'12/3/2022 Temp plug LB 1C Lower 7,601'7,608'6,683'6,690'7'12/2/2022 Temp plug LB 1D 7,640'7,645'6,720'6,725'5'12/2/2022 Temp plug LB 1F Upper 7,683'7,691'6,761'6,768'8'12/2/2022 Temp plug LB 1F Mid 7,703'7,708'6,779'6,784'5'12/2/2022 Temp plug LB 1F Lower 7,732'7,740'6,807'6,815'8'12/2/2022 Temp plug LB 1G Upper 7,764'7,772'6,837'6,845'8'11/28/2022 Temp plug LB 1G Lower 7,788’7,796’6,860'6,868'8’10/31/2022 Temp plug LB 2 7,821'7,831'6,892'6,901'10'11/28/2022 Temp plug LB 2A 7,889'7,898'6,956'6,965'9'11/28/2022 Temp plug LB 2B upper 7,911’7,921’6,977'6,987'10’10/31/2022 Temp plug LB 2B Mid 7,928’7,934’6,994'6,999'6’10/31/2022 Temp plug LB 2B Lower 7,946'7,951'7,011'7,016'5'11/28/2022 Temp plug LB 2B 7,996’8,007’7,059'7,069'11’10/31/2022 Isolated LB 3C 8,301’8,311’7,351'7,361'10’10/26/2022 Isolated LB 4B 8,468’8,474’7,513'7,519'10’10/26/2022 Isolated LB 5 Upper 8,613’8,621’7,653'7,661'8’10/26/2022 Isolated LB 5 Mid 8,631’8,636’7,671'7,676'5’10/26/2022 Isolated LB 5 Lower 8,641’8,649’7,681'7,688'8’10/24/2022 Isolated _____________________________________________________________________________________ Revised By CAH 2-17-23 PROPOSED SCHEMATIC Cannery Loop Unit – Pad # 1 Well: CLU-10RD Last Completed: 10/12/22 PTD: 222-113 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 133 / K-55 / N/A 18.73 Surf 123' 13-3/8'Surface 68 /L-80/ BTC 12.415 Surf 1,953’ 9-5/8"Intermediate 40 / L-80 / BTC 8.835 Surf 4,120’ (TOW) 7”Liner 26 / L-80 / Vamtop 6.276”3,877’5,921’ 4-1/2”Prod liner 12.6 / L-80 / DWC/C 3.958”5,682’8,801’ TUBING DETAIL 4-1/2"Tieback 12.6 / L-80 / IBT 3.958”Surf 5,678’ JEWELRY DETAIL No Depth Item 1 357’Baker S-05 TRSSSV w/ 3.813” BX Profile, full open 1,900 psi 2 3,920’Flex-lock liner hanger, HRDE ZXPN Liner Top Packer w/ 5.5” PBR 3 5,682’5” x 7” ZXP, HRDE Liner Top Packer, w. 5.25” PBR 4 ±7,300’4-1/2” CIBP w/ 10ft of cmt 5 7,450’4-1/2” WRP (1.84” OD External Fish neck), w SL catcher sub on top 6 7,985’CIBP w/ 10ft of cmt (6.4 gal) set 11/25/22 ToC 7,975’ 7 8,290’CIBP w/ 25ft of cmt (16 gal) Set 10/30/22 Toc 8,265’ OPEN HOLE / CEMENT DETAIL 8-1/2” 30 bbls spacer followed by 67 bbls of 15.3 ppg, bumped plug. Recovered 30 bbls spacer and 10 bbls of cement. CBL run 9/30/22, shows TOC @ 4,163’ MD 6-1/8”CBL run 10/16/22, shows TOC @ 4,163’ MD RA Tags @ 7,782 & 6,807’ short joints @ 7,292’ & 8,309’ Top CINGSA: 5522’ MD; 4917’ TVD Base CINGSA: 5808’ MD; 5144’ TVD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status UB 4A Upper ±6,117’±6,122’±5,408’±5,420’5 Proposed UB 4A Lower ±6,135’±6,149’±5,394’±5,398’14 Proposed MB 7A Upper 7,330’7,338’6,430’6,437’8 2/3/23 Isolated MB 7A Mid 7,342’7,347’6,441’6,446’5 2/3/23 Isolated MB 7A Lower 7,360’7,378’6,458’6,474’18 12/29/22 Isolated LB 7,501'7,516’6,589'6,603'15’12/3/2022 Isolated LB 1A Upper 7,544’7,557’6,629'6,642'10’11/2/2022 Isolated LB 1A Lower 7,564’7,572’6,648'6,656'8’11/2/2022 Isolated LB 1C Upper 7,588'7,595'6,671'6,677'7'12/3/2022 Isolated LB 1C Lower 7,601'7,608'6,683'6,690'7'12/2/2022 Isolated LB 1D 7,640'7,645'6,720'6,725'5'12/2/2022 Isolated LB 1F Upper 7,683'7,691'6,761'6,768'8'12/2/2022 Isolated LB 1F Mid 7,703'7,708'6,779'6,784'5'12/2/2022 Isolated LB 1F Lower 7,732'7,740'6,807'6,815'8'12/2/2022 Isolated LB 1G Upper 7,764'7,772'6,837'6,845'8'11/28/2022 Isolated LB 1G Lower 7,788’7,796’6,860'6,868'8’10/31/2022 Isolated LB 2 7,821'7,831'6,892'6,901'10'11/28/2022 Isolated LB 2A 7,889'7,898'6,956'6,965'9'11/28/2022 Isolated LB 2B upper 7,911’7,921’6,977'6,987'10’10/31/2022 Isolated LB 2B Mid 7,928’7,934’6,994'6,999'6’10/31/2022 Isolated LB 2B Lower 7,946'7,951'7,011'7,016'5'11/28/2022 Isolated LB 2B 7,996’8,007’7,059'7,069'11’10/31/2022 Isolated LB 3C 8,301’8,311’7,351'7,361'10’10/26/2022 Isolated LB 4B 8,468’8,474’7,513'7,519'10’10/26/2022 Isolated LB 5 Upper 8,613’8,621’7,653'7,661'8’10/26/2022 Isolated LB 5 Mid 8,631’8,636’7,671'7,676'5’10/26/2022 Isolated LB 5 Lower 8,641’8,649’7,681'7,688'8’10/24/2022 Isolated 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): Cannery Loop Unit GL: 19.8' 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 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 7" L-80 5,235' 4-1/2" L-80 7,836' 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 4-1/2" Tieback SIZE DEPTH SET (MD) 5,682' MD / 5,035' TVD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 5,682' 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 5,678' 6-1/8" 305 sx 5,035' 330 sx 3,877' 8,801' 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 272452 2388727 20-133-20553-01-00September 25, 2022 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 10/24/2022 222-113 / 322-589 LOCI 78-156 CLU-10RDOctober 9, 2022281' FSL, 531' FEL, Sec 7, T5N, R11W, SM, AK 37.8' BOTTOMCASINGWT. PER FT.GRADE CEMENTING RECORD 2389488 SETTING DEPTH TVD 2389863 TOP HOLE SIZE CBLs 9-30-22 & 10-16-22, GPT and Perf Logs, Mudlogs, LWD (ADR, CTN, ALD, PWD DDSR) Beluga Gas Pool ADL 60569 / ADL 391790 Date of Test: Oil-Bbl: Flowing *** Please see attached schematic for perforation detail *** Gas-Oil Ratio: AMOUNT PULLED 275167 275383 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, 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 only if necessary. PACKER SET (MD/TVD) 8-1/2" N/A 4,120' MD / 3,721' TVD 357' MD / 357' TVD 8,803' MD / 7,838' TVD 7,975' MD / 7,038' TVD 1093' FSL, 2169' FWL, Sec 8, T5N, R11W, SM, AK 1473' FSL, 2381' FWL, Sec 8, T5N, R11W, SM, AK Choke Size: 3,501' Per 20 AAC 25.283 (i)(2) attach electronic information 26# 12.6# 5,921' Water-Bbl: PRODUCTION TEST 11/3/2022 Sr Res EngSr Pet GeoSr Pet Eng N/A N/A Oil-Bbl: Water-Bbl: 0068 0 1/10/2023 24 Flow Tubing 0 117 N/A1170 WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 9:59 am, Feb 08, 2023 Completed 10/24/2022 JSB RBDMS JSB 021323 GSFD 2/22/2023BJM 10/26/23 DSR-10/25/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval Mid Bel 7A 7,330 6,430' 5,522' 4,917' 5,808' 5,144' 6,673' 5,850' 7,474' 6,564' 8,741' 7,778' 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 Digital Signature with Date:Contact Email:cdinger@hilcorp.com Contact Phone: 907-777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS 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. 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). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, 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). Authorized Name and Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Lower Beluga CINGSA Upper Beluga Mid Beluga Formation Name at TD: 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. 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; or 90 days after log acquisition, whichever occurs first. INSTRUCTIONS Tyonek Wellbore Schematic, Drilling and Completion Reports, Directional Surveys, Csg and Cmt Reports. Authorized Title: Drilling Manager No NoSidewall Cores: Yes No Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov 2.8.2023 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: 2023.02.08 09:40:48 -09'00' Monty M Myers _____________________________________________________________________________________ RevisedBy CJD2-8-23 Schematic Cannery Loop Unit – Pad # 1 Well: CLU-10RD Last Completed: 10/12/22 PTD: 222-113 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 133 / K-55 / N/A 18.73 Surf 123' 13-3/8'Surface 68 /L-80/ BTC 12.415 Surf 1,953’ 9-5/8"Intermediate 40 / L-80 / BTC 8.835 Surf 4,120’(TOW) 7”Liner 26 / L-80 / Vamtop 6.276”3,877’5,921’ 4-1/2”Prod liner 12.6 / L-80 / DWC/C 3.958”5,682’8,801’ TUBING DETAIL 4-1/2"Tieback 12.6 / L-80 / IBT 3.958”Surf 5,678’ JEWELRY DETAIL No Depth Item 1 357’Baker S-05 TRSSSV w/ 3.813” BXProfile, full open 1,900 psi 2 3,920’Flex-lock liner hanger, HRDE ZXPN Liner Top Packer w/ 5.5” PBR 3 5,682’5” x 7” ZXP, HRDE Liner Top Packer, w. 5.25” PBR 3A 7450’4-1/2” WRP (1.84” OD External Fish neck) 4 7,985’CIBP w/ 10ft of cmt (6.4 gal) set 11/25/22 ToC 7,975’ 5 8,290’CIBP w/ 25ft of cmt (16 gal) Set 10/30/22 Toc 8,265’ OPEN HOLE / CEMENT DETAIL 8-1/2” 30 bbls spacer followed by 67 bbls of 15.3 ppg, bumped plug. Recovered 30 bbls spacer and 10 bbls of cement. CBL run 9/30/22, shows TOC @ 4,163’ MD 6-1/8”CBL run 10/16/22, shows TOC @ 4,163’ MD RA Tags @ 7,782 & 6,807’short joints @ 7,292’ & 8,309’ Top CINGSA: 5522’ MD; 4917’ TVD Base CINGSA: 5808’ MD; 5144’ TVD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status MB 7A Up 7,330’7,338’6,430’6,438’8’2/3/23 Open MB 7A Mid 7,342’7,347’6,441’6,446’5’2/3/23 Open MB 7A Low 7,360’7,378’6,458’6,475’18’12/29/22 Open LB 7,501'7,516’6,589'6,603'15’12/3/2022 Temp plug LB 1A Upper 7,544’7,557’6,629'6,642'10’11/2/2022 Temp plug LB 1A Lower 7,564’7,572’6,648'6,656'8’11/2/2022 Temp plug LB 1C Upper 7,588'7,595'6,671'6,677'7'12/3/2022 Temp plug LB 1C Lower 7,601'7,608'6,683'6,690'7'12/2/2022 Temp plug LB 1D 7,640'7,645'6,720'6,725'5'12/2/2022 Temp plug LB 1F Upper 7,683'7,691'6,761'6,768'8'12/2/2022 Temp plug LB 1F Mid 7,703'7,708'6,779'6,784'5'12/2/2022 Temp plug LB 1F Lower 7,732'7,740'6,807'6,815'8'12/2/2022 Temp plug LB 1G Upper 7,764'7,772'6,837'6,845'8'11/28/2022 Temp plug LB 1G Lower 7,788’7,796’6,860'6,868'8’10/31/2022 Temp plug LB 2 7,821'7,831'6,892'6,901'10'11/28/2022 Temp plug LB 2A 7,889'7,898'6,956'6,965'9'11/28/2022 Temp plug LB 2B upper 7,911’7,921’6,977'6,987'10’10/31/2022 Temp plug LB 2B Mid 7,928’7,934’6,994'6,999'6’10/31/2022 Temp plug LB 2B Lower 7,946'7,951'7,011'7,016'5'11/28/2022 Temp plug LB 2B 7,996’8,007’7,059'7,069'11’10/31/2022 Isolated LB 3C 8,301’8,311’7,351'7,361'10’10/26/2022 Isolated LB 4B 8,468’8,474’7,513'7,519'10’10/26/2022 Isolated LB 5 Upper 8,613’8,621’7,653'7,661'8’10/26/2022 Isolated LB 5 Mid 8,631’8,636’7,671'7,676'5’10/26/2022 Isolated LB 5 Lower 8,641’8,649’7,681'7,688'8’10/24/2022 Isolated Activity Date Ops Summary 9/22/2022 Continue R/D Complexes, Scope down derrick, Prep and Lay over derrick, rig movers on location @ 0930 started splitting apart back yard, pulled boiler house and pump skids, catwalk and HPU building, pull jig and spot in crane pull choke house and lay over wind wall, pull iron roughneck.;Lower dog house into water tank, pull out water tank and generator skid, pull out gas buster, give state notification for upcoming BOP test.;Spot in cranes and hoist derrick off sub, hoist draw works and sub off and onto trailers, move pony subs over new well and spot cranes in, set sub on pony subs, set draw works on sub, set derrick on sub and pin, spot in water tank and raise dog house, spot in gen skid, raise wind wall.;Spot in HPU and pit module #1.;Raise derrick. R/U electrical lines, mud pumps, pit equipment, drive shaft, and brake linkage. R/U pop-off lines and jumper hoses. lower walkways install handrails, and lights on roof tops. Power up get-set raise and R/U vacuum degasser, Cont to R/U lower kelly hose,;and service loop and drill line. Install cable clamp and anchor line on DW drum. Prep to spool up drill line.;Install Derrick raise cylinder controls to derrick, Continue R/U electrical/utility lines, Install turnbuckles on TQ tube, prep to scope up derrick. Lay felt and liner for catwalk. remove shipping pins from Iron roughneck. R/U standpipe, TD hydraulics, drillers gauge and instrument lines. 9/23/2022 Scope up derrick and pin, install T bar and tur buckles on torque tube, rig movers on location 0700hrs spot in catwalk and water tank, crane in cement silo and centrifuge, set gas buster and raise, P/U top drive and secure to blocks, M/U torque bushing, hook up service loop and kelly hose.;Continue rigging up, change liners on Mud pumps t/ 5.5'', check top drive function take on water to rig tank and pits, check pit function, work on rig acceptance check list, N/D tree flange and dress top drive, bails saver sub link tilt cylinders, continue rigging up floor.;N/U BOP Stack, choke and kill lines, flow box and riser, hook up flow line, check pre- charge on all bottles, function test rams, handi berm around rig.;Energize Koomey, P/U test jt. and install test plug, flood stack with water and shell test BOP's to 3500 psi.;Function test mud pumps, flood mud lines with water and perform visual inspection, rack and tally drill pipe.;Pressure test BOPE w 4 1/2" test jt. to 250 low/3500 high for 5 min each. Perform Koomey Drawdown test. test manual and hydraulic chokes to 2000psi. Test gas alarms and PVT system. Test witnessed by AOGCC (Guy Cook).;Blind rams Fail/Pass ( functioned and bled air out of system). Well sign Fail/Pass (retrieved well sign from well house).;R/D test equipment and prep to P/U BHA and DP. 9/24/2022 Blow down lines, set wear ring 9'' ID, clear floor.;Service rig and top drive check break linkage and driveshaft.;Load pipe on racks and P/U BHA components to floor, Adjust service loop cover.;M/U Clean Out BHA, Bit, Bit Sub, Stab, XO, RIH t/ 4148' tag CIBP.;Displace well t/ 9.1 ppg 6% KCL Polymer 370 gpm 320 psi.;POOH f/ 4148' t/ surface, L/D BHA.;P/U 18 jts of HWDP and rack back in derrick.;R/U test equipment, test casing to 3500psi for 30min. 175 gal pumped, 175 gal returned. R/D test equipment, Blow down lines. Prep Whipstock BHA to PU.;M/U whip stock assembly as per rep. Shallow test MWD tools, M/U whip stock and scribe MWD.. TIH F/ 82' T4130' Orientate whip stock to 30 deg LOH. Tag bridge plug @ 4148' and trip anchor w 4K set down. P/U 5' placing top of whipstock @ 4120'. Set down 30k and shear off of whipstock.;Orientate whip stock to 30 deg LOH. Tag bridge plug @ 4148' and trip anchor w 4K set down. P/U 5' placing top of whipstock @ 4120'. Set down 30k and shear off of whipstock. 9/25/2022 Mill Window f/ 4120' TOW t/ 4134' BOW 5k WOB 400 gpm 1015 psi 80 rpm Drill t/ 4164', Drift window multiple time no issues, turn off rotary and dry drift clean no drag. 398lb of metal recovered total.;Circulate bottoms up 500 gpm 1385 psi MW 9.1ppg in and out.;R/U and perform FIT t/ 515 psi 12.16 ppg EMW27.6 gal pumped 25 gals returned , R/D test equipment and blow down lines.;POOH w/ Milling Assembly f/ 4078' t/ Surface, L/D Milling Assembly Window mill 1/4" under, follow mill 1/8" under, Gage mill 1/16" under.;Clean and clear rig floor, prep drilling BHA to P/U.;P/U 8 1/2" directional drilling BHA, and TIH f/ 692' to 4086' Calc = 67.4bbls, Act= 66.8 bbls.;Service rig and check fluids;R/U test equipment and perform Fit @ 3720' TVD. 9.1 ppg mud. pressure up 655psi. 12.48ppg EMW. 47 gal pumped, 45.5 gal returned.;Orientate to 30 deg LOH and slide thru window ( no set down) and continue to drill F/ 4164 ' T/ 4273' 53 RPM @ 5.5K tq. 470 GPM, 1285 psi. 2-6K WOB.;Circulate bottoms up 470 gpm, 1290psi. 9/26/2022 POOH f/ 4273' / 4085' No issues pulling through the window.;Change out renieer motor on top drive, function test good.;RIH f/ 4085' t/ 4273' No issues running through the window.;Drill Ahead f/ 4273' t/ 4350' 465 gpm 1357 psi 50 rpm 6.3 k tq on bottom, 5k WOB, MW 9.1 ppg ECD 9.45 ppg PUW 103k SOW 83k ROT 90k.;Drill Ahead 8 1/2'' hole section f/ 4350' t/ 4740' 467 gpm 1490 psi 60 rpm 7500 tq on bottom, 5k WOB, MW 9.2 ppg 9.71 ppg PUW 110k SOW 85k ROT 94k.;Drill Ahead 8 1/2'' hole section f/ 4470' t/ 5079' 470 gpm 1550 psi 60 rpm 8.4K tq on bottom, 5k WOB, MW 9.2 ppg 9.75 ppg PUW 118k SOW 91k ROT 100k. Pumped Hi-vis sweep @ 5040' returned 100 strokes late with 20% increase in cuttings.;Slow pump rates MP#1 = 46spm - 255psi MP#2 = 46spm - 257psi.;Drill Ahead 8 1/2'' hole section f/ 5079' t/ 5576' 450 gpm 1500 psi 60 rpm 9.1K tq on bottom, 5k WOB, MW 9.1 ppg 9.75 ECD PUW 133k SOW 86k ROT 106k. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: CLU 010RD Cannery Loop Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00102 CLU-10RD Drilling Spud Date: Mill Window f/4120' TOW t/ 4134' g perform Fit @ 3720' TVD. 9.1 ppg mud. pressure up 655psi. 12.48ppg EMW. 4 y perform FIT t/ 515 psi 12.16 ppg 9/27/2022 Drill 8 1/2'' Hole Section f/ 5478' t/ 5923' 450 gpm 1631 psi, 60 rpm 10.1k tq on bottom, 5k WOB, 142k PUW 88k SOW 110k ROT, MW 9.15 ppg ECD 9.7ppg Distance f/ Plan 20.57' 13.06' High 15.9' Left.;Circulate Bottoms up, Obtain Survey and SPR's Flow check static slight loss dropped about 2'' in riser in 10 min.;POOH on Elevators f/ 5923' t/ 4084' No hole issues or tight spots, Hole took correct fill.;Service rig grease top drive and blocks, grease crown and draw works.;RIH f/ 4084' t/ 5923' no fill on bottom, no hole issues.;Pump Hi Vis Sweep and circulate hole clean, sweep back on time no increase in cuttings, flow check well static slight loss.;POOH f/ 5923' t/ 4084' No hole issues.;Slip and cut drilling line, cut 40', calibrated hook load. Check COM.;POOH F/4084' to 139'. L/D Jar stand.;PJSM. L/D the 8 1/2" BHA. Removed the corrosion ring. L/D the flex collars. Downloaded the MWD tools. L/D DM/TM collar. L/D EWR and motor. L/D the bit. Bit graded 1,3,BT,G,X,1,TD.;Clean and clear the rig floor.;Drained the stack. C/O the UPR for 7". BOLDS pulled the wear bushing. R/U test equipment. Flooded and purged the lines.;Tested the UPR's w/the 7" test joint. 250/3500psi 5min OK.;R/D the test equipment. Installed the wear bushing ID=9".;R/U casing running tools.;PJSM for running 7" liner. RIH w/7" 26ppf L-80 Vamtop liner to 325'.;At 5923' 20.57' from the well plan 13.06' above the plan 15.90' left of the plan.;Hauled: 77 bbl Solids to KGF G&I Cumulative: 94 bbl Hauled: 233 bbl Fluid to KGF G&I Cumulative: 701 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 0 bbl Lost: 10 bbl Fluid Down Hole Cumulative:29 bbl Daily Metal: 13 lbs Cumulative: 368 lbs 9/28/2022 Continue RIH w/ 7'' Liner f/ 325' t/ 2014' M/U Liner Hanger, Mix Pal Mix, M/U Crossover to DP RIH 1 Stand.;Circulate Liner Volume 135 psi SPP 60 gpm.;Continue RIH w/ 7'' Liner on 4.5'' DP f/ 2014' t/ 5905' set down 10 k attempt to work through unable to, Wash to bottom stage pumps t / 4 bpm 350-650 psi slowly washing down.;Circulate and condition mud f/ cement job, stage pumps t/ 6 bpm 250 gpm 450 psi, M/U cement head and continue circulating f/ cement Job.;PJSM w/ Cementers, PT lines t/ 770 psi low 4440 psi High, pump 30 bbls spacer at 4 bpm 320 psi followed by 67 bbls Tail cement 15.3 ppg @ 4 bpm 225 psi . Dropped the dart and chase w/ 10 bbls water followed by 110 bbls 9.3ppg mud mud, ICP 110psi FCP 1050 psi.;Bumped the plug and held 1700 psi. Bled off .75 bbls and floats held OK. CIP@ 18:30hrs.;Pressured up to 2297psi and set the packer. Bleed off pressure and slacked off to 25K hook load. Pressured up to 3500psi and released the liner hanger running tool. Picked up and confirmed the tool had released OK. L/D the cement head. Pressured up to 500psi and picked up until the pressure;started to bleed down and rolled the pumps and circulated B/U and had 30bbls spacer and 10bbls cement to surface 425GPM 535psi.;POOH F/3850' to surface.;Clean and clear the rig floor. Break down the cement head. P/U the stack washing tool and washed the stack with inhibited water. P/U 4 1/2" test joint. Backed out the lock down screws. Removed the wear bushing.;C/O UPR's to 2 7/8" X 5" VBR's.;R/U test equipment. Flooded and purged lines.;Tested the 2 7/8" X 5" VBR's w/the 4 1/2" test joint 250/3500psi 5min OK.;Rack and tally drill pipe. P/U BHA#4. RIH while P/U 4 1/2" DP at 1000'.;Hauled: 26 bbl Solids to KGF G&I Cumulative: 120 bbl Hauled: 154 bbl Fluid to KGF G&I Cumulative: 855 bbl Hauled: 10 bbl Cement to KGF G&I Cumulative: 10 bbl Lost: 8bbl Fluid Down Hole Cumulative:37 bbl Daily Metal: 0 lbs Cumulative: 368 lb 9/29/2022 RIH p/U DP f/ 1000' t/ 3085' Filling pipe every 1500' RIH out of derrick f/ 3085' t/ 5710' setting down 5-10k.;Wash and ream f/ 5710' t/ 5738' Hard cement at 5720' 5k WOB 470 gpm 1600 psi 60 rpm CBU.;R/U and Perform casing test t/ 3500 psi f/ 30 min good test, R/D test equipment.;Drill Cement f/ 5738' t/ top of landing collar @ 5758' Drill landing collar t/ 5763' broke through continue drilling cement, float collar and shoe. Drilled 20' new hole to 5943' 330GPM 950PSI 70RPM 8.5K TQ 10K WOB P/U 127K, S/O 83K, ROT 100K.;CBU 330GPM 950PSI 70RPM 8.6K TQ.;Performed the FIT T/1145PSI EMW=13.5ppg OMW=9.3ppg. Pumped 1.5bbls bled back 1.5bbls. Blew down the choke and kill lines. R/D the test equipment.;Flow checked, well static. Pumped a dry job.;POOH 5895' to surface. L/D bit and bit sub.;Cleaned and cleared the rig floor. R/U E-line. C/O mud pump fluid ends to 5". Run the CBL log.;Hauled: 26 bbl Solids to KGF G&I Cumulative: 146 bbl Hauled: 144 bbl Fluid to KGF G&I Cumulative: 999 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 10 bbl Lost: 0 bbl Fluid Down Hole Cumulative:37 bbl Daily Metal: 0 lbs Cumulative: 368 lbs 9/30/2022 POOH Logging CBL f/ 5885' to top of liner, POOH L/D Logging tools and R/D Eline.;Service rig and top drive, grease draw works and crown.;P/U 6 1/8'' Directional BHA as per DD/MWD, Upload MWD shallow test tools load sources and RIH.;P/U 8jnts 4.5" DP and continue RIH f/ 737' t/5943'. P/U 140K S/O 85K.;Control drilled 60FPH 6 1/8" production hole F/5943' MD T/6118" MD. 230GPM, 1360psi,Diff 1775psi, 60RPM, 9K TQ, 6K WOB, 10.0ppg ECD Max gas 21 units P/U 147K, S/O 83K Rot 106K. Obtained SPR's @ 5984MD 5286TVD MW 9.3ppg 2.7BPM MP1- 500psi , MP2 -505psi.;Note: control drilling at 60FPH due to possible lost circulation zones.. Added 2 -50gal drums of NXS lube at 6110' due to difficult sliding. Sliding was much improved after the addition.;Control drilled 60FPH 6 1/8" directional BHA 6118' to 6169' P/U 147K S/O 83K, ROT 106K 230GPM, 1381 psi, 60RPM, 10K TQ, 60 ROP, 5K WOB, 186psi Diff, 9.21ppg ECD, Max gas 5 units.;Encountered 100% losses at 6169'. POOH F/6169' to 5913'.;Pumped 20bbls LCM pill @ 5913' 10ppb Baracarb 5, 10ppb Baracarb 25, 10ppb Vangaurd, 10ppb Ready Seal fine 123GPM, 494psi, Max flow 8.5%.;Built mud volume, monitor losses, static loss rate 100BPH.;Pumped 20bbls LCM pill @ 5913' 10ppb Baracarb 5, 10ppb Baracarb 25, 10ppb Vangaurd, 10ppb Ready Seal fine 128GPM, 470psi, Max flow 0%.;Built mud volume and monitored the well, static loss rate 100BPH.;At 6169' distance to well plan 19.12' 11.22' high and 15.48' left. p ;Bumped the plug and held 1700 psi. Bledppp off .75 bbls and floats held OK. ;Encountered 100% losses at 6169' POOH Logging CBL f/ 5885' to top of liner, ;Performed the FIT T/1145PSI EMW=13.5ppg p circulated B/U and had 30bbls spacer and 10bbls cement to surface gp p p gp p g pump 30 bbls spacer at 4 bpm 320 psi followed by 67 bbls Tail cement 15.3 ppg @ ppg @ 10/1/2022 Pump 20 bbl LCM pill 30# per bbl larger sized material, spot out side the bit and monitor on the trip tank, .25 bph initial loss rate 1 bph loss rate Final, Building mud, in all pits top off pits and get all LCM product in.;RIH f/ 5871' t/ 6169' no hole issues.;Drill Ahead 6 1/8'' hole section f/ 6169' t/ 6325' 230 gpm 1650 psi 55 rpm 9k tq on bottom, 143k PUW 87k SOW 111k ROT 5k WOB.;Control Drill Ahead 6 1/8'' Hole Section 60fph f/ 6325' t/ 6618' GPM 250, 1720psi, Diff-300psi, RPM 60, TQ 10.3K, WOB 5K, ECD 10.2ppg , Max gas 32 units, P/U 150K S/O 88K, ROT 112K. Obtained SPR's @ 6354'MD 5588' TVD MW 9.0ppg MP1=46spm/515psi MP2=47spm/515psi. Increased MW F/9.05ppg to 9.15ppg.;Control drilled ahead 6 1/8" Hole Section 60fph f/6618' t/6787' GPM 250, 1830psi, Diff 1000psi, RPM 60, TQ 8.8K, WOB 2K, ECD 10.9ppg, Max gas 35units, P/U 151K, S/O 90K, Rot 114K. Added in 2-50gal drums of NXS lubricant at 6728' and reduced TQ from 10.3K to 8.8K. Increased MW F/9.15ppg to 9.85ppg.;Control Drilled 6 1/8" Hole Section 60fph f/6787' t/6908 250GPM, 1850psi, RPM 60, TQ 8.2K, Diff 250psi WOB 4K, Max gas 10units, ECD 11.3ppg, P/U 147K, S/O 90K, ROT 116K,. Increased the MW 9.85ppg to 10.15ppg.;Due to difficult sliding added in 4-50gal drums NXS lubricant in at 6850' retort showed .5% concentration.;At 6855' 20.79' from the plan 17.67' low and 10.95' right.;Hauled: 24 bbl Solids to KGF G&I Cumulative: 182 bbl Hauled: 136 bbl Fluid to KGF G&I Cumulative: 1203 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 10 bbl Lost: 390 bbl Fluid Down Hole Cumulative:427 bbl Daily Metal: 0 lbs Cumulative: 368 lbs 10/2/2022 Continue Drilling 6 1/8'' hole section f/ 6908' t/ 6975' 250 gpm 1850 psi 60 rpm 8.2k tq on bottom 140k PUW 100k SOW 116k ROT, Slide drilling having issues stacking weight motor stalling, add lube and nut plug to attempt to slide, continue weighting up system slow.;Continue Drilling 6 1/8'' hole section f/ 6975' t/ 7062' 268 gpm 2063 psi 60 rpm 10.3k tq on bottom 140k PUW 100k SOW 116k ROT, Slide drilling having issues stacking weight motor stalling, add lube and nut plug to attempt to slide MW 10.4 ppg.;Continue Drilling 6 1/8'' hole section f/ 6975' t/ 7165' 265 gpm 2080 psi 60 rpm 10.5k tq on bottom 148k PUW 95k SOW 117k ROT, Slide drilling having issues stacking weight motor stalling. MW 10.4 ppg.;Continue Drilling 6 1/8'' hole section f/ 7165' t/7182' 265 gpm 2080 psi 60 rpm 10.5k tq on bottom 140k PUW 100k SOW 116k ROT, Slide drilling having issues stacking weight motor stalling, add 1-50gal drum of NXS lube and steel seal(graphite) to attempt to improve sliding MW 10.4 ppg.;At 7176' distance to the plan 11.29' 2.36' low 11.04' right.;Hauled: 19 bbl Solids to KGF G&I Cumulative: 201 bbl Hauled: 131 bbl Fluid to KGF G&I Cumulative: 1,334 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 10 bbl Lost: 0 bbl Fluid Down Hole Cumulative:427 bbl Daily Metal: 0 lbs Cumulative: 368 lbs 10/3/2022 Drill Ahead f/ 7182' t/ 7282' 283 gpm 2005 psi 80 rpm 10k tq on bottom 5k WOB 148k PUW 95k SOW 117k ROT Continue attempting to slide and drop angle stalling motor.;Circulate bottoms up, Flow check static.;POOH f/ 7282' t/ 6169' No Issues, seen 10k over pull as BHA started into the loss zone above 6169' Slacked back off didn't want to disturb it.;Service rig and top drive, grease crown and draw works.;RIH f/ 6169' t/ 7282' No hole issues.;Drilled 6 1/8" hole F/7281' to 7356' 280 GPM, 2175psi, RPM 80, TQ 11.3K, WOB 3K, ROP 65FPH, Flow 22%, ECD 11.6PPG, Max gas 40 units, P/U 147K, S/O 99K, Rot 119K.;Lost all returns while drilling ahead at 7356'. Pumped a 20bbl-40PPB LCM pill (10ppbVangaurd 10ppb Readiseal, 20ppb CaCo2, 1sxs nut plug) and spotted on bottom.;POOH F/7356' to 5907', 15K overpull through loss zone at 6169'.;Observe the well on trip tank static loss rate 48bbls/hr. While building volume in the mud tanks pumped a 16bbls LCM pill(20ppb sizedCaCo2, 10ppb Vangaurd, 10ppb readiseal, 1sxs nut plug) and spotted outside the bit.;Dynamic losses while spotting the LCM pill at 116GPM 160BPH losses decreased to 84BPH losses.;While building volume in the mud tanks observed the well on the trip tank . Initial loss rate 18BPH and decreased to 1BPH.;RIH while continuing to weight up mud to 10.4ppg in all tanks.;Distance to well plan 22.37' 16.73' high 14.85' right.;Hauled: 8 bbl Solids to KGF G&I Cumulative: 209 bbl Hauled: 72 bbl Fluid to KGF G&I Cumulative: 1,406 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 10 bbl Lost: 236 bbl Fluid Down Hole Cumulative:663 bbl Daily Metal: 0 lbs Cumulative: 368 lbs 10/4/2022 Continue RIH F/ 7100' T/ 7346' washing last stand down and staging mud pumps up to 230 GPM with SPP 1500psi. No Losses observed.;Drilled 6 1/8" hole F/ 7346' T/ 7406' 240 GPM, 1745psi, RPM 85, TQ 11.2K, WOB 5K, ROP 70FPH, Flow 18%, ECD 11.4PPG, Max gas 6 units, P/U 148K, S/O 100K, Rot 120K.;Drilled 6 1/8" hole F/ 7406' T/ 7541' 260 GPM, 2130psi, RPM 85, TQ 9K, WOB 5K, ROP 110FPH, Flow 19%, ECD 11.5PPG, Max gas 34 units, P/U 143K, S/O 100K, Rot 121K. Lost all returns.;POOH F/ 7541' pumping light mud down the backside while pulling to the 7" casing shoe @ 5919'. Pulled tight into the oscillating slides that were made throughout the day. Backream F/ 7541' T/ 7408' and continue POOH on elevators while pumping mud down the backside.;Observe the well on the trip tank while lined up to pump the LCM pill. Static losses 48BPH. Spot a 16bbls LCM pill#1(20ppb CaCo2, 10ppb Vanguard, 10ppb Ready seal, 2.5ppb nut plug, total 40ppb) at 110GPM dynamic losses 160BPH while spot the pill.;Observe the well on trip tank while build volume, serviced the rig and C/O the top drive saver sub. Static losses 72BPH and decreased to 25BPH.;Spotted a 16bbl LCM pill#2 (15PPB CaCo2, 10PPB Vanguard, 10PPB Ready seal, 2.5ppb nut plug, total 40ppb) at 110GPM lost 95bbls mud dynamic losses 158BPH while spot the pill. Monitor the trip tank while build volume. Initial static losses were 46BPH.;Continue to build volume and monitor the well for losses with the trip tank. Losses decreased to 15BPH.;Pumped LCM pill#3 16bbls(15ppb CaCo2, 10ppb Vangaurd, 10ppb readi seal, 5ppb Barofiber, 5ppb steel seal 100, 2.5ppb Nut plug, 2.5ppb Barocarb 150, total 50ppb) at 120GPM. Lost 68bbls mud while pumping the pill, 164BPH dynamic losses.;Built mud volume while monitored the well on the trip tank. Initial losses 6BPH and increased to 15bbl/hr losses. Current static loss rate 12BPH.;At 7541' distance to plan 47.31' 44.74' high 15.38' right. 10/5/2022 Pumped LCM pill#4 40bbls(15ppb CaCo2, 10ppb Vangaurd, 10ppb readi seal, 5ppb Barofiber, 5ppb steel seal 100, 2.5ppb Nut plug, 2.5ppb Barocarb 150, total 50ppb) at 120GPM. Lost 79bbls mud while pumping the pill, 158BPH dynamic losses.;Build mud volume, Line up well on trip tank and monitor, 12 to 18 BPH static loss rate, Decreased to 7 BPH after 3 hours. Submit 24 hour notice to AOGCC of intent to test BOPE.;RIH on elevators F/ 5907' MD T/ 6290', P/U 134K, S/O 100K. Confirm no build-up of open hole ID through first observed loss zone. Nothing seen going down through loss zone.;POOH F/ 6290' T/ 6036', P/U 130K, S/O 97K. Nothing seen when pulling through the original loss zone.;Pumped LCM pill#5 60bbls(15ppb Barocarb, 2.5ppb Vangaurd, 10ppb steel seal 100, 10ppb steel seal 400, 5ppb Barofiber, 5ppb Soltex 100, 2.5ppb Barocarb 150, total +50ppb) at 120GPM. Lost 68bbls mud while pumping the pill, 164BPH dynamic losses.;RIH on elevators F/ 6036' MD T/ 7541' MD Wash last stand to bottom. P/U 160K, S/O 103K. Negative displacement of -28.5 BBLs with a calculated dispacement of 24.4 BBLs and observed IA standing full of 10.3ppg mud. Loss zone taking displacement from drill pipe going in hole. Total losses at 285 BBLs.;Circulate open hole volume with no returns. GPM 111, SPP 605psi.;POOH on elevators F/ 7541' T/186'. P/U 163K, S/O 101K.;Stand back flex collars. Remove the sources from the LWD tools. Plug in and download tool data. L/D Bit and BHA. Bit graded 1,1,CT,A,X,I,PN,HP.;Clean and clear the rig floor.;Service the rig, blocks, top drive, swivel packing(inspected the saver sub), iron roughneck, drawworks, gear box, drive line, brake linkage, brake bands and floor motor. Clean the rig floor. Monitor the trip tank(lost 7bbls).;M/U the mule shoe. RIH to 6150. M/U the pump in sub and FOSV.;R/U cementers. PJSM for cementing. Pump 5bbls water and PT cement lines to 3000psi OK.;Hauled: 7 bbl Solids to KGF G&I Cumulative: 216 bbl Hauled: 68 bbl Fluid to KGF G&I Cumulative: 1,474 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 10 bbl Lost: 468 bbl Fluid Down Hole Cumulative:1,827 bbl Daily Metal: 0 lbs Cumulative: 368 lbs 10/6/2022 Mix and pump 7 BBLs of 12.0ppg Spacer at 2 BPM/ 270psi. Pump 160 SKS of plug cement at 15.8ppg, 1.15ft/sk. 5gal/sk pumped for a total of 30 BBLs of 15.8 cement with bridgemaker added to final 10 BBLS at 4 BPM/ 320psi. Pump 84 BBLs of 10.3ppg mud at 4 BPM/ 61psi.;Pump 7 BBLs of 12.0ppg of Tuned Prime Spacer at 4 BPM/ 100 psi. 40 BBLs into displacement slow rate to 2BPM/ 28psi and close Annular Preventer. Pumped a total of 84 BBLs of 10.3ppg mud. Shut down pressure was 66psi. and bled off without anything open. drill pipe and annulus on vacuum when opened.;Open Annular Preventer. Had some returns throughout job and well lost 38 BBLs during job.;Rig down cement iron on floor, POOH and stand back 2 stands F/ 6150' T/ 6028', Fill annulus and holding at surface. Drop wiper ball and pump sweep with the intention of pumping it STS, after 106 BBLs pumped and losses at 32 BBLs shut down pump.;POOH on elevators F/ 6028' T/ surface and L/D E-Kelly joint and mule shoe. P/U 110K, S/O 80K. Calculated hole fill: 46 BBLs, Actual: 47.5 BBLs.;Pull Wear Ring and wash BOPE stack.;R/U equipment for testing and purge all flow paths.;Test Bi-Weekly BOPE 250/ 3500 psi with 4-1/2" test joint with AOGCC witness Kam St. John. Tested all Gas alarms and PVT system. All tested OK, no failures.;Rigged down test equipment. Blew down the lines. Pulled the test plug. Set the wear bushing. Broke down the test joint.;P/U the 4 1/2" mule shoe. RIH to 5871'.;Install TIW. PJSM for slip and cut drilling line. Slip and cut the drilling line. Cut 21 wraps(100') drill line, respool new drill line, Torque drill line anchor. Check weight indicator and COM. Monitor trip tank, static losses 1bbl/hr.;RIH 3 stands DP to 6052'. Circulate surface to surface 285GPM 515PSI with no losses.;Flow check, well static. POOH to 3000'.;Hauled: 13 bbl Solids to KGF G&I Cumulative: 229 bbl Hauled: 117 bbl Fluid to KGF G&I Cumulative: 1,591 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 10 bbl Lost: 234 bbl Fluid Down Hole Cumulative: 2,061 bbl Daily Metal: 0 lbs Cumulative: 368 lbs 10/7/2022 Continue POOH with mule shoe F/ 3000' T/ Surface and L/D mule shoe.;Service Blocks, Top Drive, Swivel Packing, Iron Roughneck, Draworks, Gear Box, Drive Line, Brake Linkage, Brake Bands and Floor Motor. Inspect Saver Sub. Well on trip tank with no gains or losses.;P/U and M/U 6-1/8" Triple Combo BHA #6, Plug in and Download MWD tools, Shallow Test Tools. PJSM and load sources.;Continue RIH with 6-1/8" triple combo BHA #6 from Derrick F/ 120' T/ 736' with flex collars and HWDP.;Cont. RIH with BHA #6 Running 4-1/2" drill pipe F/ 736' T/ 5675' P/U 116K, S/O 82K. Filling pipe every 2000'.;Continued to RIH F/5675' to 7460' . P/U 158K S/O 97K.;Sat down 15K at 7460'. Circulated B/U while washing the remainder of the stand down to 7470' and rotating and reciprocating 270GPM ,2075PSI, 40RPM, 9.5K TQ. Washed down 7470' to 7532' and Circulated B/U up while reciprocating and rotating the stand 260GPM, 1980PSI, 40RPM, 9.1K TQ.;Encountered cement stringers while washing and reaming down. Began to work on the mud properties and increasing MW to 10.3PPG. Observed cement across the shakers and cement contamination in the mud.;Drilled ahead 6 1/8" directional hole 7541' to 7543'. Flow dropped and pump pressure dropped, observed partial returns. Racked back 1 stand to 7500' and monitored the trip tank. Static loss rate 7BPH. Circulated at pump idle 111GPM 590PSI loss rate 80BPH.;Increased the flow rate to 230GPM(minimum flow rate for MWD/LWD) loss rate 230BPH. Spot a 16bbl 40ppb LCM pill (5ppb barocarb 150,7.5ppb Vanguard, 7.5ppb readi seal, 7.5ppb steel seal 400, 7.5ppb steel seal 100, 2.5ppb nutplug) at 111GPM 590psi.;loss rate 116BPH while spotting the pill.;POOH F/7500' to 5910'(no gain or loss). No overpulls. Began to build mud volume while POOH.;Monitor the well on the trip tank at 5909', no gain or loss. Building mud volume.;At 7543' 47.31' from the plan, 44.74' high and 15.38' right.;Hauled: 0 bbl Solids to KGF G&I Cumulative: 229 bbl Hauled: 0 bbl Fluid to KGF G&I Cumulative: 1,591 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 10 bbl Lost: 69 bbl Fluid Down Hole Cumulative: 2,130 bbl Daily Metal: 0 lbs Cumulative: 368 lbs ump 160 SKS of plug cement at 15.8ppg, 1.15ft/sk. 5gal/sk pumped for a total of 30 BBLs of 15.8p p ppg p p p cement with bridgemaker added to final 10 BBLS at 4 BPM/ 320psi. 10/8/2022 Complete building 130 BBLs of WBM for active system. Build 60 BBL 40PPB and place in pit 10 for contingency. Monitor well on trip tank with no gains or losses.;RIH with 6-1/8" Directional assembly F/ 5909' T/ 7543' with calculated displacement observed, fill pipe before making up last stand. P/U 165K, S/O 115K.;Drill Ahead F/ 7543' T/ 7725' GPM 240, SPP 2100psi, Diff 400psi, RPM 70, TQ 11.5K, WOB 7K, ECD 11.32ppg, Max Gas 98 units, P/U 170K, S/O 95K, ROT 125K. SPRs at 7650' MD, 6726' TVD, MP #1 46 SPM 680 psi, MP #2 47 SPM 676 psi. Attempted to slide and slid 3' in 30 minutes with several stalls.;Continue Drilling F/ 7725' T/ 8026' GPM 245, SPP 2225psi, Diff 400psi, RPM 70, TQ 11.4K, WOB 7K, ECD 11.5ppg, Max Gas 98 units, P/U 176K, S/O 101K, ROT 130K.;Drilled ahead 6 1/8" directional hole F/8037' to T/8400'GPM 245, SPP 2340psi, Diff 400psi, RPM 70, TQ 11.9K, WOB 6K, ECD 11.7ppg, Max Gas 112 units, P/U 180K, S/O 102K, ROT 134K.;Drilled ahead 6 1/8" directional hole F/8400' to 8587' GPM 240, SPP 2350psi, Diff 400psi, RPM 75, TQ 12.5K, WOB 5K, ECD 11.9ppg, Max Gas 71 units, P/U 190K, S/O 100K, ROT 135K.;Observed the top drive saver sub was in to poor of condition to continue running. Pulled 2 stands to 8461'. C/O the saver sub. RIH to 8587'.;Drill ahead 6 1/8" directional hole F/8587' to 8610'GPM 240, SPP 2350psi, Diff 400psi, RPM 75, TQ 12.5K, WOB 5K, ECD 11.9ppg, Max Gas 40 units, P/U 190K, S/O 100K, ROT 135K.;At 8521' Distance from well plan 169.25', 168.9' above the plan and 10.71' right of plan.;Hauled: 9 bbl Solids to KGF G&I Cumulative: 238 bbl Hauled: 171 bbl Fluid to KGF G&I Cumulative: 1,591 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 10 bbl Lost: 168 bbl Fluid Down Hole Cumulative: 2,298 bbl Daily Metal: 0 lbs Cumulative: 368 lbs 10/9/2022 Continue Drilling F/ 8610' T/ 8803' MD 7838' TVD GPM 240, SPP 2375psi, Diff 400psi, RPM 60, TQ 11.5K, WOB 7K, ECD 11.95ppg, Max Gas 45 units, P/U 205K, S/O 106K, ROT 138K. MW in 10.3ppg 52 Vis, MW out 10.3ppg 54 Vis, SPRs @ 8795' MD, 7830' TVD, MP #1 46 SPM 717psi, MP#2 47 SPM 715psi.;CBU GPM 235, 1935psi., Reciprocate and rotate during circulation.;Flow check well: Static, POOH F/ 8803' T/ 7526' P/U 225K, S/O 115K.;Service Blocks, Crown, Top Drive, Swivel Packing, Iron Roughneck, Draworks, Gear Box, Drive Line, Brake Linkage, Brake Bands and Floor Motor. Inspect Saver Sub. Monitor well on trip tank with no gains or losses.;RIH with 6-1/8" Triple Combo Directional Assembly F/ 7526' T/ 8803'. Wash and Ream last stand down. P/U 220K, S/O 105K.;Break circulation, Pump Hi-Vis sweep STS GPM 245, SPP 2100psi., RPM 65, TQ 12K. Sweep came back 14 BBLs early with 20% increase in cuttings;POOH on elevators F/ 8803' T/ 6109' P/U 210K, S/O 110K.;Pumped a 60bbls of 40ppb LCM pill and spotted outside the bit.;POO F/6109' to 737'.;POOH and L/D 17 joints of 4.5" HWDP and 1-4 3/4" jars.;POOH and L/D flex collars. remove radioactive sources, download LWD data. L/D LWD tools, motor and bit. Bit graded 1,1,WT,G,X,I,NO,TD. No gain loss on trip.;Serviced blocks, top drive, was pipe, iron roughneck, drawworks, gear box, drive line, brake linkage, floor motor. clean and clear the rig floor.;R/U casing equipment. M/U FOSV to casing X/O. PJSM for running casing.;Run 4 1/2" 12.6ppf L-80 DWC/C liner. Bakerloked the shoe track.;At 8803', 213' from the plan, 213' above the plan and 7.48' right of the plan.;Hauled: 22 bbl Solids to KGF G&I Cumulative: 260 bbl Hauled: 153 bbl Fluid to KGF G&I Cumulative: 1,744 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 10 bbl Lost: 2 bbl Fluid Down Hole Cumulative: 2,300 bbl Daily Metal: 0 lbs Cumulative: 368 lbs 10/10/2022 Fill Shoe jt. Baker-Lok Float Collar jt. and fill and confirm floats are working as designed. Good Check. Baker-Lok Landing collar jt. and RIH with 4-1/2" 12.6# L- 80 Range III DWC/ HT Liner as per approved tally F/ 126' T/ 3089' Connections torqued to 6150 ft/ lbs. optimum. for a total of 76 jts.;and two marker pup jts. ( Two joints have RA tags, One at +/-1000' and one at +/- 2000' from shoe of Liner).;P/U and M/U 5" x 7" ZXP Liner Top Packer Install wiper dart and 3' pup joint. M/U to Liner confirm correct shear pins and mix and install Pal Mix. R/D casing equipment and remove from floor. Run in hole one stand from derrick T/ 3172' and circulate liner volume @ 5BPM with 160 psi.;Continue RIH with 4-1/2" Liner with 4-1/2" drill pipe from derrick F/ 3172 T/ 5915'. P/U 85K, S/O 63K.;Circulate Bottoms Up working pumps up to 250 GPM with 420psi SPP.;RIH with 4-1/2" Liner on drill pipe F/ 5915' T/ 8803' P/U 155K, S/O 95K. and circulate at 120 GPM, 640 psi SPP.;L/D Top single on stand # 92 and P/U Baker Liner Cement head with 15' pup joint on bottom and M/U to string. Work pumps up to 214 GPM , 780 psi. SPP. Continue circulating and condition mud for cement job.;PJSM for cementing. Blow down the top drive. Pumped 5bbls water ahead. Pressure tested lines to 215/4300psi. Pumped 30bbls of 12ppg spacer at 4.5BPM 700psi. Pumped 70bbls of 15.3ppg cement at 4.5BPM 250psi.;Flushed the cement lines. Kicked out dart with 10bbls water followed by 113bbls 10.3ppg mud at 4.5BPM 90psi ICP. Slowed to 3BPM 1633 FCP. Bumped the plug and held 1985psi for 3 min. Bled off pressure and checked the floats, OK. Bled back .75bbls. CIP@20:43.;Pressured up to 2100psi and slacked off to 59K and set the hanger. Pressured up to 3300psi and set the packer and released the running tool. Applied 40K down and rotated on top of the packer to insure a good set.;Pressured up to 4000psi psi and neutralized the tool. P/U to confirm the tool released (was not released). Emergency released from the liner with 4 left hand turns. P/U and confirm released, OK. L/D the cement head and 1 DP single.;Screwed into the stump and applied 500psi. Picked up and circulated out and observed 30bbls spacer and 9bbls cement circulated to surface.;POOH with the liner hanger running tools. L/D the running tool.;Break down the cement head. Wash out the BOP stack with blackwater. Cleaned mud tank #1 , tank #2 and the trip tank.;Serviced the blocks, top drive, wash pipe, iron roughneck, drawworks, gear box, drive line, brake linkage, brake bands, and the floor motor. Cleaned the rig floor.;P/U the polish mill assy and RIH on 4 1/2" DP to 750'.;Hauled: 33 bbl Solids to KGF G&I Cumulative: 293 bbl Hauled: 528 bbl Fluid to KGF G&I Cumulative: 2,272 bbl Hauled: 9 bbl Cement to KGF G&I Cumulative: 19 bbl Lost: 2 bbl Fluid Down Hole Cumulative: 2,300 bbl Daily Metal: 0 lbs Cumulative: 368 lbs 10/11/2022 Continue RIH with 5.25" polish mill assembly with 5.75" TBR Top dress mill 9.69' back from bottom of polish mill and RIH on 4 1/2" DP F/ 750' T/ 5693' Dress PBR and Liner Top. P/U 120K, S/O 82K.;Displace 10.3ppg WBM with corrosion inhibited drill water 8.3ppg with a total displacement of 329 BBLs. Submit notification on AOGCC website for witness on MIT test tomorrow. Witness waived by Jim Regg.;Perform negative pressure test on Liner Top Packer. No gain or losses observed.;POOH F/ 5693' T/ Surface' with polish mill assembly laying down 4-1/2" 16.60# S-135 CDS40 Drill Pipe and pull wiper balls through tube, Clean Pin and Box ends, Dope and install thread protectors.;RIH F/ Surface T/ 2466' with remaining drill pipe in derrick.;POOH F/ 2466' t/ surface laying down DP and polish mill.;Pull wear bushing, M/U TIW to x/o, R/U casing equipment.;M/U seal assembly and RIH w 4 1/2" 12.6ppf IBT tubing from surface to 5215'. RIH with 4-1/2" 12.6# L-j 80 Range III DWC/ HT Liner gpp Pumped 70bbls of 15.3ppg cement at 4.5BPM 250psi. pp yg RIH w 4 1/2" 12.6ppf IBT tubing from surface to 5215' observed 30bbls spacer and 9bbls cement circulated to surface. Bumped the plug and held 1985psi for 3 p y min. Bled off pressure and checked the floats, OK. 10/12/2022 Continue RIH with 4-1/2" 12.6# L-80 IBT Tie-Back string F/5215' T/ 5309'. M/U connections T/ 4400ft/ lbs. P/U 75K, S/O 56K.;R/U Pollard for Baker S-5 SSSV (Open pressure 1600psi to 2000psi.) Bleed pressure off and RIH and observe SSSV open. Pressure up to 5000psi. while continuing in hole F/ 5309' and locate LTP PBR and set down 5K on No-Go. Mark pipe and POOH taking measurement back to coupling and configure string;2- pup, Hanger and Hanger pup and Land Tie-Back .87' off of no-go at 5678.43' MD. Total of 17 stainless steel bands used. Land Hanger P/U 85K, S/O 58K. RILDS.;PJSM, R/U and MIT 4-1/2" Tie- Back/ 4-1/2" Liner T/ 3500psi F/ 30 minutes. Starting pressures TBG: 0psi, IA: 0psi, OA: 75psi. 69 gallons to pressure up TBG to 3575 psi., IA: 50psi, OA: 75psi. After 15 minutes TBG: 3550psi, IA: 50psi, OA: 75psi., At 30 minutes TBG: 3540psi, IA: 50psi, OA: 75psi. Good;Test. Bleed back 68 gallons. R/U to pressure up on IA TBG: 0psi, IA: 0psi, OA: 75psi. Pressure up IA with 172.5 gallons T/ 3575psi, TBG: 450psi, OA: 75psi. 15 minutes IA: 3575psi, TBG: 450psi, OA: 75psi 30 minutes IA: 3575psi, TBG: 450psi, OA: 75psi. Good Test Bleed back 168 gallons. R/D test equip.;Pull and L/D landing joint and Install TWC as per wellhead tech.;Flush all surface lines with Baraclean and Blow down same.;Bleed down Accumulator, Open Ram Doors and clean with pressure washer, Inspect ram elements for next well and button up doors. Remove bleeder/ hole fill lines, Turnbuckles, Flow line, Mousehole, Koomey Hoses, N/D Picture nipple, N/D Bell nipple, Remove flow box, N/D BOPE stack and mud cross;components. Remove studs from BOPE stack, remove from well and set back leaving bridge cranes attached.;N/U dry hole tree, pressure test void to 5000 psi for 15 min, pressure test tree to 5000 psi.;Pressure wash derrick, top drive, blocks, iron roughneck, remove rotary table and clean/inspect same, R/D mud pumps and pits, pressure wash pits, clear subs from rig floor.;Pressure wash cellar and sub base, R.D tongs and TD bails, remove saver sub.;Cont to pressure wash rig equipment, Disconnect service loop, Rig down de-gasser, start R/D electrical lines Rig Released @ 06:00 p Good Test pp MIT 4-1/2" Tie-g Back/ 4-1/2" Liner T/ 3500psi F/ 30 minutes. Activity Date Ops Summary 10/15/2022 PJSM and PTW. Spot equipment and rig up on well.,BOP test 250 psi low / 4000 psi high. Good test. Witness waived by Jim Regg (10/14/22 @ 1015 AM).,Standby for tree valves to be greased.,MU Yellowjacket MHA - 2-7/8" x .9' slipstyle CTC, DFCV 2-7/8" x 1.25', Disco 2-7/8" x 2.15', 3.71" x 1.1' JSN, OAL - 5.84'. Pull test CTC to 10k, 20k, and 25k. PT MHA to 3900 psi. PT lubricator to 250 psi / 4000 psi.,Pump open SSSV, block in with 4200 psi. RIH taking displacement to OTT. Tagged up at 5730'. Bring pump online at 1.5 bpm, tagged up 3 times without making any progress. POOH. Laydown lubricator and stack injector head. Secure tree. SDFN. 10/16/2022 PTW and PJSM. Warm up equipment. PU injector head and lubricator. MU milling BHA - 2.88" x .9' CTC, 2.88'" x x1.25' DFCV, 2.88" x 5.62' jars, 2.88" x 2.15' disco, 2.88" x 1.42' circ, 2.88" x 14.42' motor, 3.62" x 1.2' junk mill, 26.96' OAL.,Stab on well. PT lubricator to 250 psi and 4000 psi. Open well and RIH. Dry tagged at 8690'. Come online with the pump at 1.25 bpm. RIH and got good tag at 8740' ctmd. Pump for 15 bbls on bottom and start POOH, taking returns to OTT. Make extra pass across LT to knock any cement stringers/debris off tubing/liner wall. Out of hole. Breakdown milling BHA. Some cement in the mill. 175 bbls in OTT.,MU Halliburton memory CBL, set 2 hour timer. Open well and RIH to 8700'. Wait for tool to turn on. Log while PUH to 5200'. POOH. Good data. Laydown tool string and lubricator. Rack injector head. Install night cap and SDFN. 10/17/2022 PTW and PJSM PU injector head and lubricator. MU roll-on CTC, DFCV, 6' stinger, 2-1/8" JSN - OAL - . PT to 250 psi/4000 psi. RIH.,Begin pumping nitrogen at 1000 scfm. Pump nitrogen at 8720'. Started getting N2 at the tanks. POOH. Recovered expected volume (152 bbls). Pinch in choke and begin building WHP. At surface, close in well. SITP is 1100 psi. Pumped total of 145,900 scf of N2. Lay down BHA, lubricator and injector head. Secure the tree. RDMO. Haul ott returns and unused produced water to G&I. Coil portion of the job complete. 10/24/2022 YJ Eline on location.. PJSM & open PTW. Spot in equipment & rig up. Pick up BHA #1 & stab on lubricator. PT lubricator to 250/4000 pass.,SITP = 980. RIH w/ 14' x 1.69" WB, 8' x 2.75" GPT w/ CCL (CCL to bottom of tool 6.5'). Tag TD @ 8642.5' (sticky bottom). Find FL @ 7497'.,SITP = 950. RIH w/ 7' x 1.69" WB, 5.8' x 2.75" GR/CCL, Shock Sub, 8' x 2 7/8" Geo Dynamics Razors (6 spf). CCL to top shot = 8.5'. CCL to bottom of tool is 19'. Pull correlation pass from TD (8674') up to 7600'. Send to Geo, Shift 1' down. Shoot LB 5 Lower, 8641' - 8649' (CCL stop depth = 8632.5'). SITP = 950, 5 min = 940, 10 min = 940, 15 min = 940. POOH and begin bleeding N2 to 200 psi. Guns came back wet.,SITP = 200 psi. RIH w/ 7' x 1.69" WB, 8' x 2.75" GPT w/CCL (CCL to bottom of tool 6.5'). FL RIH @ 7450'. Tag TD @ 8658'. FL POOH @ 7451'. POOH.,Rig down Eline and secure well for the night. 10/25/2022 Fox N2 on location. Open PTW & PJSM. Rig up to companion valve. PT lines to 250/4000 psi, pass. WHP @ 200 psi. Come online w/ N2 @ 1200 scf/min. YJ Eline on location. Open PTW & PJSM. Build WH pressure to 4000 psi w/ 177,031 scf of N2. Shut in on pump and close companion valve.,Stab on w/ Eline and open up to WH pressure @ 3975 psi. RIH w/ 7' x 1.69" WB, 7' x 2.75" WB, 8' x 2.75" GPT w/ CCL. FL RIH @ 7380'. POOH & bump up. WHP @ 3940.,PT N2 lines and Eline lubricator to 250/4500 psi. Pass.,WHP @ 3948. RIH w/ 7' x 1.69" WB, 7' x 2.75" WB, 8' x 2.75" GPT w/ CCL. RIH to 2000', come online w/ N2 @ 1200 scf/min. Pump 24,049 scf. SI @ 4448 WHP. Find FL @ 7390' 10 minute WHP = 4430 psi.,Rig down N2 pump. Sit in hole w/ Eline. Obtain FL every 30 minutes and monitor WHP. FL at 7390'. WHP = 4415 psi (15 psi drop) after 3.5 hours. POOH and bump up.,WHP = 4363 psi . Rig down Eline and secure well for night. 10/26/2022 Yellowjacket EL on location. Begin digging out and starting equipment (12" of fresh snow overnight). WHP at 4338 psi, very little drop from last night. Standby and wait on plan from office.,MU 5' and 8' 2-7/8" HSC guns on a switch. Arm and RIH. Pull correlation log, send to town, make 3' shift down (make 8546' equal to 8549' per Geo). Perforate the LB 5 Mid from 8631'-8636'. Initial 4296 psi. Perforate the LB 5 Upper from 8613'-8621'. POOH. Initial 4295 psi. 5 min - 4292 psi. 10 min - 4288 psi, 15 min - 4285 psi. Lay down guns - all shots fired. Gun had some gray mud in the bull plug.,Standby for YJ to bring additional guns to location.,MU 6' and 10' 2-7/8" HSC guns on a switch. WHP is 4237 psi. Arm and RIH. Pull correlation log, send to town, make 3' shift per Geo. Perforate the LB 4B from 8464'- 8474'. Perforate the LB 3C from 8301'-8311'. WHP is 4202 psi. POOH. All shots fired. Install night cap. Final WHP - 4140 psi. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: CLU 010RD Cannery Loop Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00102 CLU-10RD Completion Spud Date: 10/30/2022 Travel from YJ shop to KGF office. Stop on way by CLU to fie up and warm equipment.,Permits, PJSM and call in.,Fuel truck arrived. Service equipment. Rig up e- line and set up CIBP.,Pressure test surface equipment to 4000 PSI. Test good.,Run in hole w/ 4" (3.50" OD) Legacy Oil Tools CIBT.,Tie in for setting depth of 8290'. (CCL to CIBP mid element 13' - 8290' set depth for CCL at 8277'),Fire setting tool. Good weight loss indication. POOH.,OOH. Inspect tools. Good set.,Production lined up valves and bled tubing down from 3930 to 1100 PSI.,Mix cement and load bailer.,Run in hole w/ 3.50" OD x 35' bailer carrying 16 gallons of cement to equal 25' of cement depth on top of CIBP.,Lightly tag CIBP at 8290'. Pick up 20' and fire bailer. Good wait loss. Wait 10 minutes for bailer to drain. POOH.,OOH. Inspect tools. Good fire on bailer.,Lay down lubricator & secure well. Will return tomorrow morning to perforate.,Travel back to YJ shop. 10/31/2022 Travel from YJ shop to KGF office.,PJSM. Permit. Call in. Travel to CLU 10RD.,Rig up e-line,Pressure test surface equipment to 1500. Test good.,Run in hole w/ 2-7/8" OD x 11' carrier guns to shoot LB 2B Lower 7996' to 8007',Tie in.,Send correlation log to town for approval.,Was advised to make 1' correction. Correction made. Spot tools. Fire Gun 5 at 7996' to 8007' in LB 2B Lower sand w/ 2-7/8" x 11' gun. Good weight drop indication. Took 5 minute surface pressure readings. Start 1100 / Fire 1125 / 5 Min 1125 / 10 Min 1125 / 15 Min 1125 while POOH.,Pad Operator bleeding down well from 1125 to 200 PSI. Set up GPT tools.,Run in hole w/ GPT w/ well still flowing. Found fluid level at 7690' Complete survey. POOH.,Lay down GPT tools. Pick up 2-7/8" x 6' and 2-7/8" x 10' guns 6 & 7 w/ switch.,Run in hole w/ Gun 6 (2-7/8" x 6') for LB 2B Mid 7928' to 7934' - Switch - Gun 7 (2-7/8" x 10') for LB 2B Upper.,Tie in and send correlation logs to town for approval.,Advised to make 1' correction. Correction made. Fired Gun 6 (2-7/8" x 6') for LB 2B Mid sand at 7928' to 7934'. (CCL to top shot 21.5 putting CCL at 7906.5). Fired gun. Good weight drop indication. 30 minute interval before firing 2nd gun. 5 minute readings taken after shot. No change from 200 PSI. Pull up hole for 2nd shot.,Spot Gun 7 (2-7/8" x 10') for LB 2B Upper sand at 7911' to 7921'. (CCL to top shot 10' putting CCL at 7901'). Fired gun. Good weight drop indication. POOH. 5 minute readings taken after shot. No change from 200 PSI.,OOH. Gun 6 & 7 both fired. Lay down Guns 6 & 7 and pick up Gun 8 (2-7/8" x 8') for LB 1G at 7788' to 7796'.,Run in hole w/ Gun 8 (2-7/8" x 8') for LB 1G at 7788' to 7796'.,Tie in.,Correlation logs to town for approval.,Fire Gun 8 at 7788' to 7796' in LB 1G Lower sand w/ 2-7/8" x 8' gun. Good weight drop indication. Took 5 minute surface pressure readings for 15 minutes. Unchanged at 200 PSI. POOH.,OOH. Inspect Gun 8. All shots fired. Lay lubricator down and secure well for the night.,Travel back to YJ shop. 11/1/2022 Travel from YJ shop to KGF office.,PJSM. Permit. Call in.,Rig up e-line.,Pressure test surface equipment to 1500 PSI. Test good.,Run in hole w/ GPT. Surface pressure 760. Found fluid level at 7405'. Log across perfs. No noticeable change.,Hang tools off below perfs at 8100'. Pad Operator bled well down from 760 to system pressure at 73 PSI.,Pull up hole w/ GPT to 6800' at 73 PSI on well. Start logging down hole. Fluid level had moved up hole to 7080'. No change across perfs. Hung tools off below perfs at 8100'. Fox N2 on location.,Fox N2 PJSM and permit.,Fox N2 spot equipment. Weaver trucking delivered N2 tank. Rig up Fox N2 on well.,Fox N2 pressure test surface equipment to 4550. Test good.,Opened well. Fox N2 begin pumping in to well. Found after approximately 25 minutes that valves were not lined up properly allowing N2 down flow line. Valves corrected. Operator informed. Continue pumping. Well pressuring up at slow but steady rate.,N2 broke over from 4200 to 3900 PSI while injecting. Continued a few minutes to confirm. Shut down N2.,Well stabilized. YJ picked up GPT tools to 7000'. Began logging across perfs. Fluid level found at bottom perfs at 8005'. POOH. Release Fox N2.,OOH. Lay down lubricator & secure well for the night. Will run perforators to 2 sands tomorrow.,Travel back to YJ shop. 11/2/2022 Travel from YJ shop to KGF office.,PJSM and permit.,Travel to location.,Snow removal.,R/U E-line & Pressure test surface equipment to 2500 PSI. Surface PSI 2450.,Run in hole w/ Gun 9 for LB 1A Lower 8 7564-7572- Switch Gun 10 for LB 1A Upper 13 7544-7557. Sat down at 357 on closed SCSSV. POOH. Using SCSSV hand pump on tree, increased control line PSI from 2500 to 4500. SCSSV equalized and tubing pressure rose from 2050 to 2450.,Run in hole w/ Gun 9 for LB 1A Lower 8 7564-7572- Switch Gun 10 for LB 1A Upper 13 7544-7557.,Tie in.,Sent correlation log to town for approval. Made 2 correction.,Fired Gun 9 for LB 1A Lower 8 7564-7572 (CCL to top shot 25.5-CCL depth equals 7538.5) Switch Fired Gun 10 for LB 1A Upper 13 7544-7557 (CCL to top shot 10-CCL depth equals 7534) No pressure changes. POOH.,Lay down Guns 9 &10. Pick up GPT tools. Pad Operator lining up to flow well. I&E Tech called to make repairs to SCSSV pump. Stand by for repairs.,Repairs complete. Open well. Tubing pressure had dropped from 2450 to 1550 since last perf run. Run in hole with GPT. Pad operator is simultaneously bleeding N2 off the well.,Found fluid level at 7960. Continue logging down.,Shut in well at 148 PSI and re-log.,POOH.,OOH. Lay down lubricator & secure well. Production will try to flow well tonight.,Travel back to YJ shop. 11/17/2022 YJ Eline on location. Open PTW & PJSM. Rig up and pick up GPT tool. PT lubricator to 250/4000 psi, pass.,Well is flowing @ 65 psi, 70 mscfd. RIH w/ 8' x 2.75" GPT tool w/ 7'x 2.75" WB (14' CCL to bottom of tool). RIH and find FL @ 4740'. Tag TOC @ 8244'. Perform second down pass across open perfs for temperature response. POOH.,Grease return line is frozen, remove from the lubricator and thaw out.,RIH w/ 7' x 1.69" WB. 4' x 1.38" Temp/CCL tool. Log down from 6900' - 8244' (tag depth). Find cooling at perfs @ 7928' - 7934'. POOH.,Rig down Eline and secure well. 11/25/2022 Yellow Jacket E-line arrive on location. Hold TBT and approve PTW. Re-head and pick up lubricator with 4-1/2" CIBP. PT lubricator to 250/4000 psi.,RIH with 4-1/2" CIBP. GR/CCL to mid plug = 11.0'. Send correlation data to RE/GEO and confirm on depth. Set CIBP at 7985'. Set down weight to confirm plug is set. POOH.,Mix 6.4 gallons (10' in 4-1/2" tubing) of cement and load in 3-1/2" bailer. RIH and dump bail cement on top of plug. TOC = 7975'.,RDMO 11/26/2022 Fox coil arrive on location. Hold TBT and approve PTW. Spot in coil unit, return tank and crane. RU hardline to tank and NU BOPE to tree.,Jim Regg with AOGCC waived witness on 11/25/22 at 09:21 via email. Function test BOP rams. Test BOPE to 250 psi low / 4000 psi high.,Secure well and SDFN. 11/27/2022 Warm up equipment. PTW and PJSM. MU BHA - 2.25" CTC, 2" DFCV, 2.25" stem, 2.25" JSN - OAL - 6.5'. Move to the well. Pressure test lubricator and stripper to 250 psi / 4000 psi. Good test.,RIH. Begin pumping nitrogen at 5000'. Tag bottom at 7962' CTMD. Pump on bottom and reciprocate across open perfs. POOH pumping at 1200 scfm. Recover 51 bbls of produced water. Close choke and begin building WHP. Pump a total of 403,511 scf of N2. Final WHP at 2250 psi after pumping all N2 on location. RDMO CT unit. Secure tree. 11/28/2022 Yellowjacket EL on location. PTW and PJSM. Rig up. MU GPT logging tools. PT to 250 psi / 4000 psi. RIH and find fluid level at 7760'. Pull up pass from 7970' to 6800'. Send to town. POOH.,MU 5' 2-7/8" HSC gun. RIH and pull correlation log. Send to town, on depth. Perforate the LB 2B Lower from 7946'-7951'. POOH. Lay down gun, all shots fired, gun was wet. Pressure data: 699 psi with no change in 15 min.,MU 9' 2-7/8" HSC gun. RIH and pull correlation log. Send to town, on depth. Perforate the LB 2A from 7889'-7898'. POOH. Lay down gun, all shots fired, gun was wet. Pressure data: 696 psi with no change in 15 min.,MU 10' 2-7/8" HSC gun. RIH and pull correlation log. Send to town, on depth. Perforate the LB 2 from 7821'-7831'. POOH. Lay down gun, all shots fired, gun was wet. Pressure data: 698 psi with no change in 15 min.,MU 8' 2-7/8" HSC gun. RIH and pull correlation log. Send to town, on depth. Perforate the LB 1G Upper from 7764'-7772'. POOH. Lay down gun, all shots fired, gun was wet. Pressure data: 696 psi with no change in 15 min. Lay down lubricator. Secure tree and SDFN. 11/29/2022 Yellowjacket EL arrive on location. PTW and PJSM. Warmup equipment. Pick up lubricator. MU 8' 2-7/8" HSC gun. While getting ready to stab on the well the YJ crane broke down. Mechanic came to location and worked on it. ECM is non-functional. Breakdown toolstring. Another Crane was brought in, completed a new PTW for laying down lubricator and laid down lubricator.,Crane is stuck in the air on location for now. SDFN. Master valve closed on well until crane is repaired. 12/2/2022 Yellowjacket EL arrive on location. PTW and PJSM. MIRU. MU 2-7/8" 8' HSC gun. Pressure test to 250 psi / 4000 psi, good test. Open up well and RIH. SITP 1632 psi. Pull correlation log, send to town, on depth. Perforate the LB 1F Lower from 7732'-7740'. POOH. Lay down gun, all shots fired. Gun was wet. Pressure data - initial - 1644 psi, 5 min - 1647 psi, 10 min - 1648 psi, 15 min - 1648 psi.,MU 2-3/4" 5' HSC gun. RIH. Pull correlation log, send to town, on depth. Perforate the LB 1F Mid from 7703'-7708'. POOH. Lay down gun, all shots fired. Gun was damp. Pressure data - initial - 1659 psi, 5 min - 1662 psi, 10 min - 1663 psi, 15 min - 1665 psi.,MU 2-3/4" 8' HSC gun. RIH. Pull correlation log, send to town, on depth. Perforate the LB 1F Upper from 7683'-7691'. POOH. Lay down gun, all shots fired. Gun was damp. Pressure data - initial - 1668 psi, 5 min - 1669 psi, 10 min - 1670 psi, 15 min - 1672 psi.,MU 2-3/4" 5' HSC gun. RIH. Pull correlation log, send to town, on depth. Perforate the LB 1D from 7640'-7645'. POOH. Lay down gun, all shots fired. Gun was damp. Pressure data - initial - 1676 psi, 5 min - 1678 psi, 10 min - 1679 psi, 15 min - 1679 psi.,MU 2-3/4" 7' HSC gun. RIH. Pull correlation log, send to town, on depth. Perforate the LB 1C Lower from 7601'- 7608'. POOH. Lay down gun, all shots fired. Gun was damp. Pressure data - initial - 1688 psi, 5 min - 1689 psi, 10 min - 1690 psi, 15 min - 1691 psi. Lay down lubricator. Install night cap. SDFN. 12/3/2022 Yellowjacket EL arrive on location. PTW and PJSM. Pickup lubricator and MU 7' 2-3/4" HSC gun. SITP 1795 psi. RIH and pull correlation log, send to town, on depth. Perforate the LB 1C Upper from 7588'-7595'. POOH. Pressure data: initial - 1790 psi - no change after 15 min. Lay down gun, all shots fired. Gun was dry.,MU 15' 2-7/8" HSC gun. SITP 1795 psi. RIH and pull correlation log, send to town, on depth. Perforate the LB 1C Upper from 7588'-7595'. POOH. Pressure data: initial - 1783 psi - no change after 15 min. Lay down gun, all shots fired. Gun was dry. Install tree cap. RDMO. Install wellhouse. 12/19/2022 -15 degrees out. Fox energy working on getting equipment fired up and to location.,PTW, JSA with Fox Energy CTU crew, Cruz crane operator, and Hilcorp Rep. MIRU CTU with 1.75" pipe. Spot in return tank, man lift, heater, field triplex pump.,24 hr. BOPE test witness notification sent to state. Witness waived via phone call from Jim Regg. Start BOPE test 250 low, 4000 psi high. Good BOPE test.,Shut down CTU equipment. Place heater on coiled tubing tractor. Location walk around complete. SDFN. 12/20/2022 PTW, JSA with coil crew , Cruz crane op, and Hilcorp Rep. -20 outside. Work on firing up equipment.,Pick injector head and lubricator. 2.125" Down jet coil connector made up for BHA. Stab on well. Grab extra field triplex pump for KGF. PT stack 250/4000 psi.,Well was flowing 150 mcfd at 68 psi. Closed for 30 minutes while stabbing on to PT. Open well and RIH with coil 252 psi WHP.. CT @ 3000' online with N2 down CT at 1000 scf/min.,Continue in hole at 40 ft/min and 1000 scf/min. Tag CIBP at 7980 (both coil counters were slipping due to ice) corrected depth at CIBP.,Pick up off bottom 2' and blow bottoms up with N2. Snow and ice in tank and returns freezing before they can find a liquid level. Estmated 65-70 bbls returned to surface. Pick up above perfs.,Shut down N2 and monitor well. WHP 250 psi with GOOD LEL at return tank after 30 minute shut down. RIH to 7980' . Back online with n2 1200 scf/min. WHP and circ pressure show good indication of slug coming to surface. Estimated 3 bbls unloaded. Total 68-73 bbls recovered from well. POOH to surface. @ 5250' Shut down N2.,Discuss swapping to test separator with night operator. Swap on the fly. All N2 and gas returns going to test. Tagged up at surface. Close swab valve. Pop off well. set down Injector head. Drop 4 soap sticks. Install night cap. Continue to flow well overnight. RIg back CTU equipment. WHP upon coil closing in swab 264 psi. Total N2 pumped 396,357 scf. 12/28/2022 Fox N2 on location. Open PTW @ PJSM. Begin rig up. Mechanical issue w/ unit, call out mechanic, fix issue. PT 250/4000 psi, pass.,Begin pumping N2 @ 1000 scf/min. WHP @ 800 psi. AK Eline on location begin rig up. See breakover @ 2800 psi, 112,000 scfs. 2650 psi @ 135,000 scfs. Pressure begins to come up. 3000 psi @ 175,000 scfs. Shut down N2 and shut in well. Eline finds bad spot on wire. Cuts 200' and re-head.,Pick up lubricator and GPT toolstring. Stab on and PT to 250/4000 psi, pass.,WHP @ 2100 psi. RIH w/ GPT toolstring. 7' x 3.125" WB, 5' x 1.69" WB, 8' x 1.69" GPT w/ CCL. Find FL @ 7610'. POOH.,Make up WRP BHA. WHP @ 1400 psi. RIH w/ 6' x 3.125" GR/CCL, 2.75" Shock sub, 3.5" Baker 10 setting tool, 2.5' x 3.76" WRP (OAL 21'). 15.5' CCL to top of plug. SL on location. Spot in and prep tools and lubricator. Set WRP @ 7450' top of plug (1.84" OD external FN) (7434.5' CCL stop depth). Pick up and RIH, tag plug. POOH.,Lay down toolstring and lubricator. SL rig up with catcher sub assembly and stab lubricator onto well. PT to 250/2500, pass.,RIH w/ 5.5' x 3.80" catcher sub. Set down @ 7452' SLM, unable to shear off catcher sub. POOH. Find pins sheared but GS dogs did not release.,RIH w/ 5.5' x 3.80" catcher sub. Set down @ 7452' SLM, Shear off. POOH. Catcher sub left in hole.,Rig down SL and secure well for the night. 12/29/2022 AK Eline on location. Open PTW & PJSM. Begin rig up. Ops bleeding down WHP from ~1200 psi to ~200 psi. Make up perf guns and stab on lubricator. Ops bled WHP to 212 psi.,RIH w/ 6.5' x 3.125" GR/CCL, 3' x 2.75" Shock Sub, 18' x 2 3/4" Geo Razor guns (6 spf). CCL to top shot = 10.2'. Pull correlation log, on depth. Shoot the MB 7A Lower from 7360' - 7378'. CCL stop depth = 7349.8'. WHP = 206 psi, 5 min = 208 psi, 10 min = 209 psi, 15 min = 211 psi. POOH. Bull plug is dry.,Bump up and stab off, stand by for ops to pop the well. Ops popped well, making ~100k gas. Will run GPT, pick up GPT toolstring.,RIH w/ 7' x 1.69" WB, 8' x 1.69" GPT w/ CCL. Found FL @ 7418', 40' below open perfs. POOH.,OOH. Lay down toolstring and lubricator. Secure well and RDMO. 2/3/2023 Yellowjacket EL arrive on location. PJSM and PTW. MIRU on well. PU lubricator and wireline valves. MU GPT tools, 5' 2-3/4" 6 spf HSC gun. Pressure test to 4000 psi.,RIH and see no definitive fluid level. Tagged plug at 7442'. Pull correlation log, send to town, add 5' per Geo. Perforate the MB7A Mid from 7342'-7347'. POOH. Lay down guns, all shots fired. Gun was wet. Pressure/flow data: (psi/mcf) initial - 66/109 5 min - 66/131 10 min - 66/109 15 min - 66/111,MU 8' 2-3/4" gun with gun/gamma. RIH, correlate, send to town, on depth. Perforate the MB 7A Upper from 7330'-7338'. POOH. Lay down gun. All shots fired. Gun was wet. Secure tree. RDMO. Pressure/flow data: (psi/mcf) initial - 66/113 5 min - 66/133 10 min - 66/112 15 min - 66/111 ! " "#$% "& '((''( $)* +* &% * ,- * * ! .* .* " #"! /0%*$% % #"! #& '()*" 1*#"!*+,!-. + / *#"! #& '()*" 20 * / " - / +* 3 +* $) /4* + +* 01)234 5 + 01)2+ ,+,+5 6"7 $ 8/! 88 . .$ 1 %* %* 51* 201* 657&. 627& $" 3 %* " """ """ 1 (** )1)(" 1)1 791"0 0*".0%5* "9" :";(<9:*7(+ 9;9<7*()7/ . 89: ;% 10 8,: + 1 89: #"! /%2+/1 &==$1"11 0>*>1"11 797 )(79 99 :7()0)*: $0*-* %2* 1#"! 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.* .* " #"! /0%*$% % #"! #& '()*" 1*#"!*+,!-. + / *#"! #& '()*" 20 * / " - &AE&A A Benjamin Hand Digitally signed by Benjamin Hand Date: 2022.10.11 11:34:18 -08'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2022.10.12 08:34:06 -08'00' TD Shoe Depth: PBTD: Jts. 1 2 1 45 Yes X No X Yes No 60 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: Primary 305 1.23 3,906.18 3,877.73 1,852.19 5,759.38 3,906.18 Liner Hanger/Packer 8 5/8 L-80 VamTop Baker 28.45 Liner Joints 7 26.0 L-80 VamTop 5,759.38 Landing Collar 7 26.0 L-80 VamTop Baker 1.01 5,759.38 5,758.37 5,879.26 5,799.20 Liner X/O Joint 7 26.0 L-80 BTC X Vam 39.82 5,799.20 1.32 5,879.26 5,877.94 Liner Joints 7 26.0 L-80 BTC 78.74 Float Collar 7 26.0 L-80 BTC 1 each joint for the shoe track. One every other joint above the shoe track. Liner Joint 7 26.0 L-80 BTC 41.74 5,919.38 5,879.26 Baker Flexlock www.wellez.net WellEz Information Management LLC ver_04818br 4 Type of Shoe:Frontier Casing Crew:Parker 5,921.005,923.00 CEMENTING REPORT Csg Wt. On Slips: 6% KCL PHPA 18:30 9/28/2022 4163' 15.3 67 Bump press CBL Bump Plug? 120/120 1700 10 Cement unit FI R S T S T A G E 10.5 30 9.3 5 95 1050 Csg Wt. On Hook:130,000 Type Float Collar:Frontier No. Hrs to Run:9.5 BTC Frontier 1.62 5,921.00 5,919.38 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.CLU 010RD Date Run 28-Sep-22 CASING RECORD County State Alaska Supv.Josh Riley 5,878.00 Floats Held3500 Mud Rotate Csg Recip Csg Ft. Min. PPG9.3 Shoe @ 5921 FC @ Top of Liner 3878 Casing (Or Liner) Detail Float shoe 7 26.0 L-80 TD Shoe Depth: PBTD: Jts. 1 1 9 12 1 12 11 1 27 Yes X No Yes X No Fluid Description: Liner hanger Info (Make/Model):Liner top Packer?:X Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? 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: RA Marker Jnt Pup Jnt Casing (Or Liner) Detail Float shoe Marker Pup Liner Joints 5 12.6 L-80 Rotate Csg Recip Csg Ft. Min. PPG10.3 Shoe @ 8801.54 FC @ Top of Liner 56828,758.80 Floats Held 10 bbls water 112bbls Mud CASING RECORD County State Alaska Supv.Jay Murphy Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.CLU 010RD Date Run 10-Oct-22 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top DWC/C Baker 1.41 8,801.54 8,800.13 6,848.43 6,807.72 3.24 7,295.38 7,292.14 7,292.144 1/2 12.6 L-80 DWC/C 443.71 DWC/C 4 1/2 12.6 L-80 DWC/C 6,848.43 DWC/C Baker 27.05 4 1/2 12.6 4 1/2 12.6 L-80 Liner Hanger/Packer 6 12.6 L-80 5,709.06 40.71 L-80 DWC/C Liner Joints 4 1/2 12.6 L-80 DWC/C 6,807.72 5,712.31 3.25 5,712.31 5,709.06 1,095.41 Csg Wt. On Hook:38,000 Type Float Collar:Baker No. Hrs to Run:11.5 10.3 4 100 1633 FI R S T S T A G E 12Tuned prime 30 122/124 1985 9 Cement 15.3 70 Bump press Returns Bump Plug? 21:43 10/10/2022 5,682 8,801.548,805.00 CEMENTING REPORT Csg Wt. On Slips: 6% KCL Polymer 5,682.01 Type of Shoe:Baker Casing Crew:Parker Baker/5"X7"ZXP HRDE Liner top packer/Hanger www.wellez.net WellEz Information Management LLC ver_04818br 4.5 1 Each on the float equipment jnts, 1 every other jnt. Total 36 total centralizers. Liner joint 4 1/2 12.6 L-80 DWC/C 41.33 8,800.13 8,758.80 Float Collar 5 12.6 L-80 DWC/C Baker 1.41 8,758.80 8,757.39 Liner joint 4 1/2 12.6 L-80 DWC/C 41.59 8,757.39 8,715.80 Landing Collar 5 12.6 L-80 DWC/C Baker 1.02 8,715.80 8,714.78 Liner joints 4 1/2 12.6 L-80 DWC/C 362.78 8,714.78 8,312.06 Pup Joint 4 1/2 12.6 L-80 DWC/C 3.21 8,312.06 8,308.85 Liner joints 4 1/2 12.6 L-80 DWC/C 486.08 8,308.85 7,822.77 RA Marker Jnt 4 1/2 12.6 L-80 DWC/C 40.77 7,822.77 7,782.00 Liner Joints 4 1/2 12.6 L-80 DWC/C 486.62 7,782.00 7,295.38 Primary 330 1.24 Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 01/26/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230126 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# TBU M-10 50733205880000 209154 12/30/2022 AK E-LINE Perf CLU 10RD 50133205530100 222113 12/29/2022 AK E-LINE GPT_Plug_Perf NCI A-14 50883201250000 208096 11/6/2022 AK E-LINE Perf BRU 214-13 50283201870000 222117 12/19/2022 AK E-LINE PPROF BRU 233-23 50283201360100 222050 12/21/2022 AK E-LINE PPROF SRU 224-10 50133101380100 222124 12/14/2022 AK E-LINE CBL Please include current contact information if different from above. By Meredith Guhl at 2:54 pm, Jan 26, 2023 T37473 T37474 T37475 T37476 T37477 T37478 CLU 10RD 50133205530100 222113 12/29/2022 AK E-LINE GPT_Plug_Perf Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.26 15:02:03 -09'00' Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 01/24/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230124 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14B 50133205390200 222057 11/21/2022 YELLOW JACKET GPT-PERF CLU 10RD 50133205530100 222113 11/17/2022 YELLOW JACKET GPT CLU 10RD 50133205530100 222113 10/26/2022 YELLOW JACKET GPT-PERF CLU 10RD 50133205530100 222113 11/28/2022 YELLOW JACKET GPT-PERF CLU 10RD 50133205530100 222113 12/2/2022 YELLOW JACKET PERF CLU 10RD 50133205530100 222113 11/25/2022 YELLOW JACKET PLUG CLU 13 50133206460000 214171 11/29/2023 YELLOW JACKET PERF PBU W-26B 50029219640200 222151 12/30/2022 YELLOW JACKET SCBL SRU 224-10 50133101380100 222124 12/19/2022 YELLOW JACKET GPT SRU 224-10 50133101380100 222124 12/16/2022 YELLOW JACKET GPT-PERF SRU 224-10 50133101380100 222124 12/21/2022 YELLOW JACKET GPT-PERF SRU 224-10 50133101380100 222124 12/29/2022 YELLOW JACKET GPT-PERF Please include current contact information if different from above. By Meredith Guhl at 9:59 am, Jan 24, 2023 T37463 T37464 T37464 T37464 T37464 T37464 T37465 T37466 T37467 T37467 T37467 T37467 CLU 10RD 50133205530100 222113 11/17/2022 YELLOW JACKET GPT CLU 10RD 50133205530100 222113 10/26/2022 YELLOW JACKET GPT-PERF CLU 10RD 50133205530100 222113 11/28/2022 YELLOW JACKET GPT-PERF CLU 10RD 50133205530100 222113 12/2/2022 YELLOW JACKET PERF CLU 10RD 50133205530100 222113 11/25/2022 YELLOW JACKET PLUG Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.24 10:05:13 -09'00' From:McLellan, Bryan J (OGC) To:Chad Helgeson Cc:Donna Ambruz; Roby, David S (OGC); Davies, Stephen F (OGC) Subject:RE: [EXTERNAL] RE: CLU-10RD PTD#222-113 (Sundry # 322-589) Additional perfs Date:Monday, January 23, 2023 3:00:00 PM Chad, Hilcorp has verbal approval to add the perforations listed below as part of sundry 322-589. 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: Monday, January 23, 2023 2:22 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: RE: [EXTERNAL] RE: CLU-10RD PTD#222-113 (Sundry # 322-589) Additional perfs Bryan, We added these perfs that you approved below with a retrievable plug below then and have been flowing them for several weeks at about 140 mcfd without any water. We feel these new perfs might add some additional rate. Our Geo team has requested to perforate a couple more sands in near the same zone. Can we get verbal approval to add the following sands all in the same pool per CO 231A and within 30ft of existing perfs? Sand Top (MD)Bottom (MD)Feet MB7A Upper 7,330’7,338’8 MB7A Mid 7,342’7,347’5 Attached is an updated schematic with these zones. Regards, Chad Helgeson From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, December 15, 2022 4:19 PM To: Chad Helgeson <chelgeson@hilcorp.com> 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: [EXTERNAL] RE: CLU-10RD PTD#222-113 (Sundry # 322-589) Additional perfs Chad, Hilcorp has approval to add the additional perf interval requested in your email below. Please submit the report of this activity on the 10-407 for sundry 322-589. 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: Thursday, December 15, 2022 12:27 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: CLU-10RD PTD#222-113 (Sundry # 322-589) Additional perfs Bryan, Attached is a current wellbore schematic for CLU-10RD. We have completed adding the perfs in the well that were part of the original sundry, with limited success. Well is currently making ~150mcfd of gas. We are blowing the well dry with N2 (per Sundry # 322-589) and would like to add some perfs above the interval approved in this sundry. We would like to add some perfs in the middle Beluga sand – MB 7A Lower from 7,360-7,378’ (18’). This zone is within the Beluga Pool per CO 231A. Let me know if you want us to submit a change of program for this one sand perf add. 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. 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. _____________________________________________________________________________________ Revised By CAH 1-23-23 PROPOSED SCHEMATIC Cannery Loop Unit – Pad # 1 Well: CLU-10RD Last Completed: 10/12/22 PTD: 222-113 TD = 8,805’ MD / 7,840’ TVD PBTD =7,975’MD / 7,038’TVD 20” RKB: MSL = 16.60’ 4-1/2” 4 3 TOW 4,120’ 13-3/8” 9-5/8” 7” 2 CLU-10 TOC @ 3,260’ 1 3A 5 4 RA @ 6,807’ RA @ 7,782’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 133 / K-55 / N/A 18.73 Surf 123' 13-3/8' Surface 68 /L-80/ BTC 12.415 Surf 1,953’ 9-5/8" Intermediate 40 / L-80 / BTC 8.835 Surf 4,120’ (TOW) 7” Liner 26 / L-80 / Vamtop 6.276” 3,877’ 5,921’ 4-1/2” Prod liner 12.6 / L-80 / DWC/C 3.958” 5,682’ 8,801’ TUBING DETAIL 4-1/2" Tieback 12.6 / L-80 / IBT 3.958” Surf 5,678’ JEWELRY DETAIL No Depth Item 1 357’ Baker S-05 TRSSSV w/ 3.813” BX Profile, full open 1,900 psi 2 3,920’ Flex-lock liner hanger, HRDE ZXPN Liner Top Packer w/ 5.5” PBR 3 5,682’ 5” x 7” ZXP, HRDE Liner Top Packer, w. 5.25” PBR 3A 7450’ 4-1/2” WRP (1.84” OD External Fish neck) 4 7,985’ CIBP w/ 10ft of cmt (6.4 gal) set 11/25/22 ToC 7,975’ 5 8,290’ CIBP w/ 25ft of cmt (16 gal) Set 10/30/22 Toc 8,265’ OPEN HOLE / CEMENT DETAIL 8-1/2” 30 bbls spacer followed by 67 bbls of 15.3 ppg, bumped plug. Recovered 30 bbls spacer and 10 bbls of cement. CBL run 9/30/22, shows TOC @ 4,163’ MD 6-1/8” CBL run 10/16/22, shows TOC @ 4,163’ MD RA Tags @ 7,782 & 6,807’ short joints @ 7,292’ & 8,309’ Top CINGSA: 5522’ MD; 4917’ TVD Base CINGSA: 5808’ MD; 5144’ TVD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status MB 7A Upper ±7,330’ ±7,338’8 Proposed MB 7A Mid ±7,342’ ±7,347’5 Proposed MB 7A Lower 7,360’ 7,378’18 12/29/22 Open LB 7,501' 7,516’6,589' 6,603'15’ 12/3/2022 Temp plug LB 1A Upper 7,544’ 7,557’6,629' 6,642'10’ 11/2/2022 Temp plug LB 1A Lower 7,564’ 7,572’6,648' 6,656'8’ 11/2/2022 Temp plug LB 1C Upper 7,588' 7,595'6,671' 6,677'7'12/3/2022 Temp plug LB 1C Lower 7,601' 7,608'6,683' 6,690'7'12/2/2022 Temp plug LB 1D 7,640' 7,645'6,720' 6,725'5'12/2/2022 Temp plug LB 1F Upper 7,683' 7,691'6,761' 6,768'8'12/2/2022 Temp plug LB 1F Mid 7,703' 7,708'6,779' 6,784'5'12/2/2022 Temp plug LB 1F Lower 7,732' 7,740'6,807' 6,815'8'12/2/2022 Temp plug LB 1G Upper 7,764' 7,772'6,837' 6,845'8'11/28/2022 Temp plug LB 1G Lower 7,788’ 7,796’6,860' 6,868'8’ 10/31/2022 Temp plug LB 2 7,821' 7,831'6,892' 6,901'10' 11/28/2022 Temp plug LB 2A 7,889' 7,898'6,956' 6,965'9' 11/28/2022 Temp plug LB 2B upper 7,911’ 7,921’6,977' 6,987'10’ 10/31/2022 Temp plug LB 2B Mid 7,928’ 7,934’6,994' 6,999'6’ 10/31/2022 Temp plug LB 2B Lower 7,946' 7,951'7,011' 7,016'5' 11/28/2022 Temp plug LB 2B 7,996’ 8,007’7,059' 7,069'11’ 10/31/2022 Isolated LB 3C 8,301’ 8,311’7,351' 7,361'10’ 10/26/2022 Isolated LB 4B 8,468’ 8,474’7,513' 7,519'10’ 10/26/2022 Isolated LB 5 Upper 8,613’ 8,621’7,653' 7,661'8’ 10/26/2022 Isolated LB 5 Mid 8,631’ 8,636’7,671' 7,676'5’ 10/26/2022 Isolated LB 5 Lower 8,641’ 8,649’7,681' 7,688'8’ 10/24/2022 Isolated _____________________________________________________________________________________ Revised By DMA 12-15-22 SCHEMATIC Cannery Loop Unit – Pad # 1 Well: CLU-10RD Last Completed: 10/12/22 PTD: 222-113 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 133 / K-55 / N/A 18.73 Surf 123' 13-3/8' Surface 68 /L-80/ BTC 12.415 Surf 1,953’ 9-5/8" Intermediate 40 / L-80 / BTC 8.835 Surf 4,120’ (TOW) 7” Liner 26 / L-80 / Vamtop 6.276” 3,877’ 5,921’ 4-1/2” Prod liner 12.6 / L-80 / DWC/C 3.958” 5,682’ 8,801’ TUBING DETAIL 4-1/2" Tieback 12.6 / L-80 / IBT 3.958” Surf 5,678’ JEWELRY DETAIL No Depth Item 1 357’ Baker S-05 TRSSSV w/ 3.813” BX Profile, full open 1,900 psi 2 3,920’ Flex-lock liner hanger, HRDE ZXPN Liner Top Packer w/ 5.5” PBR 3 5,682’ 5” x 7” ZXP, HRDE Liner Top Packer, w. 5.25” PBR 4 7,985’ CIBP w/ 10ft of cmt (6.4 gal) set 11/25/22 ToC 7,975’ 5 8,290’ CIBP w/ 25ft of cmt (16 gal) Set 10/30/22 Toc 8,265’ OPEN HOLE / CEMENT DETAIL 8-1/2” 30 bbls spacer followed by 67 bbls of 15.3 ppg, bumped plug. Recovered 30 bbls spacer and 10 bbls of cement. CBL run 9/30/22, shows TOC @ 4,163’ MD 6-1/8” CBL run 10/16/22, shows TOC @ 4,163’ MD RA Tags @ 7,782 & 6,807’ short joints @ 7,292’ & 8,309’ Top CINGSA: 5522’ MD; 4917’ TVD Base CINGSA: 5808’ MD; 5144’ TVD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status LB 7,501' 7,516’ 6,589' 6,603' 15’ 12/3/2022 Open LB 1A Upper 7,544’ 7,557’ 6,629' 6,642' 10’ 11/2/2022 Open LB 1A Lower 7,564’ 7,572’ 6,648' 6,656' 8’ 11/2/2022 Open LB 1C Upper 7,588' 7,595' 6,671' 6,677' 7' 12/3/2022 Open LB 1C Lower 7,601' 7,608' 6,683' 6,690' 7' 12/2/2022 Open LB 1D 7,640' 7,645' 6,720' 6,725' 5' 12/2/2022 Open LB 1F Upper 7,683' 7,691' 6,761' 6,768' 8' 12/2/2022 Open LB 1F Mid 7,703' 7,708' 6,779' 6,784' 5' 12/2/2022 Open LB 1F Lower 7,732' 7,740' 6,807' 6,815' 8' 12/2/2022 Open LB 1G Upper 7,764' 7,772' 6,837' 6,845' 8' 11/28/2022 Open LB 1G Lower 7,788’ 7,796’ 6,860' 6,868' 8’ 10/31/2022 Open LB 2 7,821' 7,831' 6,892' 6,901' 10' 11/28/2022 Open LB 2A 7,889' 7,898' 6,956' 6,965' 9' 11/28/2022 Open LB 2B upper 7,911’ 7,921’ 6,977' 6,987' 10’ 10/31/2022 Open LB 2B Mid 7,928’ 7,934’ 6,994' 6,999' 6’ 10/31/2022 Open LB 2B Lower 7,946' 7,951' 7,011' 7,016' 5' 11/28/2022 Open LB 2B 7,996’ 8,007’ 7,059' 7,069' 11’ 10/31/2022 Isolated LB 3C 8,301’ 8,311’ 7,351' 7,361' 10’ 10/26/2022 Isolated LB 4B 8,468’ 8,474’ 7,513' 7,519' 10’ 10/26/2022 Isolated LB 5 Upper 8,613’ 8,621’ 7,653' 7,661' 8’ 10/26/2022 Isolated LB 5 Mid 8,631’ 8,636’ 7,671' 7,676' 5’ 10/26/2022 Isolated LB 5 Lower 8,641’ 8,649’ 7,681' 7,688' 8’ 10/24/2022 Isolated _____________________________________________________________________________________ Revised By DMA 12-15-22 PROPOSED SCHEMATIC Cannery Loop Unit – Pad # 1 Well: CLU-10RD Last Completed: 10/12/22 PTD: 222-113 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 133 / K-55 / N/A 18.73 Surf 123' 13-3/8' Surface 68 /L-80/ BTC 12.415 Surf 1,953’ 9-5/8" Intermediate 40 / L-80 / BTC 8.835 Surf 4,120’ (TOW) 7” Liner 26 / L-80 / Vamtop 6.276” 3,877’ 5,921’ 4-1/2” Prod liner 12.6 / L-80 / DWC/C 3.958” 5,682’ 8,801’ TUBING DETAIL 4-1/2" Tieback 12.6 / L-80 / IBT 3.958” Surf 5,678’ JEWELRY DETAIL No Depth Item 1 357’ Baker S-05 TRSSSV w/ 3.813” BX Profile, full open 1,900 psi 2 3,920’ Flex-lock liner hanger, HRDE ZXPN Liner Top Packer w/ 5.5” PBR 3 5,682’ 5” x 7” ZXP, HRDE Liner Top Packer, w. 5.25” PBR 4 7,985’ CIBP w/ 10ft of cmt (6.4 gal) set 11/25/22 ToC 7,975’ 5 8,290’ CIBP w/ 25ft of cmt (16 gal) Set 10/30/22 Toc 8,265’ OPEN HOLE / CEMENT DETAIL 8-1/2” 30 bbls spacer followed by 67 bbls of 15.3 ppg, bumped plug. Recovered 30 bbls spacer and 10 bbls of cement. CBL run 9/30/22, shows TOC @ 4,163’ MD 6-1/8” CBL run 10/16/22, shows TOC @ 4,163’ MD RA Tags @ 7,782 & 6,807’ short joints @ 7,292’ & 8,309’ Top CINGSA: 5522’ MD; 4917’ TVD Base CINGSA: 5808’ MD; 5144’ TVD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status MB 7A Lower ±7,360’ ±7,378’ 18 Proposed LB 7,501' 7,516’ 6,589' 6,603' 15’ 12/3/2022 Open LB 1A Upper 7,544’ 7,557’ 6,629' 6,642' 10’ 11/2/2022 Open LB 1A Lower 7,564’ 7,572’ 6,648' 6,656' 8’ 11/2/2022 Open LB 1C Upper 7,588' 7,595' 6,671' 6,677' 7' 12/3/2022 Open LB 1C Lower 7,601' 7,608' 6,683' 6,690' 7' 12/2/2022 Open LB 1D 7,640' 7,645' 6,720' 6,725' 5' 12/2/2022 Open LB 1F Upper 7,683' 7,691' 6,761' 6,768' 8' 12/2/2022 Open LB 1F Mid 7,703' 7,708' 6,779' 6,784' 5' 12/2/2022 Open LB 1F Lower 7,732' 7,740' 6,807' 6,815' 8' 12/2/2022 Open LB 1G Upper 7,764' 7,772' 6,837' 6,845' 8' 11/28/2022 Open LB 1G Lower 7,788’ 7,796’ 6,860' 6,868' 8’ 10/31/2022 Open LB 2 7,821' 7,831' 6,892' 6,901' 10' 11/28/2022 Open LB 2A 7,889' 7,898' 6,956' 6,965' 9' 11/28/2022 Open LB 2B upper 7,911’ 7,921’ 6,977' 6,987' 10’ 10/31/2022 Open LB 2B Mid 7,928’ 7,934’ 6,994' 6,999' 6’ 10/31/2022 Open LB 2B Lower 7,946' 7,951' 7,011' 7,016' 5' 11/28/2022 Open LB 2B 7,996’ 8,007’ 7,059' 7,069' 11’ 10/31/2022 Isolated LB 3C 8,301’ 8,311’ 7,351' 7,361' 10’ 10/26/2022 Isolated LB 4B 8,468’ 8,474’ 7,513' 7,519' 10’ 10/26/2022 Isolated LB 5 Upper 8,613’ 8,621’ 7,653' 7,661' 8’ 10/26/2022 Isolated LB 5 Mid 8,631’ 8,636’ 7,671' 7,676' 5’ 10/26/2022 Isolated LB 5 Lower 8,641’ 8,649’ 7,681' 7,688' 8’ 10/24/2022 Isolated 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: CLU-10RD PTD#222-113 (Sundry # 322-589) Additional perfs Date:Thursday, December 15, 2022 4:18:00 PM Chad, Hilcorp has approval to add the additional perf interval requested in your email below. Please submit the report of this activity on the 10-407 for sundry 322-589. 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: Thursday, December 15, 2022 12:27 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: CLU-10RD PTD#222-113 (Sundry # 322-589) Additional perfs Bryan, Attached is a current wellbore schematic for CLU-10RD. We have completed adding the perfs in the well that were part of the original sundry, with limited success. Well is currently making ~150mcfd of gas. We are blowing the well dry with N2 (per Sundry # 322-589) and would like to add some perfs above the interval approved in this sundry. We would like to add some perfs in the middle Beluga sand – MB 7A Lower from 7,360-7,378’ (18’). This zone is within the Beluga Pool per CO 231A. Let me know if you want us to submit a change of program for this one sand perf add. 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 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. Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/15/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221215 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14A 50133205390100 213196 9/22/2022 YELLOW JACKET PERF CLU 10RD 50133205530100 222113 10/24/2022 YELLOW JACKET PERF-GPT CLU 05RD 50133204740100 215160 7/15/2022 YELLOW JACKET PLUG-PERF CLU 10 50133205530000 205106 7/16/2022 YELLOW JACKET PERF KALOTSA 4 50133206650000 217063 8/24/2022 YELLOW JACKET PERF MPU K-09 50029232470000 205014 12/11/2022 READ CaliperSurvey Please include current contact information if different from above. T37376 T37377 T37378 T37379 T37380 T37381 By Meredith Guhl at 10:10 am, Dec 16, 2022 CLU 10RD 50133205530100 222113 10/24/2022 YELLOW JACKET PERF-GPT Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.16 10:11:16 -09'00' liilrnrp ;11tuka, UX Date: 12/01/2022 David Douglas Hilcorp Alaska, LLC ; 2 Z ^ I 1 Sr. GeoTechnician 3800 CenterPoint Drive, Suite 1400 10025 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com To: Alaska Oil & Gas Conservation Commission Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL RECEIVED WELL: CLU-10111) PTD: 222-113 API: 50-133-20553-01-00 Washed and Dried Well Samples (09/25/2022 to 10/09/2022) B Set (3 Boxes): ALL BOX SAMPLE INTERVAL (FEET / MD) CLU 1 ORD BOX 1 OF 3 4120' - 5800' MD CLU 1 ORD BOX 2 OF 3 5800' - 7300' MD CLU 1 ORD BOX 3 OF 3 7300' - 8303' MD (TD) Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal. Received �w Date: z2- DEC 01 2022 AOCCC STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:8 DATE:11/26/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2221130 Sundry #322-589 Operation:Drilling:Workover:x Explor.: Test:Initial:x Weekly:Bi-Weekly:Other: Rams:250/4000 Annular:N/A Valves:250/4000 MASP:3731 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.NA Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 0 NA Test Fluid Water Inside BOP 0 NA FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75"P Trip Tank NA NA Annular Preventer 0 NA Pit Level Indicators NA NA #1 Rams 1 1.75" BS P Flow Indicator NA NA #2 Rams 1 1.75" PS P Meth Gas Detector NA NA #3 Rams 0 NA H2S Gas Detector NA NA #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 2 2"P Time/Pressure Test Result HCR Valves 0 NA System Pressure (psi)3000 P Kill Line Valves 2 2"P Pressure After Closure (psi)2450 P Check Valve 0 NA 200 psi Attained (sec)6 P BOP Misc 0 NA Full Pressure Attained (sec)15 P Blind Switch Covers:All stations YES CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA NA No. Valves 5 P ACC Misc 0 NA Manual Chokes 2 P Hydraulic Chokes 0 NA Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 0 NA #1 Rams 22 P Coiled Tubing Only:#2 Rams 24 P Inside Reel valves 1 P #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:2.0 HCR Choke 0 NA Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice YES Date/Time 11/25/22 08:03 Waived By Test Start Date/Time:11/26/2022 11:00 (date)(time)Witness Test Finish Date/Time:11/26/2022 13:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Fox Accumulator system 4 bottles at 1400psi. Terence Rais Hilcorp Alaska Brad Gathman CLU-10RD Test Pressure (psi): Trais@FoxEnergyAK.com brad.gathman@hilcorp.com Form 10-424 (Revised 08/2022)2022-1126_BOP_Fox8_CLU-10RD           jbr J. Regg; 12/28/2022 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: 11/17/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTALT#20221117-1 Log Print Files and Log Data Files: Well API #PTD #Log Date Log Company Log Type AOGCC Eset# CLU 05RD2 50133204740200 222092 9/27/2022 Yellowjacket CBL CLU 10 50133205530000 205106 8/7/2022 Yellowjacket CBL-PLUG CLU 10RD 50133205530100 222113 9/30/2022 Yellowjacket CBL CLU 10RD 50133205530100 222113 10/16/2022 Halliburton RCBL CLU 13 50133206460000 214171 10/2/2022 Yellowjacket CBL Please include current contact information if different from above. T37265 T37266 T37267 T37267 T37268 By Meredith Guhl at 1:32 pm, Nov 17, 2022 CLU 1 0RD 501 33205530100 222113 9 /30/2022 Ye llowjac ke t CBL CLU 1 0RD 501 33205530100 222113 1 0 /16/2022 Halliburton RCBL Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.17 13:32:28 -09'00' 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: 11/07/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: CLU-10RD PTD: 222-113 API: 50-133-20553-01-00 MUDLOGS - EOW DRILLING REPORTS (09/25/2022 to 10/09/2022) 1. FINAL EOW REPORT 2. DAILY REPORTS 3. SHOW REPORTS 4. DIGITAL DATA (LAS) 5. MUDLOG PRINTS (2” and 5” MD and TVD COLOR PRINTS – TIFF AND PDF FORMATS) Formation Log LWD Combo Log Gas Ratio Log Drilling Dynamics Log SFTP Transfer - Data Folders: Please include current contact information if different from above. PTD:222-113 T37240 Kayla Junke Digitally signed by Kayla Junke Date: 2022.11.08 12:29:07 -09'00' 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: 11/07/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: CLU-10RD PTD: 222-113 API: 50-133-20553-01-00 FINAL LWD FORMATION EVALUATION LOGS (09/25/2022 to 10/09/2022) x EWR-M5, AGR, PCG, ADR, 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. PTD:222-113 T37240 Kayla Junke Digitally signed by Kayla Junke Date: 2022.11.08 12:27:48 -09'00' 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Monday, November 7, 2022 11:52 AM To:Jay Murphy - (C) Cc:Regg, James B (OGC) Subject:RE: CLU-10RD MIT Hilcorp 169 10-12-2022 Jay, I revised the report, replacing Pearl 8 (well #) to reflect 10RD. Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907Ͳ793Ͳ1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From:Jay MurphyͲ(C) <Jay.Murphy@hilcorp.com> Sent:Wednesday, October 12, 2022 3:25 PM To:Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject:CLUͲ10RD MIT Hilcorp 169 10Ͳ12Ͳ2022 Thank You and Best Regards, Jay Murphy/DSM Hilcorp Alaska, LLC HAK Rig 169 Office: 907Ͳ283Ͳ1369 Cell: 907Ͳ715Ͳ9211 Jay.Murphy@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 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. &DQQHU\/RRS8QLW5' 37' revised the report, MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, April 6, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM: P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 10RD CANNERY LOOP UNIT 10RD Jim Regg OperatorSrc: 10RD N SPT 5060 2221130 3500 0 3575 3550 3540 75 75 75 75 Other (describe in notes)Pass Rig MIT-T. Witness waived. 30 MinPretestInitial15 Min Type Test Notes: Interval P/F Well Type Inj TVD PTD Test psi Tubing OA Packer Depth 0 50 50 50IA 45 Min 60 Min 50-133-20553-01-00 222-113-0 10/12/2022 Well Name Permit Number: API Well Number Inspector Name:CANNERY LOOP UNIT 10RD Inspection Date:Insp Num: Rel Insp Num: MITOP000009513 BBL Pumped:1.6 BBL Returned:1.6 Thursday, April 6, 2023 Page 1 of 1 1RWZLWQHVVHG 9 9 9 9 9 9 9 9 9 :HOOLVD*DVSURGXFHU WHVWGDWH MEU 1RWZLWQHVVHG 1 Regg, James B (OGC) From:Michael Hibbert - (C) <Michael.Hibbert@hilcorp.com> Sent:Tuesday, October 18, 2022 12:17 PM To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay Subject:BOP Test Form - CLU-10RD - 10/15/22 Attachments:BOPE Test Report CLU 10RD 10-15-2022.xlsx Hello, Here is the test form for the BOPE test performed on well CLU‐10RD on 10/15/22. Let me know if you have any questions. Thanks, Michael Hibbert Wellsite Supervisor Hilcorp Alaska 907‐903‐5990 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. 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. Cannery Loop Unit 10RD PTD 2221130 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:8 DATE:10/15/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2221130 Sundry #322-589 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/4000 Annular:NA Valves:250/4000 MASP:3731 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 0 NA Test Fluid Other Inside BOP 0 NA FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75"P Trip Tank NA NA Annular Preventer 0 NA NA Pit Level Indicators NA NA #1 Rams 1 1.75" B/S P Flow Indicator NA NA #2 Rams 1 1.75" P/S FP Meth Gas Detector NA NA #3 Rams 0 NA NA H2S Gas Detector NA NA #4 Rams 0 NA NA MS Misc 0 NA #5 Rams 0 NA NA #6 Rams 0 NA NA ACCUMULATOR SYSTEM: Choke Ln. Valves 2 2"P Time/Pressure Test Result HCR Valves 0 NA NA System Pressure (psi)3000 P Kill Line Valves 2 2"P Pressure After Closure (psi)2550 P Check Valve 0 NA NA 200 psi Attained (sec)3 P BOP Misc 0 NA NA Full Pressure Attained (sec)11 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):N/A NA No. Valves 5 P ACC Misc 0 NA Manual Chokes 2 P Hydraulic Chokes 0 NA Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 0 NA #1 Rams 15 P Coiled Tubing Only:#2 Rams 15 P Inside Reel valves 1 P #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:7.0 HCR Choke 0 NA Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 0/13/2022 / 4:56PM Waived By Test Start Date/Time:10/15/2022 9:30 (date)(time)Witness Test Finish Date/Time:10/15/2022 16:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Fox Test Fluid: Methanol. Bottle Precharge: 1400 psi. Pipeslips fail initial due to wellhead leak. After greasing retest passed. Landry Lynn Hilcorp Alaska Michael Hibbert CLU-10RD Test Pressure (psi): trais@foxenergyak.com michael.hibbert@hilcorp.com Form 10-424 (Revised 08/2022)2022-1015_BOP_Fox8_CLU-10RD          ====1  jbr J. Regg; 11/25/2022 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________CANNERY LOOP UNIT 10RD JBR 12/09/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Test with 4 1/2" test joint. Had to work a little air out of the system on test # 1. 15 accumulator bottles at 906 psi avg Test Results TEST DATA Rig Rep:Trick/ColemanOperator:Hilcorp Alaska, LLC Operator Rep:Murphy/Lawson Rig Owner/Rig No.:Hilcorp 169 PTD#:2221130 DATE:10/6/2022 Type Operation:DRILL Annular: 250/3500Type Test:BIWKLY Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopKPS221008150927 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4 MASP: 3323 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 11" 5K P #1 Rams 1 2 7/8" X 5" V P #2 Rams 1 Blind rams P #3 Rams 1 4.5" Fixed 5K P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 3 1/8" & 2 1/1 P Kill Line Valves 2 3 1/8x 2 1/16 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1650 200 PSI Attained P25 Full Pressure Attained P87 Blind Switch Covers:Pall Stations Bottle precharge P Nitgn Btls# &psi (avg)P4 @ 2475 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P26 #1 Rams P4 #2 Rams P4 #3 Rams P5 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill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a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aa 72: 3HUIRUDWLRQ'HSWK0'IW SVL SVL SVL /HQJWK 6L]H 3URSRVHG3RROV 79'%XUVW 35(6(17:(//&21',7,216800$5< aaa a1$ 0' 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 $33/,&$7,21)25681'5<$33529$/6 $$& )((+LOFRUSIRUPHUO\$'/$'/ &DQQHU\/RRS 8QLW 1$%HOXJD*DV &2$ +LOFRUS$ODVND//& &HQWHUSRLQW'ULYH6XLWH $QFKRUDJH$ODVND &/85' 7XELQJ*UDGH7XELQJ0'IW3HUIRUDWLRQ'HSWK79'IW7XELQJ6L]H / 2FWREHU /LQHU7RS3NU%DNHU6756669 a 0' 79'DQG 0' 79' 6HH6FKHPDWLF 6HH6FKHPDWLF ,KHUHE\FHUWLI\WKDWWKHIRUHJRLQJLVWUXHDQGWKHSURFHGXUHDSSURYHGKHUHLQZLOOQRWEHGHYLDWHGIURPZLWKRXWSULRUZULWWHQDSSURYDO $XWKRUL]HG1DPHDQG 'LJLWDO6LJQDWXUHZLWK'DWH $2*&&86(21/< &KDG+HOJHVRQ2SHUDWLRQV(QJLQHHU FKHOJHVRQ#KLOFRUSFRP 1RHO1RFDV2SHUDWLRQV0DQDJHU P Q 3 V W )RUP5HYLVHG$SSURYHGDSSOLFDWLRQYDOLGIRUPRQWKVIURPGDWHRIDSSURYDO6XEPLW3')WRDRJFFSHUPLWWLQJ#DODVNDJRY By Anne Prysunka at 4:26 pm, Oct 05, 2022 'LJLWDOO\VLJQHGE\1RHO1RFDV '1FQ 1RHO1RFDV RX 8VHUV 'DWH 1RHO1RFDV %-0 &7 %23 WHVW WR SVL '65 ; 6)'*&: Jessie L. Chmielowski Digitally signed by Jessie L. 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Chmielowski Digitally signed by Jessie L. 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" # $%$$ & ' & 3150 3500 3850 4200 4550 4900 5250 5600 5950 6300 6650 7000 7350 7700 8050 8400True Vertical Depth (700 usft/in)1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 Vertical Section at 70.00° (700 usft/in) CLU-10RD Tgt1 CLU-10RD Tgt2 3 50 0 4 0 0 0 4 5 0 0 5 0 0 0 550 0 6000 6500 7000 7500 8000 845 0 Cannery Loop Unit 10 4 1/2" 35 0 0 4 0 0 0 4 5 0 0 5 0 0 0 5 5 0 0 6 0 0 0 6 5 0 0 7 0 0 0 7 5 0 0 8 0 0 0 8 5 0 0 8 7 0 5 CLU-10RD wp07 KOP: 12.3º/100' : 4120' MD, 3720.66'TVD : 30° LT TF End Dir : 4137' MD, 3736.06' TVD Start Dir 3º/100' : 4157' MD, 3754.04'TVD End Dir : 5221.41' MD, 4678.97' TVD Start Dir 3º/100' : 6598.64' MD, 5771.71'TVD End Dir : 7520.66' MD, 6607.8' TVD Total Depth : 8704.64' MD, 7773.8' TVD Top CINGSA Base CINGSA UB4 Lower Beluga Top Tyonek (TD) 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: Cannery Loop Unit 10 Ground Level: 19.80 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 2388727.30 272452.09 60° 31' 56.843 N 151° 15' 48.374 W SURVEY PROGRAM Date: 2022-08-08T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 131.80 4120.00 CLU-10 (Cannery Loop Unit 10) 3_MWD 4120.00 4520.00 CLU-10RD wp07 (CLU-10RD) 3_MWD_Interp Azi+ 4520.00 8704.64 CLU-10RD wp07 (CLU-10RD) 3_MWD+IFR1+MS+ FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 4951.80 4914.00 5565.27 Top CINGSA 5151.80 5114.00 5817.34 Base CINGSA 5360.80 5323.00 6080.75 UB4 6607.80 6570.00 7520.66 Lower Beluga 7773.80 7736.00 8704.64 Top Tyonek (TD) REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: Cannery Loop Unit 10, True North Vertical (TVD) Reference:CLU-10RD As-Built @ 37.80usft Measured Depth Reference:CLU-10RD As-Built @ 37.80usft Calculation Method: Minimum Curvature Project:Kenai C.I.U. Site:Cannery Loop Unit #1 Pad Well:Plan: Cannery Loop Unit 10 Wellbore:CLU-10RD Design:CLU-10RD wp07 CASING DETAILS TVD TVDSS MD Size Name 7773.80 7736.00 8704.64 4-1/2 4 1/2" SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 4120.00 24.13 103.53 3720.66 -281.59 1468.88 0.00 0.00 1283.99 KOP: 12.3º/100' : 4120' MD, 3720.66'TVD : 30° LT TF 2 4137.00 25.94 101.06 3736.06 -283.12 1475.91 12.30 -30.00 1290.07 End Dir : 4137' MD, 3736.06' TVD 3 4157.00 25.94 101.06 3754.04 -284.80 1484.50 0.00 0.00 1297.56 Start Dir 3º/100' : 4157' MD, 3754.04'TVD 4 5221.41 37.49 41.57 4678.97 -81.86 1939.77 3.00 -97.52 1794.79 End Dir : 5221.41' MD, 4678.97' TVD 5 6598.64 37.49 41.57 5771.71 545.25 2496.02 0.00 0.00 2531.97 Start Dir 3º/100' : 6598.64' MD, 5771.71'TVD 6 7520.66 10.00 32.37 6607.80 828.29 2729.63 3.00 -176.57 2848.31 CLU-10RD Tgt1 End Dir : 7520.66' MD, 6607.8' TVD 7 8704.64 10.00 32.37 7773.80 1001.94 2839.70 0.00 0.00 3011.13 CLU-10RD Tgt2 Total Depth : 8704.64' MD, 7773.8' TVD -500-375-250-1250125250375500625750875100011251250South(-)/North(+) (250 usft/in)625 750 875 1000 1125 1250 1375 1500 1625 1750 1875 2000 2125 2250 2375 2500 2625 2750 2875 3000West(-)/East(+) (250 usft/in)CLU-10RD Tgt2CLU-10RD Tgt1Cannery Loop Unit 104 1/2"22502500275030003250350037504 0 0 0 4 2 5 0450047505000525055005750600062506500675070007250750077507774CLU-10RD wp07KOP: 12.3º/100' : 4120' MD, 3720.66'TVD : 30° LT TFEnd Dir : 4137' MD, 3736.06' TVDStart Dir 3º/100' : 4157' MD, 3754.04'TVDEnd Dir : 5221.41' MD, 4678.97' TVDStart Dir 3º/100' : 6598.64' MD, 5771.71'TVDEnd Dir : 7520.66' MD, 6607.8' TVDTotal Depth : 8704.64' MD, 7773.8' TVDCASING DETAILSTVDTVDSS MDSize Name7773.80 7736.00 8704.64 4-1/2 4 1/2"Project: Kenai C.I.U.Site: Cannery Loop Unit #1 PadWell: Plan: Cannery Loop Unit 10Wellbore: CLU-10RDPlan: CLU-10RD wp07WELL DETAILS: Plan: Cannery Loop Unit 10Ground Level: 19.80+N/-S +E/-WNorthingEastingLatitudeLongitude0.00 0.002388727.30 272452.09 60° 31' 56.843 N 151° 15' 48.374 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: Cannery Loop Unit 10, True NorthVertical (TVD) Reference:CLU-10RD As-Built @ 37.80usftMeasured Depth Reference:CLU-10RD As-Built @ 37.80usftCalculation Method:Minimum Curvature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eparation Factor4200 4500 4800 5100 5400 5700 6000 6300 6600 6900 7200 7500 7800 8100 8400 8700 9000 9300 9600 9900Measured Depth (600 usft/in)CLU Storage 4Cannery Loop Unit 10CLU Storage 4No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS: Plan: Cannery Loop Unit 10 NAD 1927 (NADCON CONUS) Alaska Zone 04Ground Level: 19.80+N/-S+E/-W NorthingEastingLatitudeLongitude0.000.002388727.30 272452.09 60° 31' 56.843 N 151° 15' 48.374 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: Cannery Loop Unit 10, True NorthVertical (TVD) Reference: CLU-10RD As-Built @ 37.80usftMeasured Depth Reference:CLU-10RD As-Built @ 37.80usftCalculation Method:Minimum CurvatureCASING DETAILSTVD TVDSS MD Size Name7773.80 7736.00 8704.64 4-1/2 4 1/2"SURVEY PROGRAMDate: 2022-08-08T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool131.80 4120.00 CLU-10 (Cannery Loop Unit 10) 3_MWD4120.00 4520.00 CLU-10RD wp07 (CLU-10RD) 3_MWD_Interp Azi+Sag4520.00 8704.64 CLU-10RD wp07 (CLU-10RD) 3_MWD+IFR1+MS+Sag0.0060.00120.00180.00240.00300.00Centre to Centre Separation (120.00 usft/in)4200 4500 4800 5100 5400 5700 6000 6300 6600 6900 7200 7500 7800 8100 8400 8700 9000 9300 9600 9900Measured Depth (600 usft/in)CLU Storage 4Cannery Loop Unit 10CLU Storage 4GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference4120.00 To 8704.64Project: Kenai C.I.U.Site: Cannery Loop Unit #1 PadWell: Plan: Cannery Loop Unit 10Wellbore: CLU-10RDPlan: CLU-10RD wp07Ladder/S.F. Plots HHEADERINFORMATIONŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞ HCOMPANY:HilcorpAlaska,LLC HFIELD:KenaiC.I.U. HSITE:CanneryLoopUnit#1Pad HWELL:Plan:CanneryLoopUnit10 HWELLPATH:CLUŞ10RD HDEPTHUNT:usft HSURVDATE:1/1/1990 HŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞ HWELLINFORMATION HWELLEWMAP:272452.09 HWELLNSMAP:2388727.30 HDATUMELEVN:37.80 HVSECTANGLE:70.00 HVSECTNORTH:0.00 HVSECTEAST:0.00 HŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞ HSURVEYTYPEINFORMATION H131.80Ş4120.00CLUŞ10:3_MWD H4120.00Ş4520.00CLUŞ10RDWP07:3_MWD_INTERPAZI+SAG H4520.00Ş8704.64CLUŞ10RDWP07:3_MWD+IFR1+MS+SAG HŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞŞ HSURVEYLIST HMDINCAZITVDTVDSSEWNS 18.000.000.0018.00Ş19.800.000.00 131.800.50138.40131.8094.000.33Ş0.37 192.800.10330.20192.80155.000.48Ş0.52 253.800.3033.20253.80216.000.54Ş0.34 313.800.202.00313.80276.000.63Ş0.11 374.800.6097.30374.80337.000.95Ş0.04 434.800.70121.70434.79396.991.57Ş0.27 494.800.20142.90494.79456.991.95Ş0.55 553.800.60110.90553.79515.992.30Ş0.74 614.800.80121.20614.78576.982.96Ş1.08 675.800.50151.80675.78637.983.45Ş1.53 736.801.30111.20736.77698.974.22Ş2.02 799.801.40114.60799.76761.965.59Ş2.60 862.802.20116.30862.72824.927.37Ş3.45 925.803.60112.60925.64887.8410.28Ş4.75 989.805.10109.30989.46951.6614.82Ş6.46 1052.806.50111.901052.131014.3320.78Ş8.72 1114.8010.10106.501113.471075.6729.25Ş11.57 1178.8012.70104.201176.201138.4041.45Ş14.89 1241.8015.70101.901237.271199.4756.51Ş18.35 1303.8018.30100.701296.561258.7674.28Ş21.89 1367.8020.6099.801356.901319.1095.25Ş25.67 1430.8023.0099.801415.391377.59118.31Ş29.65 1493.8025.20101.801472.901435.10143.57Ş34.49 1556.8028.30100.701529.151491.35171.38Ş40.01 1619.8030.8098.601583.951546.15202.01Ş45.19 &/85'ZSB*HR 1683.8032.6099.501638.401600.60235.21Ş50.49 1743.8032.1099.501689.091651.29266.88Ş55.79 1806.8031.8099.301742.551704.75299.77Ş61.23 1869.8032.8097.801795.801758.00333.06Ş66.23 1998.8034.2098.501903.371865.57403.53Ş76.33 2123.8034.2096.402006.761968.96473.19Ş85.44 2248.8033.8097.602110.392072.59542.57Ş93.95 2375.8033.50102.602216.132178.33611.80Ş106.27 2501.8033.60101.602321.142283.34679.89Ş120.87 2628.8033.50101.602426.982389.18748.64Ş134.98 2753.8033.90100.602530.972493.17816.70Ş148.33 2879.8033.60101.202635.742597.94885.44Ş161.57 3006.8033.70100.202741.462703.66954.58Ş174.63 3132.8033.60100.202846.352808.551023.30Ş187.00 3195.8032.90100.402899.032861.231057.28Ş193.17 3258.8032.20100.002952.142914.341090.64Ş199.18 3320.8030.90100.503004.972967.171122.57Ş204.95 3382.8029.5099.603058.553020.751153.27Ş210.39 3444.8028.0099.803112.913075.111182.67Ş215.42 3507.8027.4099.603168.693130.891211.53Ş220.35 3570.8026.60100.303224.823187.021239.71Ş225.29 3632.8026.10100.503280.383242.581266.77Ş230.26 3695.8026.00102.703336.983299.181293.87Ş235.82 3758.8025.80105.303393.663355.861320.57Ş242.47 3822.8025.50105.403451.353413.551347.28Ş249.81 3885.8025.20104.903508.283470.481373.32Ş256.86 3946.8025.20104.703563.483525.681398.43Ş263.49 4010.8025.20105.003621.393583.591424.77Ş270.47 4073.8024.50103.903678.553640.751450.40Ş277.08 4120.0024.13103.533720.663682.861468.88Ş281.59 4125.0024.66102.793725.213687.411470.89Ş282.06 4137.0025.94101.063736.063698.261475.91Ş283.12 4157.0025.94101.063754.043716.241484.50Ş284.80 4200.0025.8098.123792.743754.941502.99Ş287.93 4300.0025.7191.223882.823845.021546.23Ş291.46 4400.0025.9484.353972.863935.061589.69Ş289.77 4500.0026.4977.674062.594024.791633.25Ş282.85 4600.0027.3471.314151.784113.981676.80Ş270.73 4700.0028.4565.354240.174202.371720.21Ş253.43 4800.0029.8159.854327.544289.741763.37Ş231.01 4900.0031.3854.824413.634375.831806.15Ş203.52 5000.0033.1250.254498.214460.411848.44Ş171.05 5100.0035.0246.104581.054543.251890.13Ş133.67 5200.0037.0442.334661.934624.131931.10Ş91.50 5221.4137.4941.574678.974641.171939.77Ş81.86 5300.0037.4941.574741.324703.521971.51Ş46.07 5400.0037.4941.574820.674782.872011.90Ş0.54 5500.0037.4941.574900.014862.212052.2945.00 5600.0037.4941.574979.364941.562092.6890.53 5700.0037.4941.575058.705020.902133.06136.06 5800.0037.4941.575138.045100.242173.45181.60 5900.0037.4941.575217.395179.592213.84227.13 6000.0037.4941.575296.735258.932254.23272.66 6100.0037.4941.575376.075338.272294.62318.20 6200.0037.4941.575455.425417.622335.01363.73 6300.0037.4941.575534.765496.962375.40409.27 6400.0037.4941.575614.105576.302415.79454.80 6500.0037.4941.575693.455655.652456.18500.33 6598.6437.4941.575771.715733.912496.02545.25 6600.0037.4541.575772.795734.992496.57545.87 6700.0034.4641.255853.735815.932535.40589.89 6800.0031.4640.885937.635899.832571.15630.90 6900.0028.4740.446024.255986.452603.70668.78 7000.0025.4839.916113.366075.562632.97703.43 7100.0022.4939.256204.716166.912658.88734.75 7200.0019.5138.396298.066260.262681.36762.66 7300.0016.5337.246393.146355.342700.34787.08 7400.0013.5635.616489.706451.902715.78807.94 7500.0010.6133.086587.486549.682727.63825.19 7520.6610.0032.376607.806570.002729.63828.29 7600.0010.0032.376685.946648.142737.01839.93 7700.0010.0032.376784.426746.622746.30854.60 7800.0010.0032.376882.906845.102755.60869.26 7900.0010.0032.376981.386943.582764.90883.93 8000.0010.0032.377079.867042.062774.19898.60 8100.0010.0032.377178.347140.542783.49913.26 8200.0010.0032.377276.827239.022792.79927.93 8300.0010.0032.377375.307337.502802.08942.60 8400.0010.0032.377473.787435.982811.38957.26 8500.0010.0032.377572.267534.462820.68971.93 8600.0010.0032.377670.747632.942829.97986.60 8704.6410.0032.377773.807736.002839.701001.94 Design,MD_usft,TVDSS_usft,TVD_usft,X_usft, Y_usft,Comment CLUŞ10RD,18.00,Ş19.80,18.00,272452.09, 2388727.30, CLUŞ10RD,131.80,94.00,131.80,272452.41, 2388726.92, CLUŞ10RD,192.80,155.00,192.80,272452.55, 2388726.76, CLUŞ10RD,253.80,216.00,253.80,272452.62, 2388726.94, CLUŞ10RD,313.80,276.00,313.80,272452.71, 2388727.18, CLUŞ10RD,374.80,337.00,374.80,272453.04, 2388727.24, CLUŞ10RD,434.80,396.99,434.79,272453.65, 2388726.99, CLUŞ10RD,494.80,456.99,494.79,272454.02, 2388726.71, CLUŞ10RD,553.80,515.99,553.79,272454.37, 2388726.51, CLUŞ10RD,614.80,576.98,614.78,272455.03, 2388726.16, CLUŞ10RD,675.80,637.98,675.78,272455.51, 2388725.70, CLUŞ10RD,736.80,698.97,736.77,272456.27, 2388725.20, CLUŞ10RD,799.80,761.96,799.76,272457.62, 2388724.59, CLUŞ10RD,862.80,824.92,862.72,272459.39, 2388723.70, CLUŞ10RD,925.80,887.84,925.64,272462.28, 2388722.35, CLUŞ10RD,989.80,951.66,989.46,272466.78, 2388720.55, CLUŞ10RD,1052.80,1014.33,1052.13,272472.69, 2388718.18, CLUŞ10RD,1114.80,1075.67,1113.47,272481.10, 2388715.17, CLUŞ10RD,1178.80,1138.40,1176.20,272493.24, 2388711.61, CLUŞ10RD,1241.80,1199.47,1237.27,272508.23, 2388707.87, CLUŞ10RD,1303.80,1258.76,1296.56,272525.93, 2388703.99, CLUŞ10RD,1367.80,1319.10,1356.90,272546.83, 2388699.80, CLUŞ10RD,1430.80,1377.59,1415.39,272569.80, 2388695.38, CLUŞ10RD,1493.80,1435.10,1472.90,272594.96, 2388690.06, &/85'ZSB*,6 CLUŞ10RD,1556.80,1491.35,1529.15,272622.66, 2388684.01, CLUŞ10RD,1619.80,1546.15,1583.95,272653.18, 2388678.24, CLUŞ10RD,1683.80,1600.60,1638.40,272686.28, 2388672.30, CLUŞ10RD,1743.80,1651.29,1689.09,272717.83, 2388666.40, CLUŞ10RD,1806.80,1704.75,1742.55,272750.61, 2388660.32, CLUŞ10RD,1869.80,1758.00,1795.80,272783.80, 2388654.69, CLUŞ10RD,1998.80,1865.57,1903.37,272854.06, 2388643.24, CLUŞ10RD,2123.80,1968.96,2006.76,272923.53, 2388632.79, CLUŞ10RD,2248.80,2072.59,2110.39,272992.73, 2388622.95, CLUŞ10RD,2375.80,2178.33,2216.13,273061.71, 2388609.30, CLUŞ10RD,2501.80,2283.34,2321.14,273129.50, 2388593.40, CLUŞ10RD,2628.80,2389.18,2426.98,273197.97, 2388577.97, CLUŞ10RD,2753.80,2493.17,2530.97,273265.75, 2388563.32, CLUŞ10RD,2879.80,2597.94,2635.74,273334.22, 2388548.77, CLUŞ10RD,3006.80,2703.66,2741.46,273403.10, 2388534.38, CLUŞ10RD,3132.80,2808.55,2846.35,273471.56, 2388520.70, CLUŞ10RD,3195.80,2861.23,2899.03,273505.42, 2388513.87, CLUŞ10RD,3258.80,2914.34,2952.14,273538.66, 2388507.23, CLUŞ10RD,3320.80,2967.17,3004.97,273570.47, 2388500.85, CLUŞ10RD,3382.80,3020.75,3058.55,273601.06, 2388494.81, CLUŞ10RD,3444.80,3075.11,3112.91,273630.35, 2388489.22, CLUŞ10RD,3507.80,3130.89,3168.69,273659.12, 2388483.74, CLUŞ10RD,3570.80,3187.02,3224.82,273687.19, 2388478.26, CLUŞ10RD,3632.80,3242.58,3280.38,273714.15, 2388472.77, CLUŞ10RD,3695.80,3299.18,3336.98,273741.14, 2388466.69, CLUŞ10RD,3758.80,3355.86,3393.66,273767.70, 2388459.53, CLUŞ10RD,3822.80,3413.55,3451.35,273794.27, 2388451.68, CLUŞ10RD,3885.80,3470.48,3508.28,273820.16, 2388444.13, CLUŞ10RD,3946.80,3525.68,3563.48,273845.14, 2388437.02, CLUŞ10RD,4010.80,3583.59,3621.39,273871.34, 2388429.53, CLUŞ10RD,4073.80,3640.75,3678.55,273896.84, 2388422.43, CLUŞ10RD,4120.00,3682.86,3720.66,273915.23, 2388417.57, CLUŞ10RD,4125.00,3687.41,3725.21,273917.23, 2388417.06, CLUŞ10RD,4137.00,3698.26,3736.06,273922.23, 2388415.90, CLUŞ10RD,4157.00,3716.24,3754.04,273930.78, 2388414.06, CLUŞ10RD,4200.00,3754.94,3792.74,273949.21, 2388410.58, CLUŞ10RD,4300.00,3845.02,3882.82,273992.37, 2388406.21, CLUŞ10RD,4400.00,3935.06,3972.86,274035.85, 2388407.07, CLUŞ10RD,4500.00,4024.79,4062.59,274079.54, 2388413.15, CLUŞ10RD,4600.00,4113.98,4151.78,274123.31, 2388424.44, CLUŞ10RD,4700.00,4202.37,4240.17,274167.04, 2388440.90, CLUŞ10RD,4800.00,4289.74,4327.54,274210.62, 2388462.49, CLUŞ10RD,4900.00,4375.83,4413.63,274253.92, 2388489.15, CLUŞ10RD,5000.00,4460.41,4498.21,274296.83, 2388520.80, CLUŞ10RD,5100.00,4543.25,4581.05,274339.22, 2388557.37, CLUŞ10RD,5200.00,4624.13,4661.93,274380.99, 2388598.75, CLUŞ10RD,5221.41,4641.17,4678.97,274389.84, 2388608.22, CLUŞ10RD,5300.00,4703.52,4741.32,274422.26, 2388643.39, CLUŞ10RD,5400.00,4782.87,4820.67,274463.52, 2388688.13, CLUŞ10RD,5500.00,4862.21,4900.01,274504.77, 2388732.88, CLUŞ10RD,5600.00,4941.56,4979.36,274546.03, 2388777.63, CLUŞ10RD,5700.00,5020.90,5058.70,274587.28, 2388822.38, CLUŞ10RD,5800.00,5100.24,5138.04,274628.54, 2388867.13, CLUŞ10RD,5900.00,5179.59,5217.39,274669.79, 2388911.87, CLUŞ10RD,6000.00,5258.93,5296.73,274711.04, 2388956.62, CLUŞ10RD,6100.00,5338.27,5376.07,274752.30, 2389001.37, CLUŞ10RD,6200.00,5417.62,5455.42,274793.55, 2389046.12, CLUŞ10RD,6300.00,5496.96,5534.76,274834.81, 2389090.87, CLUŞ10RD,6400.00,5576.30,5614.10,274876.06, 2389135.62, CLUŞ10RD,6500.00,5655.65,5693.45,274917.31, 2389180.36, CLUŞ10RD,6598.64,5733.91,5771.71,274958.01, 2389224.50, CLUŞ10RD,6600.00,5734.99,5772.79,274958.57, 2389225.11, CLUŞ10RD,6700.00,5815.93,5853.73,274998.24, 2389268.38, CLUŞ10RD,6800.00,5899.83,5937.63,275034.76, 2389308.69, CLUŞ10RD,6900.00,5986.45,6024.25,275068.03, 2389345.94, CLUŞ10RD,7000.00,6075.56,6113.36,275097.96, 2389380.02, CLUŞ10RD,7100.00,6166.91,6204.71,275124.47, 2389410.84, CLUŞ10RD,7200.00,6260.26,6298.06,275147.48, 2389438.31, CLUŞ10RD,7300.00,6355.34,6393.14,275166.93, 2389462.36, CLUŞ10RD,7400.00,6451.90,6489.70,275182.76, 2389482.92, CLUŞ10RD,7500.00,6549.68,6587.48,275194.94, 2389499.93, CLUŞ10RD,7520.66,6570.00,6607.80,275197.00, 2389503.00, CLUŞ10RD,7600.00,6648.14,6685.94,275204.60, 2389514.49, CLUŞ10RD,7700.00,6746.62,6784.42,275214.17, 2389528.98, CLUŞ10RD,7800.00,6845.10,6882.90,275223.75, 2389543.46, CLUŞ10RD,7900.00,6943.58,6981.38,275233.33, 2389557.95, CLUŞ10RD,8000.00,7042.06,7079.86,275242.90, 2389572.43, CLUŞ10RD,8100.00,7140.54,7178.34,275252.48, 2389586.92, CLUŞ10RD,8200.00,7239.02,7276.82,275262.06, 2389601.40, CLUŞ10RD,8300.00,7337.50,7375.30,275271.63, 2389615.89, CLUŞ10RD,8400.00,7435.98,7473.78,275281.21, 2389630.37, CLUŞ10RD,8500.00,7534.46,7572.26,275290.79, 2389644.85, CLUŞ10RD,8600.00,7632.94,7670.74,275300.36, 2389659.34, CLUŞ10RD,8704.64,7736.00,7773.80,275310.38, 2389674.50, Application: COMPASS5000.15 ReportDate: 08/09/2022 ReportTime: 16:46:20 Company: HilcorpAlaska,LLC SurveyCalculationMethod: MinimumCurvature Field/Project: KenaiC.I.U. GeodeticSystem: USStatePlane1927(Exactsolution) GeodeticDatum: NAD1927(NADCONCONUS) Ellipsoid: Clarke1866 Zone: AlaskaZone04 LocalCoŞordinateReference: Well Site: CanneryLoopUnit#1Pad Gridconvergence(+E/WŞ):Ş1.100066 SystemTVDReference: MeanSeaLevel North/AzimuthReference: True Well: Plan:CanneryLoopUnit10 WellEWMap: 272452.09 WellNSMap: 2388727.30 WellTVDreference: CLUŞ10RDAsŞBuilt KBabovesystem: 37.80 GLabovesystem: 19.80 Latitude: 60°31'56.843N Longitude: 151°15'48.374W Spuddate: 01/01/1990 Wellbore: CLUŞ10RD ParentWell: CanneryLoopUnit10 TieŞonDepth: 4120.00 Magneticmodel: BGGM2022 Magneticdate: 09/08/2022 Magneticdec(+E/WŞ): 14.54 Magneticfieldstrength: 55164.37 Magneticdip: 73.45 TotalAzimuthCorr(+E/WŞ): 14.54 Profile: CLUŞ10RDwp07 SurveyCompany: DatumElevation: 37.80 Surveydate: 01/01/1990 Totalsurveystations: 112 MDoffirstsurvey: 18.00 MDoflastsurvey: 8704.64 VerticalSectionOrigin: Slot VerticalSectionPlane: 70.00 DDI: &/85'ZS Station,MD,Inc,Azim.,SSTVD,TVD,N/S,,E/W,,Y,,X,,DLS,TFO,V.S.,V.S.A.H.,V.S.LAT,Commen t ,(ft),(Deg),(Deg),(ft),(ft),(ft),,(ft),,(ft),(ft),dega/100usft,(Deg),(ft),(ft),(ft) 1,18.00,0.00,0.00,Ş19.80,18.00,0.00,N, 0.00,E,2388727.296,N,272452.085,E,0.00,0.00,0.00,0.00, 0.00, 2,131.80,0.50,138.40,94.00,131.80,Ş0.37,S, 0.33,E,2388726.918,N,272452.407,E,0.44,138.40,0.18,0.50, 0.46,3_MWD(1) 3,192.80,0.10,330.20,155.00,192.80,Ş0.52,S, 0.48,E,2388726.763,N,272452.555,E,0.98,Ş178.04,0.27,0.82, 0.66, 4,253.80,0.30,33.20,216.00,253.80,Ş0.34,S, 0.54,E,2388726.941,N,272452.619,E,0.44,82.29,0.39,1.03, 0.51, 5,313.80,0.20,2.00,276.00,313.80,Ş0.11,S, 0.63,E,2388727.176,N,272452.713,E,0.28,Ş141.21,0.56,1.29, 0.32, 6,374.80,0.60,97.30,337.00,374.80,Ş0.04,S, 0.95,E,2388727.235,N,272453.035,E,1.07,113.15,0.88,1.72, 0.37, 7,434.80,0.70,121.70,396.99,434.79,Ş0.27,S, 1.57,E,2388726.991,N,272453.654,E,0.49,82.61,1.39,2.40, 0.80, 8,494.80,0.20,142.90,456.99,494.79,Ş0.55,S, 1.95,E,2388726.708,N,272454.024,E,0.86,171.98,1.64,2.87, 1.18, 9,553.80,0.60,110.90,515.99,553.79,Ş0.74,S, 2.30,E,2388726.509,N,272454.370,E,0.75,Ş45.83,1.91,3.28, 1.49, 10,614.80,0.80,121.20,576.98,614.78,Ş1.08,S, 2.96,E,2388726.161,N,272455.027,E,0.39,37.40,2.42,4.03, 2.03, 11,675.80,0.50,151.80,637.98,675.78,Ş1.53,S, 3.45,E,2388725.697,N,272455.508,E,0.74,145.45,2.72,4.72, 2.62, 12,736.80,1.30,111.20,698.97,736.77,Ş2.02,S, 4.22,E,2388725.197,N,272456.269,E,1.60,Ş60.07,3.28,5.68, 3.34, 13,799.80,1.40,114.60,761.96,799.76,Ş2.60,S, 5.59,E,2388724.593,N,272457.624,E,0.20,40.40,4.36,7.16, 4.35, 14,862.80,2.20,116.30,824.92,862.72,Ş3.45,S, 7.37,E,2388723.702,N,272459.391,E,1.27,4.67,5.75,9.14, 5.77, 15,925.80,3.60,112.60,887.84,925.64,Ş4.75,S, 10.28,E,2388722.351,N,272462.275,E,2.24,Ş9.47,8.04,12.33, 7.98, 16,989.80,5.10,109.30,951.66,989.46,Ş6.46,S, 14.82,E,2388720.552,N,272466.782,E,2.38,Ş11.12,11.72,17.18, 11.14, 17,1052.80,6.50,111.90,1014.33,1052.13,Ş8.72,S, 20.78,E,2388718.182,N,272472.689,E,2.26,11.92,16.54,23.55, 15.30, 18,1114.80,10.10,106.50,1075.67,1113.47,Ş11.57,S, 29.25,E,2388715.166,N,272481.103,E,5.93,Ş14.90,23.53,32.50, 20.88, 19,1178.80,12.70,104.20,1138.40,1176.20,Ş14.89,S, 41.45,E,2388711.613,N,272493.240,E,4.12,Ş11.05,33.86,45.14, 28.17, 20,1241.80,15.70,101.90,1199.47,1237.27,Ş18.35,S, 56.51,E,2388707.867,N,272508.228,E,4.84,Ş11.77,46.82,60.60, 36.57, 21,1303.80,18.30,100.70,1258.76,1296.56,Ş21.89,S, 74.28,E,2388703.989,N,272525.932,E,4.23,Ş8.26,62.32,78.72, 45.97, 22,1367.80,20.60,99.80,1319.10,1356.90,Ş25.67,S, 95.25,E,2388699.805,N,272546.825,E,3.62,Ş7.85,80.73,100.03, 56.70, 23,1430.80,23.00,99.80,1377.59,1415.39,Ş29.65,S, 118.31,E,2388695.381,N,272569.797,E,3.81,0.00,101.03,123.43, 68.33, 24,1493.80,25.20,101.80,1435.10,1472.90,Ş34.49,S, 143.57,E,2388690.059,N,272594.959,E,3.72,21.28,123.11,149.15, 81.51, 25,1556.80,28.30,100.70,1491.35,1529.15,Ş40.01,S, 171.38,E,2388684.010,N,272622.656,E,4.98,Ş9.57,147.36,177.50, 96.21, 26,1619.80,30.80,98.60,1546.15,1583.95,Ş45.19,S, 202.01,E,2388678.237,N,272653.177,E,4.29,Ş23.42,174.37,208.57, 111.56, 27,1683.80,32.60,99.50,1600.60,1638.40,Ş50.49,S, 235.21,E,2388672.305,N,272686.277,E,2.91,15.10,203.76,242.20, 127.89, 28,1743.80,32.10,99.50,1651.29,1689.09,Ş55.79,S, 266.88,E,2388666.399,N,272717.833,E,0.83,180.00,231.70,274.30, 143.70, 29,1806.80,31.80,99.30,1704.75,1742.55,Ş61.23,S, 299.77,E,2388660.324,N,272750.611,E,0.50,Ş160.65,260.75,307.64, 160.07, 30,1869.80,32.80,97.80,1758.00,1795.80,Ş66.23,S, 333.06,E,2388654.687,N,272783.796,E,2.03,Ş39.35,290.32,341.31, 176.15, 31,1948.80,33.66,98.23,1824.08,1861.88,Ş72.27,S, 375.92,E,2388647.826,N,272826.537,E,1.13,15.72,328.54,384.60, 196.48,133/8" 32,1998.80,34.20,98.50,1865.57,1903.37,Ş76.33,S, 403.53,E,2388643.235,N,272854.063,E,1.13,15.36,353.09,412.50, 209.74, 33,2123.80,34.20,96.40,1968.96,2006.76,Ş85.44,S, 473.19,E,2388632.791,N,272923.531,E,0.94,Ş90.87,415.43,482.76, 242.13, 34,2248.80,33.80,97.60,2072.59,2110.39,Ş93.95,S, 542.57,E,2388622.947,N,272992.727,E,0.62,121.30,477.71,552.66, 273.86, 35,2375.80,33.50,102.60,2178.33,2216.13,Ş106.27,S, 611.80,E,2388609.301,N,273061.707,E,2.19,98.26,538.56,623.04, 309.11, 36,2501.80,33.60,101.60,2283.34,2321.14,Ş120.87,S, 679.89,E,2388593.401,N,273129.498,E,0.45,Ş80.16,597.54,692.67, 346.12, 37,2628.80,33.50,101.60,2389.18,2426.98,Ş134.98,S, 748.64,E,2388577.971,N,273197.966,E,0.08,180.00,657.33,762.86, 382.89, 38,2753.80,33.90,100.60,2493.17,2530.97,Ş148.33,S, 816.70,E,2388563.319,N,273265.751,E,0.55,Ş54.63,716.71,832.22, 418.71, 39,2879.80,33.60,101.20,2597.94,2635.74,Ş161.57,S, 885.44,E,2388548.766,N,273334.220,E,0.36,132.24,776.78,902.22, 454.66, 40,3006.80,33.70,100.20,2703.66,2741.46,Ş174.63,S, 954.58,E,2388534.377,N,273403.101,E,0.44,Ş80.19,837.29,972.59, 490.59, 41,3132.80,33.60,100.20,2808.55,2846.35,Ş187.00,S, 1023.30,E,2388520.697,N,273471.564,E,0.08,180.00,897.63,1042.41, 525.71, 42,3195.80,32.90,100.40,2861.23,2899.03,Ş193.17,S, 1057.28,E,2388513.870,N,273505.423,E,1.12,171.18,927.45,1076.95, 543.13, 43,3258.80,32.20,100.00,2914.34,2952.14,Ş199.18,S, 1090.64,E,2388507.228,N,273538.660,E,1.16,Ş163.08,956.75,1110.85, 560.19, 44,3320.80,30.90,100.50,2967.17,3004.97,Ş204.95,S, 1122.57,E,2388500.846,N,273570.465,E,2.14,168.83,984.77,1143.29, 576.53, 45,3382.80,29.50,99.60,3020.75,3058.55,Ş210.39,S, 1153.27,E,2388494.811,N,273601.060,E,2.37,Ş162.47,1011.76,1174.47, 592.15, 46,3444.80,28.00,99.80,3075.11,3112.91,Ş215.42,S, 1182.67,E,2388489.224,N,273630.351,E,2.42,176.42,1037.67,1204.30, 606.92, 47,3507.80,27.40,99.60,3130.89,3168.69,Ş220.35,S, 1211.53,E,2388483.737,N,273659.116,E,0.96,Ş171.28,1063.11,1233.58, 621.43, 48,3570.80,26.60,100.30,3187.02,3224.82,Ş225.29,S, 1239.71,E,2388478.257,N,273687.186,E,1.37,158.65,1087.89,1262.18, 635.71, 49,3632.80,26.10,100.50,3242.58,3280.38,Ş230.26,S, 1266.77,E,2388472.772,N,273714.151,E,0.82,170.02,1111.62,1289.70, 649.63, 50,3695.80,26.00,102.70,3299.18,3336.98,Ş235.82,S, 1293.87,E,2388466.691,N,273741.136,E,1.54,96.90,1135.19,1317.37, 664.13, 51,3758.80,25.80,105.30,3355.86,3393.66,Ş242.47,S, 1320.57,E,2388459.527,N,273767.698,E,1.83,101.16,1158.00,1344.89, 679.51, 52,3822.80,25.50,105.40,3413.55,3451.35,Ş249.81,S, 1347.28,E,2388451.682,N,273794.266,E,0.47,171.83,1180.59,1372.59, 695.54, 53,3885.80,25.20,104.90,3470.48,3508.28,Ş256.86,S, 1373.32,E,2388444.134,N,273820.161,E,0.58,Ş144.71,1202.65,1399.56, 711.07, 54,3946.80,25.20,104.70,3525.68,3563.48,Ş263.49,S, 1398.43,E,2388437.019,N,273845.138,E,0.14,Ş90.09,1223.97,1425.53, 725.89, 55,4010.80,25.20,105.00,3583.59,3621.39,Ş270.47,S, 1424.77,E,2388429.531,N,273871.338,E,0.20,90.14,1246.34,1452.78, 741.46, 56,4073.80,24.50,103.90,3640.75,3678.55,Ş277.08,S, 1450.40,E,2388422.430,N,273896.841,E,1.33,Ş147.06,1268.16,1479.26, 756.44, 57,4120.00,24.13,103.53,3682.86,3720.66,Ş281.59,S, 1468.88,E,2388417.566,N,273915.230,E,0.87,Ş157.90,1283.99,1498.28, 767.00,KOP:12.3º/100':4120'MD,3720.66'TVD:30°LTTF 58,4125.00,24.66,102.79,3687.41,3725.21,Ş282.06,S, 1470.89,E,2388417.058,N,273917.231,E,12.30,Ş30.27,1285.72,1500.35, 768.13,3_MWD_InterpAzi+Sag(2) 59,4137.00,25.94,101.06,3698.26,3736.06,Ş283.12,S, 1475.91,E,2388415.904,N,273922.227,E,12.30,Ş30.72,1290.07,1505.48, 770.84,EndDir:4137'MD,3736.06'TVD 60,4157.00,25.94,101.06,3716.24,3754.04,Ş284.80,S, 1484.50,E,2388414.061,N,273930.779,E,0.00,0.00,1297.56,1514.22, 775.35,StartDir3º/100':4157'MD,3754.04'TVD 61,4200.00,25.80,98.12,3754.94,3792.74,Ş287.93,S, 1502.99,E,2388410.579,N,273949.209,E,3.00,Ş97.52,1313.87,1532.99, 784.62, 62,4300.00,25.71,91.22,3845.02,3882.82,Ş291.46,S, 1546.23,E,2388406.213,N,273992.369,E,3.00,Ş94.87,1353.29,1576.44, 802.73, 63,4400.00,25.94,84.35,3935.06,3972.86,Ş289.77,S, 1589.69,E,2388407.072,N,274035.851,E,3.00,Ş88.65,1394.71,1620.00, 816.00, 64,4500.00,26.49,77.67,4024.79,4062.59,Ş282.85,S, 1633.25,E,2388413.152,N,274079.537,E,3.00,Ş82.47,1438.01,1664.17, 824.40, 65,4600.00,27.34,71.31,4113.98,4151.78,Ş270.73,S, 1676.80,E,2388424.437,N,274123.307,E,3.00,Ş76.47,1483.08,1709.44, 827.90,3_MWD+IFR1+MS+Sag(3) 66,4700.00,28.45,65.35,4202.37,4240.17,Ş253.43,S, 1720.21,E,2388440.897,N,274167.041,E,3.00,Ş70.80,1529.79,1756.22, 826.49, 67,4800.00,29.81,59.85,4289.74,4327.54,Ş231.01,S, 1763.37,E,2388462.487,N,274210.618,E,3.00,Ş65.53,1578.01,1804.90, 820.18, 68,4900.00,31.38,54.82,4375.83,4413.63,Ş203.52,S, 1806.15,E,2388489.146,N,274253.920,E,3.00,Ş60.73,1627.62,1855.79, 808.99, 69,5000.00,33.12,50.25,4460.41,4498.21,Ş171.05,S, 1848.44,E,2388520.802,N,274296.828,E,3.00,Ş56.40,1678.47,1909.15, 792.94, 70,5100.00,35.02,46.10,4543.25,4581.05,Ş133.67,S, 1890.13,E,2388557.369,N,274339.224,E,3.00,Ş52.53,1730.42,1965.17, 772.07, 71,5200.00,37.04,42.33,4624.13,4661.93,Ş91.50,S, 1931.10,E,2388598.746,N,274380.992,E,3.00,Ş49.09,1783.35,2023.99, 746.45, 72,5221.41,37.49,41.57,4641.17,4678.97,Ş81.86,S, 1939.77,E,2388608.219,N,274389.843,E,3.00,Ş46.04,1794.79,2036.96, 740.36,EndDir:5221.41'MD,4678.97'TVD 73,5300.00,37.49,41.57,4703.52,4741.32,Ş46.07,S, 1971.51,E,2388643.387,N,274422.264,E,0.00,0.00,1836.85,2084.79, 717.59, 74,5400.00,37.49,41.57,4782.87,4820.67,Ş0.54,S, 2011.90,E,2388688.135,N,274463.518,E,0.00,0.00,1890.38,2145.66, 688.61, 75,5500.00,37.49,41.57,4862.21,4900.01,45.00,N, 2052.29,E,2388732.883,N,274504.772,E,0.00,0.00,1943.91,2206.52, 659.64, 76,5565.27,37.49,41.57,4914.00,4951.80,74.72,N, 2078.65,E,2388762.090,N,274531.699,E,0.00,0.00,1978.85,2246.25, 640.73,TopCINGSA 77,5600.00,37.49,41.57,4941.56,4979.36,90.53,N, 2092.68,E,2388777.631,N,274546.027,E,0.00,0.00,1997.43,2267.39, 630.67, 78,5700.00,37.49,41.57,5020.90,5058.70,136.06,N, 2133.06,E,2388822.379,N,274587.281,E,0.00,0.00,2050.96,2328.25, 601.69, 79,5800.00,37.49,41.57,5100.24,5138.04,181.60,N, 2173.45,E,2388867.127,N,274628.535,E,0.00,0.00,2104.49,2389.12, 572.72, 80,5817.34,37.49,41.57,5114.00,5151.80,189.49,N, 2180.46,E,2388874.886,N,274635.688,E,0.00,0.00,2113.77,2399.67, 567.70,BaseCINGSA 81,5900.00,37.49,41.57,5179.59,5217.39,227.13,N, 2213.84,E,2388911.875,N,274669.789,E,0.00,0.00,2158.02,2449.98, 543.75, 82,6000.00,37.49,41.57,5258.93,5296.73,272.66,N, 2254.23,E,2388956.623,N,274711.043,E,0.00,0.00,2211.54,2510.85, 514.77, 83,6080.75,37.49,41.57,5323.00,5360.80,309.43,N, 2286.85,E,2388992.757,N,274744.357,E,0.00,0.00,2254.77,2560.00, 491.38,UB4 84,6100.00,37.49,41.57,5338.27,5376.07,318.20,N, 2294.62,E,2389001.371,N,274752.298,E,0.00,0.00,2265.07,2571.71, 485.80, 85,6200.00,37.49,41.57,5417.62,5455.42,363.73,N, 2335.01,E,2389046.119,N,274793.552,E,0.00,0.00,2318.60,2632.58, 456.82, 86,6300.00,37.49,41.57,5496.96,5534.76,409.27,N, 2375.40,E,2389090.867,N,274834.806,E,0.00,0.00,2372.12,2693.44, 427.85, 87,6400.00,37.49,41.57,5576.30,5614.10,454.80,N, 2415.79,E,2389135.615,N,274876.060,E,0.00,0.00,2425.65,2754.31, 398.88, 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