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Home My WebLink About222-0021a. 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): North Trading Bay Unit GL: N/A BF: N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22. Logs Obtained: 23. BOTTOM N/A 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 N/A 664' FSL, 566' FEL, Sec 34, T10N, R13W, SM, AK 66 Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl:Flow Tubing Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: N/A Gas-Oil Ratio: AMOUNT PULLED N/A 224244 TOP SETTING DEPTH MD suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary PACKER SET (MD/TVD) BOTTOMCASINGWT. PER FT.GRADE CEMENTING RECORD N/A SETTING DEPTH TVD 2527330 TOP HOLE SIZE N/A N/A 5,115' MD / 3,920' TVD N/A 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 218864 2523116 50-733-20064-02-00April 10, 2022 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 3/24/2023 222-002 N/A TBU A-10RD2May 20, 20221602' FSL, 550' FEL, Sec 4, T9N, R13W, SM, AK 101' Trading Bay Undefined Gas Pool ADL 18731, 392195, 17597 11,276' MD / 6,852' TVD 5,115' MD / 3,920' TVD 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 N/A SIZE DEPTH SET (MD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. WINJ Suspended AbandonedSPLUG Other Stratigraphic Test No No (attached) No Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 2:07 pm, Jun 09, 2023 Abandoned 3/24/2023 JSB RBDMS JSB 060923 xGDSr-6/21/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval N/A 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: Wellbore Schematic, 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. INSTRUCTIONS Tyonek D2 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. 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 No NoSidewall Cores: Yes No Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov For Monty Myers Digitally signed by Cody Dinger (2323) DN: cn=Cody Dinger (2323) Date: 2023.06.09 13:38:34 - 08'00' Cody Dinger (2323) _____________________________________________________________________________________ Updated By: CJD 6/9/2023 P&A SCHEMATIC North Trading Bay Unit Well: A-10RD2 PTD: 222-002 API: 50-733-20064-02-00 Cement Detail Item PB1 5-5-22 From 9510’ MD Pumped 9.1 bbls 16.5# cmt, TOC @ 9209’ MD 5-6-22 From 9179’ MDPumped 20 bbls 17.0# cmt, TOC 8850’ MD Suspension 5-22-22 Pumped 48 bbls 15.3 ppg Class G, thru cmt retainer @ 8,250’ MD, 10 bbls of cmt on top of retainer. TOC tagged hard at 7,969’ (PB depth) CASING DETAIL Size Wt Grade Conn ID Top Btm 20”Conductor Pile Surface ~264’ 13-3/8”61 K-55 BTC 12.515”Surface 1,095’ 9-5/8”47 L-80 DWC/C 8.681” Surface 5,115’ (TOW) 7”29 L-80 CDC HTQ 6.125”(SD)5,528’8,325’ TUBING DETAIL 4-1/2”12.6 L-80 IBT 3.958”Surface 548’ JEWELRY DETAIL No Depth (MD) Depth (TVD)Item 1 5,115’3,920’Whipstock 2 5,145’3,935 Tripoint Packer Activity Date Ops Summary 3/1/2023 install walkway to rig cellar, rig up glycol lines to rig, stow 4 knack box's under heliport and shovel snow from same.;Last chopper load of Enterprise crew arrived at 11:30hrs. Orient all crew to Monopod and hold Hilcorp expectation meeting and pre-job. Conduct walk thru with Co.Men, crew and Pushers on work needing completion.;Install new shortened bleed off line in cellar, remove mud bucket hose. Pull hand rails on back of sub. Set strong backs for cement silo's and 500bbl tanks from boat. Install HP mud line to sub, LP mud line to sub and turn on Glycol to sub and check for leaks and fix same.;Blow air thru deluge system and make sure lines and jets are clear. Install deluge line to sub. Set fork lift in dry sack room. Hang power cable for vac-unit. Shovel snow from rig floor.;Rest crews. 3/2/2023 Fix glycol heater under hopper rm. Chip ice from water flood roof and spot Top Drive VFD and hyd. unit. Spot slop tank in cellar and blow air thru each drain hose, rig up diaphragm pump and pump out same. Cont. shovel rig floor and pipe deck.;Send cutting box tank stand to weld shop for modification. Rig up jet heater to thaw out mud ditch with flow lines froze in them. Spot cuttings tank stand, clean and power up elect/mechanics shops.;Install 10" air boot and plug in shaker water base ditch. Thaw shaker and koomey hoses with jet heater, shovel off pits. Service and inspect used choke and kill hoses from steelhead and install cover plates on same and ready for back load to DW. Unable to get a boat today due to 404 rig move.;Use jet heater to thaw 2 more boxes of koomey hoses. Change out fitting and install glycol heater behind drill console. Install flow line from poor boy and well to mud ditch and hook up ground lines. Pull cover on rotary table traction motor, pull desiccant packs, install brushes and armatures.;Rest crews... 3/3/2023 Work boat: Off load top drive connex, cement silo, centrifuge, centrifuge VFD, stand alone transfer pump, back-up choke/kill hoses and misc. cargo. Back load misc. over packs, steelhead old choke/kill hoses, oily waste totes.;Hand reported getting water in his ear on the 1st March and sent to beach to get it cleared before going to 151 to assist on their rig up. Hand was cleared for work without restrictions and the incident was classified as a first aid on HAK report.;Spot cement silo, cross chain to strong back and weld dwn same. Spot jet heater in cellar to cont. heat up rig and Top Drive VFD. Install koomey line in cellar.;Spot centrifuge, centrifuge VFD and stand alone transfer pump. Install mouse hole, spot back-up choke/kill hoses in cellar. Cont. installing koomey hoses.;Boat un- able to retrieve man camp from Baker Platform do to weather.;Install hand rails on strong back for 500bbl tank. Install catwalk under beaver slide. Spot vac shock/cuttings tanks. Meg all electric motor except mud pumps, and checked all brushes and armatures. Start draining choke manifold.;Rest crews.... 3/4/2023 Finish installing koomey lines, dress mud pump #1, install blank on J-tube overboard line from shakers. Start hanging SRL's on rig and start to rig up vac unit lines. Finish Megging electric motors on mud pumps and check brushes and armatures. Install bleeder on driller glycol heater.;Finish hanging SRL's on rig and draining choke manifold oil. Welder building manifold for vac unit, begin wiring MWD,centrifuge VFD and stand-alone transfer pump.Well head hand set BPV and check pressures,ann/tubing 0/0, 13-3/8"-85, surf pipe-87psi. Derrick inspection.;Work Boat: Off-load 500bbl tank and spot, empty 2ea. ISO's of diesels, hydril, single gate, dbl gate, riser pipe, BOP lifter and mud cross w/choke and kill valves. Misc. cargo.;Rest crews... 3/5/2023 Safe out RPM tank w/hand rails and ladder. Empty hopper rm of hoses and lay out on top RPM tank.Dress #1pump and start on #2. Finish welding vac. hose manifold and install fittings. Install bridge from rig to top of water flood for access to VFD and HPU.;Cont. hook up power/comms to MWD shack, centrifuge and transfer pump.;Turn centrifuge 180 and install new dump shoot. R/U suction/discharge lines from RPM tank to transfer pump, pits and reserve pit. Inspectors from All-Rigs started inspecting derrick.;Held muster and abandon platform drill with all personnel, then held post drill meeting to discuss any issues (12min.).;Rest crews... 3/6/2023 Install hand rails were we could, welder working on the rest. Power up man camps, spot porta-john and clean up deck around weld shot. Cont. house keeping in drilling area's-pits, pipe deck and cellar. Spot top drive connex next to man camp.;Start plumbing vac lines to rig cellar and building manifold. Hand Canrig, Sperry and camera screens at driller's console. Install camera in cellar. Finish installing new centrifuge dump line.;Finish hanging service lines to to top drive VFD and hyd. unit and plug in same. Load Master finished derrick inspection, waiting on report. All Rig still performing MPI's and sling inspections. finish vac line plumbing to rig cellar and floor.;Welder starting to install handrail and stiff arm on centrifuge unit. C/o cable on manrider/winches and air tugger.;Rest crews... 3/7/2023 Plumbed: 2" base oil line f/deck t/top of pits, 3" suction t/centrifuge feed pump and 2" discharge valve w/blow down, 6" centrifuge under flow t/4" discharge hose into pits. Centrifuge Rep. commissioned unit-good.;House keeping in all drilling area's. CanRig rep. on location taking inventory and laying out equipment for rig up. Install 26" elephant trunk duct from rig drawworks motors t/water flood. CCI welder cont. installing hand rail and strong arm for cuttings vac hose.;Stack mud- X on single gate and install lifter. Mechanic discovered oil in the glycol reservoir from the oil cooling coil, pulled oil coil and pressure tested, leaking at bulk head fitting, removed and cleaned fittings and re-installed with sealant-letting dry until tomorrow.;Drained glycol to re-use in draw works cooler and drained oil for pickling choke manifold on stack out. oil and glycol will be on tomorrows boat. Enterprise welder working on bridge and stairs to RPM tank.;Safety audit from Main office went well no major issues: cellar stair, forklift seat belt, bridge /stairs t/RPM tank-WIP and PPE locker.;Rest crews.... 3/8/2023 CanRig cont. R/U, Run DWKs-checked COM, crown saver, brake cooler and Dyno. Dyno kept tripping in drill mode and had a burnt card, installed spare-tested good. Hung last SRL at the crown. Removed old service loop wrap.;Welder finished mid-rails on strong arm rail, hung splitter for cutting box and pump rm w/valves. Hung shaker vac hose on strong arm w/chain fall. Install 2" centrifuge feed line to unit. Wired up power to centrifuge feed pump.;Welder working on man camp roof hand railing, 2nd welder finished bridge stairs to RPM tank. Pull dry hole tree from A10-RD3 and install HP riser, single gate and mud-X. Start install of new service loop.;Work boat- get rid of back load to free up deck space for pipe tomorrow. Off-load from boat -ST-80, ISO32 hyd. oil, glycol, test jts/pups, bails, trash pumps, ST-80 tool box and DSA.;Rest crews... n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: TBU A-10RD3 Trading Bay North Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:231-00045 TBU A-10RD3 Drilling Spud Date: 3/9/2023 Cont. CanRig R/u. Welders working on hand rails on man camp and ladder on RPM tank. Crane hoses from RPM tank to pipe deck and lay out for fill up line and vac. Quadco rep. on board for gauge calibrations. Fill Top Drive Hyd. unit w/oil and cooling tank w/glycol, purge out air in hyd. lines.;Install new service line and new wrap for same. Rig electrician pulled away to rig 151-lost heat; all wire connections work stopped until return. R/U 2-50ft 3" fill up lines for Base oil and reserve tanks. Hung 3" hose to pump room and cuttings box.;Clear west pipe deck for Drill pipe coming on boat. Set iron ruff neck on rig floor, no pedestal-on boat. Work on DS tongs-froze up. Prep DSA's, manual valves, HCR's and Choke/kill hoses for install.;Welders finish hand rails on man camp. Quadco rep. finished gauge calibration.;Rest crews...work boat-off load Iron ruff neck base, 174jt 4.5"DP, DC and HW. Take on water.;Rest crews... 3/10/2023 Replace all 3 multiple hose fill up lines w/new 3"-50ft hoses to base oil, reserve tank and RPM tank. Remove off-set from iron ruffneck pedestal and instal on ruff neck. Install ruffneck on rig floor and check all functions-good. Install torque gauge in drillers console. Fixed Dyno-Matic;Free up ODS frozen tong. Welders working on 6" mud bucket line and drillers console screen mount. Run test pump, c/o 1/4 turn valves and order parts.;Clean RPM tank of debris. Welder finish drillers console screen mount. Start commissioning TOP Drive-pipe handler function working, link tilt working, no rotation-just rocking back n forth. Set brake and rocking stops as if brake is holding.;Cont. trouble shoot: Got top drive to spin in drill, increased to 35rpm then it faulted out VFD with many codes....cont. trouble shoot. Remove bell guide air boot and 1/2 moon plates f/rig floor t/cellar.;Simop-N/U BOPs-move all manual and HCR valves into cellar and install both manuals and 1 HCR. Start working boat off-loading OBM.;Finish working boat-off loading OBM @1900hrs. Rest crews... 3/11/2023 Call NOV and start process for tech consultation on top drive-waiting on call back. Rig mech/electrician powered up system and top drive operated like it is supposed to forward/reverse etc.. Shut down and repeat-good, M/U and B/O subs w/grabber-good- Top Drive commissioned.;Commission Iron ruffneck: spin subs in.out and trq same, break out subs and compare trq readings on unit to console-good. N/U BOP's-HCR, DSA's. Dress mud pump #2 with seats and valves. Install duct on DWKs.;Cont. N/U BOP's-choke/kill hoses, DBL Gate, Annular. Free up under flow risers in mud pits and replace winch. Close up pits bulk head. Test reserve tank agitators and transfer pump.;Test Degasser and pit agitators, tested RPM tank agitators and transfer pump. Hang all hoses on top of RPM tank on hand rails.;Rest crews..... 3/12/2023 Torque up BOP's, Paint mud bucket line. Repair hydraulic leak on iron ruffneck. Clean out dry sack/pump room for mud product. Grease all agitator, pumps and motors.;Fill pill pit #1 and #2 w/60bbls sea water and transfer fluid to reserve pit #4, trip tank, RPM tank #1, RPM tank #2 and active pits to confirm system containment integrity, c/o leaky valves. Clean and organize pipe deck. Install 6" mud bucket hose under rig floor. Cont. torquing BOP's.;Rest crew....Boat scheduled for 2300hrs with mud product and OBM... 3/13/2023 Finish torquing up BOP's and side outlet lines. Install drylocks on BOP's and hook up koomey lines. Received 84bbls OBM into reserve pit #4. Transfer OBM from RPM tank #3 to active pit #1 and #2 and treat same.;Pressure up accumulator and check for leaks, function test same from unit. Grease choke manifold. Set Bell nipple air boot flange on annular. Work boat.;Open doors pull top 2-7/8 x 5-1/2 var. rams and inspect/compare seals with bottom 2-7/8 x 5-1/2 var rams- take measurements and pic's, stamp lower rams with UOCD #'s and correct size (mis-labled from vendor) re-install both top/bottom rams and re-torque doors.;P/U bails and install on top drive, pressure up koomey and function test from both remotes. Cont. treat mud and work boat. M/U 4.5" test jt. set and fill stack w/water for shell test, set mouse hole and bring subs, slips and elevators to floor. set half moons around stack and mouse hole.;Replace shaker bed rubber and dress shaker... 3/14/2023 Troubleshoot and repair test pump - changeout valve and regulator.;BOP pressure assurance tests: shell test against annular with 4.5" test joint 250/3500 psi - good test. Pressure test against UPR with 4.5" test joint 250/5000 psi;Held Pre-Spud meeting with Drill crews, Production crews, and Hilcorp representatives - CIO Area Operations Manager, Drilling Manager, Drilling Engineer, Reservoir Engineer, Geologist, Safety and DSMs in attendance.;Resume BOP pressure assurance tests. Troubleshoot Top Drive link-tilt, pipe handler and IBOP functions: issue with pump on Top Drive HPU - remove and send in for repairs.;Function IBOP manually and continue with BOP pressure assurance tests. Troubleshoot and retorque connections on stack. Work boat and offload 2 iso's base oil (DrillSol) and scraper assembly. Troubleshoot and remove seized pump on reserve pit. Troubleshoot and repair regulator on test pump.;Hook up rig HPU to top drive and function test pipe handler, IBOP and link-tilt - good.;Continue to chase leaks on BOP pressure assurance tests. Isolate Lower Kelly Valve on Top Drive - leaking. Grease and function choke manifold valves. Observe leak at open casing valve. Build and condition mud per mud engineer.;Continue to build and condition mud per mud engineer. Clear ice from reserve tank suction line and centrifugal pump. Blow down top drive and test equipment. 3/15/2023 Continue with BOP pressure assurance testing. Test UPR and LPR with both 4.5" and 5" test joints 250/5000 psi. Continue to build and condition mud. Thaw, repair and replace centrifugal pump on reserve pit. Sperry DD and MWD, rig up shack and strap tools.;Remove and replace lower IBOP on top drive. Yellow Jacket rep pull and replace lower pipe ram shaft seal. Continue to build and condition mud. Spot and rig up Sperry GeoSpan.;Pressure test LPR to 5000 psi and verify ram shaft seal and door seal holding. Transfer mud from Pits 1 & 2 to Reserve. Transfer Base oil to Pits 1 & 2 and resume building mud. Send out 48hr notice to AOGCC for initial BOP test. Strap 4.5" drill pipe on deck. 3/16/2023 Continue to build and condition mud. Blow down and rig down test hoses and test equipment. Blow down top drive and clear rig floor of test equipment. Assist Sperry and install plumbing for GeoSpan. Change out bladder on accumulator bottle #4. Install bell nipple and turnbuckles on stack.;Continue to build and condition mud. Install drip pan above annular. Rig up ropes and belly belts in derrick. Continue to work on rig acceptance checklist.;Continue to build and condition mud. Continue to work on rig acceptance checklists. General housekeeping throughout rig - re-route hoses to reduce trip hazards. Clean out hydraulic reservoir for top drive HPU.;Continue to build and condition mud. Continue to work on rig acceptance checklists. General housekeeping throughout rig. 3/17/2023 Continue to work on rig acceptance checklist. General housekeeping - work on organizing rig floor and cellar areas.;Continue to work on rig acceptance checklist. Dress mud bucket and modify outlets to fit return line. Install glycol heat lines on mud pump jumper hose. General housekeeping - continue to organize rig floor and prep to pick up drill pipe.;Held PJSM with rig crew prior to picking up and racking back 4.5" drill pipe. Driller found 4.5" elevators were mis-marked.;Strap, tally pick up and rack back 4.5" drill pipe in derrick.;Lost power to rig - standby while production crew troubleshot issue and got power back on. Restart agitators in pits and check equipment.;Strap, tally pick up and rack back 4.5" drill pipe in derrick.;Rig up to test BOPE. Install 4.5" test joint and make up test assemblies. 3/18/2023 Rig up to test BOPE. Purge air from system and perform shell test while waiting for AOGCC rep Adam Earl to arrive on location.;Test BOPE per Hilcorp / AOGCC 250/5000 psi for 5/5 charted min each. Test Annular to 250/3500 psi for 5/5 charted min. Tests #1-8 performed with 4.5" test joint. Test gas alarms: 1 FP- change out head and re-tested good. Perform drawdown test - good.;Troubleshoot BOP test. Replace stem packing on Choke HCR. CMV #4 re-grease valve. Top Drive Lower Kelly Valve Adjust Torque Fenner ring and re-grease.;Troubleshoot leak during blind ram test: Tighten HCR Shoke Stem Protector. Changeout leaking grease zerk on CMV #4. Troubleshoot test manifold and replace 2 leaking valves and a plugged needle valve.;Test Upper and Lower VBRs with 5" test joint 250/5000 psi for 5/5 charted min. Test #2 FOSV and Upper and Lower Kelly valves on top drive - good tests. Attempt to work boat - high wind and seas, unable to offload.;Pull and lay down 5" test joint and rig up to re-test blind rams.;While attempting to test blind rams, observed issue with accumulator tri-plex. Found packing on inner plunger on pump #1 had come apart. Repair pump and replace packings on all 3 plungers. Work boat that was loaded on 3/17 and had been on weather hold. 3/19/2023 Continue to repair accumulator pump. Work boat that was loaded on 3/17 and had been on weather hold.;Complete BOPE test. Test blind rams 250/5000 psi or 5/5 charted min.;Install riser and flow line down to stack. Pull bell nipple and replace leaking air boots. Install gasket and re-seal rotary pan. Change out regulator on accumulator.;Calibrate block heights with CanRig and Sperry MWD. Prep rig floor for picking up 4.5" drill pipe.;Strap, tally, pick up and rack back remainder of 4.5" CDS40 drill pipe in derrick.;Flush all surface lines and pressure test mud lines to 3000 psi with water.;Change handling equipment. Pick up Sperry ADR and break. Lay down to deck in 2 sections to allow MWD to reset battery.;Assist Vault Wellhead rep. Retrieve blanking sub and lay down. Pick up dry-rod and retrieve BPV and lay down. Make up landing joint, XO's to tubing hanger and FOSV.;Rig up Parker Wellbore tongs and 4.5" tubing handling equipment. Vault Wellhead rep back out lock down screws on tubing hanger.;Make up landing joint into hanger and rig up trip tank. Fill stack and assess leaks on low pressure riser. Work boat - offload additional mud product.;Pull hanger off seat at 45 Klbs pull free to floor at 34 Klbs. Lay down landing joint and hanger with 6.81' hanger pup.;Pull and lay down 4.5", 12.6# IBT Kill string - recovered 16 full joints, 1 muleshoe, 6.81' hanger pup and hanger.;Rig down and Parker Wellbore tongs and handling equipment and clear rig floor. Rig up to repair leaks on low pressure riser.;Mobilize casing scraper BHA to rig floor. Replace leaking air boots on low pressure riser.;Pick up and run in the hole with 8.5" casing scraper assembly. 3/20/2023 Run in the hole and set wear ring. Run in 2 lockdowns, pull out of the hole and lay down running tool.;Work boat - offload additional 5" drill pipe and WTT tools. Install pollution pan under rig floor.;Mobilize WTT tools and NRPs to rig floor. Verify NRP placement on 5" drill pipe.;Hold PJSM with rig crew, DD, WTT and crane crew on picking up BHA and 5" drill pipe from deck. Make up and run in the hole with bit, scraper and 6.5" drill collars to 100' MD.;Hold fire and platform abandonment drill with all personnel on platform.;Finish picking up and running in the hole with casing scraper assembly to 287'. Monitor well with trip tank while running in - correct displacement.;Run in the hole with casing scraper assembly, picking up 5" drill pipe off deck to 1449'. Install 2 NRP's per joint with WWT per plan. Monitor well with trip tank while running in - correct displacement.;Work boat with crane crew. Perform trip drill with rig crew and work through derrick rescue drill and manrider hydraulic failure. Free up rotary locks and organize NRP's on rig floor. Walk drill crew through pit light water system and rig deluge system.;Continue to trip in the hole with scraper assembly, picking up 5" drill pipe and installing 2 NRP's per joint with WTT to 2195'. Monitor well with trip tank while running in - correct displacement.;Work boat with crane crew - offload and empty 1 Iso of base oil to pits. Organize and mobilize additional NRPs to rig floor. Walk drill crew through pit light water system and rig deluge system.;Continue to trip in the hole with scraper assembly, picking up 5" drill pipe and installing 2 NRP's per joint with WTT to ~3000'. Monitor well with trip tank while running in - correct displacement. 3/21/2023 Continue to trip in the hole with scraper assembly, picking up 5" drill pipe and installing 2 NRP's per joint with WTT to 3290'. Monitor well with trip tank while running in - correct displacement.;While filling pipe, H2S sensor at the bell nipple alarmed with 25 ppm. Shut in well and all personnel mustered. Notifications were made. Plan to run in the hole and circulate the well over to FIW.;Continue to trip in the hole with scraper assembly, picking up 5" drill pipe and installing 2 NRP's per joint with WTT to 4333'. Monitor well with trip tank while running in - correct displacement.;Continue to trip in the hole with scraper assembly, picking up 5" drill pipe and installing 2 NRP's per joint with WTT to 5273'. Monitor well with trip tank while running in - correct displacement.;Rig down WTT NRP equipment from rig floor. Strap and tally 5" HWDP on deck. Change gear oil and oil filters on top drive. Troubleshoot gear oil pump pressure issue.;Pick up 5" HWDP and continue in the hole. Tag top of liner with 5 Klbs at 5531'. PU 160 Klbs, SO 90 Klbs.;Trip out of the hole F/ 5531' T/ 5273' and rack back 5" HWDP stands.;Trip in the hole picking up 5" HWDP F/ 5273' T/ 5456' and then stand back in derrick.;Change handling equipment, strap and tally 4.5" HWDP and rack back in the derrick (4 stands);Re-position pollution pan in cellar and secure. Move jacking HPU out of cellar area and square up Jet heater on strong back. Clear drain line under pipe racks.;Displace well to clean FIW. PJSM with production crew and walk shipping lines. 3/22/2023 Continue displace well to fresh FIW taking returns to production @ 2 bpm and total of 600 bbls;Adjust fluid level in TDS. Calibrate block height. Commission auto driller, service TDS, DWK, blocks and crown. Check stroke counter on #2 mud pump and rod wash mtr failed. Work on Swaco stroke counter and Elmago brake controller. Charge pump #1 mech seal failed. Work boat.;Pooh rack back 5" dp F/ 5456' T/ 287' while monitoring well on trip tank. New rod wash motor arrived on helicopter.;Pull and rack back 6.5" drill collars. Lay down bit and scraper assembly. Work on replacing rod wash motor.;Replace check valve on accumulator. Rebuild leaking blind ram 4-way valve on accumulator. Adjust bails and Fenner ring on top drive. Replace rod wash motor. Run lines from Mud Pump #2 to shipping header for displacement.;Pick up and make up 9-5/8" x 3-1/2" Model D Packer with Tripoint rep. Mobilize additional NRP's to rig floor and stage for trip in the hole.;Trip in the hole with Model D packer on 5 stands of 5" HWDP from derrick. Continue to trip in the hole on 5" DP, adding 2 NRP's per joint on the first 3 stands. Adjust additional NRP's on trip in. Monitor well on trip tank for proper displacement. At ~ 4000'. 3/23/2023 Continue Rih slow w/ Tri-point 9-5/8" CIBP f/ 4000' t/ 5440' and Finish adjusting and installing NRP's;Establish parameters Up/dn 145k/100k and drop 1" ball let fall for 30 min bring pump on line w/ no ball seat dn pump and wait additional 10 min bring pump on line w/ ball on seat and stage up pressure t/ sheer out @ 3350 psi p/up and re-tag w/ 35k w/ Top of CIBP @ 5440' DPM;Prep for OBM chg over;PJSM w/ all involved and displace well f/ FIW t/ 9.5 ppg OBM @ 3.5 bpm @ 450 psi and taking FIW returns to production and catching spacer in trip tanks;Continue and finish rebuild of pump on centrifugal transfer pump @ pill pit. While finishing prepping rig floor for OBM and clean water out of pits and transfer spacer to RPM pit #3. Work boat. Circulate 3x hole volume to shear mud stage up to 450 gpm, 2400 psi. Build and pump slug prior to pulling.;Complete rig acceptance checklist.;Trip out of the hole F/ 5400' T/ 3085', wiping pipe and cleaning OBM from NRP's on trip out. Monitor well with trip tank and hole fill for proper fill.;Repair service loop sleeve. Clean rig floor and place absorb on walkways to help mitigate tracking OBM throughout platform.;Continue to trip out of the hole F/ 3085' T/ 1935' at time of report, wiping pipe and cleaning OBM from NRP's on trip out. Monitor well with trip tank and hole fill for proper fill. 3/24/2023 Continue to trip out of the hole F/ 1935' wiping pipe and cleaning OBM from NRP's on trip out. Monitor well with trip tank and hole fill for proper fill. Clean, inspect and lay down packer setting tool.;Clean rig floor and dispose of OBM soaked waste. Troubleshoot elmagco brake fire control card.;Rig up and pressure test 9- 5/8" casing to top of packer at 5440' - 3500 psi for 30 charted min - good test initial test pressure 3648 psi, lost 58 psi over 30 min period. Test with 9.2 ppg OBM. Troubleshoot elmagco brake fire control card.;Hold safety meeting with crew, MWD and WIS. Pick up and run in the hole with 9-5/8" whipstock and window milling assembly T/ 365'. Pulse test MWD - good.;Run in the hole with 9-5/8" whipstock and window milling assembly T/ 5413' monitoring well on trip tank - good displacement. Run in the hole at ~3 min per stand, checking NRP's on trip in.;Stage up pumps in 1 bpm increments to 10 bpm, 428 psi. Orient whipstock to 35 LOHS with MWD and slack off to set whipstock. Trip anchor, engage slips and shear off mills - shear bolt went at 28 kbs. PU 152 Klbs, SO 97 Klbs.;Mill window in 9-5/8" casing F/ 5412' (4065' TVD) T/ 5421' (9') per WIS representative. 428 gpm, 1625 psi, 80 rpm, 13 Kft-lbs torque, 0-2 Klbs WOB, PU 152 Klbs, SO 97 Klbs, ROT 112 Klbs. MW in/out 9.3 ppg.;Troubleshoot top drive VFD fault. 1 Regg, James B (OGC) From:Sloan Sunderland <ssunderland@hilcorp.com> Sent:Tuesday, March 21, 2023 10:05 AM To:Regg, James B (OGC) Cc:Sean McLaughlin; Shane Hauck; Monty Myers; Ryan Cowie; David Hebert - (C) Subject:Monopod H2S Alarms Mr. Regg, This morning at 0639 our H2S alarms sounded while filling pipe at 3000.The alarm was at the trip tank and the highest reading was 25 ppm. The fluid in the hole is FIW from a year ago. All personnel were clear and H2S possibility were discussed prior to the event. When the alarm sounded the annular was closed and the crew mustered per procedure. When the pump was shut down the H2S readings went to zero. The annular was opened and again H2S readings were confirmed to be zero. The target depth for this scrapper run is 5500.For the remained of the trip pipe will be filled but circulation will be kept to a minimum. Returns will be taken to pit 3, which offers more ventilation. Personnel will be kept clear of the pits. At bottom, the annular will be closed and the remaining FIW will be taken straight to production. Sloan Sunderland Hilcorp Alaska LLC Sr Drilling Forman Cookinlet Offshore Office 776 6618 Cell Phone 907 715 0591 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. When the alarm sounded the annular was closed DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-733-20064-02-00Well Name/No.TRADING BAY ST A-10RD2Completion StatusSUSPCompletion DatePermit to Drill2220020OperatorHilcorp Alaska, LLCMD11276TVD6852Current StatusSUSP12/16/2022UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:LWD: GR/RES for mainbore and PB1NoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF6/3/20228320 11276 Electronic Data Set, Filename: TBU A-10RD2 LWD Final.las36679EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 Final MD.cgm36679EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 Final TVD.cgm36679EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 - Definitive Survey Report.pdf36679EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 DSR Actual_Plan.pdf36679EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 DSR Actual_Vsec.pdf36679EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2_Definitive Surveys.txt36679EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2_Definitive Survey_seun.txt36679EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2_GIS_DSR.txt36679EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2_Surveys.xlsx36679EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 Final MD.emf36679EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 Final TVD.emf36679EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 Final MD.pdf36679EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 Final TVD.pdf36679EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 Final MD.tif36679EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 Final TVD.tif36679EDDigital DataDF6/3/20228324 12786 Electronic Data Set, Filename: TBU A-10RD2 PB1 LWD Final.las36680EDDigital DataFriday, December 16, 2022AOGCC Page 1 of 3PB1TBU A-10RD2 LWD Final.lasTBU A-10RD2 PB1 LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-733-20064-02-00Well Name/No.TRADING BAY ST A-10RD2Completion StatusSUSPCompletion DatePermit to Drill2220020OperatorHilcorp Alaska, LLCMD11276TVD6852Current StatusSUSP12/16/2022UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYMud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:Release Date:2/1/2022DF6/3/2022 Electronic File: TBU A-10RD2 PB1 Final MD.cgm36680EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 PB1 Final TVD.cgm36680EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 PB1 - Definitive Survey Report.pdf36680EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 PB1_Definitive Surveys.txt36680EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 PB1_Definitive Surveys_seun.txt36680EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 PB1_GIS_DSR.txt36680EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 PB1 Final MD.emf36680EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 PB1 Final 36680EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 PB1 Final MD.pdf36680EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 PB1 Final TVD.pdf36680EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 PB1 Final MD.tif36680EDDigital DataDF6/3/2022 Electronic File: TBU A-10RD2 PB1 Final TVD.tif36680EDDigital DataFriday, December 16, 2022AOGCC Page 2 of 3 DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-733-20064-02-00Well Name/No.TRADING BAY ST A-10RD2Completion StatusSUSPCompletion DatePermit to Drill2220020OperatorHilcorp Alaska, LLCMD11276TVD6852Current StatusSUSP12/16/2022UICNoComments:Compliance Reviewed By:Date:Friday, December 16, 2022AOGCC Page 3 of 3M. Guhl12/16/2022 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: _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): North Trading Bay Unit GL: N/A BF: N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22. Logs Obtained: 23. BOTTOM N/A 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 May 20, 2022 April 10, 2022 ADL 18731, 392195, 17597 N/A N/A 8,325' MD / 5,571' TVD66 N/A 11,276' MD / 6,852' TVD LWD (Gamma Ray and Resistivity) (+PB1) Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: Oil-Bbl: suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A Water-Bbl: PRODUCTION TEST N/A Date of Test: Flow Tubing Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information DEPTH SET (MD) N/A PACKER SET (MD/TVD) CASING WT. PER FT.GRADE N/A 224244 TOP SETTING DEPTH MD SETTING DEPTH TVD 2527330 BOTTOM TOP HOLE SIZE AMOUNT PULLED 50-733-20064-02-00 TBU A-10RD2 218864 2523116 N/A CEMENTING RECORD N/A 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 5/22/2022 1602' FSL, 570' FEL, Sec 4, T9N, R13W, SM, AK 664' FSL, 566' FEL, Sec 34, T10N, R13W, SM, AK 222-002 / 322-318 Trading Bay Undefined Gas Pool 101' 7,969' MD / 5,383' TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 548'4-1/2" SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 1:29 pm, Jun 07, 2022 Suspended 5/22/2022 MDG RBDMS 6/7/2022 GSFD 8/12/2022 SFD BJM 12/14/22 DSR-6/8/22 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval N/A 9248' 6006' 9925' 6312' 10663' 6621' Tyonek D2 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Contact Email:cdinger@hilcorp.com Authorized Contact Phone: 777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: Wellbore Schematic, Drilling Reports, Definitive Directional Surveys (+PB1) Signature w/Date: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. INSTRUCTIONS Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Tyonek D1 Tyonek D2 Tyonek D This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 6.3.2022 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: 2022.06.03 13:48:02 -08'00' Monty M Myers _____________________________________________________________________________________ Updated By: CJD6/3/2022 SCHEMATIC North Trading Bay Unit Well: A-10RD2 PTD: 222-002 API: 50-733-20064-02-00 Cement Detail Item PB1 5-5-22 From 9510’ MD Pumped 9.1 bbls 16.5# cmt, TOC @ 9209’ MD 5-6-22 From 9179’ MDPumped 20 bbls 17.0# cmt, TOC 8850’ MD Suspension 5-22-22 Pumped 48 bbls 15.3 ppg Class G, thru cmt retainer @ 8,250’ MD, 10 bbls of cmt on top of retainer. TOC tagged hard at 7,969’ (PB depth) CASING DETAIL Size Wt Grade Conn ID Top Btm 20”Conductor Pile Surface ~264’ 13-3/8”61 K-55 BTC 12.515”Surface 1,095’ 9-5/8”47 L-80 DWC/C 8.681”Surface 5,818’ 7”29 L-80 CDC HTQ 6.125”(SD)5,528’8,325’ TUBING DETAIL 4-1/2”12.6 L-80 IBT 3.958”Surface 548’ JEWELRY DETAIL No Depth (MD) Depth (TVD)Item Activity Date Ops Summary 4/3/2022 Continue r/up test equipment for bope test / AOGCC Mr. Guy Cook on board @ 07:30 hrs Platform orientation / DSM tour inspector around sub base and cellar and inspected Bopes / go to rig floor inspect equipment meet driller and pusher discuss testing and state man wanted start w/ koomey test.;Time closing of each each component all good except annular, Inspector time for bag to close was 47sec. repeated test 3 times w/ best inspector time @ 37 sec test Pre charge pressure of all bottles all with in 10% except one @ 875psi and charge same / shorten both feed and return lines to;annular by 50' and retest only gained 4 sec to 43 sec . Inspector wanted terminate testing operation tell tell bag closure time is resolved Inspector left location.;Locate and borrowed two 50' 1- 1/2" Koomey hoses from rig #151 and transported to rig and prep to install same.;Plumb in and install 1-1/2" Koomey hoses from bag to Koomey unit. Clean all screens on accumulator and purge air from new hoses and pumps. Install 22.5deg. pup on TDS S-pipe.;Test annular closing time as per inspector parameters x5-closing times-25,24,22,21 sec. on 5" and 4" jts respectively.;9-5/8" x 13-3/8" = 92 psi / 13-3/8" x 20" = 90 psi;R/D 5" test jt. and R/U Jagger pump to drain stack. P/U wear ring running tool and set wear ring. Run in 4 LDS. Install new torque gauge on ST-80.;P/U 5" 19.5#DP , torqued t/35k and rack in derrick. 12jts picked up total.;cont. P/U 5" 19.5#DP , torqued t/35k and rack in derrick. 4/4/2022 Cont. P/U 5" 19.5# S-135 IF DP , torqued t/35k and rack back in derrick. 43 std total. while changing out Blatter In kommey bottle #16.;Aline torque tube and center TDS over rotary table and secure same / chk torque on TDS , Iron rough neck and tongs against each other IR and tong same w/ TDS just a little +- 600 lbs more / NOV Rep. held connection and TYD function training w/ night driller.;Pull wear ring and set test plug w/ 5" test jt and r/up test equipment and warm koomey unit while waiting on AOGCC inspector.;AOGCC Mr. Guy Cook on board @ 13:30 hrs. performed accumulator draw down and tested annular closing time, inspector time was 29 sec Pass / Continue testing BOPE, 250L / 5000H and Annular @ 250L/3500H 5/5min on chart as per regulations.;Cont. testing BOPE, multiple failure on testing equipment (test manifold). leak on gland nut on well head, tightened-retested-good. Failure on CMV#2, service valve-failed, move on to next test while rebuilding valve #2.;L/D 5" test jt. and P/U 4" test jt.. Continue test w/4"jt. Rebuild choke manifold valve #2 while testing w/4"jt. and will re-test CMV#2 w/blinds-good. Valve #6 fail. Cont. trouble shoot testing.;9-5/8" x 13-3/8" = 92 psi / 13-3/8" x 20" = 90 psi 4/5/2022 Continue w/BOPE test after replacing seal in CMV #6, test 13-5/8 5m bop t/250low and 5k high, annular t/250low 3.5k high. Test of valve #2 and #6-good.;Pre- spud meeting with all crews.;Test stand pipe manifold, stand pipe and Kelly hose. t/250 low -5k high for 5min. Function test mud pumps. L/D test jt and test equipment.;Repair leak on Beyond trip nipple, pump out the stack, install drain hoses on MPD drip pan and clean up cellar.;Replace bolts on torque tube and center up over rotary.;P/U running tool M/U landing jt. and install wear bushing. Run in LDS x4. Function- Blind rams, choke HCR while out of the hole.;P/U drift/clean out BHA #1 w/7" scraper, RIH out of derrick w/4"DP t/944ft. monitor well on trip tank.;Re-adjust Kelly hose on TDS, blocking the rotary and stump.;RIH out of derrick w/4"DP t/2000ft. monitor well on trip tank.;R/U circulating sub on stump t/standpipe, break circulation at 2BPM, work pump up to 80spm/8bpm 800psi. No noticeable returns changes at bottoms up, just dark stink water. R/D circ. sub.;Bell Nipple H2S alarms sound during circulation, crews responded by evacuating and off tour personnel mustered in galley for roll call; Drilling communicated with production operator, slowed pumps to bring H2S reading t/ a non- alarm level. Finished circulation at reduced rate.;RIH w/4"DP out of the derrick f/2000md. t/2880md.;9-5/8" x 13-3/8" = 92 psi 13-3/8" x 20" = 90 psi 4/6/2022 Continue to P/U 4'' DP F/ 2881' T/ 3130'. M/U Scraper 9 5/8 assembly. P/U 4'' DP F/ 3136' T/ 4000'. Getting the correct pipe displacement.;M/U circ hose to stump & Break circ staging up to 5 BPM. Monitoring H2S levels. While getting dirty fluid back ShakerH2S alarms went off and monitors screens showing 20 PPM. Areas were evacuated and hands mustered in the Primary muster area for roll call. Production verified the 0 reading.;Production called the all clear and operation proceeded at a reduced rate. No solids in returns or oil residue. Just dirty water.;Continue P/U 4''dp F/ 4000' T/ 7107'. Change handling equipment to 5''. P/U 5''dp F/ 7107' T/ 8410', Tag TOL @5560'md (DP) with 9-5/8 scraper. We notified the state of the H2S readings over 20 PPM in email at 6:59 4-6- 2022.;M/U circ hose to stump & Break circ @2bpm, 110psi, staging up to 5 BPM. Monitoring H2S levels. Pump 20bbl soap pill followed by 20bbl hi-vis pill, rotate and reciprocate @10rpm, trq=5.8-6k, 5bpm, 500psi, flow=20%. No solids or oil residue in returns.;Fill Trip Tank, Break out top drive, monitor well for 10minutes. POOH w/14 stds of 5", c/o handling equipment T/4", POOH w/4"dp to 9-5/8" scraper, L/D 4-1/2IF x XT39 XO. P/U WWT NRP's and equipment to rig floor.;RIH w/5"dp installing NRP's as per WWT rep. F/2900' T/ 3400'. Installing one NRP per joint. 4/7/2022 RIH w/5"dp installing NRP's as per WWT rep. F/2900' T/ 3400'. Installing one NRP per joint on stands 4-24, install two centralizers per joint on stands 25-57. Make TD connection on last stand. RIH & TD would not break out.;Trouble shoot TD. Get stand broke out 30' up. Decide to adjust torque rail as per NOV. Notice service loop was wearing on Torque rail. Remove 45 deg from Kelley hose and adjust 22 deg to get kelly hose riding better and off of serve loops.;Found coolant drip on service loop at board. Tighten fitting. Test TD break out at floor. Good. Check TD connections. Good.;Change handling equipment & RIH to tag LT on 4'' dp. Tag with 9 5/8 scraper at 5532'md dp measurement.;Circ hole clean with clean FIW 2bpm/80psi, stage up t/4bpm/250psi, called clean as per Haliburton Mud Engineer. Monitor well, fill trip tank.;POOH (strapping out w/SLM) F/ 8285 T/3750. re-locating NRP's as per MPD rep. while POOH f/ std #39- 25.;Pull trip nipple and install MPD bearing, low test MPD equipment 450psi and high test 1250psi. Train crews on trapping pressure on connections. 4/8/2022 Pump through MPD putting 450 PSi on on the well to test rot bearing with NRPs. Train Crews. Mud releasing out upper seal while pulling NRPs through. Make containment plan. POOH with 5'' DP & stand bearing back on last stand. Install Trip nipple. Fix leak at air boot.;L/D scraper BHA, Clean and clear floor.;Prep for wire line coming on boat. Work boat. R/U Wire line & test CCL. Remove camera from derrick board to replace with shaker camera. Start choke valve #2 replacement.;RIH with wire line & tri point 7'' CIBP. Set depth at rig floor. RIH to 8420 & make two logging passes. Log collars at 8348' & 8306'. Put plug on depth 6' above collar at 8348. Set plug at 8342'. Good indication of release with 200 psi of line wt drop off. POOH with Eline & R/D same.;Continue changing out #2 choke manifold valve. Welder installing stop plates on torque rail plate. Modified camera mounts & install camera at b oard and handrail for shakers. cleaning pits. Test CMV#2 and upper/lower IBOP's 250/5000psi.;Pre-job w/WIS and Haliburton, P/U whipstock BHA#2 as per WIS & Haliburton. Shallow test MWD w/250gpm/500psi at 150ft. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: TBN A-10RD2 Trading Bay North Hilcorp Energy Company Composite Report , Alaska 4/10/2022 Contractor AFE #: AFE $: Job Name:221-00021 TBN A-10RD2 Drilling Spud Date: p multiple failure on testing equipment (t py@p / Continue testing BOPE, 250L / 5000H and Annular @ 250L/3500H 5/5min on chart as per regulations. 4/9/2022 M/U Whipstock to mills. RIH with whipstock T/ 3600'. Fill pipe. RIH with whipstock To top of liner at 5528'. Didn' s ee top of liner but seen drag at 5590'. 4K. Work pipe & drag fell off. Kelley up and fill pipe. RIH T/ 8250'. Fill pipe and orientate to 35 LHHS. RIH & set down on CIBP at 8346'.;Set Whipstock as per WIS. . Work set down wt in 5K set downs to 45K. Didn't see clear indication of shear pin but picked up free. Prep for displacement to mud.;Btm of whipstock set @ 8345', Top of whipstock set @8325.5'; Help Pre-job w/crew, production and Mud Engineers on displacing the hole t/8.8ppg LSND, walked down the line.;Pumped 20bbl soap pill followed by 20bbl hi-vis pill. Displace hole volume @2bpm/90psi, staged up pumps t/4.5bpm/590psi with returns t/pit #3, t/production header and down pipeline t/trading bay. 416bbls total pumped.;Clean pits #2 and #3 and sand trap. flange off shute t/totes, build spray bar for over board shute and install same. 4/10/2022 Start up wash bar and overboard line plugged. Attempts to free with Conduit and air. No luck. Remove blinds and dump shoot to tote in Sack Room. Unable to get to Plug. Pull apart over board line in pump room and remove plug. Reassemble lines and test. Good.;Start pumps and establish circ. #3 pit inspection hatch Leaking. Tighten same. Take slow pump rates & Start milling operations.;Mill window F/ 8325' T/ 8335' at 80-100 RPM, 250 GPM 8-12 K TQ, MW at 8.7 +. Cont. drilling 20ft new hole f/8335' t/8355', sweep hole as needed with hi-vis pill.;TOW @8325', BOW @8335', 5571TVD, up wt.=152k, dwn wt.=125k, rot wt.=140k, 275gpm, 1000psi, 100rpm, 2-4 WOB, 10-13k trq. SPR's @8325' #1pmp=20spm/190psi, 30spm/275psi, 40spm/470psi. #2pmp=20/200, 30/280, 40/450, 8.7ppg mud wt.;Sweep hole @8355' w/hi-vis sweeps. adding barite t/mud system t/ get 8.9ppg in and out.;R/U and purge kill line, choke manifold. Isolate on pit #1, line up bleed to Trip Tank, strap same. Perform FIT t/14.7ppg. 1665psi, 4.1bbl pumped, 3.4bbl bleed back, shut in @1665psi stabilized t/ 1272psi in 13min.;Monitor well f/10min. POOH f/8320' t/7585'. 4/11/2022 POOH F/ 7585' T/ 5532'. (7'' LT) .;Lt & Circ high vis sweep around. Recovered 30# metal.;POOH & Stand back 5’’ DP. WWT hand inspecting NRPs. Looked good. We did notice wear on the hard bands that went in the hole new. POOH standing back 4’’ Dp to BHA. Stand back HWDP & L/D Milling BHA. Starter mill 1/8 Under, Chase mill 1/16 under and water melon in gauge.;Service rig while crane clearing V door. Drawworks, Crown, TD, ST-80.;P/U Two 5'' singles 5’’ & Pulling Wear Bushing. M/U Wash tool, Flush stack, Function rams & Annular, Blow down choke and kill lines. Set Wear bushing. RILD. L/D Two singles.;P/U BHA #3 as per DD. Hughes STX-1 Tricone 6-1/8" bit (TFA=0.5890), Sperry 4-3/4" TerraForce Lobe 1.5 DEG Bent 1.1 Motor; FS, DM collar, TM HOC, Flex DC x2, XO, 4-4"HWDP, 4-3/4" Hyd. Drilling Jars, 8-4" HWDP=520.01ft.;TIH f/520' t/992', shallow pulse test @250gpm, 750psi. cont. TIH f/992' t/8345', pump trip tank, get parameters and SPR's.;SPR's @8272ft, 8.9ppg; pmp #1-20/30/40 spm, 410/500/650psi; pmp #2-20/30/40spm, 400/510/700psi.;Work pipe and get TF 45LHHS, tag bottom -no fill, slide as per DD f/8355' t/8420, 240gpm, 1150psi, hst wt=157k, s/o wt=125k, Rot wt=140k. 4/12/2022 Continue drilling kick off F/ 8420' T/ 8554'. 300 PGPM, 60 RPM. MW 8.9, Vis 40, Last survey showing 3.6 DEG difference in INC from old well bore.;Pump out of the hole F/ 8554' T/ 8400'. Pull through shoe with no pumps. Clean. Circ sweep around with no increase in cuttings. Pump Slug.;POOH wet F/ 8300' T/ 3425' standing back 5'' DP.;Clean mud from cellar and rig floor. Clear plugged floor drains, re-install tarps in cellar to redirect drips to drip pan. Dress mud bucket with 4" rubbers and rig up with line to trip tank.;Change handling equipment to 4''. POOH standing back 4'' DP F/ 3425' T/ 520'. Stand back HWDP NMFC & Jar. Lay down MWD, motor and bit - dull bit grade: 1-1-NO-A-E-I-NO-BHA.;Pull wear bushing and install test plug. Pick up and Make up test assemblies for BOP test.;Test BOPE 250/3500 psi for 5/5 charted min. Test witness waived by AOGCC rep Lou Laubenstein. Test upper and lower VBRs with 5" and 4" test joint. Test annular with 4" test joint. 4/13/2022 Testing BOPE: AOGCC Lou Laubenstein waived witness. Tested Upper and lower VBRs to 250/3500 psi for 5/5 charted min with 5" test joint. Tested all choke manifold valves, 5" FOSV, 5" dart, Upper and Lower IBOP, Choke and Kill line HCR and manual valves.;Replaced washed out regulator on test pump, 2 high pressure hose fittings, a high pressure ball valve and needle valve on the test manifold, and a high pressure grease fitting on the choke manifold that were leaking.;Rig down 5" test assembly and change out handling equipment to 4". Break down 1 stand of 4" DP in derrick for test joint and MPD bearing assembly. Make up 4" test assembly.;Continue testing BOPE: AOGCC Lou Laubenstein waived witness. Tested Upper and lower VBRs to 250/3500 psi for 5/5 charted min with 4" test joint. Test annular to 250/2500 psi 4" test joint. Tested 4" FOSV and dart valve, 2 manual chokes and 1 hydraulic choke. All tests performed with water.;Perform accumulator drawdown test and tested gas alarms.;Break and lay down 4" test assembly and rig down test equipment.;Pull test plug and Install wear bushing - run in 4 lock-downs.;Clean and clear rig floor. Clean out drains on rig floor. Clean and fill cracks around rotary table with foam and silicone to prevent mud leaking into cellar and platform. Make up 4" MPD bearing assembly on 4" drill pipe and stage on deck. Service top drive, ST-80 and rig floor equipment.;Replace leaking 4-way valve on accumulator. Rebuild manifold pressure regulator. Clean suction strainer on #1 electric accumulator pump. Verify pressures and functions. Re-perform drawdown test.;Make up BHA #4, 6-1/8" Kymera bit and RSS BHA per DD and MWD and plug into MWD. Shallow test MWD and GeoPilot on first joint of HWDP at 187': 241 gpm, 780 psi and 50 rpm. Continue making up BHA #4 to 560'.;Trip in the hole with BHA #4 on 4" drill pipe stands out of the derrick from 560' to 5561'. Fill pipe every 30 stands. 4/14/2022 RIH F/ 5561' T/ 8110'. Fill pipe every 2500'. Perform Trip drill with a CRTY at 75 SEC.;Service Rig. Grease TD & Blocks, Ceck oil levels in TD & Drawworks, Slip & 68' of Cut drilling line. had to repair the drilling line cutter. Prep for Drilling performing final checks.;Pull Trip nipple. Install MPD rotary bearing. Circ through MPD equipment getting everything running. Wash down in the hole getting the crews ready for OH To 8300' taking up to 20 to push through MPD head with NRPs. Take parameters, UP/DN /ROT 160/80/110 230 GPM at 1200 PSI.;Pump gauges bouncing all over. Decide to lower Pulsation Pre-charge to 650. Smoothed everything out to a manageable level.;Wash down through the shoe at 230 GPM. Set down twice. Hard to tell with Centralizers going through MPD bearing. Work through & wash down to 8485'. No issues. Wash & Ream down F/ 8485' T/ 8554'.;80 RPM, 10 K TQ, 240 GPM, 1100 PSI, UP/DN/ROT 160/85/110. MW 8.9, Vis 41.;Drilling ahead 6 1/8 Hole F/ 8554' T/ 8638'. 84' @ 42 FPH AV. Dope TJ & NRPs to help with drag going through bearing. Getting good Block height numbers to keep track of TJs in bearing. 140 RPM, 11K TQ, 260 GPM, 1200 PSI, Wob, 4-6. Still taking 6-15K To get TJ through bearing.;Drilling ahead 6 1/8 Hole F/ 8638' T/ 8844'. 206' @ 34.3 FPH AV Dope TJ & NRPs to help with drag going through bea ring. 140 RPM, 11K TQ, 260 GPM, 135 PSI, 180K up, 80K dn, 115K rot. WOB, 4-6. Still taking 6-13K To get TJ /NRP through bearing. MW in/out 9.0+, Vis 43. Max gas - 110 units.;Drilling ahead 6 1/8 Hole F/ 8844' T/ 9050'. 206' @ 34.3 FPH AV Dope TJ & NRPs to help with drag going through bearing. 60-140 RPM, 10-12K TQ, 260 GPM, 135 PSI, 190K up, 90K dn, 115K rot WOB, 4-8. Still taking 6-13K To get TJ /NRP through bearing. MW in/out 9.1/9.1+, Vis 38 Max gas - 270 units.;Inlet water used daily/cumulative (bbls): 8.3 / 8.3 Volume discharged to inlet daily/cumulative (bbls): 10.7 / 10.7 Metal recovered on ditch magnets daily/cumulative (lbs): 29 / 113.5 4/15/2022 Drilling ahead 6 1/8 Hole F/ 9050' T/ 9560. 510' @ 42 FPH AV Dope TJ & NRPs to help with drag going through bearing. 60-140 RPM, 10-12K TQ, 280 GPM, 1650 PSI, 205K up, 90K dn, 120K rot WOB, 5-10. Still taking 6-13K To get TJ /NRP through bearing. MW in/out 9.1/9.1+, Vis 41 Max gas - 500 units.;Pumped Sweep at 9500'. Came back on time with 20% increase in cuttings. Max gas was at 9340'. Cut MW back to 8.6 PPG on the NP scale.;Drill 6-1/8" hole F/ 9560' T/ 9730. 170' @ 28.3 FPH AV Dope TJ & NRPs to help with drag going through bearing. 60-140 RPM, 10-13K TQ, 280 GPM, 1680 PSI, 220K up, 95K dn, 122K rot WOB, 6-10. Still taking 6-15K To get TJ /NRP through bearing. MW in/out 9.0+/9.1, Vis 41 Max gas - 211 units.;ECD = 10.1. BEYOND holding 300 psi at connections;Platform lost power and air. Picked up off bottom and secured well. Crew mustered at galley. Opened MPD bypass and establish circulation at 83 gpm, 280 psi, 15 rpm, 13K tq. Stand by while production crew got systems back online.;Drill 6-1/8" hole F/ 9730' T/ 9870'. 140' @ 28 FPH AV Dope TJ & NRPs to help with drag going through bearing. 80-120 RPM, 10-12K TQ, 275 GPM, 1450 PSI, 220K up, 95K dn, 120K rot WOB, 5-10. Still taking 6-13K To get TJ /NRP through bearing. MW in/out 9.1/9.1+, Vis 41 Max gas - 35 units.;ECD = 10.1 BEYOND holding 300 psi at connections. Distance from wp06: 8.97' - 7.15' Low, 5.43' Left;Inlet water used daily/cumulative (bbls): 24.1 / 886.9 Volume discharged to inlet daily/cumulative (bbls): 60.7 / 80.1 Metal recovered on ditch magnets daily/cumulative (lbs): 35 / 148.5 gg g MW in/out 9.0+, V ggpg ;Test BOPE 250/3500 psi for 5/5 charted min. Test witness waived by AOGCC rep Lou Laubenstein. pg Perform FIT t/14.7ppg. Disagree. Leakoff was achieved at 13.4 ppg based on LOT data plot. - bjm 4/16/2022 Drill 6-1/8" hole F/ 9870' T/ 10350'. 480' @ 40 FPH AV Dope TJ & NRPs to help with drag going through bearing. 80-120 RPM, 10-12K TQ, 275 GPM, 1600 PSI, 225K up, 95K dn, 121K rot WOB, 5-12. MW in/out 9.1/9.1+, Vis 41 Max gas - 435 units. after D-1 Coal.;Grease TD swivel packing & adjust service loop cover. Brought black product up to 4PPB Soltex & 4 PPB baratrol. Drilled D-1 @ 9860' . No issues. Seeing Volcanic fines s in cuttings. Pumped sweep at 9900'. Brought back 25% increase in cuttings and on time.;Drill 6-1/8" hole F/ 10,350' T/ 10,470'. 120' @ 20 FPH AV. Dope TJ & NRPs to help with drag going through bearing. 80-120 RPM, 10-13K TQ, 270 GPM, 1650 PSI, 225K up, 95K dn, 125K rot WOB, 5-12. MW in/out 9.1/9.1+, Vis 41 Max gas - 460 units ~10,407';Beyond holding 387 psi during connections. ECD = 10.3 ppg Pumped sweep at 10,394'. Brought back 10% increase in cuttings 10,400' - hard spot and diff. psi spikes as sweep exited bit. Work pipe off bottom several times. Once sweep out of the hole issues with diff psi went away and ROP came back.;Drill 6- 1/8" hole F/ 10,470' T/ 10,572'. 102' @ 17 FPH AV. Dope TJ & NRPs to help with drag going through bearing. 80-120 RPM, 10-13K TQ, 270 GPM, 1550 PSI, 225K up, 95K dn, 125K rot WOB, 5-13. MW in/out 9.1/9.1+, Vis 41 Max gas - 180 units;Beyond holding 430 psi during connections. ECD = 10.3 ppg. Distance from wp06: 3.64' - 0.42' High, 3.61' Right.;Inlet water used daily/cumulative (bbls): 78 / 964.9 Volume discharged to inlet daily/cumulative (bbls): 39.7 / 119.8 Metal recovered on ditch magnets daily/cumulative (lbs): 13 / 161.5 4/17/2022 Drill 6-1/8"" hole F/ 10,572'. T/ 10636 105' Started packing off. 80-120 RPM, 10-13K TQ, 270 GPM, 1550 PSI, 225K up, 95K dn, 125K rot WOB, 5-13. MW in/out 9.1/9.1+, Vis 41 Max gas - 421 units.;Back ream back through. Logs show top of tyonek D-2 Coal at 10621'. Took several attempts getting reamed back to btm. Drill stand down to 10668'. Pump sweep around with no increase in cuttings. Still fine coals. Attempt to back ream whole stand.;Work pipe getting pack offs and hang ups when pulling in to 10625-10621'. Work free easy. Decide to drill another 30' to get our stabilizer through coal. Drilled F/ 10700'. back ream back up and still fighting pack offs and hang ups at 10630-10621'. Able to work through. Max gas - 490 units;Decision made to POOH & change out Geopilot for new bit and motor assembly. Line up MPD on top of hole, Establish circulation and back pressure permeators. POOH on elevators with 10-25 over pulls on centralizers . D-1 Coal pulled clean. WWT hand inspecting centralizers on trip.;POOH F/ 10603' T/ 8200'. Hole taking proper fill. Holding 400-600 psi on MPD while pulling. Pulled Clean in to window other than centralizer overpulls. Note Two clamps will need adjusted on the trip back in. Clamps slid up while drilling.;Pump 17 BBL high vis sweep. Circ well clean 250 GPM, 60 RPM working full stand. No increase in cuttings. Just coal fines in cuttings. Line back up on circ line to MPD.;Continue to POOH F/ 8200' T/ 7200'. Hole taking proper fill. Holding 400-600 psi on MPD while pulling. WWT hand inspecting centralizers on trip.;Trap 400 psi on well with annular preventer and bleed off MPD. Pull and lay down 5" MPD bearing. Change to 4" handling equipment. Make up and strip in with 4" MPD bearing. Continue to hold 330-400 psi on well during bearing swap out. Transfer mud and rig up mud bucket line to active pit.;Continue to POOH F/ 7200' T/ 560', standing back 4" DP stands in derrick. Hole taking proper fill. Stage back pressure on MPD down from 550-0 psi on MPD while pulling per schedule.;Pull and stand back 4" MPD bearing on last stand of 4" drill pipe. Pick up and install trip nipple and line up to tak e returns to trip tank while laying down BHA.;Pull out of the hole with BHA #4, 6-1/8" RSS drilling assembly. Rack back HWDP, jars and flex collars. Plug in and download MWD.;Distance from wp06: 5.37' - 0.06' Low, 5.37' Right Inlet water used daily/cumulative (bbls): 15 / 979.9 Volume discharged to inlet daily/cumulative (bbls): 64.1 / 183.9 Metal recovered on ditch magnets daily/cumulative (lbs): 3 / 164.5 4/18/2022 Download MWD tools. l/D MWD , Bit & Geopilot. Bit Grade- 1-2-CT-A-X-I-WT-BHA, Cone Grade- 1-1-WT-E-I-NO-BHA.;Clean & Clear Rig Floor, M/U BHA #5. New 6 1/8 Kymera with 4 D cutters, & 1.5 Bend motor, . M/U MWD & carry scribe. plug in and upload tools. @ 102'.;RIH on HWDP T/ 570'. , Shallow pulse test. Good. 250 GPM.;Pull trip nipple and install 4'' MPD bearing.;Swap out 9' bales for 11' 350 ton bales to be able to work 4'' pipe in open hole. Change clamps & set distance for derrick board. Adjust service loop cover and secure same.;RIH P/U 4'' DP F/ 660' T/ 2364'. Pick up total of 54 joints. Monitor returns through MPD choke - holding 360 psi back pressure while stripping in.;RIH F/ 2364' T/ 5570' on 4" DP stands from derrick. Monitor returns through MPD choke - holding 410 psi back pressure while stripping in. Fill pipe every 30 stands. No issues running through 7" liner top.;RIH F/ 2364' T/ 9200' on 4" DP stands from derrick. Monitor returns through MPD choke - holding 410 psi back pressure while stripping in. Fill pipe every 30 stands. Orient motor prior to exiting 7" window. Set down 10-15K several times at 9200' with no overpulls pulling back up.;Make up top drive, orient motor with DD and wash and ream down from 9155' to planned MPD bearing swap depth of 9250'. 250 gpm, 1650 psi, 65 rpm, 11-12K tq.;Inlet water used daily/cumulative (bbls): 66.2 / 1046.1 Volume discharged to inlet daily/cumulative (bbls): 0 / 183.9 Metal recovered on ditch magnets daily/cumulative (lbs): 0 / 164.5 4/19/2022 Back ream through set down at 9200. RIH no pumps . Good. Shut down and Swap 4'' bearing to 5'' Bearing. Bearing swap no trapped pressure.;RIh on 5'' Dp F/ 9250' T/ 9900'. Set down. P/U & Over pull 25-40K. Start pumps and packed off. Try to free with Rotation. Stall out. packed off. Bleed pressure down and try several times to free pipe & Get circ. Work pipe free picking up with still no circ.;Pick up above D-1 Coal and get 30' +/- Good pipe movement F/8840' T/ 8810'. Work several times and stage up pumps from 30 GPM to 230 GPM. Attempt to Wash down once btm up. Wash down and tag at top of D-1 Coal. 8855'.;Wash & Ream F/ 8845' T/ 9938'. Slight WOB but fell through. RIH no pumps to 10088'. Tag up. Wash down to 10334'. Tag up. Wash & Ream F/ 10334' T/ 10700' 220 GPM, 1500 PSi, 80-100 RPM. Full Returns with No pack off issues.;Establish parameters resume drilling 6-1/8" hole f/ 10,700' in rotary mode while sending around a 20 bbl high vis sweep, 25% increase in coal cuttings at surface. Rotate and slide per DD t/ 11,162' maintain ~66.5° Inc and ~9.5° Az. 462' @ 51.3 FPH ave 75 RPM, 13K tq, 270 gpm, 2100 psi, 6-10K WOB.;225K up, 95K dn, 126K rot. MPD holding 450 psi on connections. Max gas - 791 units.;Drill 6-1/8" hole f/ 11,162' to 11,500'. 338'; @ 56.3 FPH ave. Pump 20 bbl high vis sweep at 11,260', 10% increase in cuttings. 90 RPM, 13K tq, 270 gpm, 22100 psi, 6-10K WOB. 225K up, 100K dn, 130K rot. MPD holding 450 psi on connections. Max gas - 160 units MW in/out 9.1;Distance from wp06: 12.02' - 3.62' Low, 11.46' Right Inlet water used daily/cumulative (bbls): 50.1 / 1096.2 Volume discharged to inlet daily/cumulative (bbls): 38.7 / 222.6 Metal recovered on ditch magnets daily/cumulative (lbs): 7 / 171.5 4/20/2022 Continue drill 6-1/8" directional hole f/ 11,500' t/ 11,743' as per WP#06 @ 75 RPM, 13K tq, 270 gpm, 2100 psi, 6-10K WOB.225K up, 95K dn, 126K rot. MPD holding 450 psi on connections and holding ECD @ 10.4 ppg while drilling . Max gas - 620 units.;Survey and circ btm up for short trip while rotating and reciprocating full stand.;Attempt short trip pooh on elevators f/ 11,743' work pipe through coal @ 11,415' but unable work by 11,322'.;Kelly up and attempt to pump ooh unable to pass 11,225' w/ no pack off issues / back ream ooh and clean up multiple tight spots and one pack-off @ 11, 002' t/ 10,700'.;Rotate and reciprocate full std pump 20 bbl high sweep around back 2 bbls late w/ 45% increase.;Rih on elevators w/ set dn @ 11,415' and work through same and continue rih and wash and ream last stand to btm.;Resume directional drilling 6-1/8" hole f/ 11,743' and pump around 20 bbl hi gh vis sweep while drilling and reposition an NRP, 25% increase in fine cuttings at surface. Drill t/ 12,142', 399' @ 49.9 FPH ave 85 rpm, 13K tq, 270 gpm, 2300 psi, 6-10K wob, 225K up, 105K dn, 135K rot. MW in/out 9.1+.;Backreaming full stands at connections. ECD 10.6 ppg, MPD holding 450 psi on connections. Max gas - 917 units. Perform weekly BOPE function test, function all components except blind rams from driller's console. Will function blinds when out of the hole next.;Drill 6-1/8" hole f/ 12,142' t/ 12,315', 173' @ 28.8 FPH ave. 85 rpm, 13.5K tq, 270 gpm, 2350 psi, 6-15K wob, 245K up, 102K dn, 135K rot. MW in/out 9.2 ppg. Backreaming full stands at connections. ECD 10.65 ppg, MPD holding 450 psi on connections. Max gas - 88 units.;Distance from wp06: 5.50' - 2.57' High, 4.86' Right Inlet water used daily/cumulative (bbls): 123 / 1219.2 Volume discharged to inlet daily/cumulative (bbls): 135.6 / 358.2 Metal recovered on ditch magnets daily/cumulative (lbs): 9 / 180.5 p Performgppggpg weekly BOPE function test, function all components except blind rams from driller's console. Will function blinds when out of the hole next. gpp ;Pull out of the hole with BHA #4, 6-1/8" RSS drilling assembly. 4/21/2022 Continue Drill 6-1/8" hole f/ 12,315' t/ 12.400'. 85 rpm, 13.5K tq, 270 gpm, 2350 psi, 6-15K wob, 245K up, 102K dn, 135K rot. MW in/out 9.2 ppg. Backreaming full stands at connections. ECD 10.65 ppg, MPD holding 450 psi on connections.;Attempt to slide to raise Inclination several times having weight stacking issues added some lube and rotating 5-6' at a time and continue attempting to get in a good slide t/ 12,544'.;Perform short trip from 12,544' to 11,745', Backream each stand: 270 gpm, 2200 psi, 60 rpm 11-13k tq. MPD holding 450 psi on connections. No hole issues on short tip.;Circulate the hole clean with a 30 bbl low-vis / 20 bbl high-vis tandem sweep while reciprocating and rotating from 11,745' to 11,650'. 270 gpm, 2200 psi, 60 rpm 11-13K tq. Hole unloaded with 100% increase in cuttings brought back to surface.;Trip in the hole on elevators from 11,650' to 12,544' - washed the last stand down. MPD holding 450 psi back pressure throughout trip in. No hole issues running in.;Drill from 12,544' to 12,620'. Difficulty sliding from 12,559' to 12,575', continues to stack weight and trouble holding toolface. 85 rpm, 15.5K tq, 270 gpm, 2380 psi, 6-15K wob, 245K up, 102K dn, 135K rot.;MW in/out 9.2+ ppg. Backreaming full stands at connections. ECD 10.7 ppg, MPD holding 450 psi on connections.;Distance from wp06: 11.89' - 11.88' Low, 0.14' Right Inlet water used daily/cumulative (bbls): 68 / 1287.2 Volume discharged to inlet daily/cumulative (bbls): 45.1 / 403.3 Metal recovered on ditch magnets daily/cumulative (lbs): 7 / 187.5 4/22/2022 Continue slide Drill 6-1/8" hole f/ 12,620' to 12,666' / rotary drill f/ 12,666' t/ 12690' kelly dn (MPD bearing leaking).;Pooh on elevators 3 std t/ 12,392' w/ no issue shut in and trap pressure.;Chg out MPD bearing.;Rih on elevators and wash ream last std to btm w/ no issue.;Resume directional drill 6-1/8" hole f/ 12,690' t/ 12, 721' and preform a chk shot 12,717' w/ a 64.13 inc.;Resume slide drilling f/ 12,721' to 12,758' attempting to build inclination to ~66°. Multiple motor stalls and difficulty holding tool face. Decide to rotate kelly down to 12'784' and shoot a survey. Lay down top single and re-install NRP's removed while sliding stand down.;Slow ROP while rotating and difficulty directionally drilling - decision made to pull out of the hole for BHA change. 48hr notification made to AOGCC for BOPE test at 04:20 on 4-25-22.;Circulate bottoms up prior to pulling out of the hole. Rotate and reciprocate from 12,747' to 12,655', 265 gpm, 2250 psi, 72 rpm, 11K tq MW in/out 9.2+/9.2 ppg.;Distance from wp06: 24.52' - 24.13' Low, 4.4' Right. Inlet water used daily/cumulative (bbls): 35 / 1322.2 Volume discharged to inlet daily/cumulative (bbls): 31.9 / 435.2 Metal recovered on ditch magnets daily/cumulative (lbs): 2 / 189.5 4/23/2022 Continue Circulate bottoms up prior to pulling out of the hole. Rotate and reciprocate from 12,747' to 12,655', 265 gpm, 2250 psi, 72 rpm, 11K tq. MW in/out 9.2+/9.2 ppg.;Back ream ooh f/ 12,753' t/9440' @ 265 gpm @ 1900 psi @ 60 rpm w/ no issues.;Circ Tandem sweep around and rotate and reciprocate full stand w/ 15% increase in fines.;Rack back 5" MPD bearing / change handling equipment t/ 4" and install 4" Bearing. Offload and strap 4-1/2" liner from boat.;Pooh wet on elevators and work through tight spot coal @9123' unable work by coal @ 8800' / Make up XO and kelly up and wash area clean and drift same w/ no pumps ok / and pull through window w/ no issue. Continue to offload and strap 4-1/2" liner from boat.;Continue POOH to 5476', above 7" liner top with MPD holding 450 psi on well. Continue to offload and strap 4-1/2" liner from boat - total of 222 joints.;Circulate tandem sweep (low/high) at 5476', above 7" liner top rotate and reciprocate full stand w/ 10% increase in fines. 260 gpm, 1250 psi.;Continue to POOH with BHA #5 from 5476' to top of BHA. MPD holding 450 psi on well to 2000', then staging down to 0 psi by 1000'.;Pull 4" MPD bearing with last stand of 4" drill pipe and rack back in derrick. Pick up and install trip nipple.;Pull and lay down BHA #5 per DD/MWD. Stand back HWDP, jars and flex collars in derrick. Lay out MWD tools, motor and bit to deck. 6-1/8" Kymera bit grade: PDC : 2-8-B-ST-X-10-JD-PR, Roller Cone: 3-5-LC-H-8-10-CT-PR;Clean and clear rig floor.;Inlet water used daily/cumulative (bbls): 6 / 1328.2 Volume discharged to inlet daily/cumulative (bbls): 48 / 483.2 Metal recovered on ditch magnets daily/cumulative (lbs): 2 / 191.5 4/24/2022 Continue house cleaning after wet trip / rebuild koomey KR valve and btm pipe ram valve / chg out annular hose fittings from dry lock to rail road unions and test same w/ same results / mobilize 80 gal sphere type koomey bottle from rig 151 and chase need fittings / service rig / clean suction.;Screens on both mud pumps / preform derrick inspection / stab up back up dual RCD bearing on jt 5" dp / work boat / spot and plumb in 80 gal koomey bottle and set pre charge / sent Mr. Regg an E-mail notification of of no contact for bope test notice.;P/up and rack back 63 jts of 4' xt-39 DP and chk annular closing time right at 30 sec.;Pick up BHA #6, 6-1/8" ReedHycalog SK613M-A-1B bit w/ 1.5° Sperry TerraForce motor to 570'. Shallow test MWD: 250 gpm, 915 psi - good. Continue running in the hole with on 4" drill pipe to 2455'.;Inspect and change out top drive saver sub.;Inlet water used daily/cumulative (bbls): 0 / 1328.2 Volume discharged to inlet daily/cumulative (bbls): 0 / 483.2 Metal recovered on ditch magnets daily/cumulative (lbs): 0 / 191.5 4/25/2022 Continue to chg out saver sub and broken dies / saver sub tq to 44k.;Retrieve wear ring and hang off test plug w/ 77k up and 70k dn weight / R/up test equipment and purge air.;Test BOPE per Hilcorp and AOGCC regulations 250L/ 3500H 5/5 on chart with water. Test with 4" & 5" test joint on rams and annular. Test gas alarms - 1 Failure: H2S sensor at shakers. Annular close 29s, Upper & Lower Rams 9s. 200 psi - 39s, Full - 203s.;Rig down test equipment. Pull test plug with 77K up. Install wear bushing and run in lockdowns.;Change elevators to 4". Pull trip nipple and install MPD 4" RCD bearing.;Run in the hole with 4" drill pipe to 8201', just above the 7" window, with MPD holding 450 psi backpressure. Fill pipe every 30 stands.;Inlet water used daily/cumulative (bbls): 65.4 / 1393.6 Volume discharged to inlet daily/cumulative (bbls): 0 / 483.2 Metal recovered on ditch magnets daily/cumulative (lbs): 0 / 191.5 4/26/2022 Cut and slip 80' drill line @ 8296', just above the 7" window / Reset C.O.M and test same / Service rig.;Exit window w/ no issues / Rioh on elevators had to wash and ream through tight spots @ 10,119, 10,239' 10,653' and 10,682 w/ some pack off issues w/ coals @ 250 gpm @ 2100 psi 80 rpm w/ tq 10k @ p/u/so/rot 215/ 80/120k.;While washing and reaming Pits H2S alarm went off w/ high of 47 PPM / all nonessential personnel mustered production swept area and monitored area while finish circ btm up.;Continue Rioh t/ 11, 212' on elevators.;Swap from 4" RCD bearing t/ 5" duel RCD bearing.;Continue rih on elevators and staging in t/ set dn @ 12,440' (344' of btm).;Kelly up and attempt wash and ream thru same w/ no joy / Discuss options w/ town, decision made pooh inspect bit.;Pump tandem sweep around, 30bbl low-vis / 20bbl hi-vis. no increase of cuttings at B/U, 63spm, 1600psi, 40rpm, 12k trq, 240k up wt., 95km dwn wt., 125k rot. Get SPR's.;SPR@ 12,434'md, 7,338'TVD, 9.2+PPG. SPR#1 30spm-1140/370psi, 40SPM-1340/360psi. SPR#2 30SPM-1150/370, 40SPM- 1340/360psi.;POOH f/12,440' t/12,000' (5stds) monitor well for 15min.-w/357psi back pressure, 326psi at 15min. cont. POOH f/12,ooo' t/5500' holding back pressure w/Beyond.;Inlet water used daily/cumulative (bbls): 65.4 / 1393.6 Volume discharged to inlet daily/cumulative (bbls): 0 / 483.2 Metal recovered on ditch magnets daily/cumulative (lbs): 0 / 191.5 4/27/2022 Continue POOH wet f/5,500' t/1041' MPD stage dn pressure to zero f/ 2000' / open choke monitor well no flow / Remove 4" RCD Bearing / Install trip nipple and confirm no leaks.;Pooh Pipe dry? f/ 1041' t/ 33' / We had twisted off at connection on btm of TM collar leaving float sub+ Mtr and Bit in hole = 33.47' E.T.O.F @ 12,454'.;Discuss options w/ town and mobilize cmt equipment / down load tools and find swelled collar on DM collar / L/dn complete BHA to send in for inspection.;Clean rig floor and cellar from wet trip / Install New 1-1/2" KR valve and regulator / clean suction screens and pump out sand trap. cont. mobilize cmt equipment and 5-7/8"bit and breaker for BHA.;P/U BHA#7, 5-7/8" Rockbit, float sub w/float, 12jts 4" 29.7# HWDP. install 4" RCD element, TIH filling pipe every 2-3k ft, holding back pressure w/Beyond f/2500ft t/11,200', c/o RCD f/4" t/5" cont. t/RIH t/11,500'.;Note: well A-10 pressure @2330hrs (9-5/8"x 13- 3/8"annulus=92psi)(13-3/8"x 20"annulus=90psi). qggpg ;Test BOPE per Hilcorp and AOGCC regulations 250L/ 3500H 5/5 on chart with water ;MW in/out 9.2+ ppg. g 48hr notification made to AOGCC for g BOPE test at 04:20 on 4-25-22. pp p p p p g sent Mr. Regg an E-mail notification of of no contact for bope test notice.;P E.T.O.F @ 12,454' pp gp We had twisted off at connection on btm of TM collar leaving float sub+Mtr and Bit in hole = 33.47' 4/28/2022 Cont. RIH f/11,500' t/12,270'. w/ no issues.;Kelly up wash down t/12,421' tagged TOF X2. 225gpm, 1100psi, up wt=225k, dwn wt=124k, rpm=0. Then stayed at least 5' off T.O.F.;Circulate and condition mud, rot and reciprocate f/12,410 t/12,360', 230gpm, 1100psi, 70=rpm, 12-14k=trq. Meeting w/cementers, on pumping a balance plug / space out and R/U cement equipment and lines.;Test lines 1000L Psi and 5000H psi good / Halliburton Mix and pumped 13 bbl spacer @ 10.5 ppg @ 1/2 bpm followed by 9.1 bbls cmt @ 16.5 ppg @ 3bpm and 7 bbls spacer @ 10.5 ppg behind @ 3.5 bpm and displaced w/ 133 bbls of 9.2 ppg mud @ 4 bpm.;Pull out of balance plug 3 std slow 10-15FPM / C.I.P @ 14:50 hrs and pull 3 more std @ 20 FPM t/ 11,813'.;Circ w/ rig @ 7 bpm @ 1500 psi while rotating 50 rpm @ 11k TQ and reciprocating full std f/ 11,831' t/ 11,736' w/ no cmt back and trace of spacer / dump 20 bbls.;POOH f/11,736' holding back pressure w/MPD, t/2,440'. Bleed backpressure off w/MPD, L/D 4" RCD.;Cont. POOH f/2440' t/surf., L/D BHA#7.;Pooh on single to chg brakes and tested TD TQ and IR and Tongs against other w/ same results as when we commissioned them TD running a little high +- 500# IR and tongs still the the same. 4/29/2022 Finish L/dn and inspect Bha BHA#7 / Clean rig floor and cellar from wet trip / remove 80 gal sphere type Koomey bottle and prep to return to rig #151 / pull "C" manual choke apart on choke manifold and inspect ( received wrong rebuild kit reassemble same and chase parts ).;Pick up BHA #8, 6-1/8" Kymera Hybrid bit w/ 1.5° Sperry TerraForce motor and chk off set to 905' / Shallow test MWD @ 230 gpm, 1010 psi - good.;Continue running in the hole w/ 4" drill pipe out of derrick to 11,147' w/ no issues w/ TOL or exiting window ? and filling pipe every +- 2500'.;Fill pipe and warm mud above D-1 coal, surf/surf pumped, 250gpm, 2000psi, 70rpm, 10-11k trq, up wt=130k, dwn wt=122k, max gas 600 units, beyond flow out=300, beyond psi=41.;Continue rih t/ 11,213' and swap 4" RCD bearing t/ 5" Duel RCD bearing; cont. wash and ream t/11,850', last depth circulated after pumping cement.;Start washing and reaming f/ 11,850' t/12,169'. Start drilling ratty cement f/12,169 t/12,205', 250gpm, 2160psi, 70rpm, 12k trq., Beyond flow out-260, Beyond psi-36, DPress-950-1000.;Inlet water used daily/cumulative (bbls): 65.4 / 1393.6 Volume discharged to inlet daily/cumulative (bbls): 0 / 483.2 Metal recovered on ditch magnets daily/cumulative (lbs): 0 / 191.5 Note: well A-10 pressure @2330hrs (9-5/8"x 13-3/8"annulus=92psi)(13-3/8"x 20"annulus=90psi) 4/30/2022 Finish drilling ratty cement f/12,169 t/12,205', Polish off hard cmt t/ 12,210'.;Trough 30' F/ 12, 180' t/ 12,210' @ 130 right.;Time drill 130R 5min inch f/ 12,208' t/ 12,217' having weight stacking issues and also w/ tool joint going through RCD bearing and manually oscillating / rocking pipe.;Drill crew noticed drops on deck dispatched derrick man to inspect top drive Found hose drip and tighten same and wrapped hose in absorbant to soak up resido a short time latter production notified me they found drops on grating and seen drop go into inlet notified town.;P/up to first tool jt and attempted brk out double. Gripper slipping thinking that was hose leak. Broke out double w/ tongs and TD and of course it broke out in middle. L/dn double dispatched derrick man via man rider removed hose ( bearing lube inlet hose ) found fitting cracked and bad.;"O" ring while new hose was being made power washed TDS installed new hose and verified no leak and p/up double back up total estimated spill 1/4 cup hyd fluid (wind @ 22kt).;Acquire acceptable tool face @ 130 R and resume kick off operations f/12,217' t/12244', 36ft slide; 265gpm, 2150psi on btm, 2020psi off btm, 3-6k wob, varying TF from 130R to 30R , time drilled 5min/inch, 3min/inch and 1min/inch.;drill f/12,244' t/12,259', 265gpm, 2240psi, 80rpm, 12-13k trq, 3-6k wob.;Make connection at 12,259' orient TF 65R for slide, can't find bottom, believed to have broke through to main bore hole. Turn pumps down from 265gpm to 100gpm, wash Dwn to find bottom @12,279'.;Trough 17ft f/12,284' t/12,262' @ 65R.;Time drill 65R 5min inch f/ 12,284' t/12,286'.;P/U and S/O attempt to sit dwn w/pumps@90gpm f/12,286' t/12,311'. sat dwn @ 12,311' w/75diff pressure and 14k wob.;Trough 20+-ft f/12,311' t/12,294' @ 95R. 5/1/2022 Slow pumps wash dn @ 90 gpm f/ 12,286' t/ 12,311' find hard btm / clean Mud pump suction screens.;Trough 25' F/ 12, 311' t/ 12,286' @ 140R / Continue Power wash rig floor and cellar and clean same / clean and organize all work areas / fabricate and install missing bridge pins and install safety chains.;Trough 55' f/ 12,311' t/ 12,256' @ 140R / Replace bent stair tread / work boat I cruise on board / take on drill water and heat same / Isolate "C" manual choke and pull apart and inspect and clean internals.;Time drill at 1 inch every 5 min f/ 12,311' t/ 12,322', working stacking weight issues. Change out 3" mud bucket drain line to 4". 5/2/2022 Continue Time drill at 1 inch every 5 min f/ 12,322' ' t/ 12,321' / 1" every 4 min t/ 12,326' / 1" every 3 min t/ 12,331' 1" every 2 min t/ 12,334' and continue working stacking weight issues with oscillation, rocking, pipe stretch and pulling off btm as needed @ 274 gpm @ 2340 psi.;cont. sliding f/ 12,334' t/12,353' w/1-5k wob, @ 274 gpm @ 2340 psi. Shoot survey @ bottom and 12,311' in new hole and compare t/ survey @12,315' in original bore hole, determined we were still in the old hole.;Call Rig Engineer and discuss options. Circulate B/U while waiting on orders @63spm, 2300psi, reciprocating pipe f/12,330' t/12,353', check PH and confirm cement from original bore hole at B/U.;POOH f/12,353' t/11,219', holding back pressure w/Beyond MPD. c/o 5"RCD bearing F/4"RCD and handling tools.;POOH f/11,219 t/2300', holding back pressure w/Beyond MPD.;bleed off MPD, monitor well, rack back 4"RCD bearing on std. Cont. POOH f/2300'. 5/3/2022 Continue POOH f/2300' / to bha inspect same brk bit grade PDC - 1-2-LT-S-X-1-NO-DP / Roller Cone 1-1-NO-A-E-1 NO-DP.;Down load tools / L/dn bha / while off loading boat / clean rig floor and cellar after wet trip.;Continue clean rig floor and cellar after wet trip service rig inspect TDS and noise from dolly bogy wheels / strap tally 2-7/8" cmt stinger w/ diffuser. repair 4-way valve on koomey. clean discharge screens on MP's.;R/U 2-7/8" handling equipment. P/U BHA#9 2-7/8" cement stinger.;RIH w/ BHA#9 f/surface t/8300". tracking displacement on the TT.;Circ. B/U 65spm, 270gpm, 1000psi Simop-R/U cement equipment.;Cont. RIH w/ BHA#9 f/8300' t/11,014'. Taking weight, tracking displacement on the TT.;Kelly up and try to work through tight hole. Set down 5k, work up and down with and with out pump. 115gpm/540psi-no go, 140gpm/580psi-no go, 225gpm/1030psi stopped us from coming down after the up stroke.;POOH f/11,014' t/6500', monitor fill on trip tank. 5/4/2022 Cont. POOH f/6500' t/353'.;L/D BHA#9 2-7/8"tbg stinger and defuser. R/D 2-7/8" handling tools, clean n clear rig floor. Service rig, C/O dies in ST-80, tighten wrap on service loop.;Pick up 5-7/8" bit -bit sub-XO. RIH w/4"DP f/surface t/12259', set down 10k, Kelly up unable to pump down DP w/o pressuring up string- possible plugged jet/jets. Tight hole and packed off.;Work thru tight hole get jets unplugged, by surging and bleeding standpipe. Stage pumps up t/3bpm, 6% flow, 12-1400psi. Rotation stalling with packing-off no circulation. Work free point t/12,143'- 12074'.;Cont. work tight hole and try to establish circulation. f/12,143' t/12,074', Unable to establish circulation. Pipe free but packed off up high. POOH on elevators F/ 12074' T/ 11430'. Work through tight spot. P/U working single POOH to 11300 with free pipe.;Attempting to establish circulation. P/U Working single and L/D once pipe free. L/D 1 single. Establishing circulation staging pumps up .5bpm at a time.;Still working pipe staging up pumps while fighting packing off. 206gpm, 965psi, 57rpm, 9.6k trq. Black sand starting to come back over shakers @ 1/2 btm up . Still fighting packing off issues but getting better. Pumps up to 230 GPM;Drilling rates attained-55spm, 1060psi, 228gpm, 7.3% flow, 57rpm, 9-10k trq; Circulate bottoms up @11,148'. 5/5/2022 Wash & Ream in hole at 75 RPM, 9K TQ, 230 GPM F/ 11,148'. T/ 11450'. Decision made from town to POOH & have meeting.;POOH on elevators F/ 11450' T/ 9440'. Clean hole. Had meeting with town and decided to perform two cmt jobs. RIH to get on depth for plugs. RIH F/ 9440' T/ 9900'. Clean.;Stage up pumps to circ hole clean. Unable to get circulation. Work parameters for 1.5 hrs. packing off and unable to move pipe after. Work free and able to move pipe free with out pumps. Decide to pull up hole above D1 Coal at 9200. POOH on elevators from 9900' to 9200 clean.;Establish circ with minimal packing off at first. hanging up pipe on pack offs. Work free and stage up pumps to drilling rate at 250 GPM. Circ btm up working full stand at 75 RPM at 8800 TQ 1000 psi.;Wash & Ream in hole with no problems F/ 9130' T/ 9600'. Gel plug depth.;Circ tandem sweep around at 250 GPM, 75 RPM, 9K TQ. Working full stand. Crumbled coal coming over shakers steadily.;pump 7.5bbl barazan pill , chase w/96.6bbl mud to spot @ 9710' t/9510'. 5bpm, 800psi, 75rpm,8k torq.;POOH t/8519', c/o from 4" t/5" handling equipment. TIH w/5"DP t/9510'. hoist wt.=165k, slack off wt.=95k, 130=gpm, 600=psi.;Pre-job w/cementers, mud man and crew. Checking line ups, ship water and mud t/cement unit. Shut down 3" camlock hose leaking, c/o hose. Test lines 450/4045psi low/hi.;start cement job- pump 13.4bbl 10.5# spacer @4bpm, 640psi. Pump 9.1bbl 16.5# cement @3bpm, 630psi. pump 6.6bbl 10.5# spacer @3bpm, 335psi. Pump/chased w/93.5bbl 9.4# LSND mud @5.5bpm, 430psi.;Cement in place @0200hrs; H2O temp=66deg. F, R/D cement equipment, blow down lines.;POOH f/9510' t/9217' @20ft/min., cont. POOH t/8642' @45ft/min. Tight spot 180k/205k up wt.@ 9284'/8960' respectively.;Circulate B/U @170gpm, 500psi, 27rpm, 6.4k torq.;POOH f/9217' t/6700'. pqgp / Halliburton Mix and pumped 13 bbl spacer @ pg p qp 10.5 ppg @ 1/2 bpm followed by 9.1 bbls cmt @ 16.5 ppg @ 3bpm yp p TIH w/5"DP t/9510'. ;Kelly up wash down t/12,421' tagged TOF X2. Pump 9.1bbl 16.5# cement @3 5/6/2022 POOH F/6700' T/ BHA. L/D 5 7/8 Bit.;Clean rig floor. Inspect TD rollers. Service rig. Change handling equipment to 2 7/8. M/U 2 7/8 bull nose diffuser with 11' of 1/2 holes. RIH with 353' of 2 7/8 pipe. Change handling equipment to 4''. RIH to window @8180', c/o handling epuip. p/u 5" single and kelly up and hang off top drive.;Slip/cut drill line, torqued deadman bolts t/450ft/#.;Break out and l/d 5" single and c/o handling equipment. RIH w/ 4" t/8276', c/o handling equipment , cont. RIH w/ 5"dp t/9040'. bring pump up t/170gpm, 560psi, 4% flow, wash down t/9209' tag w/5k down twice .TOC 9209'. L/D single , P/U cement equipment.;Circulate condition mud for 550' cement plug job. 170gpm, 620psi, 4% flow. pump 18bbl hi-vis sweep, stage up pumps t/230gpm, 940psi, no increase in flow or cuttings seen at B/U or sweep return.;Pre-job, flood lines check for leaks, test line 680/4520psi low/hi. Rig pump 35bbl 10.5# mud push @5bpm/820psi-233.5bbl t/DP and 11bbls t/cementers.;Cementers pumped 20bbls 17# cement 3bpm/500psi, followed by 11.5bbls 10.5# mud push @3bpm/91psi and chased w/83 bbls 9.3# mud 6bpm/180psi. 120sx cement. cement in place @0417hrs. est. TOC @8659';POOH f/9209' @20ft/min for 550', cont. POOH t/TOW 8325';Drop wiper ball and circulate bottoms up. 335gpm/1200psi.;Inlet Water Used Today (bbls): 20 Inlet Water Used Cumulative (bbls): 1648.3 Discharge Today (bbls): 0 Discharge Cumulative (bbls): 808.6 5/7/2022 Cont. circ. mhole clean @TOW 8325', 328gpm, 1250psi, flow check 10min., Pmp dry job.;POOH F/ 5325’ t/surface, Repair hose on ST-80.;L/D 2 7/8 Cmt stinger & handling equipment. Recover wiper ball.;P/U test plug running tool and pull wear ring. Drain BOP stack.;M/U test plug and test jt w/ TIW valve and Kelly up on top drive . Set test plug with open anulus valve.;Flush sea water thru all surface lines, choke manifold, annulus and kill line. R/U HP test lines t/test jt, Dart and test manifold.;Pre-job; Test 13-5/8" BOPE equipment, Choke manifold, choke line, kill line, upper and lower IBOP's and 4" and 5" TIW and dart valves on 4", 5" test jt. Test all equipment to 250-350psi low and 3500psi hi, 5minuts each. H2S and LEL gas detectors. Witnessed by AOGCC Rep.;Inlet Water/Drill Water Used Today (bbls): 28.3 Inlet Water/Drill Water Used Cumulative (bbls): 1676.6 Discharge Today (bbls): 28.3 Discharge Cumulative (bbls): 836.9 5/8/2022 BOP test of accumulator draw down and closing times. Finished testing w/2 FP, rebuilt kill line demco, re-test good and purge air from choke manifold-re-test CMV#6 good.;Accumulator draw down: system pressure=3075psi after closure=1300psi 200psi attn.=34sec. full system pressure=226sec. Nitrogen bottle=6@2375psi.;R/D testing equipment, pull test plug, set wear ring and RILDS. C/O handling equipment f/BHA. C/O saver sub. Grease and function IBOP on top drive.;Pre-job w/all involved. P/U BHA- M/U Mud motor w/1.83 degree bend to 6.125" Smith PDC, M/U PWD/LWD tools and upload same. M/U flex DC as per DD/MWD.;RIH w/jars and 12jts HWDP t/559' and shallow test MWD tools while cycling pumps.;TIH f/559' t/7630', filling pipe every 2k ft and monitoring displacement on the TT.;Drain bell riser and strip up pipe std, break out connection and L/D same. C/O handling equip. f/4" t/5" and install 5" RCD bearing. Cont. RIH t/8485’.;start washing down t/8759’ (est. TOC@8659’) @246gpm, 1700psi, 110k s/o wt., 175k hoist wt, slight differential increase and loss of dwn wt.;Circulate hi-vis sweep around, differential and WOB increase. TOC polished@8850’., staying above 8640’. Mud push and 1 point PH increase seen at B/U. Start orient tool face and trough for;Cont. washing down t/8850’ @246gpm, 1700psi, 110k s/o wt., 175k hoist wt, differential and WOB increase. Top of polished cement @8850'.;Begin troughing for slide and kick-off (target40-60R) f/8850', 249gpm, 1730psi, 3-4k wob, hoist wt=175k, s/o wt=110k.;Inlet Water/Drill Water Used Today (bbls): 148.0 Inlet Water/Drill Water Used Cumulative (bbls): 1824.6 Discharge Today (bbls): 25.0 Discharge Cumulative (bbls): 861.9 5/9/2022 Time drill f/8850' t/8852', @60R, 5min./inch. Time drill f/8852' t/8858', @60R 3min./inch. Ream/orient tool face. Time drill f/8858' t/8860', 60R 2min./inch. Connection/survey. Time drill f/8860' t/8870', @60R 2min./inch.;Slide f/8870' t/8875', @50R 230gpm, 1650psi, 25-50ROP.;Work pipe and take check shot @8874.9, 61.38inc., 39.46azi.;Drilling f/8875' t/8955', 270gpm, 2050psi, 50rpm, 10-11k torq., 4-14k wob. 145k hoist wt., 110k s/o wt.,;Back ream out of hole f/8955' t/8486', 230gpm, 1350psi, 50rpm, 10-11k torq., 145k hoist wt., 110k s/o wt. RIH t/8955', installing torq reducer/Csg guard, oriented tool @ kick off point. No issues.;Cont. Drilling f/8955' t/9027 (72') @ 20 FPH average. 200-270gpm, 2100psi, 50rpm, 10-11k torq., 4-14k wob. 145k hoist wt., 110k s/o wt.,;Inlet Water/Drill Water Used Today (bbls): 0 Inlet Water/Drill Water Used Cumulative (bbls): 1824.6 Discharge Today (bbls): 26 Discharge Cumulative (bbls): 887.9;Distance to well plan wp8: 1.66'HI, .28'Right 5/10/2022 Drill ahead F/ 9011’ T/ 9085’ with slow ROP 10-15 FPH. Work all parameters. Better drilling while sliding. Decision ma de to POOH.;POOH f/9084' t/7630', monitoring fill on the TT.;L/D 5"RCD bearing, install trip nipple and c/o 5" t/4" handling equipment., Monitor well f/15min.;POOH f/7630' t/599', monitoring fill on the TT.;Std back HWDP, jars and flex DC. C/O 4' t/3.5" handling equipment. L/D BHA #12, upload MWD tools, Bit green-RR on this trip. P/U BHA#13, down load MWD tools w/Geo-pilot and same bit. M/u flex dc, jars and HWDP.;Break in seal on Geo-pilot w/10-20-30-40-60 RPM. Shallow pulse test MWD @703', 230gpm, 710psi.;RIH f/730' t/7597', monitoring Displ. on TT, filling pipe every 2.5-3k ft.;Inlet Water/Drill Water Used Today (bbls): 0 Inlet Water/Drill Water Used Cumulative (bbls): 1824.6 Discharge Today (bbls): 22.6 Discharge Cumulative (bbls): 896.5;Distance to well plan wp8: 7.91' High / Low: 7.29 Hi Left / Right: 3.09' Rt 5/11/2022 RIH on 5'' DP f/7597' to window at 8325'. RIH through window clean. RIH past kick off at 8550' clean to 8945'. Kelly up and establish circ at 220 gpm. Ream down f/8945' t/9085'. Work through coal at 8945'-8960. Slight pack offs.;Kelly up and establish circ at 220 gpm. Ream down F/ 8945' T/ 9085'. Work through coal at 8945'-8960. Slight pack offs. Clean hole after.;Drill ahead establishing permeators. Working with wt from 5-24. ROT at 60-150, Flow 200-270. Drilled 30- 50' per hr f/9085-9110'. ROP slowed to 5-15 FPH f/9110; t/9139'. Tried all parameters to get it drilling. No luck. Decision made to trip for a bit before D1 coal.;Back ream out of the hole f/9139' t/8740. Back ream through kick off with out issue. We did see the coal at 9045'. Worked through twice with slight pack offs again. Pulled through & Circ btm up with minimal coal back.;POOH on elevators f/8740' t/7500'. Clean through window & OH. Pull MPD bearing & install trip nipple.;Cont. POOH f/ 7500' t/4235'.;Service rig, fill TT.;Cont. POOH f/4235' t/'490.;Std back wt. pipe, flex DC. break out bit-green. Install new bit, dwn load MWD.;RIH t/2893’, shallow pulse test MWD, cont. RIH t/6000', monitoring fill on the TT, filling pipe every 2.5K ft.;Inlet Water/Drill Water Used Today (bbls): 8.0 Inlet Water/Drill Water Used Cumulative (bbls): 1832.6 Discharge Today (bbls): 11.7 Discharge Cumulative (bbls): 908.2;Distance to Well Plan wp8: 12.21' High/ Low: 11.68' Hi Left/Right: 3.55'Rt j ;Cementers pumped 20bbls 17# cement 3bpm/ OH sidetrack. - bjm ggqp wash down t/9209' tag w/5k down twice .TOC 9209' gg@gp ;Begin troughing for slide and kick-off (target40-60R) f/8850' Witnessed by AOGCC Rep.;I y TOC @8659'; gp Test 13-5/8" BOPE equipment, pppp ;start washing down t/8759’ (est. TOC@8659’ 5/12/2022 RIH on 4'' Dp F/ 6000' T/ 7671'. pull trip nipple & Install MPD bearing on 5'' DP.;Service Rig, Troubleshoot TD lube pump alarms. Change filters & add 2 gal oil. Electritoin Found bad wire in service loop lube pump feed wire. Use other wire in service loop to feed the third faze for the lube pump. Test Good.;RIH to shoe at 8300, Fill pipe & circ to warm up mud. Downlink GEOPILOT.;RIH on elevators F/ 8300' T/ 8955'. Tag up in coal. Work through with 100 RPM & 225 GPM with pack offs and set downs. Work through twice unable to clean up with Geopilot. Wash & ream down F/ 8960' T/ 9139'. 20 Fill on btm. Break in bit with 2-5 K WOB & 60 RPM.;Drill 6-1/8" hole F/ 9139' T/ 9353', 214' @ 28.5 FPH ave. 250 GPM, 1550 PSI 125-130 RPM, 5-12K WOB 10-11K TQ 175K up, 75K dn, 115K rot MW in/out 9.3/9.2+ Max gas - 241 units;Drill 6-1/8" hole F/ 9353' T/ 9550', 197' @ 31.8 FPH ave. 250 GPM, 1550 PSI 125-130 RPM, 5-12K WOB 10-11K TQ 175K up, 75K dn, 115K rot MW in/out 9.3/9.2+ Max gas - 340 units;Inlet Water/Drill Water Used Today (bbls): 20.0 Inlet Water/Drill Water Used Cumulative (bbls): 1852.6 Discharge Today (bbls): 12.8 Discharge Cumulative (bbls): 921.0 Metal Recovered Today (lbs): 5.0 Metal Recovered Cumulative (lbs): 209.5;Distance to Well Plan wp8: 18.61' High/Low: 16.74' High Left/Right: 8.13' Left 5/13/2022 Drill 6-1/8" hole F/ 9550' T/ 9905'. 355' @ 29.6 FPH ave. 250 GPM, 1580 PSI 130-100 RPM, 5-12K WOB 10-13K TQ 185K up, 75K dn, 125K rot MW in/out 9.3/9.2+ ppg Backream full stand at connections;Drill 6-1/8" hole F/ 9905' T/ 10,079'. 174' @ 24.9 FPH ave. 250 GPM, 1594 PSI 130-100 RPM, 5-12K WOB 10-13K TQ 185K up, 95K dn, 115K rot MW in/out 9.3 ppg Backream full stand at connections;Geo-Pilot RPM sensor failure at 10,004'. Work pipe and DD/MWD troubleshoot with tech support. Drill remainder of stand down to 10,079' and pull out of the hole.;Circulate hole clean prior to pulling out of the hole. Pump tandem 15 bbl Low vis / 15 bbl high vis sweep - no increase in cuttings with sweep at surface. 260 GPM, 1770 PSI, 94 RPM, 10-11K TQ;Trip out of the hole on elevators F/ 10,079' T/ 9680', MPD holding 340 psi - wipe tight spots at 9841', 9814', 9720', 9705' Pulled 30K over 2x at 9632'. ran back into 9680' Backream out of the hole F/ 9680': 60-80 RPM, 10-12K TQ, 240 GPM, 1590 PSI Pack off at 9396', work pipe and pumps to clean up.;While working pack-off and tight hole, regained sleeve rotation on Geo-Pilot - RPM sensor working and indicating good sleeve rotation. Continue to work pack-off and tight hole to 9335'.;Inlet Water/Drill Water Used Today (bbls): 75.0 Inlet Water/Drill Water Used Cumulative (bbls): 1927.6 Discharge Today (bbls): 30.2 Discharge Cumulative (bbls): 951.2 Metal Recovered Today (lbs): 0 Metal Recovered Cumulative (lbs): 209.5;Distance to Well Plan wp8: 17.39' High/Low: 5.07' High Left/Right: 16.63' Left 5/14/2022 Pump out of the hole F/ 9335' T/ 8849' with no significant issues. Continue to pull out of the hole on elevators F/ 8849' T/ 8264', inside 7" window. Hold 330 psi backpressure with MPD while pulling (10.3 ppg EMW).;Circulate a bottoms up at 7" window. 250 GPM, 1600 PSI;Trip out of the hole, racking back 5" DP F/8264' T/7617' while holding 300 psi backpressure with MPD (10.3 ppg EMW).;Trap 450 psi on well with annular and change out 5" duel RCD bearing with 4" bearing. Pull 5" bearing off pipe to replace element.;Trip out of the hole racking back 4" DP F/ 7617' T/ 550', top of BHA, while holding backpressure on well with MPD per trip schedule.;Pull 4" RCD bearing and install trip nipple.;Rack back 4" HWDP, jars and flex collars. Plug in and download MWD tools. Break down and layout Geo-Pilot - Steering Bearing locked up and unable to turn by hand at surface. Layout MWD tools to pipe deck. Dull bit grade: 1-2-CT-T-X-I-NO-DMF;Make up and run in with BHA #15, 6-1/8" Hycalog SK613M bit & 4-3/4"Sperry TerraForce 1.5° AKO motor to 559.8'. Plug in and upload to MWD tools.;Pull trip nipple and install 4" RCD bearing. Perform weekly BOPE function test. Perform shallow test of MWD tools - good.;Trip in the hole with BHA #15 on 4" drill pipe with MPD holding 320 psi back pressure (10.3 ppg EMW) per trip schedule T/ 6220' Fill pipe every 30 stands.;Service top drive, blocks, drawworks and rig floor equipment.;Continue to trip in the hole with BHA #15 on 4" drill pipe with MPD holding 320 psi back pressure (10.3 ppg EMW) per trip schedule F/ 6220' T/ 7500'.;Inlet Water/Drill Water Used Today (bbls): 0 Inlet Water/Drill Water Used Cumulative (bbls): 1927.6 Discharge Today (bbls): 16.8 Discharge Cumulative (bbls): 968.0 Metal Recovered Today (lbs): 0 Metal Recovered Cumulative (lbs): 209.5;Distance to Well Plan wp8: 26.37' High/Low: 5.82' Low Left/Right: 25.72' Right 5/15/2022 Continue to trip in the hole with BHA #15 on 4" drill pipe with MPD holding 320 psi back pressure (10.3 ppg EMW) per trip schedule F/ 7500' T/ 8764'.;Pull 4" RCD bearing and install 5" Duel RCD bearing while holding 300 psi pressure on well with annular. Change elevators to 5" drill pipe.;Trip in the hole with 5" drill pipe F/ 8764' T/ 9265' with MPD holding 10.3 ppg EMW per trip schedule. Stage up pumps and wash and ream through ratty hole F/ 9265' T/ 9400'. Trip on elevators F/ 9400' T/ 9905'. Wash and ream F/ 9905' T/10,079' at 60 RPM, 12K TQ, 240 GPM, 1700 PSI;Drill 6-1/8" hole per DD and wp8 F/ 10,079' T/ 10,207', 128' @ 17.1 FPH ave. 60-80 RPM, 9-13K TQ, 240-270 GPM, 2000-2200 PSI 4-10K WOB, PU 185K, SO 95K, ROT 115K MW in/out 9.3 ppg Backream each stand. MPD holding 450 psi on connections;Drill 6-1/8" hole per DD and wp8 F/ 10,207' T/ 10,231', 24' @ 3.4 FPH ave. 30-100 RPM, 9-10K TQ, 220-270 GPM, 1520-2080 PSI 4-18K WOB, PU 185K, SO 95K, ROT 115K MW in/out 9.3 ppg Pump low/high tandem sweep with no change. Vary parameters and unable to get any diff pressure on motor or change in TQ.;Discuss with ODE and decision made to pull out of the hole.;Pull out of the hole on elevators F/ 10,231' T/ 8764' MPD holding 320 psi back pressure (10.3 ppg EMW) per trip schedule.;Pull 5" Duel RCD bearing and install 4" RCD bearing while holding 300 psi pressure on well with annular. Change elevators for 4" drill pipe.;Trip out of the hole, racking back 4" drill pipe F/ 8764' T/ 5400' MPD holding 10.3 ppg EMW per trip schedule.;Inlet Water/Drill Water Used Today (bbls): 70 Inlet Water/Drill Water Used Cumulative (bbls): 1997.6 Discharge Today (bbls): 43.0 Discharge Cumulative (bbls): 1011.0 Metal Recovered Today (lbs): 10 Metal Recovered Cumulative (lbs): 224.5;Distance to Well Plan wp8: 35.01' High/Low: 14.48' Low Left/Right: 31.87' Right 5/16/2022 Trip out of the hole, racking back 4"" drill pipe F/ 5400' T/ 559', top of BHA MPD holding 10.3 ppg EMW per trip schedule.;Pull 4" RCD bearing and strip from pipe for service. Install trip nipple and change handling tools for BHA.;Stand back HWDP, jars and flex collars. Bit balled up with 3 ports and 1 nozzle port plugged and all 3 nozzles missing - 1-1-LN-A-X-I-BU-PR Download MWD data. Lay down SP4 collar due to limited battery life left.;Make up BHA #16, new 6-1/8" Halliburton MM54D bit with Previous run 1.5° TerraForce motor and MWD to 572' Plug in and upload to MWD tools.;Change handling equipment for 4" drill pipe. Shallow test MWD - good.;Trip in the hole with BHA #16 on 4" drill pipe F/ 572' T/ 2345';Pull trip nipple and install newly serviced 4" RCD bearing.;Trip in the hole with BHA #16 on 4" drill pipe F/ 2345' T/ 8114' with MPD holding backpressure = 10.3 ppg EMW per trip schedule;Establish parameters and orient motor high-side prior to exiting 7" window. 250 GPM, 1870 PSI;Trip in the hole with BHA #16 on 4" drill pipe F/ 8114' T/ 8800' with MPD holding backpressure = 10.3 ppg EMW per trip schedule;Pull 4" RCD bearing and install 5" Duel RCD bearing while holding 300 psi pressure on well with annular. Change elevators to 5" drill pipe.;Trip in the hole with BHA #16 on 5" drill pipe F/ 8800' T/ 9890' with MPD holding backpressure = 10.3 ppg EMW per trip schedule.;Tag up at 9850' and attempt to work down. Work down to 9900' with 10-15K set downs. Pick up and attempt to stage up pumps - packed-off. Work pipe up to 9827' and stage up pumps in 2 spm increments to clean up hole. At 4 bpm / 1260 psi - pack off again.;Dropped rate to 1.5 bpm / 445 psi and slack off and able to establish rotation 85 RPM, 13K TQ Stage pumps back up to 220 GPM, 1620 PSI. Wash and ream down to 9921'.;Inlet Water/Drill Water Used Today (bbls): 3 Inlet Water/Drill Water Used Cumulative (bbls): 2000.6 Discharge Today (bbls): 3.1 Discharge Cumulative (bbls): 1014.1 Metal Recovered Today (lbs): 0 Metal Recovered Cumulative (lbs): 224.5;Distance to Well Plan wp8: 35.01' High/Low: 14.48' Low Left/Right: 31.87' Right 5/17/2022 Continue wash and ream and work tight hole and pack-offs f/ 9921' t/ 9850' and hung pipe and pull free w/ 50k over continue wash ream t/ 10,230' @ 80 rpm w/ 11-12k TQ 60 spm @ 1800 psi;Attempt to continue drilling 6-1/8" directional hole f/ 10,230' w/ poor ROP and very little differential and weight stacking in slide mode work all parameters in rotation and slide modes ratty drilling t/ +- 10,290' with rop and differential getting a little better;Was able to get a slide in before coal packages T/ 10,323' Pull NRP on slides and reinstall after backreaming at connections to help with WOB working through the MPD bearing.;Rotary Drill F/ 10,323' T/ 10,484' per DD, 161' @ 24.8 FPH ave. 80 RPM, 11-12K TQ, 240 GPM, 2085 PSI, 8-10K WOB, PU 185K, SO 95K, ROT 130K Backreaming full stands and MPD holding 450 PSI on connections. From 10,390' on able to get good differential across motor 50-150 PSI w/ inst. ROP 25-100 FPH;Drill F/ 10,484' T/ 10,696' per DD, 212' @ 35.3 FPH ave. 80 RPM, 11-12K TQ, 240 GPM, 2110 PSI, 6-10K WOB, PU 185K, SO 95K, ROT 130K Backreaming full stands and MPD holding 450 PSI on connections. Differential across motor 70-150 PSI w/ inst. ROP 30-110 FPH MW in/out 9.3+;Pull NRP on slides and reinstall after backreaming at connections to help with WOB working through the MPD bearing.;Inlet Water/Drill Water Used Today (bbls): 51 Inlet Water/Drill Water Used Cumulative (bbls): 2051.6 Discharge Today (bbls): 101.6 Discharge Cumulative (bbls): 1115.7 Metal Recovered Today (lbs): 10 Metal Recovered Cumulative (lbs): 224.5;Distance to Well Plan wp8: 40.17' High/Low: 15.37' Low Left/Right: 37.11' Right 5/18/2022 Drill F/ 10,696' T/ 10,845' per DD, 80 RPM, 11-12K TQ, 240 GPM, 2100 PSI, 8-10K WOB, PU 190K, SO 100K, ROT 125K Backreaming full stands and MPD holding 450 PSI on connections. MW in/out 9.3+;Started reaching max set torque @ 13k and experiencing issues keeping drill string rotating stationary or in up stroke / Pump around tandem 15 bbl low and 20 bbl high vis sweep 30 bbls late w/ 10% increase with no improvement in torque / discuss issue with town;Short trip Pooh on elevators f/ 10,845' t/ 9985' w/ no issues / Rih on elevators w/ no issues t/ 10,777' and set dn;Hung pipe w/ good circ and no pack off but unable to rotate or fire jars work pipe back back out of tight hole t/ 10,280' and regained max torque 13k rotation in dn stroke / discuss issue w/ town;Started reaming in hole t/ 10,560' with 250 GPM, 1800 PSI - well started to unload coal. Discuss coal with ODE and decision made to pull up to 1 std below coals and circulate hole clean.;Backream ot of the hole F/10,560' T/10,008' - 1 std below D1 coal. 250 GPM, 1800 PSI, 40-80 RPM, 13K TQ - rotation was torque limited. Well continued to unload coal.;Pump 30 bbl low-vis / weighted (2ppg over) tandem sweep while rotating and reciprocating a stand F/10,0082' T/ 10,008' 250 GPM, 1900 PSI, 40-100 RPM, TQ limited at 13K. Sweep came back 30 bbls late w/ 10% increase in fine coal.;Backream out of the hole F/ 10,008' T/ 9330': 250 GPM, 1800 PSI, 40-80 RPM, 13K TQ - rotation was torque limited. Rotation stalled out completely at 9345', work pipe down and regain rotation. Pack-off and stall out right before making connection at 9330', work pipe several times to clear.;Stage up pumps slowly and pump out 1 stand T/ 9236' - above D0 Coal 240 GPM, 1798 PSI;Pull out of the hole on elevators F/ 9236' T/8782' - Top of 4" drill pipe.;Trap 300 PSI on well with annular and change out 5" Duel RCD bearing for 4" RCD bearing.;Continue to trip out of the hole on elevators F/ 8782' T/8295' - inside 7" window, with MPD holding 415 PSI back pressure.;Circulate hole clean inside 7" window, rotating and reciprocating pipe.;Inlet Water/Drill Water Used Today (bbls): 97.5 Inlet Water/Drill Water Used Cumulative (bbls): 2149.1 Discharge Today (bbls): 1546 Discharge Cumulative (bbls): 1270.3 Metal Recovered Today (lbs): 10 Metal Recovered Cumulative (lbs): 224.5;Distance to Well Plan wp8: 37.71' High/Low: 14.10' Low Left/Right: 34.97' Right 9-5/8" x 13-3/8" = 92 psi, 13-3/8" x 20" = 90 psi 5/19/2022 Continue Circulate tandem sweep around inside 7" window @ 8304' , rotating and reciprocating pipe w/ 20% increase in coal fines;Service rig and disassemble and repair and test dynamatic brake controller and burnt wire / cut and slip 102' of drill line and calibrate block height while holding pressure w/ MPD;Rih on elevators f/ 8304' t/ 8776' using MPD w/ no issues;Swap out MPD 4" RCD bearing to 5" RCD bearing;Continue rih on elevators f/ 8776' t/ set dn @ 9271' unable to work by;Ream in hole f/ 9271' t/ 10,480' @ 150-400 fph monitoring torque and differential and hole unloading coal most of the time at 50-80 rpm @ 11-13k torque and 240 gpm @ 1780 psi and still below torque limit in up and dn stroke and stationary rotary modes;Continue ream in hole f/ 10,480' t/ 10,845'@ 150-250 fph monitoring torque and differential and hole unloading coal most of the time at 50-80 rpm @ 11-13k torque and 240 gpm @ 1780 psi and still below torque limit in up and dn stroke and stationary rotary modes;Drill 6-1/8" hole F/ 10,845' T/ 11,140', 295' @ 36.8 FPH ave. 75-80 RPM, 12.5-13.5K TQ, 245 GPM, 1990 PSI, 6-14K WOB PU 195K, SO 105K, ROT 135K Backream full stands at connections. MW in/out 9.3/9.2+ Max gas - 470 units;Pumped 30 bbl low-vis/high-vis tandem sweep at 10,845', came back 30 bbls late with 10% increase in fines. Pumped 4 ppb Stickless 20 beads at 10,850' and began adding at 1 pail/hr to system to help with TQ issues. Drill string floats leaking at 10,951' - unable to hold constant backpressure with MPD;Drilling break F/ 10,980' T/ 11,030', TQ came down to 12.5K and instantaneous ROP > 90 FPH;Inlet Water/Drill Water Used Today (bbls): 77.5 Inlet Water/Drill Water Used Cumulative (bbls): 2226.6 Discharge Today (bbls): 133.4 Discharge Cumulative (bbls): 1403.7 Metal Recovered Today (lbs): 10 Metal Recovered Cumulative (lbs): 224.5;Distance to Well Plan wp8: 33.04' High/Low: 8.12' Low Left/Right: 31.00' Right 9-5/8" x 13-3/8" = 92 psi, 13-3/8" x 20" = 90 psi 5/20/2022 Drill 6-1/8"" hole F/ 11,140' T/ 11,276', 136' @ 34 FPH ave. 75-80 RPM, 12.5-13.5K TQ, 250 GPM, 2000 PSI, 6-14K WOB PU 205K, SO 105K, ROT 130K Backream full stands at connections. MW in/out 9.3/9.2+ Max gas - 165 units;Received orders to temporary suspend operations cease drilling operations and pump sweep around 28 bbls la te w/ 10% increase / take TD survey work boat back load 4-1/2" csg;Pooh on elevators racking back stands and removing NRPs w/ no issues t/ 8695' remove MPD 5" RCD bearing and l/dn same. Install trip nipple and monitor well static. l/dn 4" RCD bearing. Continue backloading 4-1/2" csg on boat;Resume pooh racking back 4" dp to top of BHA. 20K over pull bringing BHA through window at 8325' Pump slug at 7700' and pulled dry, monitoring well with hole fill and trip tank.;Pull and lay down BHA #16 per DD / MWD. Rack back HWDP. Lay down jars and flex collars. Plug in and download MWD. Clean and lay down all MWD components - Inline stab to ADR collar connection bulged and showing indications of over-torque. Dull bit grade: 1-2-BT-S-X-I-CT-TD Offload cmt unit from boat.;Clean and clear rig floor of BHA components. Pressure wash floor and cellar area. Rig down MWD equipment and prep for loadout. Rig down airline and plumbing to Geo-span. Offload cement pods from boat. Backload remainder of 4-1/2" casing and mud product to boat.;Rig up to test BOPE. Pull wear bushing and install test plug. Continue to clean rig.;Inlet Water/Drill Water Used Today (bbls): 70.0 Inlet Water/Drill Water Used Cumulative (bbls): 2296.6 Discharge Today (bbls): 104.8 Discharge Cumulative (bbls): 1508.5 Metal Recovered Today (lbs): 0 Metal Recovered Cumulative (lbs): 224.5 9-5/8" x 13-3/8" = 92 psi, 13-3/8" x 20" = 90 psi 5/21/2022 Continue r/up test equipment and test BOPEs as per regulations 250L / 3500H 5/5 on chart w/ one F/P on low test of #5 bleed air retest good on both 4" and 5" test jts . R/dn test equipment and set wear ring . AOGCC Jim Regg waived witness on 5-19-22 at 14:32;While continuing r/dn MPD and Sperry equipment and centrifuge clean and prep equipment for boat;P/up and M/up Bha #17: 7" cement retainer, running tool and XO from 3-1/2" IF to XT39. Run in at 60 FPM from surface to 5500' (top of 7" liner) 40 FPM from 5500' to 8250' per Tripoint rep. Backload Sperry tools, mud product, and centrifuge to boat.;Halliburton arrived on location. Spotted and rigged up cement equip.;Space out and set 7" cement retainer at 8250' per Tripoint rep. Rig up cement line on rig floor. Continue backloading MWD and directional tools, mud product and empty cuttings boxes to boat.;Continue to backload Directional tools and un-used 4" drill pipe to boat. Pressure wash and clean wind walls behind drawworks. Pressure wash and clean shaker deck and pits.;Check lineups and hold hold PJSM for cementing.;Inlet Water/Drill Water Used Today (bbls): 40.0 Inlet Water/Drill Water Used Cumulative (bbls): 2336.6 Discharge Today (bbls): 50.0 Discharge Cumulative (bbls): 1558.5 Metal Recovered Today (lbs): 0 Metal Recovered Cumulative (lbs): 224.5 9-5/8" x 13-3/8" = 92 psi, 13-3/8" x 20" = 90 psi 5/22/2022 Check line ups and hold PJSM, While stung in pressure up back side t/ 500 psi w/ DP open and test retainer and seals for 5 min good / preform injection rate w/ rig pump @ .5 bpm = 1420 psi , 1 bpm = 1550 psi, 1.5 bpm = 1704 psi, 2 bpm = 1630 psi;w/ total 14.5 bbls pumped. dn pump 1 min bleed dn = 1685psi, 2 min = 1630 psi, 3 min =1600 psi , bleed to zero w/ 10.25 bbls back ( 4.25 total injected ) un sting and hold PJSM on cmt job. brk circ w/ cmt unit and PT low @ 925 psi and high @ 4855 psi ok. Batch up cmt 15.3 ppg;Halliburton pump 20 bbls freshwater ahead followed by 220 sx 48 bbls of 15.3 ppg cmt @ 2 bpm @ 1800 psi while holding 1500 psi staging up t/ 2200 psi on back side followed by 5 bbls fresh water behind and displaced with 21 bbls mud, stab retainer and pump 48 more bbls mud displacement;un sting and pump 6 more bbls mud to balance the 10 bbls cmt left on top of retainer. L/dn cmt head and single + 3 std slow at 15fpm C.I.P @ 10:50 hrs and 7 more std at 25 fpm est top of cmt @ 7981';P/up cmt head and r/up and reverse circ 4x pipe volume 6.7 bpm 850 psi w/ no sign of cmt in returns. Pump dry job and r/dn cmt head.;Pooh l/dn drill pipe vacuuming wiper balls and servicing threads and loading out same, while waiting on cmt also loading boat w/ sperry and misc equipment. load mt tail cmt silo on boat transfer unused lead cmt to transport silos and load out same plus mt lead cmt silo. Laid down 4" DP to 4906';Change handling equipment to 5" and make up XO on top of 4" pipe in hole. Run in the hole with 5" drill pipe out of the derrick F/ 4906' T/ 7283';POOH and lay down 5" drill pipe F/ 7283' T/ 4906', vacuuming wiper balls to clean pipe and servicing threads before laying out and bundling for load out. Flush out pill pit.;Run in the hole with 5" drill pipe out of the derrick F/ 4906' T/ 7223' removing NRPs from pipe on trip in the hole. Vacuum and clean out pill pit for upcoming displacement.;POOH and lay down 5" drill pipe F/ 7223', vacuuming wiper balls to clean pipe and servicing threads before laying out and bundling for load out.;Inlet Water/Drill Water Used Today (bbls): 0.0 Inlet Water/Drill Water Used Cumulative (bbls): 2336.6 Discharge Today (bbls): 0.0 Discharge Cumulative (bbls): 1558.5 Metal Recovered Today (lbs): 0 Metal Recovered Cumulative (lbs): 224.5 9-5/8" x 13-3/8" = 92 psi, 13-3/8" x 20" = 90 psi gp p y p ;un sting and pump 6 more bbls mud to balance the 10 bbls cmt left on top of retainer. Provided 48 hrs notice to AOGCC for opportunity to witness tag and pressure test of cement plug. Witness was waived by AOGCC on 5/22/22. -bjm est top of cmt @ 7981'; test BOPEs as per regulations ;Space out and set 7" cementpy retainer at 8250' (j)g j Batch up cmt 15.3 ppg;Halliburton pump 20 bbls freshwater ahead followed by 220 sx 48 bbls of 15.3 ppg cmt jqp g AOGCC Jim Regg waived witness on 5-19-22 at 14: 5/23/2022 Continue yoyoing dp out derrick and lay down all unneeded drill pipe t/ no deeper then 7283', removing NRP's , vacuuming wiper balls to clean pipe and servicing threads before laying out and bundling for load out. and loading same on boat;Rih w/ last of 4" dp out of derrick t/ 7740' prep for chg over and work on demobe list load out equipment on boat;Kelly up establish parameters wash dn to 7965' and tag wash green cmt t/ 15k hard tag @ 7969';L/dn double and R/up and test csg with 9.3ppg LSND to 2664 psi for 30 charted min. Lost 24 psi in first 5 min then stabilized at 2640 psi - good test. Pumped 4.5 bbls / bled back 4.5 bbls.;Rig up and flush mud pumps, choke manifold, trip tank and all surface lines with FIW prior to displacing well.;Displace well to corrosion inhibited FIW. Reverse in 20 bbl High-vis spacer followed by FIW treated with 2% BARACOR 95 at 5 BPM. Initial Circulating Pressure = 820 PSI Final Circulating Pressure = 460 PSI Total of 482 bbls displaced.;Rig down reverse line, break out and lay down pump-in sub. Fill trip tank.;Pull and lay down 4" drill pipe from 7966', vacuuming wiper ball and servicing threads prior to laying out and bundling for backload.;Inlet Water/Drill Water Used Today (bbls): 481.0 Inlet Water/Drill Water Used Cumulative (bbls): 2817.6 Discharge Today (bbls): 531.1 Discharge Cumulative (bbls): 2089.6 Metal Recovered Today (lbs): 0 Metal Recovered Cumulative (lbs): 224.5 9-5/8" x 13-3/8" = 92 psi, 13-3/8" x 20" = 90 psi 5/24/2022 Continue POOH laying dn last of 4" drill pipe and servicing threads prior to laying out and bundling for backload. Inspect BHa #17 retainer running tool OK w/ just a little cmt sheath on it;L/dn Bha #17;Pull l/dn wear ring;Clear clean floor while electrician chk and confirmed lost other leg in TDS service loop for lube pump strap and tally 4-1/2" 12.6# L-80 IBT kill string;R/up weatherford Tubing handling equipment. P/up rabbit and run 4-1/2" 12.6" IBT kill string m/up hanger and land mule shoe @ 547.71' RKB, up wt=38k, dwn wt=35k.;R/D weatherford casing and handling equipment.;P/U Johnny whacker and flush BOP's and all service equipment X2 and X1 with fresh water, dumping mud from pits and cleaning pits, possum belly and shakers. Power wash all XO and handling equipment on rig floor and Beyond equipment in cellar.;Nipple dwn low pressure riser and beyond head and valve, drip pan, choke hose, kill hose, hydril.;Inlet Water/Drill Water Used Today (bbls): 84.0 Inlet Water/Drill Water Used Cumulative (bbls): 2901.6 Discharge Today (bbls): 320.8 Discharge Cumulative (bbls): 2410.4 Metal Recovered Today (lbs): 0 Metal Recovered Cumulative (lbs): 224.5 9-5/8" x 13-3/8" = 92 psi, 13-3/8" x 20" = 90 psi 5/25/2022 Continue nip/dn bopes finish power washing cleaning inspecting and preserving Annular server chunking of element prep same for boat and send to yellow jacket for element and seal change before going to Tyonek platform continue and finish cleaning reserve pit.;Remove rams from double and single gate remove double gate power wash and clean and inspect and preserve same. remove choke and kill valves and remove mud cross power wash clean and inspect and preserve same while cleaning active system.;Continue cleaning active system while continue to nip/dn riser remove same power wash and preserve. Canrig continue r/dn rig watch system. Continue clean active system pits. Work on demobe list.;Install and test 13-5/8" 5M dry hole tree t/250-low/5K-high for 5minuts ea. Pulled 2-way check and install BPV.;Pull choke and kill line hoses from cellar and clean face and grease ring groove, install blind flanges on same. Pull, drain Koomey line, clean and store in Mud box w/liner and absorb. load all 4" and 5" subs in separate baskets for back haul.;Simop-cleaning pits and prepping loads for back haul.;Pull, drain Koomey line, clean and store in Mud box w/liner and absorb. load all 4" and 5" subs in separate baskets for back haul. Simop- cleaning pits and prepping loads for back haul.;Inlet Water/Drill Water Used Today (bbls): 135.0 Inlet Water/Drill Water Used Cumulative (bbls): 3036.6 Discharge Today (bbls): 167.0 Discharge Cumulative (bbls): 2577.4 5/26/2022 Continue remove pressure wash and clean Koomey hoses and store same. Continue cleaning active pit and r/dn Canrig rig watch system and prepping loads for back haul. and load boat. sent 1/2 drilling crew to rig #151 working small Skelton crews around clock for demobe.;Continue cleaning active pit system Remove all equipment of top of mech and elect connex and cover storge jore flat w/ grating and prep for storage of drilling equipment. stow and secure mouse hole remove pollution wrap on TDS service loop in prep to remove Bad service line.;Power wash clean Blocks & TDS . off load boat and store Canrig equipment.;Finished cleaning pits, sand trap and cutting box shute. Un-load boat. Preserve spare choke valves and store in dry sack rm. inventory koomey hoses and box up-plus spares. Install jacks on sub, finish clearing off mech. shop and lay grating for storage.;Pickle choke manifold w/oil. preserve choke line spool. pull multi-conductor from saddle on Top Drive for electrician. separate service lines on RPM tank. start cleaning RPM tanks. ready koomey hose jumpers, extra hyd. lines for back load to warehouse.;Crane spare tugger line into pump rm for storage. Pull ditch magnets and crate for mudman. Load extra chicksan from rig floor into basket for iron rack t/ back load.;Inlet Water/Drill Water Used Today (bbls): 0.0 Inlet Water/Drill Water Used Cumulative (bbls): 3036.6 Discharge Today (bbls): 0.0 Discharge Cumulative (bbls): 2577.4 5/27/2022 Continue demobe of rig #56 w/ Skelton Crews. Continue stow and prep equipment for boat . Remove bad continuous service loop from derrick and prep for back load and remove 20" fresh air intake trunk to rig and stow in water flood. field weld repair shaker bed #2;Stow misc hoses in hopper room. Remove ST-80 and prep for transport . Remove bails. remove and stow camera system.;Clean-power wash Derrick, Torque tube, all dark corners, gator backs and sumps, draw works, dog house and office, Hang cement line and mud buckets. clear floor of unnecessary equipment. clean n grease bushings, pull hatch on rotary table and clean.;Inlet Water/Drill Water Used Today (bbls): 0.0 Inlet Water/Drill Water Used Cumulative (bbls): 3036.6 Discharge Today (bbls): 0.0 Discharge Cumulative (bbls): 2577.4 5/28/2022 Continued Demobe of rig #56 w/ around the clock Skelton crews. Elect pulled brushes meg and serviced rotary table traction mtr. chk RT tranny oil ok, and serviced back brake, clean cover lips and reinstall same and seal. shut dn unhook TDS VFD and roll back cables.;welder continued repair of possum belly screw gate dump. valve and misc handrail repair. Continue Clean-power wash equipment. Hang and secure all TDS service loops on top of choke house for storage. Install TDS service loop pollution cover. Park TDS at high derrick and secure;Service line and kelly hose to minimize tugger line interference. remove anti falls from derrick. Had platform shut dn then fire alarm all mustered permits voided waiting on production for weld and pit cleaning reactivation. continue prep. loads for boat.;Work boat, shovel and vac solids in cellar deck, R/U pressure washers and clean cellar from top down.;Cont. clean cellar, load basket of misc. equipment out of cellar. R/D flow line t/pits and poor boy line t/pits. Unbolt mud line from rig t/deck. r/d RPM transfer pump hoses and H2O lines and coil in hopper rm.;Stage metal dumpster for trip tank demo, r/d glycol hoses f/RPM tank.;Inlet Water/Drill Water Used Today (bbls): 0.0 Inlet Water/Drill Water Used Cumulative (bbls): 3036.6 Discharge Today (bbls): 0.0 Discharge Cumulative (bbls): 2577.4 qp yp p test csg with 9.3ppg LSND to 2664 psi for 30 charted min. pp hard tag @ 7969' ppp ;Install and test 13-5/8" 5M dry hole tree t/250-low/5K-high for 5minu 5/29/2022 Continued Demob of rig #56 w/ Skelton crews. Remove bridge from rig floor to weld shop landing . load out 500 bbl RPM tank and 1000 psf strong back on boat . install handrails and safe out sub landing . welder continued and finish repair of possum belly dump gate;and worked on misc. handrail repair. Shut dn last MTU prime mover and Electricians swapped power back to production and took megger reading lifted brushed and chk armatures and left heaters on and installed desiccant bags on DWK tractions mtrs. pickel test pump and fill w/ R/V antifreeze.;finish inventory of TDS critical spare parts connex and prep for boat. Remove the rest MPD equipment and prep for boat. Continue finish cleaning active system. Continue power washing and cleaning equipment. move rig east 6- 1/2' to access vacuum and centrifuge feed pump . start pickel both MP'S;r/u vac unit on ODS rig. separate bridge and spot on mech. shop roof. Wrap bridge cranes, palletize extra wood f/back haul, put away extra shaker screens, wrap drill line spool, remove mud line from back of ri g, preserve same and stow. Gather SRL's and 6-point harness's-stow in crate.;Remove power feed cables for VFD from transformer and stow in elect. house. Work boat.;Empty misc. buckets, stow loose tools and equipment on pipe deck. clear off hopper rm roof. Clean catwalk and spot on west side, clean pipe rack, behind rig and around pit area, pull centrifuge feed pump f/back haul.;Inlet Water/Drill Water Used Today (bbls): 0.0 Inlet Water/Drill Water Used Cumulative (bbls): 3036.6 Discharge Today (bbls): 0.0 Discharge Cumulative (bbls): 2577.4 5/30/2022 Continued Demob of rig #56 w/ Skelton crews. welder continued working on handrails. continued power washing and cleaning equipment and prepping loads for boat. continued putting mud pumps to bed. skidded rig back against pits and secured same continued Power washing decks and stowing equipment;Start to remove old trip tank. Continue work demobe list, stow hand rails for top of mech/elect-shop and sweep upper deck, MWD/DD deck, clear off hopper house roof and sweep same, install shaker shute gaurds. gather loose tools from around rig.;Box in and tarp drillers console, grease tongs, p/u more loose tools around rig. Gather and empty drain sludge and garbage into waste drums. Clean pump rm, hopper area and dry sax rm. Inventory pmp and koomey parts. Gather chains from pits/parts rm and back of rig t/pipe deck. !"# $ !%"& '(()* +,- .- " - / - - ! 0- 01- " #$% " #$% #-&& '()#$#*$$ +, '(- -" #$%1-.,"!/ . -'()#$#*$$ +, '(- 2# - '" #$% .- 3 .- +, 4- . .-"!! 0 #1%2+(3 - . #1%2+. ,.,."!- 4$5 ! 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+8- ## #$8*1# 89*%9 6*77 8 299*66 5 #98*59 6 %8%*$98 892*66 % 6%2 #25*9% %%5 %%6*9# #*68 8 727*88 7='/;#/!/! +8- ## %$%*65 82*92 6*8$ 8 9%5*%8 5 %25*21 6 %2$*678 2%7*%8 % 6%2 %8%*1$ %%5 %78*79 $*6$ 8 56%*71 7='/;#/!/! +8- ## %72*86 82*8# 6*15 8 972*68 5 7$2*#% 6 %27*9$8 278*68 % 6%2 %16*#5 %%5 %5$*57 #*#8 8 59#*7$ 7='/;#/!/! +8- ## %28*$$ 82*8# 6*15 8 96%*#2 5 75%*71 6 %22*528 26#*#2 % 6%2 77$*7# %%5 %55*15 $*$$ 8 6#%*1$ 0,C(( @@ @ Benjamin Hand Digitally signed by Benjamin Hand Date: 2022.05.25 11:21:48 -08'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2022.05.25 11:42:50 -08'00' !"# $ !%"& '!& ())*+(& ',- .- " - / - - ! 0- 01- " #$% " #$%&# #-'' ()*#$#+$$ ,- (). -" #$%&#1-/-"!0 / -()*#$#+$$ ,- (). 2# - (" #$% .- 3 .- ', 4- . .-"!! & #1%2,)3 . / #1%2,/ -/-/"!. 4$5 ! "( & " 0 0' - - 5 - 2# - 657"0 627" '% 0#- " #$% $+$$ $+$$ % 6%7 ##8+%9$ %#9 985+6#6 8%+$$0#5-#$#+$$ $+$$ 8$+9189%%:/ #6#+629299:( 01 89: $ # 8: . 89: " #$%&# 2. ; 5<#8<%$%% #6+2# 27+86 66 $$#+$$$$$$$$ '#-/- 2- " #$%&# #+$ " / - #$.8/: 8 : 627" 8 : 89: 657"0 8 : ;#-9 %6$+$$ 7%+1#$+$$$+$$$+$$ $. 8 : ' . 2. 801: 8 : 6<%6<%$%% ! 7=>?&=& $2#> @!;?%6+$$ 1$$+$$ #$!;?>,! #$.$2<#5<%$%# 7='!! $62 @' ' ' 162+$$ # #$8+$$ #$!!,! #$.#%<$6<#182 7=(0;#0!0! $#$A@;B' 0 # #9%+$$ 6 26%+$$ #$&#(- 0! ,! $2<#5<%$%# 7=(0;#0!0! $#$A@;B' 0 6 9#9+$$ 9 %6$+$$ #$(- 0! ,! #$$9<7$<%$#1 7=(0;#0!0! $#$A@;B' 0 9 7%6+$$ #% 257+#1 (0;#0!0! ," #$%&$7<%1<%$%% 8 : < 89: = 89: 657"0 8 : 627" 8 : / 8 : / 8 : 2# 8: 5 8: / 8: 897&>: 2. $+$$ $+$$ $+$$ $+$$ $+$$ $+$$#$#+$$ % 6%7 ##8+%9 %#9 985+6% $+$$ $+$$ "/);/) %6+$$ $+## 27+76 %6+$$ $+$# $+$%28+$$ % 6%7 ##8+%1 %#9 985+65 $+55 $+$% 7=>?&=&,#. 6$+$$ $+%# 27+76 6$+$$ $+$7 $+$16#+$$ % 6%7 ##8+7$ %#9 985+8# $+5$ $+$2 7=>?&=&,#. 26+$$ $+%2 68+#8 26+$$ $+$2 $+#9%8+$$ % 6%7 ##8+76 %#9 985+2$ $+72 $+#8 7=>?&=&,#. #$$+$$ $+%# 51+78 #$$+$$ $+#5 $+%2#+$$ % 6%7 ##8+5# %#9 985+29 $+%2 $+%8 7=>?&=&,#. #%6+$$ $+#2 57+5# #%6+$$ $+#1 $+77%5+$$ % 6%7 ##8+58 %#9 985+96 $+#9 $+75 7=>?&=&,#. #6$+$$ $+5% 6%+9% #6$+$$ $+%2 $+5751+$$ % 6%7 ##8+65 %#9 985+16 #+$% $+58 7=>?&=&,#. #26+$$ $+88 62+81 #26+$$ $+5# $+8%25+$$ % 6%7 ##8+82 %#9 986+#5 $+19 $+89 7=>?&=&,#. %$$+$$ $+9$ 66+78 %$$+$$ $+69 $+9111+$$ % 6%7 ##8+95 %#9 986+5# $+62 $+12 7=>?&=&,#. %%6+$$ $+2% 67+86 %%5+11 $+29 #+#8#%7+11 % 6%7 ##2+$7 %#9 986+81 $+77 #+%9 7=>?&=&,#. ',- .- " - / - - ! 0- 01- " #$% " #$%&# #-'' ()*#$#+$$ ,- (). -" #$%&#1-/-"!0 / -()*#$#+$$ ,- (). 2# - (" #$% 8 : < 89: = 89: 657"0 8 : 627" 8 : / 8 : / 8 : 2# 8: 5 8: / 8: 897&>: 2. %6$+$$ $+27 88+8% %51+11 $+17 #+57#59+11 % 6%7 ##2+#9 %#9 986+18 $+88 #+68 7=>?&=&,#. %26+$$ $+69 #$%+$7 %25+11 $+12 #+2$#27+11 % 6%7 ##2+%# %#9 988+%5 #+81 #+25 7=>?&=&,#. 7$$+$$ #+$9 #56+6$ %11+11 $+26 #+18#19+11 % 6%7 ##8+19 %#9 988+51 7+$9 #+81 7=>?&=&,#. 7%6+$$ #+2$ #86+76 7%5+19 $+#1 %+#9%%7+19 % 6%7 ##8+5% %#9 988+2$ 7+#$ #+76 7=>?&=&,#. 76$+$$ %+#1 #92+69 751+12 $+85 %+%#%59+12 % 6%7 ##6+61 %#9 988+2# 7+68 $+82 7=>?&=&,#. 726+$$ 7+%$ %#%+$# 725+15 #+2$ #+29%27+15 % 6%7 ##5+65 %#9 988+%6 8+$7 $+58 7=>?&=&,#. 5$$+$$ 7+1% %#9+15 711+91 %+18 $+92%19+91 % 6%7 ##7+7$ %#9 986+7% 7+76 %+$# 7=>?&=&,#. 5%6+$$ 5+2# %%8+2# 5%5+9% 5+77 $+5#7%7+9% % 6%7 ###+18 %#9 985+$$ 7+1% 7+98 7=>?&=&,#. 56$+$$ 6+65 %75+9# 551+2% 6+27 %+#5759+2% % 6%7 ##$+8# %#9 98%+%7 5+5$ 6+12 7=>?&=&,#. 526+$$ 8+7% %71+98 525+61 2+## 5+7%727+61 % 6%7 #$1+%2 %#9 98$+$% 7+26 9+7% 7=>?&=&,#. 6$$+$$ 2+%7 %5%+78 511+5# 9+67 8+1$719+5# % 6%7 #$2+1# %#9 962+5# 7+97 #$+1% 7=>?&=&,#. 6%6+$$ 9+%9 %5%+62 6%5+#9 #$+$1 1+1$5%7+#9 % 6%7 #$8+57 %#9 965+79 5+%$ #7+96 7=>?&=&,#. 66$+$$ 1+%5 %5%+%$ 659+91 ##+98 #7+%2552+91 % 6%7 #$5+25 %#9 96$+18 7+96 #2+#8 7=>?&=&,#. 626+$$ 1+99 %5#+91 627+65 #7+9# #8+1552%+65 % 6%7 #$%+91 %#9 952+%6 %+62 %$+21 7=>?&=&,#. 8$$+$$ #$+72 %5#+98 619+#6 #6+99 %$+9#512+#6 % 6%7 #$$+1# %#9 957+77 #+18 %5+85 7=>?&=&,#. 8%6+$$ #$+91 %5%+$6 8%%+2% #9+$5 %5+996%#+2% % 6%7 $19+95 %#9 971+%# %+$9 %9+82 7=>?&=&,#. 86$+$$ ##+82 %5#+55 852+%5 %$+78 %1+#1658+%5 % 6%7 $18+87 %#9 975+95 7+#8 7%+16 7=>?&=&,#. 826+$$ #%+%8 %5#+2# 82#+2$ %%+97 77+2662$+2$ % 6%7 $15+%2 %#9 97$+%7 %+72 72+6$ 7=>?&=&,#. 2$$+$$ #7+$2 %5#+97 818+$1 %6+5% 79+69616+$1 % 6%7 $1#+9$ %#9 9%6+75 7+%5 5%+7$ 7=>?&=&,#. 2%6+$$ #7+98 %5#+9% 2%$+5$ %9+#2 57+2#8#1+5$ % 6%7 $91+#2 %#9 9%$+#5 7+#8 52+5$ 7=>?&=&,#. 26$+$$ #5+81 %5#+15 255+87 7#+$2 51+#6857+87 % 6%7 $98+5$ %#9 9#5+85 7+7% 6%+21 7=>?&=&,#. 226+$$ #6+69 %5#+18 289+28 75+#5 65+1#882+28 % 6%7 $97+52 %#9 9$9+9$ 7+68 69+6$ 7=>?&=&,#. 9$$+$$ #8+78 %5%+$# 21%+9$ 72+72 8$+1981#+9$ % 6%7 $9$+71 %#9 9$%+88 7+#% 85+6# 7=>?&=&,#. 9%6+$$ #2+$9 %5%+$1 9#8+25 5$+25 82+772#6+25 % 6%7 $22+#2 %#9 218+%% %+99 2$+21 7=>?&=&,#. 96$+$$ #9+$2 %5%+%1 95$+62 55+%2 25+$#271+62 % 6%7 $27+9# %#9 291+58 7+12 22+72 7=>?&=&,#. 926+$$ #9+17 %5%+6# 985+%9 52+15 9#+$5287+%9 % 6%7 $2$+7$ %#9 29%+76 7+56 95+%9 7=>?&=&,#. 1$$+$$ #1+9# %5%+85 992+92 6#+28 99+5$298+92 % 6%7 $88+88 %#9 225+1$ 7+6% 1#+59 7=>?&=&,#. 162+$$ %#+6$ %55+$$ 15#+%$ 8$+29 #$8+7295$+%$ % 6%7 $69+$9 %#9 268+2% 7+$9 #$9+9% 7='!!,%. # #$8+$$ %8+$$ %56+$$ # $22+66 98+68 #8$+67128+66 % 6%7 $77+8# %#9 2$#+15 7+$7 #61+91 7='!!,%. # #9%+$$ %$+97 %79+67 # #52+%9 #$$+82 #92+#9# $58+%9 % 6%7 $%$+#6 %#9 825+12 2+61 #98+%# 7=(0;#0!0! ,7. # %29+$$ #6+97 %78+%# # %79+79 ##8+92 %#%+85# #72+79 % 6%7 $$5+68 %#9 851+#7 6+%8 %#7+86 7=(0;#0!0! ,7. # 728+$$ ##+88 %7%+21 # 777+66 #7$+7$ %7#+85# %7%+66 % 6%% 11#+61 %#9 8%1+9# 5+77 %76+%6 7=(0;#0!0! ,7. # 6$9+$$ 9+5% %75+%9 # 587+6# #55+$# %6$+### 78%+6# % 6%% 129+77 %#9 8##+$# %+58 %68+9$ 7=(0;#0!0! ,7. # 8$6+$$ 2+6# %66+86 # 661+8$ #51+27 %8%+$%# 569+8$ % 6%% 12%+1$ %#9 619+18 7+#2 %89+$2 7=(0;#0!0! ,7. # 811+$$ 8+%7 %16+#9 # 86%+12 #51+$9 %2%+8$# 66#+12 % 6%% 127+9$ %#9 699+5# 6+#$ %27+%2 7=(0;#0!0! ,7. # 291+$$ 5+78 7%7+5# # 25%+8$ #55+%8 %21+$8# 85#+8$ % 6%% 129+29 %#9 69%+$2 7+6$ %2%+27 7=(0;#0!0! ,7. # 996+$$ 7+17 %6+72 # 979+71 #79+76 %21+9%# 272+71 % 6%% 195+2$ %#9 69#+55 5+58 %89+#1 7=(0;#0!0! ,7. # 19$+$$ 9+#8 6%+18 # 17%+98 #7#+76 %27+$5# 97#+98 % 6%% 11#+66 %#9 699+71 6+%9 %69+8% 7=(0;#0!0! ,7. % $27+$$ #7+%7 8$+87 % $%5+%% #%%+#5 %69+51# 1%7+%% % 6%7 $$$+5$ %#9 8$7+#8 6+86 %5%+11 7=(0;#0!0! ,7. % #89+$$ #8+$2 8%+$$ % ##8+#% ##$+85 %72+5$% $#6+#% % 6%7 $##+71 %#9 8%5+6% 7+$# %%#+92 7=(0;#0!0! ,7. ',- .- " - / - - ! 0- 01- " #$% " #$%&# #-'' ()*#$#+$$ ,- (). -" #$%&#1-/-"!0 / -()*#$#+$$ ,- (). 2# - (" #$% 8 : < 89: = 89: 657"0 8 : 627" 8 : / 8 : / 8 : 2# 8: 5 8: / 8: 897&>: 2. % %8%+$$ #1+%9 8$+1% % %$6+82 18+19 %#%+76% #$5+82 % 6%7 $%5+55 %#9 851+1$ 7+57 #18+21 7=(0;#0!0! ,7. % 766+$$ %5+6$ 62+82 % %1#+15 21+%$ #9%+8#% #1$+15 % 6%7 $5#+6$ %#9 89$+$6 6+28 #86+2$ 7=(0;#0!0! ,7. % 56%+$$ %8+79 68+%7 % 721+67 68+58 #52+2$% %29+67 % 6%7 $87+71 %#9 2#6+6$ %+$5 #%2+86 7=(0;#0!0! ,7. % 652+$$ 7%+89 68+6# % 58%+#6 7$+66 #$9+27% 78#+#6 % 6%7 $99+78 %#9 266+$9 8+87 95+2% 7=(0;#0!0! ,7. % 85$+$$ 76+89 68+6# % 671+$9 #+2% 86+#8% 579+$9 % 6%7 ##8+#7 %#9 211+77 7+%7 78+96 7=(0;#0!0! ,7. % 276+$$ 79+27 61+6% % 8#5+25 %9+86 #8+57% 6#7+25 % 6%7 #56+7% %#9 959+29 7+25 #6+#7 7=(0;#0!0! ,7. % 97$+$$ 5%+%9 87+#2 % 898+12 69+#8 72+27% 696+12 % 6%7 #27+6# %#9 1$7+87 5+51 81+7% 7=(0;#0!0! ,7. % 1%5+$$ 52+75 86+69 % 267+85 98+25 12+58% 86%+85 % 6%7 %$$+86 %#9 185+$7 6+89 #%6+22 7=(0;#0!0! ,7. 7 $#2+$$ 6#+8# 86+92 % 9#5+$8 ##6+21 #8#+99% 2#7+$8 % 6%7 %%9+#5 %#1 $%1+#5 5+8$ #96+#8 7=(0;#0!0! ,7. 7 ##7+$$ 66+$7 86+2$ % 92#+71 #52+72 %7%+$1% 22$+71 % 6%7 %69+$% %#1 #$$+$9 7+62 %51+9% 7=(0;#0!0! ,7. 7 %$2+$$ 66+89 88+%7 % 1%5+97 #29+98 7$%+2%% 9%7+97 % 6%7 %92+9$ %#1 #2#+56 $+97 7#5+87 7=(0;#0!0! ,7. 7 7$%+$$ 62+15 86+21 % 128+97 %##+#1 726+75% 926+97 % 6%7 7#9+72 %#1 %55+97 %+5# 79#+%7 7=(0;#0!0! ,7. 7 712+$$ 61+$9 86+85 7 $%8+58 %55+6$ 551+#9% 1%6+58 % 6%7 751+1$ %#1 7#1+56 #+%# 551+7% 7=(0;#0!0! ,7. 7 51%+$$ 61+68 85+7% 7 $25+17 %21+$8 6%7+%%% 127+17 % 6%7 79%+88 %#1 715+%1 #+7$ 6#9+66 7=(0;#0!0! ,7. 7 698+$$ 8$+%1 87+9# 7 #%%+$5 7#5+85 618+727 $%#+$5 % 6%7 5#8+52 %#1 589+%9 $+1# 699+#8 7=(0;#0!0! ,7. 7 89#+$$ 62+1# 8%+6$ 7 #2$+9% 76#+57 881+#$7 $81+9% % 6%7 56#+6$ %#1 65#+92 %+22 869+62 7=(0;#0!0! ,7. 7 228+$$ 62+8% 8%+#5 7 %%#+51 799+28 25$+%87 #%$+51 % 6%7 592+#$ %#1 8#7+1# $+55 2%9+62 7=(0;#0!0! ,7. 7 982+$$ 69+%9 8%+## 7 %81+29 5%5+9% 9$9+557 #89+29 % 6%7 6%#+6# %#1 89%+15 $+27 216+91 7=(0;#0!0! ,7. 7 187+$$ 61+$$ 8#+81 7 7#1+25 587+55 99$+267 %#9+25 % 6%7 669+72 %#1 268+#8 $+95 982+8$ 7=(0;#0!0! ,7. 5 $61+$$ 62+27 87+11 7 72$+#$ 6$$+26 167+587 %81+#$ % 6%7 617+17 %#1 9%1+25 %+57 179+57 7=(0;#0!0! ,7. 5 #67+$$ 69+#7 85+96 7 5%$+$# 676+#5 # $%6+7$7 7#1+$# % 6%7 8%8+69 %#1 1$%+5$ $+99 # $$8+75 7=(0;#0!0! ,7. 5 %51+$$ 69+12 86+$9 7 52$+#$ 681+9$ # $11+6#7 781+#$ % 6%7 861+55 %#1 122+5# $+1$ # $26+26 7=(0;#0!0! ,7. 5 75%+$$ 61+61 86+#2 7 6#2+8# 8$7+57 # #2%+$57 5#8+8# % 6%7 81#+7# %%$ $6$+27 $+82 # #57+71 7=(0;#0!0! ,7. 5 578+$$ 62+61 85+5$ 7 688+61 872+8$ # %55+8%7 586+61 % 6%7 2%7+2% %%$ #%5+## %+%5 # %##+6# 7=(0;#0!0! ,7. 5 67#+$$ 62+%1 87+18 7 8#2+2% 82%+52 # 7#8+817 6#8+2% % 6%7 268+96 %%$ #12+$$ $+6$ # %21+15 7=(0;#0!0! ,7. 5 8%8+$$ 62+9% 85+%$ 7 889+81 2$2+6# # 799+9$7 682+81 % 6%7 21$+#6 %%$ %81+17 $+8$ # 759+65 7=(0;#0!0! ,7. 5 2#1+$$ 69+8# 85+58 7 2#2+82 25#+28 # 58$+$67 8#8+82 % 6%7 9%%+88 %%$ 75#+19 $+99 # 5#8+$$ 7=(0;#0!0! ,7. 5 9#5+$$ 61+## 85+62 7 288+9$ 228+25 # 677+567 886+9$ % 6%7 966+92 %%$ 5#8+%$ $+65 # 596+%6 7=(0;#0!0! ,7. 5 1$7+$$ 61+51 85+95 7 9#%+%5 9$1+55 # 8$%+857 2##+%5 % 6%7 998+91 %%$ 598+#8 $+6$ # 66$+%1 7=(0;#0!0! ,7. 6 $$%+$$ 61+6$ 85+19 7 98%+51 956+8# # 821+917 28#+51 % 6%7 1%#+#1 %%$ 685+%8 $+#% # 8%%+87 7=(0;#0!0! ,7. 6 $19+$$ 61+2$ 86+66 7 1##+$2 99$+%8 # 266+$17 9#$+$2 % 6%7 165+$% %%$ 85$+%2 $+66 # 81%+69 7=(0;#0!0! ,7. 6 #1%+$$ 8$+7% 86+5# 7 169+$8 1#5+$5 # 9%1+#87 962+$8 % 6%7 198+$# %%$ 2#6+#5 $+82 # 28#+#1 7=(0;#0!0! ,7. 6 %99+$$ 8$+18 86+%% 5 $$6+#7 159+11 # 1$6+#17 1$5+#7 % 6%5 $#1+## %%$ 21#+19 $+81 # 97#+97 7=(0;#0!0! ,7. 6 725+$$ 8#+5% 86+#1 5 $58+62 19$+61 # 127+617 156+62 % 6%5 $51+$8 %%$ 98#+#7 $+65 # 916+6% 7=(0;#0!0! ,7. 6 581+$$ 8%+%1 86+67 5 $1#+79 # $#6+6# % $51+277 11$+79 % 6%5 $9%+#5 %%$ 179+$9 $+12 # 188+%# 7=(0;#0!0! ,7. 6 687+$$ 8$+97 85+15 5 #78+#6 # $6$+#7 % #%5+215 $76+#6 % 6%5 ##5+15 %%# $#7+16 #+86 % $78+$6 7=(0;#0!0! ,7. 6 862+$$ 69+98 85+61 5 #97+78 # $95+29 % #19+7#5 $9%+78 % 6%5 #52+9# %%# $99+%9 %+#% % #$6+$1 7=(0;#0!0! ,7. 6 26%+$$ 61+$% 85+81 5 %7%+79 # ##1+85 % %2#+955 #7#+79 % 6%5 #9$+99 %%# #8%+87 $+#1 % #25+7$ 7=(0;#0!0! ,7. 6 9#9+$$ 69+%5 86+#1 5 %88+25 # #57+6$ % 7%%+915 #86+25 % 6%5 %$7+6% %%# %#5+%5 #+76 % %%%+$9 7=(0;#0!0! ,5. 6 1#6+$$ 8$+79 85+52 5 7#8+%5 # #29+19 % 719+795 %#6+%5 % 6%5 %72+#2 %%# %1$+68 %+7$ % %1%+92 7=(0;#0!0! ,5. 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Received By: Date: Date: 6/02/2022 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: TBU A-10RD2 + TBU A-10RD2PB1 PTD: 222-002 API: 50-733-20064-02-00 + 50-733-20064-71-00 FINAL LWD FORMATION EVALUATION LOGS (04/10/2022 to 05/20/2022) ROP, PCG, DGR, ADR, EWR (2” & 5” MD/TVD Color Logs) Final Definitive Directional Survey Main Folder Contents: Sub-Folder Contents: Please include current contact information if different from above. PTD: 222-002 T36679 PB1: T36680 Kayla Junke Digitally signed by Kayla Junke Date: 2022.06.03 08:57:59 -08'00' 5HJJ-DPHV%2*& )URP6KDQH+DXFNVKDXFN#KLOFRUSFRP! 6HQW0RQGD\0D\30 7R5HJJ-DPHV%2*&%URRNV3KRHEH/2*&'2$$2*&&3UXGKRH%D\ &F6HDQ0F/DXJKOLQ%U\DQ/DIOHXU& 6XEMHFW+LOFRUS0RQRSRG$UGERSWHVWUHSRUW $WWDFKPHQWV+LOFRUS[OV[ Dƌ͘ZĞŐŐ ,ĞƌĞŝƐŽƵƌƚĞƐƚƌĞƉŽƌƚ dŚĂŶŬƐ ^ŚĂŶĞZ,ĂƵĐŬ ,ŝůĐŽƌƉ^D ZŝŐϵϬϳͲϳϳϲͲϲϵϳϬ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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:56 DATE: 5/22/22 Rig Rep.: Rig Phone: 907-776-6677 Operator: Op. Phone:907-776-7970 Rep.: E-Mail Well Name: PTD #22220020 Sundry # Operation: Drilling: X Workover: Explor.: Test: Initial: Weekly: Bi-Weekly: X Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:3074 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 4P Standing Order Posted P Misc.NA Inside BOP 2P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8 5m P Pit Level Indicators PP #1 Rams 1 2 7/8 x 5 1/2 5K P Flow Indicator PP #2 Rams 1 Blinds 5K FP Meth Gas Detector PP #3 Rams 1 2 7/8 x 5 1/2 5K P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8 manual 5K P Inside Reel valves 0NA HCR Valves 2 3 1/8 CIW 5K P Kill Line Valves 2 1/8 Demco CIW 5 P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0NA Time/Pressure Test Result System Pressure (psi)3025 P CHOKE MANIFOLD:Pressure After Closure (psi)1300 P Quantity Test Result 200 psi Attained (sec)38 P No. Valves 16 P Full Pressure Attained (sec)225 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 6 @ 2500 av P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:1 Test Time:11.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 5/18/2022, 19:17 Waived By Test Start Date/Time:5/21/2022 5:00 (date) (time)Witness Test Finish Date/Time:5/22/2022 19:00:00 PM BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Used 4'' & 5'' test joints for testing. 1 Total F/P of low test #5. Purged air and retested good. Tested all gas alarms good. Bag closed in 13 sec. Lafleur/Boyd Hilcorp Alaska Hauck / Anderson Tradiong Bay St A-10RD2 Test Pressure (psi): shauck@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0522_BOP_Hilcorp56_TB_State_A-10RD2 9 9 9 9 9 9 9 9 9 9 9 9 -5HJJ F/P of low test #5. Bag closed in 13 sec. 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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Shane Hauck To:Regg, James B (OGC) Cc:Brooks, Phoebe L (OGC) Subject:RE: [EXTERNAL] RE: Hilcorp rig #56 Monopod A-10rd2 Bope test report Date:Wednesday, April 27, 2022 4:32:42 PM Attachments:Hilcorp 56 4-25-2022 BOP Test.xlsx Sorry Mr. Regg Here is Revised test report w/ correct date and times Thanks Shane Hauck Hilcorp DSM Rig 907-776-7970 From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Wednesday, April 27, 2022 3:18 PM To: Shane Hauck <shauck@hilcorp.com> Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: [EXTERNAL] RE: Hilcorp rig #56 Monopod A-10rd2 Bope test report Start/End dates (and times?) incorrect; please revise and resend Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Shane Hauck <shauck@hilcorp.com> Sent: Wednesday, April 27, 2022 6:10 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: David Hebert Jr. - (C) <David.Hebert@hilcorp.com>; Brett Anderson - (C) <Brett.Anderson@hilcorp.com>; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com> Subject: Hilcorp rig #56 Monopod A-10rd2 Bope test report Mr. Regg Here is our Test report. Request was sent in 4-23-22 @ 04:40 hrs and two fallow up E-mails with no Reply's Thanks 7UDGLQJ%D\6WDWH$5' 37' Hilcorp DSM Shane Hauck Rig 907-776-7970 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:56 DATE: 4/25/22 Rig Rep.: Rig Phone: 907-776-6677 Operator: Op. Phone:907-776-7970 Rep.: E-Mail Well Name: PTD #22220020 Sundry # Operation: Drilling: X Workover: Explor.: Test: Initial: Weekly: X Bi-Weekly: Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:3074 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 3P Standing Order Posted P Misc.NA Inside BOP 2P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8 5m P Pit Level Indicators PP #1 Rams 1 2 7/8 x 5 1/2 5K P Flow Indicator PP #2 Rams 1 Blinds 5K P Meth Gas Detector PP #3 Rams 1 2 7/8 x 5 1/2 5K P H2S Gas Detector FP FP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8 manual 5K P Inside Reel valves 0NA HCR Valves 2 3 1/8 CIW 5K P Kill Line Valves 2 1/8 Demco CIW 5 P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0NA Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)1400 P Quantity Test Result 200 psi Attained (sec)32 P No. Valves 16 P Full Pressure Attained (sec)203 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 6 @ 2300 av P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:2 Test Time:8.5 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 4/23/2022, 04:20 Waived By Test Start Date/Time:4/25/2022 13:30 PM (date) (time)Witness Test Finish Date/Time:4/25/2022 22:00 PM BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Hilcorp Used 4'' & 5'' test joints for testing. 2 Total F/P. H2S sensor @ pits failed chg out same and retested good. Annular closing time was @ 29 sec. Bruce Hebert/Daryl Boyd Hilcorp Alaska Hauck /Anderson Trading Bay ST A-10RD2 Test Pressure (psi): shauck@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0425_BOP_Hilcorp56_TBU_A-10RD2 9 9 9 9 9 9 0RQRSRG3ODWIRUP 9 9 9 9 99 9 9 -5HJJ 1RWLILFDWLRQV\VWHPLVVXHVRYHUWKH ZHHNHQG$2*&&ZDLYHULQUHVSRQVH WRWHVWQRWLFHQRWVHQWMEU -5HJJ 4/25/22 Annular closing time was @ 29 sec. FP FP 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:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: High gas alarm activation Date:Wednesday, April 27, 2022 9:52:44 AM TBU A-10RD2 (PTD 2220020) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Shane Hauck <shauck@hilcorp.com> Sent: Wednesday, April 27, 2022 7:23 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>; Steve Dambacher - (C) <Steve.Dambacher@hilcorp.com>; Sloan Sunderland <ssunderland@hilcorp.com>; Brett Anderson - (C) <Brett.Anderson@hilcorp.com>; David Hebert Jr. - (C) <David.Hebert@hilcorp.com> Subject: High gas alarm activation Well- Trading Bay State A-10RD Mr. Regg, We are informing you that we had our pits H2S alarms sound while we were washing and reaming to btm with quick High spike t/ 47 ppm all nonessential personnel mustered in primary muster area and production swept and monitored area for remainder of the circulation w/ a few more spikes t/ 16- 17 PPM after bottom up we have had zero readings ever since Thanks Shane Hauck Hilcorp DSM Rig 907-776-7970 From:McLellan, Bryan J (OGC) To:Sean McLaughlin Cc:Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: Adding MPD equipment to A-10RD2 (222-002) Date:Tuesday, March 29, 2022 5:13:00 PM Sean, Hilcorp has approval to use the MPD system as described in this email chain. I’ll add this documentation to the existing PTD 222-002, so no need to submit a sundry for change to approved permit. Regards 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: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com> Sent: Tuesday, March 29, 2022 4:36 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: Adding MPD equipment to A-10RD2 (222-002) Bryan, See answers below: 1. The pump lines are independent of the kill line. They tee into the standpipe. 2. The return line is stand alone. 3. CH-01 is an auto choke Regards, sean From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, March 29, 2022 2:55 PM To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com> Subject: [EXTERNAL] RE: Adding MPD equipment to A-10RD2 (222-002) Sean, A couple questions about the MPD rig-up: 1. Are the MPD pump lines tied in to the standpipe or kill line somehow, or is it a standalone piping system? 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:Sloan Sunderland To:Regg, James B (OGC);DOA AOGCC Prudhoe Bay;Brooks, Phoebe L (OGC) Cc:Sean McLaughlin;Cody Dinger;Steve Dambacher - (C);Shane Hauck;Bryan Lafleur - (C);Donnie Durham Subject:RE: [EXTERNAL] RE: Hilcorp 56 4-13-2022 Bop Test Date:Friday, April 15, 2022 4:31:57 AM Annular Close time was 28 Sec, Rams were 8 sec, & HCrs 1sec. From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Thursday, April 14, 2022 8:54 PM To: Sloan Sunderland <ssunderland@hilcorp.com>; doa aogcc prudhoe bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>; Cody Dinger <cdinger@hilcorp.com>; Steve Dambacher - (C) <Steve.Dambacher@hilcorp.com>; Shane Hauck <shauck@hilcorp.com>; Bryan Lafleur - (C) <Bryan.Lafleur@hilcorp.com>; Donnie Durham <ddurham@enterpriseoffshore.com> Subject: [EXTERNAL] RE: Hilcorp 56 4-13-2022 Bop Test Changed from Drilling/Weekly to Drilling/Initial I count 5 failures What were the close times for Annular, Rams, HCR? Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Sloan Sunderland <ssunderland@hilcorp.com> Sent: Thursday, April 14, 2022 7:54 AM 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> Cc: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>; Cody Dinger <cdinger@hilcorp.com>; Steve Dambacher - (C) <Steve.Dambacher@hilcorp.com>; Shane Hauck <shauck@hilcorp.com>; Bryan Lafleur - (C) <Bryan.Lafleur@hilcorp.com>; Donnie Durham <ddurham@enterpriseoffshore.com> Subject: Hilcorp 56 4-13-2022 Bop Test See attached Report 7UDGLQJ%D\6WDWH$5' 37' Annular Close time was 28 Sec, Rams were 8 sec, & HCrs 1sec. Sloan Sunderland Hilcorp Alaska LLC Sr Drilling Forman Cookinlet Offshore Office 776-7970 Cell Phone 907-715-0591 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:56 DATE: 4/13/22 Rig Rep.: Rig Phone: 907-776-6677 Operator: Op. Phone:907-776-7970 Rep.: E-Mail Well Name:PTD #22220020 Sundry # Operation: Drilling: X Workover: Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:3074 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 3P Standing Order Posted P Misc.NA Inside BOP 2P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8 5m P Pit Level Indicators PP #1 Rams 1 2 7/8 x 5 1/2 5K P Flow Indicator PP #2 Rams 1 Blinds 5K P Meth Gas Detector PP #3 Rams 1 2 7/8 x 5 1/2 5K P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8 manual 5K FP Inside Reel valves 0NA HCR Valves 2 3 1/8 CIW 5K FP Kill Line Valves 2 1/8 Demco CIW 5 P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0NA Time/Pressure Test Result System Pressure (psi)3100 P CHOKE MANIFOLD:Pressure After Closure (psi)1400 P Quantity Test Result 200 psi Attained (sec)35 P No. Valves 16 FP Full Pressure Attained (sec)203 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 6 @ 2458 av P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:5 Test Time:13.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 4/09/2022, 1450 Waived By Test Start Date/Time:4/12/2022 23:30:00 PM (date) (time)Witness Test Finish Date/Time:4/13/2022 13:30:00 PM BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Lou Laubenstein Hilcorp Use 4'' & 5'' test joints for testing. 5 Total F/P. Test #3 Changed Test fittings and test manifold valve. Retest Good. Test #4 CMV 2,4,6 FP. Failed on low, Work valves change choke manifold Grease fitting on valve #4. Test #5 Bled below 3500, pump up Test sensator & retest Good. All rams tested to 250/3500, Annular tested to 2500 psi. Bruce Hebert/Bill McGehee Hilcorp Alaska Sunderland/Anderson Trading Bay State A-10RD2 Test Pressure (psi): ssunderland@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0413_BOP_Hilcorp56_TBU_State_A-10RD2 9 9 9 9 99 9 9 9 9 9 9 9 9 - 5HJJ 9 FP FP FP 5 Total F/P.j Test #4 CMV 2,4,6 FP. BOPE Test Charts – Hilcorp 56 Trading Bay State A-10RD2 (PTD 2220020) 4/13/2022 DATE:RIG # 56 TIME: Test #Low PSI High PSI Pass/ Fail 1 250 3500 Pass 2 250 3500 Pass 3 250 3500 FP 4 250 3500 FP 5 250 3500 FP 6 250 3500 Pass 7 250 3500 Pass 8 250 2500 Pass 9 250 3500 Pass 0 Pass 10 250 3500 Pass 11 250 3500 Pass 12 250 2500 Pass Manifold Annular 1500 600 1500 600 4'' TJ, TPR, 4'' TIW, 4'' IBOP, Choke HCR & Kill INITIAL 200 PSI = 35 SEC / FULL = 203 SEC Accumulator Test Accumulator Initial Pressure Final Pressure Re-charge Time 1400 3100 4&5 13 5/8 5K Preventer Type Closing Time 4'' TJ, LPR, #2 4'' TIW 5 and 5 4'' Pipe, Annular #2 TIW, HCR Choke & Kill 5 and 5 5 and 5 HILCORP BOP TEST SHEET SUPERINTENDENT: TESTING COMPANY:Monty Myers Enterprize 13-Apr-22 RIG CONTRACTOR: WELL NAME: 5 and 55'' TJ, TPR, 5'' TIW,HCR Kill ,CMV 8,9,12,13,14 Minutes Held (Low/High) 2330-1300 HILCORP REP: Monopod A-10RD2 Enterprize TYPE OF OPERATION - (DRILLING / WORKOVER / OTHER): Drilling RIG SUPERVISOR: Hebert/McGeheeSunderland/Anderson Components Tested BOP SIZE & RATING:DP SIZES: Back up No2 = 2458 @ 6 Btls psi 5 and 5 Choke 1,2&3 Pump through and bleed down test 5'' TJ, TPR, Manual Kill ,CMV 1,7,10,11,13 5'' TJ, TPR, Manual kill, TD Lower Kelly ,CMV 2,4,6 5'' TJ, TPR, Manuel kill, TD Upper Kelly , HCR Choke 5'' TJ, TPR, 5'' IBOP, 4';' Demcokill, CMV, 3,5,15,16 5'' TJ, TPR, Manuel kill, TD Upper Kelly , Manual Choke ,5'' 5 and 5 5'' TJ, LPR, 5'' TIW 5'' TJ, Annular, 5'' TIW, manual Choke, Manual kill Blinds, Manual kill 5 and 5 5 and 5 5 and 5 5 and 5 5 and 5 5 and 5 Shafer 13 5/8 Annular 9 9 9 13-Apr-22 Monopod A-10RD2 FP FP FP Contract Testing Representative Signature:Hilcorp Representative Signature: Rig Supervisor Signature: Test #3 failed on high. Test #4 CMV 2,4,6 FP. Failed on low, Work valves change choke manifold Grease fitting on valve #4 Test #5 Bled below 3500, pump up Test sensator & retest Good. EXPLANTATION OF TESTS ON NEXT PAGE. ATTACH BOP AND MANIFOLD SCHEMATIC. Test witness waived By Lou Laubenstein with AOGCC All rams tested to 250/3500, Annular tested to 2500 psi. HILCORP BOP TEST NOTES We had three FP -5HJJ Test #3 failed on high. Test #4 CMV 2,4,6 FP. Test #5 Bled below 3500, 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. 2. Is the MPD return line tied in to your choke line, or is it standalone? 3. Is the CH-01 Auto back-pressure control console essentially an automated choke? 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: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com> Sent: Tuesday, March 22, 2022 4:17 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Adding MPD equipment to A-10RD2 (222-002) Bryan, Managed Pressure Drilling equipment will be rigged up on the A-10RD2 drill well. The equipment will be used to maintain constant bottom hole pressure while drilling and tripping. The intention is to enhance coal stability. P&ID is attached MPD equipment will not be used for well control The pump line will be tested to 1500 psi Planned mud weight will not change Target BHP will be equal to the ECD Please let me know if you have questions or concerns, Sean Sean McLaughlin Hilcorp Alaska, LLC Drilling Engineer Sean.McLaughlin@hilcorp.com Cell: 907-223-6784 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MANUAL GATE VALVE FL-02 FL-03CORIOLIS FLOW METER BOP STACK ACTUATED BALL VALVE GLOBE VALVE BUTTERFLY VALVE CHECK VALVE NEEDLE VALVE BALL VALVE PRESSURE RELIEF VALVE MANUAL CHOKE VALVE ACTUATED CHOKE VALVE PLUG VALVE INSTRUMENT FLAME ARRESTOR VALVE & FITTINGS LEGEND PIPE LINES AND INSTRUMENTATION LEGEND 2" 4" 6" CREATED BY: Ryan Ciolkosz DATE: APPROVED BY: Roberto Jacobs DATE: CLIENT: Hilcorp WELL: A-10RD2 MonoPodRIG: FILENAME: DIAGRAM INFORMATIONNOTES / OBSERVATIONS  THIS IS A STANDARD GENERIC P&ID FOR ILLUSTRATIONS PURPOSES ONLY.  PIPE SPECIFICATIONS, INCLUDING CONNECTION TYPE AND SCHEDULES SHALL BE INCLUDED IN A JOB SPECIFIC P&ID  ALL VALVES SHALL BE TAGGED IN A JOB SPEIFIC P&ID AV 10" CH-01 INSTRUMENTATION LINE PNEUMATIC LINE HYDRAULIC LINE FLOW RATE TEMPERATURE DENSITY TRANSMITTER Open Valve Close Valve Remove Color 22-Mar-22 From MP #1 From MP #2 FL-01 TO SHAKERSLT-01 LT-02 LT-07 LT-05 AUTO BACKPRESSURE CONTROL CONSOLE PRV FL-04 AVTo ShakersDraft 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty Myers Drilling Manger Hilcorp North Slope, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: North Trading Bay Field, Trading Bay Undefined Gas Pool, TBU A-10RD2 Hilcorp North Slope, LLC Permit to Drill Number: 222-002 Surface Location: 1602’ FSL, 570’ FEL, SEC. 4, T9N, R13W, SM, AK Bottomhole Location: 118’ FSL, 37’ FWL, SEC. 26, T10N, R13E, SM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,composite curves for well logs run must be submitted to the AOGCCwithin 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of February, 2022. Jeremy Price Digitally signed by Jeremy Price Date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y Samantha Carlisle at 8:52 am, Jan 18, 2022 'LJLWDOO\VLJQHGE\0RQW\00\HUV '1FQ 0RQW\00\HUVF 86 R +LOFRUS$ODVND//&RX 7HFKQLFDO 6HUYLFHV$.'ULOOLQJ HPDLO PP\HUV#KLOFRUSFRP 5HDVRQ,DPDSSURYLQJWKLVGRFXPHQW 'DWH 0RQW\0 0\HUV ; 7%8 ; EMP '/% 6HH DWWDFKHG FRQGLWLRQV RI DSSURYDO RQ WKH IROORZLQJ SDJH ; ; ; ; %-0 '65 ; JLC 2/1/2022 2/1/22 Jeremy Price Digitally signed by Jeremy Price Date: 2022.02.01 16:20:26 -09'00' PTD 222-002 TBU A-10RD2 Conditions of Approval 1.Initial BOP test to Rated Working Pressure 5000 psi. 2.Subsequent BOP tests to 3500 psi, subsequent annular tests to 2500 psi. 3.Send FIT/LOT data to AOGCC within 2 days of performing test. 4.Wellwork prior to exiting the window follows workover regulation with BOP test frequency of 7 days. Normally for the first well after a rig has been stacked, 7- day test frequency is required by AOGCC for the entire drilling operation. For this well, because of the risk to wellbore stability, a 14-day test frequency will be accepted if a BOP test if performed after the FIT, before drilling 6-1/8" hole section, and if good results are achieved on initial BOP tests. Hilcorp to confirm drilling BOP test frequency with AOGCC Jim Regg after results of first two BOP tests are available. 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OHDVWSSJKLJKHUWKDQWKHHVWLPDWHGUHVHUYRLUSUHVVXUHDQGDOORZLQJIRUDQDSSURSULDWHDPRXQWRINLFN WROHUDQFHLQFDVHZHOOFRQWUROPHDVXUHVDUHUHTXLUHG :KHUHUHTXLUHGWKH/27LVSHUIRUPHGLQWKHVDPHIDVKLRQDVWKHIRUPDWLRQLQWHJULW\WHVW,QVWHDGRI VWRSSLQJDWDSUHGHWHUPLQHGSRLQWVXUIDFHSUHVVXUHLVLQFUHDVHGXQWLOWKHIRUPDWLRQEHJLQVWRWDNHIOXLG DWWKLVSRLQWWKHSUHVVXUHZLOOFRQWLQXHWRULVHEXWDWDVORZHUUDWH7KHV\VWHPLVVKXWLQDQGSUHVVXUH PRQLWRUHGDVZLWKDQ),7 3DJH5HYLVLRQ'HFHPEHU NTB A-10RD2 PTD Program Rev 0 &KRNH0DQLIROG6FKHPDWLF 3DJH5HYLVLRQ'HFHPEHU NTB A-10RD2 PTD Program Rev 0 &DVLQJ'HVLJQ,QIRUPDWLRQ 3DJH5HYLVLRQ'HFHPEHU NTB A-10RD2 PTD Program Rev 0 ´+ROH6HFWLRQ0$63 3DJH5HYLVLRQ'HFHPEHU NTB A-10RD2 PTD Program Rev 0 3ORW1$'*RYHUQPHQWDO6HFWLRQV 3DJH5HYLVLRQ'HFHPEHU NTB A-10RD2 PTD Program Rev 0 6ORW'LDJUDP 3DJH5HYLVLRQ'HFHPEHU NTB A-10RD2 PTD Program Rev 0 'LUHFWLRQDO3URJUDPZS$WWDFKHGVHSDUDWHO\ !""# $%&'( )* & 49505400585063006750720076508100855090009450True Vertical Depth (900 usft/in)3600 4050 4500 4950 5400 5850 6300 6750 7200 7650 8100 8550 9000 9450 9900 10350 10800 11250 11700 12150Vertical Section at 32.91° (900 usft/in)A-10RD2 wp4 tgt1750080008500900095001000010500110001150012000125001300013500140001450015000TBS A-10RD7" TOW4 1/2" x 6 1/8"75008000850090009500100001050011000115001200012500130001350014000145001500015500160001650016523TBS A-10RD2 wp06KOP : 12.75º/100' : 8300' MD, 5557.72'TVD : 30° LT TFEnd Dir : 8317' MD, 5566.43' TVDStart Dir 4º/100' : 8337' MD, 5576.4'TVDEnd Dir : 9531.42' MD, 6145.97' TVDStart Dir 4º/100' : 15775.26' MD, 8641'TVDTotal Depth : 16522.63' MD, 9101' TVDHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: TBS A-10Water Depth: 62.00+N/-S +E/-W Northing EastingLatitudeLongitude0.00 0.002523116.280 218864.515 60.896822°N 151.578788°WSURVEY PROGRAMDate: 2021-08-19T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool25.00 900.00 A-10 SDI Keeper Gyro (TBS A-10) 3_Gyro-CT-KPR_Pipe957.00 1106.00 A-10 MSS (TBS A-10) 3_CB-Film-MSS1182.00 5752.00 A-10RD PB1 MWD OnTrak+Sag (TBS A-10RD PB1) 3_MWD+IFR1+MS+Sag5818.00 8300.00 A-10RD MWD OnTrak+Sag (TBS A-10RD) 3_MWD+IFR1+MS+Sag8300.00 8700.00 TBS A-10RD2 wp06 (Plan: TBS A-10RD2) 3_MWD_Interp Azi+Sag8700.00 16522.63 TBS A-10RD2 wp06 (Plan: TBS A-10RD2) 3_MWD+IFR1+MS+SagFORMATION TOP DETAILSNo formation data is availableREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well TBS A-10, True NorthVertical (TVD) Reference:WELL @ 101.00usft (Original Well Elev)Measured Depth Reference:WELL @ 101.00usft (Original Well Elev)Calculation Method: Minimum CurvatureProject:Trading Bay - McArthur River FieldSite:MonopodWell:TBS A-10Wellbore:Plan: TBS A-10RD2Design:TBS A-10RD2 wp06CASING DETAILSTVD TVDSS MD Size Name5557.72 5456.72 8300.00 7 7" TOW9101.00 9000.00 16522.63 4-1/2 4 1/2" x 6 1/8"SECTION DETAILSSecMD Inc Azi TVD +N/-S +E/-W Dleg TFace VSectTargetAnnotation1 8300.00 58.24 63.95 5557.72 2015.92 4254.08 0.00 0.00 4003.64 KOP : 12.75º/100' : 8300' MD, 5557.72'TVD : 30° LT TF2 8317.00 60.12 62.70 5566.43 2022.48 4267.12 12.75 -30.00 4016.23 End Dir : 8317' MD, 5566.43' TVD3 8337.00 60.12 62.70 5576.40 2030.43 4282.53 0.00 0.00 4031.28 Start Dir 4º/100' : 8337' MD, 5576.4'TVD4 9531.42 66.45 9.22 6145.97 2856.72 4864.51 4.00 -95.79 5041.17 End Dir : 9531.42' MD, 6145.97' TVD5 15775.26 66.45 9.22 8641.00 8506.46 5781.42 0.00 0.0010282.55 A-10RD2 wp4 tgt1 Start Dir 4º/100' : 15775.26' MD, 8641'TVD616522.63 36.55 9.22 9101.00 9077.28 5874.06 4.00 180.0010812.10 Total Depth : 16522.63' MD, 9101' TVD 22002750330038504400495055006050660071507700825088009350South(-)/North(+) (1100 usft/in)1650 2200 2750 3300 3850 4400 4950 5500 6050 6600 7150 7700 8250 8800 9350 9900 10450 11000 11550West(-)/East(+) (1100 usft/in)A-10RD2 wp4 tgt1T B S A -1 0 R D 7" TOW4 1/2" x 6 1/8"5 2 5 0 5 5 0 0575060006250650067507000725075007750800082508500875090009101TBS A-10RD2 wp06KOP : 12.75º/100' : 8300' MD, 5557.72'TVD : 30° LT TFEnd Dir : 8317' MD, 5566.43' TVDStart Dir 4º/100' : 8337' MD, 5576.4'TVDEnd Dir : 9531.42' MD, 6145.97' TVDStart Dir 4º/100' : 15775.26' MD, 8641'TVDTotal Depth : 16522.63' MD, 9101' TVDCASING DETAILSTVDTVDSS MDSize Name5557.72 5456.72 8300.00 7 7" TOW9101.00 9000.00 16522.63 4-1/2 4 1/2" x 6 1/8"Project: Trading Bay - McArthur River FieldSite: MonopodWell: TBS A-10Wellbore: Plan: TBS A-10RD2Plan: TBS A-10RD2 wp06WELL DETAILS: TBS A-10Water Depth: 62.00+N/-S +E/-WNorthingEastingLatitudeLongitude0.00 0.002523116.280 218864.515 60.896822°N 151.578788°WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well TBS A-10, True NorthVertical (TVD) Reference:WELL @ 101.00usft (Original Well Elev)Measured Depth Reference:WELL @ 101.00usft (Original Well Elev)Calculation Method:Minimum Curvature + # % " # , - , . . !" # !"$% ()%#( &' && '()!"!*""+,- '(. $ !"$%/"0 1-23 1 $ & ,'()!"!*""+,- '(. / ' , ' !" & % 0 ( + & 1 %(2 !4%5,(6 . 1 $!4%5,1 $-1-12. 7"8 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eparation Factor8400 8800 9200 9600 10000 10400 10800 11200 11600 12000 12400 12800 13200 13600 14000 14400 14800 15200 15600 16000Measured Depth (800 usft/in)A-04A wp5TBS A-10RDNo-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS: TBS A-10 NAD 1927 (NADCON CONUS) Alaska Zone 04Water Depth: 62.00+N/-S+E/-W NorthingEastingLatitudeLongitude0.000.002523116.280218864.51560.896822°N151.578788°WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well TBS A-10, True NorthVertical (TVD) Reference: WELL @ 101.00usft (Original Well Elev)Measured Depth Reference:WELL @ 101.00usft (Original Well Elev)Calculation Method:Minimum CurvatureCASING DETAILSTVD TVDSS MD Size Name5557.72 5456.72 8300.00 7 7" TOW9101.00 9000.00 16522.63 4-1/2 4 1/2" x 6 1/8"SURVEY PROGRAMDate: 2021-08-19T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool25.00 900.00 A-10 SDI Keeper Gyro (TBS A-10) 3_Gyro-CT-KPR_Pipe957.00 1106.00 A-10 MSS (TBS A-10) 3_CB-Film-MSS1182.00 5752.00 A-10RD PB1 MWD OnTrak+Sag (TBS A-10RD PB1) 3_MWD+IFR1+MS+Sag5818.00 8300.00 A-10RD MWD OnTrak+Sag (TBS A-10RD) 3_MWD+IFR1+MS+Sag8300.00 8700.00 TBS A-10RD2 wp06 (Plan: TBS A-10RD2) 3_MWD_Interp Azi+Sag8700.00 16522.63 TBS A-10RD2 wp06 (Plan: TBS A-10RD2) 3_MWD+IFR1+MS+Sag0.0040.0080.00120.00160.00200.00Centre to Centre Separation (80.00 usft/in)8400 8800 9200 9600 10000 10400 10800 11200 11600 12000 12400 12800 13200 13600 14000 14400 14800 15200 15600 16000Measured Depth (800 usft/in)A-04A wp5TBS A-10RDGLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference8300.00 To 16522.63Project: Trading Bay - McArthur River FieldSite: MonopodWell: TBS A-10Wellbore: Plan: TBS A-10RD2Plan: TBS A-10RD2 wp06Ladder/S.F. Plots 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:Sean Mclaughlin Subject:RE: [EXTERNAL] NTB A-10RD2 PTD Date:Friday, January 28, 2022 3:26:00 PM Attachments:image003.png image004.png Got it. Thanks. I am assuming a 0.5 ppg kick intensity above MW. Still plenty of kick tolerance. 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: Sean Mclaughlin <Sean.Mclaughlin@hilcorp.com> Sent: Friday, January 28, 2022 2:05 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] NTB A-10RD2 PTD Bryan, Rig 56 is the platform Rig on the Monopod. It has drilled every well on the platform and was last used in 2019 during the A-10RD drill. The casing test to 3500 psi is within limits of the equipment and justified based on the 3074 psi MASP and required 50% of casing burst test. The casing packoff prevents overpressure of the bottom casing spool flange. With the packoff installed in the casing head the system rating is 5000 psi. I’ve pasted the inputs and results of the KT calculator below for your review. Regards, sean From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, January 28, 2022 1:15 PM To: Sean Mclaughlin <Sean.Mclaughlin@hilcorp.com> Subject: [EXTERNAL] NTB A-10RD2 PTD Sean, I’m going over the PTD for this well. Program looks good, just a couple questions and topics for discussion. 1. You mentioned Rig 56 in the program. Where does Rig 56 operate? 2. In section 9, it says that the Casing spool is rated to 3000 psi. I’ll grant a variance since the casing spool will have been pressure tested pre-rig to 3500 psi. I’ll add it into the program if that’s something you want to request. 3. The 14.5 ppg FIT gives plenty of kick tolerance, so that number is fine. When I run the calculation, I don’t get an infinite kick tolerance and I’d like to have a discussion to understand why our numbers don’t match up. It’s not urgent, so let me know when is a good time for you. 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 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. 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Revised 2/2015 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: ____________________________ POOL: ______________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit No. _____________, API No. 50-_______________________. Production should continue to be reported as a function of the original API number stated above. Pilot Hole In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name (_______________________PH) and API number (50-_____________________) from records, data and logs acquired for well (name on permit). Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (_____________________________) as Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for well ( ) until after ( ) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (________________________) must contact the AOGCC to obtain advance approval of such water well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (_______________________________) in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. 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