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Home My WebLink About220-070RECEIVED By Samantha Carlisle a19:17 am, Jun 02, 2021 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 2]. Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: 0 1b. Well Class: Development Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or Aband.: 5/8/2021 14. Permit to Drill Number / Sundry: • 220-070 / 321-169 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: 12/20/2020 15. API Number: 50-029-23688-00-00 ' 4a. Location of Well (Governmental Section): Surface: 2670' FSL, 3383' FEL, Sec. 28, T13N, RE10E, UM, AK Top of Productive Interval: 920' FSL, 936' FWL, Sec. 20, T13N, R10E, UM, AK Total Depth: 587' FSL, 2574' FEL, Sec. 24, T13N, R09E, UM, AK 8. Date TD Reached: 1/4/2021 16. Well Name and Number: MPU J-29 9. Ref Elevations: KB: 68.08' GL: 33.7' BF: 33.7' 17. Field / Pool(s): Milne Point Field, Schrader Bluff Oil Pool 10. Plug Back Depth MD/TVD: 9,073'/ 3,770' 18. Property Designation: ADL 025906, 025517, 025515 & 025514 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 551934 y- 6015068 Zone -4 TPI: x- 545660 y- 6018556 Zone -4 Total Depth: x- 536921 y- 6018174 Zone -4 11. Total Depth MD/TVD: 17,921' / 3,566' 19. DNR Approval Number: 88-005 12. SSSV Depth MD/TVD: None 20. Thickness of Permafrost MD/TVD: 2125'/ 1930' 5. Directional or Inclination Survey: Yes L (attached) No Ld Submit electronic information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: N/A 22. Logs Obtained: 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, 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 ROP, AGR, ABG, DGR, EWR, ADR MD & TVD 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 129.5# X-52 Surface 147' Surface 147' Driven 47# L-80 Surface 2,429' Surface 2,117' 12-1/4" Stg 1 L - 1015 sx / T - 400 sx 9-5l8" 40# L-80 2,429' 9318' 2,117' 3,786' Stg 2 L - 730 sx / T - 270 sx 4-1/2" 13.5# L-80 8,152' 17,921' 3,648' 1 3,566' 8-1/2" Uncemented Screen liner 1 24. Open to production or injection? Yes ❑ No 0 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Abandonment Date 5/8/2021 HEW 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) None 9152'/ 3783' Liner Top Packer 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes rj No n Per 20 AAC 25.283 (i)(2) attach electronic information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9104' Set CIBP 9073' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate --Np� Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (torr): Sr Pet EngMGR07JUL2021 Sr Pet GeoDLB 06/22/2021 Sr Res Eng RBDMS HEW 6/3/2021 SFD 612412021 XG irm 1 n -4n7 Ravicarl 3/9n9n Ruhmit within'.In rinvc of (`mmnlatinn Ai mnancinn nr Ah—Hnmmn 28. CORE DATA Conventional Core(s): Yes ❑ No 21 Sidewall Cores: Yes ❑ No 2] 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. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top 36' 36' Permafrost - Base 2161' 1956' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 9159' 3783' information, including reports, per 20 AAC 25.071. SV 5 1473' 1418' SV 1 2456' 2131' Ugnu LA3 7093' 3366' Schrader Bluff NA 8984' 3755' Schrader Bluff NB 9159' 3783' Formation at total depth: SB NB 9159' 3783' 31. List of Attachments: Drilling Report, Wellbore Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloaical report, production or well test results, oer 20 AAC 25,070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Monty Myers Contact Name: Joe Lastufka Authorized Title: Drilling Manager Contact Email: 'Ose h.lastufka hi1cor .com Authorized Monty M DN�allyM-tyMMy— = $Yew 6 . 1 . 2021 Contact Phone: 777-8400 o=Hilcorp Alaska. LLC, ou Techni Signature w/Date: Servi es-AK Drillin vers Rea ort la ppmv thlsd... ment INSTRUCTIONS Date. 2021.06011]'. 135 -08'00 General: 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. Item 1a: 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. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: 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. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: 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. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: 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. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: 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. Item 30: 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. 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. Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment KHilcorp Energy Company Composite Report Well Name: MP J-29 Field: Milne Point County/State: , Alaska API #: 50.029--23688-00.00 Activity Date Ops Summary 4/30/2021 Finish hooking up rear sub tires on I pad. Jack up sub. Mob sub to J pad. Back - n onto mats. Disconnect truck and remove steering arm. Remove rear sub tires. Spot subbase over J-29. 24 -hr notice to AOGCC for BOPE test sent. Matt nerrera waived witness., Shim and level subbase Spot and shim cattle chute, pipe shed, mud mod and gen mod. Retract stompers and set down. Set outriggers. Rig up pipe shed interconnect and stairways. C/O spare geo-span. Spot beyond shack.,Plug in rig and swap to gen power at 22:30. Hookup all interconnects. Energize steam, water and air systems. Safe out all walkways, stairways and rooftops. Begin rig acceptance checklist. Scope up derrick and bridal down. Sim Ops: put together mud pumps. spot and set break shack and envirovac. Mob shop from I pad to J pad.,Conl. working on rig acceptance checklist. Hang rig tongs, inspect iron roughneck. Function test all rig floor equipment. Update well sign. Thaw out cellar box and install grating Post rig move denick inspection. Rig Accepted at 04:00,Spot and rig up flow back tank. Rig up hoses. Bleed off 100 psi gas cap on IA and tubing. 5/1/2021 Install BPV. N/D tree . Install capon penetrator. Install CTS to BPV for upcoming BOP test.,) nstall 11"x 13-5/8" DSA. Remove test cap from RCD due to limited working ht when N/U stack. N/U stack, choke and kill lines. 4 pt stack. Install drip pan. Re -install RCD test cap and tighten clamp. N/U MPD hard lines to orbital valve. Sym Ops -Filter koomey oil and sub HPU oil via. Process 5" drill pipe in shed., Cont. N/U BOPE. M/U choke and kill lines. Hook up hole -fill line. C/O UPR's to 7-5/8" solid body. Conned accumulator lines and energize system. Obtain RKB's. Grease choke manifold and stack valves. Bring al needed XO's and subs on rig floor., Flood and purge stack, choke and kill line. Test mud line, stack and MPD head to 3000 psi for 5 minutes -good. Pull MPD test cap and install hser.,R/U to test ROPE, pickup and M/U 5" test joint with pump in sub, and TIW. Flood stack and surface lines, purge air., Test BOPE 250/3000 psi; 5" and 3.5" test joints. AOGCC right to witness waived by Matt Herrera. Test gas alarms, PVT, flow show alarms. No failures. Accumulator draw down test: Initial pressure 3000 psi, final 1650 psi, first 200 psi recharge 23 seconds, full recharge 83 seconds. (6) N2 backup at 2391 psi average.,Rig down testing equipment. Break down test joints, XO's, pump in sub, TIW, and dart. Blau down choke and kill lines. Pick up T-Bar.,Verify no pressure on IA. Pull CTS plug, observe fluid in stack drain. Screw into BPV and ensure no pressure below, Pull BPV. M/U XO and landing joint.,Circulate 38 bbis baraklean pill followed by 341 bbls 90° seawater. Took 48 bible to catch pressure, 74 bbls to fill hole, 6 bpm, 500 psi. Displace to 10.0 ppg brine, pump high vis spacer followed by 364 bbls brine until good brine returns FCP 725 psi. Monitor well, static. Blow dawn line to flavback tank.,BOLDS. Unseat hanger. Pull hanger to just below annular observing drag up to 150K with some breakover.,Rig up to POOH with ESP. R/U power tongs, bring centrilift box to floor, R/U sheave in derrick for ESP spooler. Daly disposal to G&I 57 bbls, total=157 bbls. Daily water from 6 mile lake 860 bbls total=860 bbls. Daily Metal 0 lbs, total=0 lbs. Daily fluid lost 0 bbis, total= 0 bbls 5/2/2021 Cont. to pull 3.5" hanger to floor and break over @ 150k then gradually climb to 165k up over 15' up (75k overpull / drag). Wt fell off after 20' to 1051k. Drag indicates sand around ESP @ 7898' MD. B/0 and UD tubing hanger (TCII). POOH spooling ESP cable and removing cannon clamps. POOH F/ 7898'- T/ 5331' MD (691k up / 481k dn).,Continue POOH laying dawn 3.5"ESP completion F/ 5331'- T/ surface. ESP cable showed flat spot @ 2155' MD. Mtr/Pump assy appeared to be in good shape but did have minimal residua sand around components. ESP was grounded out phase to ground. Will take assy back to shop to troubleshoot. UD a total of 249 jt, 2 GLM's, 1 XN, 135 cannon clamps,13 motor/pump clamps, 1 protectorlizer,Cut cable and spooled on drum. RID sheaves and ESP running equipment. Clean and clear rig floor of cannon clamps, thread protectors, Centnlift and Weatherford equipment. LID 3.5" handling equipment and power tongs., Mobilize XT -39 subs and XO's to rig floor. P/U M/U Dart, TIW, and pump in sub and test 250/3000 psi - good. Change out elevators. Load and process 4" drill pipe., Install wear bushing and RILDS.,M/U Bit, bit sub. Pick up, drift and single in the hole to 950', drift size 2.375". PUW 47K, SOW 49K., Hang blocks. Slip and cut 100' of drilling line. Check air gap on brakes - good. Monitor well on trip tank - static.,Service rig: inspect iron roughneck, top drive and blocks. Check top drive gear oil level - good. perform monthly sheave wobbly EAM on crown and blocks., Continue to pick up drift (2.375") and single in hole with cleanout assembly on 4" drill pipe from 950' to 3606'. PUW 74K SOW 57K. Daily disposal to G&I 727 bbls, total=884 bbls. Daily water from 6 mile lake 120 bbls total=980 bbls. Daily Metal 0lbs, total=0 lbs. Daily fluid lost 0 bbls, total= 0 bbls. 5/3/2021 Continue single in hole with 6-1/8" cleanout assy F/ 3606'- T/ 7811' MD picking up 4" XT -39, S-135, 14# drill pipe. Drift 2.375". 128k up, 451k dn. Saw 3-5k drag starting @ 7811' MD.,Kelly up and wash down F/ 7811' - T/ 7968' MD. 40 rpm, 7k tq, 350 gpm, 1240 psi, 48% F/O. 2-4k wob @ 10-15 fpm. Observed heavy oil and sand back at shakers. 15 bph static loss rate, 50 bph dynamic loss rate with 10 ppg brine.,Continue wash down F/ 7968' - T/ 9164" MD (btm of tieback seals @ 9159' MD). 40 rpm, 6.1 k tq, 350 gpm, 1285 psi, 47% F/O. 2-4k wob @ 10-15 fpm. Continued seeing heavy oil and sand back at shakers with bgg gas 760u, Reduce MW from 10 ppg to 9.8 ppg due to losses. 26 BPH losses with 9,8 brine.,Pump 30 bbls high vis sweep (no increase in cuttings) followed by 20 bbls brine and 30 bbls heated soap pill. CBU x 2, observe shakers clean up. at 350 gpm 1355 psi, 40 rpms, 5 -60 -lbs. Max gas 728U falling to 25U. Monitor well, initial flow back recorded 43 bbls consistently slowing to 8 bph over 2 hrs.,POOH with clean out assembly from 9100' to 861 T. Observe well, rate still decreasing to 5 bph. Cont. POOH to 7784'. PUW 132K, SOW 55K.,Service ng; grease crown sheaves, service/inspect iron roughneck. Clean rig floor. Monitor well, flow slowed to 3.5 bph.,Cont. to POOH to laying down drill pipe from 7784' to 2,499'. PUW 65K, SOW 52K. Monitor well, flaw slowed to 2 bph.,Pump 10.0 ppg brine top cap at 3.5 bph, 170 psi. Monitor well, static. Daily disposal to G&I 199 bbls, total= 1083 bbls. Daly water from 6 mile lake 240 bbls total= 1220 bbls. Daily Metal 0 lbs, total=0 lbs. Daily fluid lost 201 bbls, total= 201 bbls. 5/4/2021 Continue POOH laying dawn 4" dp with 6-1/8" cleanout assy F/ 2499'- T/ surface. B/O and UD bit, bit sub. Well static.,Pull wear bushing. Install test plug and R/U to test upper pipe rams (SBR's 7-5/8"). Test upper pipes w/ 7-5/8" test joint to 250 low/ 3000 high. Chart and record, 5 min hold on each. RID test equipment., R/U OA to flowback tank. Ensure OA is zero. M/U running tool and engage packoff assy. BOLDS. Pull packoff w/ 5-71k to unseat. B/O and L/D. M/U left hand acme landing joint., Reduce bag psi to 700 psi. Close annular on landing jt. PJSM, Strip up (-8')and expose 1" ports on seal assy @ liner top 9144' MD. Circulate out to flatback tank 164 bbls diesel and Cl brine. Take returns back to pits. 3-6bpm, 200-350 psi. 65-78 % retums. 177k up (bag dosed).157k up without stripping. 750-1130u gas consistently after 5.5x btmsup, 26-54 bph dynamic loss rate., Monitor well, initial flaw back 54 bph slowing consistently to 9 bph after 1 hour, flawing both ways. Pump 25 bbls 10.8 ppg dry job, monitor well inital 19 bph slowing to 1.7 bph, pump 10 additional bbls dry job to stop the flow up the casing.,POOH with 7-5/8" casing from 9129' to 8122', observe well swabbing; static while not moving pipe. Work pipe up and down multiple times, still flowing. WU XO and S pup joint, rotate 3-10 rpm, 7000 ft -lbs attempting to break free whatever is causing the swabbing effect. PUW 155K, SOW 95K.,Discuss options. Build 40 bbls soap pill and rig up to reverse circulate. Close annular. Reverse circulate 40 bbls soap pill, stage pumps up to 7.5 bpm, 540 psi with 40-50 bbis dynamic loss rate. Slow rate to 2 bpm as soap pill crosses 8.25" No -Go on seal assembly. 45 bbls lost on circulation. Observe thick crude oil on bottoms up. Max Gas 1910U.,Monitor well; initial flow back 28 bph, slowing to 4.7 bph in 40 minutes. Pump 40 bbls 10.8 ppg dry job. Monitor 7-5/8" - no flow. Monitor 7-5/8" x 9-5/8", initial 7.8 bph slaving to trickle. Daily disposal to G&I 57 bbls, total= 1197 bbls. Daily water from 6 mile lake 160 bbls total= 1380 bbls. Daily Metal 0 lbs, total=0 lbs. Daily fluid lost 146 bbls, total= 347 bbls. 5/5/2021 Attempt to POOH with 7-5/8" casing, still swabbing. Rig up Volant, side door elevators. Pump out of hole with 7-5/8" casing from 8120' to 7000', at 10 spm pulling 15 fpm, 30 strokes per joint. PUW 145K, SOW 69K.,Cont. to pump out of the hole with 7-5/8" casing from 7000' to 5100', pump 20 strokes (0.75 bbls) per joint (Displacement 0.4 bbls), pulling 13-25 fpm. PUW 118K, SOW 90K, max gas 82U. Perform flaw check at 7000' and 5891', initial flow back 0.45 bph slowing to 0.2 bph after 10 minutes. Attempt to pullout, and confirm well still swabbing. Cad hole fill.,Conl. to pump out of the hole with 7-5/8" casing from 5100' to 3293', 20-35 strokes per joint, pulling 15-25 fpm. PUW 101 K, SOW 85K, max gas 274U.,Ccnt. to pump out of the hole with 7-5/8" casing from 3293' to 2682', 35 strokes per joint, pulling 15-25 fpm. PUW 101K, SOW 85K, maxgas 45U. PUW 95K, SOW 80K., Monitor well, observe slight ooze. Blend 10.1 ppg brine and cap well with 198 bbls at 3.5 bpm, 52 psi. 10.1 ppg in/out 20 bbls lost during circulation Max gas 177U. Monitor well, silght flaw at 5.7 bph going static in 40 minutes. Pump dry job. Daily disposal to G&I 57 bbls, total= 1254 bbls. Daily water from 6 mile lake 80 bbls total= 1460 bbls. Daily Metal 0 lbs, total=0 lbs. Daily fluid lost 38 bbls, total= 385 bbls, Confirm swabbing, continue to pump out of the hole with 7-5/8" casing from 2682' to 828' pumping 25-35 strokes per joint, pulling 15-25 fpm. Started pulling wet. Loss rate 4 bph @ 15 bbls,Circulate out old dry job from backside, monitor well, flowing 5.5 bph slowing to static in 30 minutes, pump 15 bbl 11 ppg dry job.,Confir m swabbing, continue to pump out of the hole with 7-5/8" casing from 828' to seal assy pumping 25-35 strokes per joint, pulling 15-25 fpm. UD 225 jts total and seal assy. 15.7 bbl losses total pumping out of hole, Monitor well, static loss rate 4.2 bph, R/D volant, power tongs and casing handling equipment, R/U 5" DP elevators, drain stack, install 9" ID wear bushing, RILDS.,PJSM, P/U WOT 9 5/8" BB bridge plug and running tool assy, Drift, P/U and RIH with 20 jts 5" HWDP, and drill pipe to 890'. PUW 64K, SOW 63K. 4 bph loss rate RIH,Continue to drift (3.125"), P/U and RIH with bridge plug on 5" drill pipe from 890' to 5077'. PUW 119K, SOW 70K. Calc displacement 27.7 bbls, Actual 14.4 bbls. Lost 13.3 bbls.Servioe rig: grease crown, blocks, top drive, wash pipe, drawworks, iron roughneck and handling equipment. Check oil in top drive and inspect weld on cradle., Continue to drift (3.125"), P/U and RIH with bridge plug on 5" drill pipe from 5077' to 9106'. PUW 160K, SOW 55K. Calc displacement for entire trip 86.2 bbls, Actual 42.5 bbls. Lost 43.7 bible., Break circulation. Drop 1.75" ball and pump down at 3 bpm, observe ball on depth at 83 bbls. Pressure up to 3500 psi, felt tool shift at 2400 psi but no pressure drop. Bleed off pressure and attempt x 3. Daily disposal to G&I 57 bbls, total= 1311 bbls. Daly water from 6 mile lake 50 bbis total= 1510 bbls. Daily Metal 0 lbs, total=0 lbs. Daily fluid lost 123 bbis, total= 508 bbis k overpull, work pipe several times observing release at 220k, pressure did not drop, P/U to 9085'. R/U and attempt to reverse circulate, pressure to 500 psi, red off press. PU 158K, SO 54K,PJSM, R/U test equipment, close annular, pump down kill line testing CIBP to 1600 psi for 10 minutes charted, good test, .ad off, open annular. 2.4 bbls pumped, 2 bbis bled back,UD single, blow down top drive, choke and kill lines, TOOH on elevators from 9085' to 4254' racking ck stands 5" DP in derrick, pulling wet, use continuous hole fill with trip tank,Change out hydraulic hose on pipe spinner, service and inspect iron roughneck, mtinue to TOOH on elevators from 4254' to 630' racking back stands 5" DP in derrick, pulling wet, Correct displacement., Drift, P/U and single in with 24 joints DP from 630' to 1393', TOOH, inspect and UD setting tool, Note: nothing visual seen wrong with setting tool- send to W FD shop to be tore down and Ipected. Correct displacement,Clear and clean rig floor, PJSM, drift, P/U and RIH with 8-6 1/4" drill collars and rack in dernck,Drain stack, de -energize cumulator. Change out 7.625" said body UPR's with 2-7/8" x 5.5" VBR's. Energize accumulator.,BOLDS, pull wear bushing. Install test plug., Pickup 5" test 1t. Flood stack and purge air. Test UPR's 250/3000 psi with 5" test jant. UD test joint and B/D kill line., Pull test plug. Install wear bushing: 9" ID, 10.75" OD, " Iong.,WU whipstock BHA: Tri -mill, flexjoint, watermelon mill, float sub, DM collar, TM collar. Measure RFO MWD to whipstock face: 3.27"/5.5" = 214.03'. U single, RIH and shallow pulse test - good. UD single and B/D top drive. P/U and M/U whipstock with 40K shear bolt and 6K trip anchor.,RIH with lipstock assembly on 5" drill pipe from 91' to 6766'. PUW 126K, SOW 61 K. Calculated displacement. Sim Ops: load and process 5" drill pipe in pipe shed. ily disposal to G&I 215 bible, total= 1526 bole. Daly water from 6 mile lake 70 bbls total= 1580 bbis. Daly Metal 0 lbs, total=0 lbs. Daily fluid lost 15 bbis, total= B bbis. H WIN wnlpS[OCK assentmy on b- Onll pipe From ti/titi' to /Uti4'. RIH Wlm 4 Stas ti 1/4" UGs to /33U' tnen 1U stOs 5" HW UN to /ti/U', Continue RIH with stds 5" ' to 9035', M/U std 128 and top drive. Correct displacement TIH. Sim Ops: load and process 5" drill pipe in pipe shed.,Break circulation, pump 415 gpm, 1020 Work pipe 30' orienting WS 45 deg left, M/U single, continue to pump 415 gpm, verify 45 deg left. RIH tag BP @ 9104', continue to S/0 setting 13k shearing chor pin, P/U to 170k, P/U additional 2', set down confirm anchor set. Work pipe attempting to shear bolt PU 150K and SO to 30k. PU 170K, SO 83K. Note: an a fair amount of sand and crude oil @ BU, Max gas 521 u,Pump and spot 40 bbl 7% NXS lube pill on backside, 415 gpm, 1020 psi. With pump off work le several more limes setting down 101k and PU to 185k, P/U 40' to 8924', establish rotation 15 rpm @ 9500 free torque, UD single M/U std and TD. Top WS 9073.02',Establish parameters, wash down tagging too of whipstock (M 9073'. TOW. Mill 8.5" window in 9-5/8" casing T/ 9093' BOW and 20' of new hole to 13' at 415 gpm, 1020 psi, 80 rpm, 9-13k to, 2-5k wt on mill. Seeing a good amount of metal at shakers and on magnets. Pump 40 bbl hi vis sweep @ 9079' )% increase), 9091'(20% increase), and 9110' (no increase). All sweeps back on time, increase in metal, some cement., Circulate hole clean while working IIs though window. Work through 3.5X with rotary/pumps, without rotary, and without rotary pumps 2-3K drag as bottom mill exits window. Flow check well, Itic. Max gas 130u. PU 160k, SO 102k, ROT 126K, Rig up and perform FIT. Flood and purge lines. Shut UPR's, Perform FIT to 12.0 oog EMW with 10.05 g drillino fluid. Pumped 1.1 bbls, bled back 1.0 bbis. Blow dawn choke and kill lines., Monitor well, static. POOH from 9073' to 8760', no indication of ebbing, Pump dryjob. Continue to POOH to 7655'. PUW 162K, SOW 105K. Calculated displacement.,Cont. to POOH from 7655' to 62' with milling sembly, laying down drill collars. Calculated displacement observed.,UD BHA; TM collar, DM collar, float sub, watermelon mill, flexjoint, Tri -mill. Starter mill I" under gauge, middle mill 1/16" under gauge, top mill in gauge.,Clean and clear rig floor. Pull wear ring.,Final report for Pre -Drill WBS, Swap to Drilling. ily disposal to G&I 57 bbls, total= 1583 bbls. Daily waterfrom 6 mile lake 80 bbis total= 1660 bbls. Daily Metal 145 lbs, total= 145 lbs. Daily fluid lost 0 bbls, al= 508 bbis. Hilcorp Alaska, LLC Orig. KB Bev.: 68.08'/GL Elev.: 33.70' 20" t, 15/5'ES' Cementer @ 2,406' MD t; ftipstock set @ 9073 CIBPSet @ 9104' A 9-5/8" � j 9 10 See Screen/ Solid Liner Detail Milne Point Unit Well: MPU J-29 SCHEMATIC Last Completed: 1/11/21 PTD: 220-070 TREE & WELLHEAD Tree Cameron 3-1/8" SM w/ 3-1/8" 5M Cameron Wing Wellhead I Cameron 11" 5K x sliplock bottom w/ (2) 2-1/16" 5K outs OPEN HOLE/ CEMENT DETAIL CASING DETAIL Driven 20" 12-1/4" Stg 1 Lead — 1015 sx / Tail — 400 sx ID Stg 2 Lead — 730 sx / Tail 270 sx 8-1/2" Cementless Screened Liner CASING DETAIL 0 7 8 4-1/2" Shoe @ 17,919 li11 TD=17,921' (MD)/TD=3,565' (TVD) PBTD =17,921' (MD) / PBTD = 3,565' (TVD) TUBING DETAIL WELL INCLINATION DETAIL PERMAFROST DETAIL KOP @ 333' Bottom = 2,161' MD / 1,955 TVD Max Hole Angle = 96° @ 12,620' MD JEWELRY DETAIL No. Size Type Wt/ Grade/ Conn ID Top Btm BPF (MD) 20" Conductor 129.5 / X52 / Weld N/A Surface 147' N/A 9-5/8" Surface 47 / L-80 / TXP 8.681 Surface 2,429' 0.0758 6 9-5/8" Surface 40 / L-80 / TXP 8.835 2,429' 9,318' 0.0732 8 9,152' BOT SLZXP LTP / Liner Hanger 7" x 9-5/8" (3,783' TVD) 6.190" 9 9,154' Locator Sub, 7" TXP Box x Box 6.180" 10 4-1/2" Liner 13.5 / L-80 / Hyd 625 1 3.920 9,152' 17,921' .0149 0 7 8 4-1/2" Shoe @ 17,919 li11 TD=17,921' (MD)/TD=3,565' (TVD) PBTD =17,921' (MD) / PBTD = 3,565' (TVD) TUBING DETAIL WELL INCLINATION DETAIL PERMAFROST DETAIL KOP @ 333' Bottom = 2,161' MD / 1,955 TVD Max Hole Angle = 96° @ 12,620' MD JEWELRY DETAIL No. Top MD Item ID Btm (MD) (TVD) (MD) (TVD) 207 9,327' 1 3,786' 17,882' 1 3,566' 6 9,073' Whipstock 7 9,104' CIBP 8 9,152' BOT SLZXP LTP / Liner Hanger 7" x 9-5/8" (3,783' TVD) 6.190" 9 9,154' Locator Sub, 7" TXP Box x Box 6.180" 10 9,173' 7" H563 x 4.5" TSH 625 XO 3.840" it 17,919' Shoe 3.950" 4-1/2" 250µ SCREENS LINER DETAIL its Top Top Bt m Btm (MD) (TVD) (MD) (TVD) 207 9,327' 1 3,786' 17,882' 1 3,566' GENERAL WELL INFO API : 50-029-23688-00-00 Drilled and Completed by Doyon 14 1/11/21 Revised By: JNL 6/1/2021 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _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): GL: 33.7' BF: 33.7' Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22.Logs Obtained: 23. BOTTOM 20" X-52 147' L-80 2,117' L-80 3,786' 4-1/2" L-80 3,566' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 9-5/8"12-1/4" ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, Uncemented Screen liner8-1/2" TUBING RECORD Liner Top Packer None SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Stg 2 L - 730 sx / T - 270 sx 8,152' Driven Surface 2,429' Stg 1 L - 1015 sx / T - 400 sx STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 5/8/2021 2670' FSL, 3383' FEL, Sec. 28, T13N, RE10E, UM, AK 587' FSL, 2574' FEL, Sec. 24, T13N, R09E, UM, AK 220-070 / 321-169 Milne Point Field, Schrader Bluff Oil Pool 68.08' 9,073' / 3,770' HOLE SIZE AMOUNT PULLED 50-029-23688-00-00 MPU J-29 551934 6015068 920' FSL, 936' FWL, Sec. 20, T13N, R10E, UM, AK CEMENTING RECORD 6018556 SETTING DEPTH TVD 6018174 BOTTOM TOP Surface Surface CASING WT. PER FT.GRADE 13.5# 545660 536921 TOP SETTING DEPTH MD Surface Per 20 AAC 25.283 (i)(2) attach electronic information 40# 17,921' 2,117' 3,648' DEPTH SET (MD) 9152' / 3783' PACKER SET (MD/TVD) 129.5# 47# 147' 2,429' 9318' Gas-Oil Ratio:Choke Size: Set Whipstock 9104' Set CIBP Water-Bbl: PRODUCTION TEST Not on Production Date of Test: Flow Tubing Oil-Bbl: suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 9073' N/A ROP, AGR, ABG, DGR, EWR, ADR MD & TVD Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 1/4/2021 12/20/2020 ADL 025906, 025517, 025515 & 025514 88-005 2125' / 1930' N/AN/A None 17,921' / 3,566' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 9:17 am, Jun 02, 2021 RBDMS HEW 6/3/2021 Abandonment Date 5/8/2021 HEW xGDLB 06/22/2021 MGR07JUL2021 SFD 6/24/2021 DSR-6/7/21 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD 36' 36' 2161' 1956' Top of Productive Interval 9159' 3783' 1473' 1418' 2456' 2131' 7093' 3366' 8984' 3755' 9159' 3783' SB NB 9159' 3783' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Joe Lastufka Contact Email:joseph.lastufka@hilcorp.com Authorized Contact Phone: 777-8400 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: FORMATION TESTS Permafrost - Top 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. Drilling Report, Wellbore Schematic Signature w/Date: If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Schrader Bluff NB Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): Formation at total depth: Ugnu LA3 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 Schrader Bluff NA SV 5 SV 1 The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). 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). 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. 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. Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 6.1.2021Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.06.01 17:13:50 -08'00' Monty M Myers Activity Date Ops Summary 4/30/2021 Finish hooking up rear sub tires on I pad. Jack up sub. Mob sub to J pad. Back sub onto mats. Disconnect truck and remove steering arm. Remove rear sub tires. Spot sub base over J-29. 24-hr notice to AOGCC for BOPE test sent. Matt Herrera waived witness.,Shim and level sub base. Spot and shim cattle chute, pipe shed, mud mod and gen mod. Retract stompers and set down. Set outriggers. Rig up pipe shed interconnect and stairways. C/O spare geo-span. Spot beyond shack.,Plug in rig and swap to gen power at 22:30. Hook up all interconnects. Energize steam, water and air systems. Safe out all walkways, stairways and rooftops. Begin rig acceptance checklist. Scope up derrick and bridal down. Sim Ops: put together mud pumps. spot and set break shack and envirovac. Mob shop from I pad to J pad.,Cont. working on rig acceptance checklist. Hang rig tongs, inspect iron roughneck. Function test all rig floor equipment. Update well sign. Thaw out cellar box and install grating. Post rig move derrick inspection. Rig Accepted at 04:00,Spot and rig up flow back tank. Rig up hoses. Bleed off 100 psi gas cap on IA and tubing. 5/1/2021 Install BPV. N/D tree . Install cap on penetrator. Install CTS to BPV for upcoming BOP test.,Install 11" x 13-5/8" DSA. Remove test cap from RCD due to limited working ht when N/U stack. N/U stack, choke and kill lines. 4 pt stack. Install drip pan. Re-install RCD test cap and tighten clamp. N/U MPD hard lines to orbital valve. Sym Ops - Filter koomey oil and sub HPU oil via . Process 5" drill pipe in shed.,Cont. N/U BOPE. M/U choke and kill lines. Hook up hole-fill line. C/O UPR's to 7-5/8" solid body. Connect accumulator lines and energize system. Obtain RKB's. Grease choke manifold and stack valves. Bring al needed XO's and subs on rig floor.,Flood and purge stack, choke and kill line. Test mud line, stack and MPD head to 3000 psi for 5 minutes - good. Pull MPD test cap and install riser.,R/U to test BOPE, pick up and M/U 5" test joint with pump in sub, and TIW. Flood stack and surface lines, purge air.,Test BOPE 250/3000 psi; 5" and 3.5" test joints. AOGCC right to witness waived by Matt Herrera. Test gas alarms, PVT, flow show alarms. No failures. Accumulator draw down test: Initial pressure 3000 psi, final 1650 psi, first 200 psi recharge 23 seconds, full recharge 83 seconds. (6) N2 backup at 2391 psi average.,Rig down testing equipment. Break down test joints, XO's, pump in sub, TIW, and dart. Blow down choke and kill lines. Pick up T-Bar.,Verify no pressure on IA. Pull CTS plug, observe fluid in stack drain. Screw into BPV and ensure no pressure below. Pull BPV. M/U XO and landing joint.,Circulate 38 bbls baraklean pill followed by 341 bbls 90° seawater. Took 48 bbls to catch pressure, 74 bbls to fill hole, 6 bpm, 500 psi. Displace to 10.0 ppg brine, pump high vis spacer followed by 364 bbls brine until good brine returns FCP 725 psi. Monitor well, static. Blow down line to flowback tank.,BOLDS. Unseat hanger. Pull hanger to just below annular observing drag up to 150K with some breakover.,Rig up to POOH with ESP. R/U power tongs, bring centrilift box to floor, R/U sheave in derrick for ESP spooler. Daily disposal to G&I 57 bbls, total=157 bbls. Daily water from 6 mile lake 860 bbls total=860 bbls. Daily Metal 0 lbs, total=0 lbs. Daily fluid lost 0 bbls, total= 0 bbls. 5/2/2021 Cont. to pull 3.5" hanger to floor and break over @ 150k then gradually climb to 165k up over 15' up (75k overpull / drag). Wt fell off after 20' to 105k. Drag indicates sand around ESP @ 7898' MD. B/O and L/D tubing hanger (TCII). POOH spooling ESP cable and removing cannon clamps. POOH F/ 7898' - T/ 5331' MD (69k up / 48k dn).,Continue POOH laying down 3.5"ESP completion F/ 5331' - T/ surface. ESP cable showed flat spot @ 2155' MD. Mtr/Pump assy appeared to be in good shape but did have minimal residual sand around components. ESP was grounded out phase to ground. Will take assy back to shop to troubleshoot. L/D a total of 249 jt, 2 GLM's, 1 XN, 135 cannon clamps,13 motor/pump clamps, 1 protectorlizer,Cut cable and spooled on drum. R/D sheaves and ESP running equipment. Clean and clear rig floor of cannon clamps, thread protectors, Centrilift and Weatherford equipment. L/D 3.5" handling equipment and power tongs.,Mobilize XT-39 subs and XO's to rig floor. P/U M/U Dart, TIW, and pump in sub and test 250/3000 psi - good. Change out elevators. Load and process 4" drill pipe.,Install wear bushing and RILDS.,M/U Bit, bit sub. Pick up, drift and single in the hole to 950', drift size 2.375". PUW 47K, SOW 49K.,Hang blocks. Slip and cut 100' of drilling line. Check air gap on brakes - good. Monitor well on trip tank - static.,Service rig: inspect iron roughneck, top drive and blocks. Check top drive gear oil level - good. perform monthly sheave wobbly EAM on crown and blocks.,Continue to pick up drift (2.375") and single in hole with cleanout assembly on 4" drill pipe from 950' to 3606'. PUW 74K SOW 57K. Daily disposal to G&I 727 bbls, total=884 bbls. Daily water from 6 mile lake 120 bbls total=980 bbls. Daily Metal 0 lbs, total=0 lbs. Daily fluid lost 0 bbls, total= 0 bbls. 5/3/2021 Continue single in hole with 6-1/8" cleanout assy F/ 3606' - T/ 7811' MD picking up 4" XT-39, S-135, 14# drill pipe. Drift 2.375". 128k up, 45k dn. Saw 3-5k drag starting @ 7811' MD.,Kelly up and wash down F/ 7811' - T/ 7968' MD. 40 rpm, 7k tq, 350 gpm, 1240 psi, 48% F/O. 2-4k wob @ 10-15 fpm. Observed heavy oil and sand back at shakers. 15 bph static loss rate, 50 bph dynamic loss rate with 10 ppg brine.,Continue wash down F/ 7968' - T/ 9164'' MD (btm of tieback seals @ 9159' MD). 40 rpm, 6.1k tq, 350 gpm, 1285 psi, 47% F/O. 2-4k wob @ 10-15 fpm. Continued seeing heavy oil and sand back at shakers with bgg gas 760u. Reduce MW from 10 ppg to 9.8 ppg due to losses. 26 BPH losses with 9.8 brine.,Pump 30 bbls high vis sweep (no increase in cuttings) followed by 20 bbls brine and 30 bbls heated soap pill. CBU x 2, observe shakers clean up. at 350 gpm 1355 psi, 40 rpms, 5-6Kft-lbs. Max gas 728U falling to 25U. Monitor well, initial flow back recorded 43 bbls consistently slowing to 8 bph over 2 hrs.,POOH with clean out assembly from 9100' to 8617'. Observe well, rate still decreasing to 5 bph. Cont. POOH to 7784'. PUW 132K, SOW 55K.,Service rig; grease crown sheaves, service/inspect iron roughneck. Clean rig floor. Monitor well, flow slowed to 3.5 bph.,Cont. to POOH to laying down drill pipe from 7784' to 2,499'. PUW 65K, SOW 52K. Monitor well, flow slowed to 2 bph.,Pump 10.0 ppg brine top cap at 3.5 bph, 170 psi. Monitor well, static. Daily disposal to G&I 199 bbls, total= 1083 bbls. Daily water from 6 mile lake 240 bbls total= 1220 bbls. Daily Metal 0 lbs, total=0 lbs. Daily fluid lost 201 bbls, total= 201 bbls. 5/4/2021 Continue POOH laying down 4" dp with 6-1/8" cleanout assy F/ 2499' - T/ surface. B/O and L/D bit, bit sub. Well static.,Pull wear bushing. Install test plug and R/U to test upper pipe rams (SBR's 7-5/8"). Test upper pipes w/ 7-5/8" test joint to 250 low/ 3000 high. Chart and record, 5 min hold on each. R/D test equipment.,R/U OA to flowback tank. Ensure OA is zero. M/U running tool and engage packoff assy. BOLDS. Pull packoff w/ 5-7k to unseat. B/O and L/D. M/U left hand acme landing joint.,Reduce bag psi to 700 psi. Close annular on landing jt. PJSM, Strip up (~8')and expose 1" ports on seal assy @ liner top 9144' MD. Circulate out to flowback tank 164 bbls diesel and CI brine. Take returns back to pits. 3-6 bpm, 200-350 psi. 65-78% returns. 177k up (bag closed).157k up without stripping. 750-1130u gas consistently after 5.5x btms up, 26-54 bph dynamic loss rate.,Monitor well, initial flow back 54 bph slowing consistently to 9 bph after 1 hour, flowing both ways. Pump 25 bbls 10.8 ppg dry job, monitor well inital 19 bph slowing to 1.7 bph, pump 10 additional bbls dry job to stop the flow up the casing.,POOH with 7-5/8" casing from 9129' to 8122', observe well swabbing; static while not moving pipe. Work pipe up and down multiple times, still flowing. M/U XO and 5' pup joint, rotate 3-10 rpm, 7000 ft-lbs attempting to break free whatever is causing the swabbing effect. PUW 155K, SOW 95K.,Discuss options. Build 40 bbls soap pill and rig up to reverse circulate. Close annular. Reverse circulate 40 bbls soap pill, stage pumps up to 7.5 bpm, 540 psi with 40-50 bbls dynamic loss rate. Slow rate to 2 bpm as soap pill crosses 8.25" No-Go on seal assembly. 45 bbls lost on circulation. Observe thick crude oil on bottoms up. Max Gas 1910U.,Monitor well; initial flow back 28 bph, slowing to 4.7 bph in 40 minutes. Pump 40 bbls 10.8 ppg dry job. Monitor 7-5/8" - no flow. Monitor 7-5/8" x 9-5/8", initial 7.8 bph slowing to trickle. Daily disposal to G&I 57 bbls, total= 1197 bbls. Daily water from 6 mile lake 160 bbls total= 1380 bbls. Daily Metal 0 lbs, total=0 lbs. Daily fluid lost 146 bbls, total= 347 bbls. 5/5/2021 Attempt to POOH with 7-5/8" casing, still swabbing. Rig up Volant, side door elevators. Pump out of hole with 7-5/8" casing from 8120' to 7000', at 10 spm pulling 15 fpm, 30 strokes per joint. PUW 145K, SOW 69K.,Cont. to pump out of the hole with 7-5/8" casing from 7000' to 5100', pump 20 strokes (0.75 bbls) per joint (Displacement 0.4 bbls), pulling 13-25 fpm. PUW 118K, SOW 90K, max gas 82U. Perform flow check at 7000' and 5891', initial flow back 0.45 bph slowing to 0.2 bph after 10 minutes. Attempt to pull out, and confirm well still swabbing. Cacl hole fill.,Cont. to pump out of the hole with 7-5/8" casing from 5100' to 3293', 20-35 strokes per joint, pulling 15-25 fpm. PUW 101K, SOW 85K, max gas 274U.,Cont. to pump out of the hole with 7-5/8" casing from 3293' to 2682', 35 strokes per joint, pulling 15-25 fpm. PUW 101K, SOW 85K, max gas 45U. PUW 95K, SOW 80K.,Monitor well, observe slight ooze. Blend 10.1 ppg brine and cap well with 198 bbls at 3.5 bpm, 52 psi. 10.1 ppg in/out 20 bbls lost during circulation Max gas 177U. Monitor well, silght flow at 5.7 bph going static in 40 minutes. Pump dry job. Daily disposal to G&I 57 bbls, total= 1254 bbls. Daily water from 6 mile lake 80 bbls total= 1460 bbls. Daily Metal 0 lbs, total=0 lbs. Daily fluid lost 38 bbls, total= 385 bbls. 50-029--23688-00-00API #: Well Name: Field: County/State: MP J-29 Milne Point Hilcorp Energy Company Composite Report , Alaska 5/6/2021 Confirm swabbing, continue to pump out of the hole with 7-5/8" casing from 2682' to 828' pumping 25-35 strokes per joint, pulling 15-25 fpm. Started pulling wet. Loss rate 4 bph @ 15 bbls,Circulate out old dry job from backside, monitor well, flowing 5.5 bph slowing to static in 30 minutes, pump 15 bbl 11 ppg dry job.,Confirm swabbing, continue to pump out of the hole with 7-5/8" casing from 828' to seal assy pumping 25-35 strokes per joint, pulling 15-25 fpm. L/D 225 jts total and seal assy. 15.7 bbl losses total pumping out of hole,Monitor well, static loss rate 4.2 bph, R/D volant, power tongs and casing handling equipment, R/U 5'' DP elevators, drain stack, install 9" ID wear bushing, RILDS.,PJSM, P/U WOT 9 5/8'' BB bridge plug and running tool assy, Drift, P/U and RIH with 20 jts 5'' HWDP, and drill pipe to 890'. PUW 64K, SOW 63K. 4 bph loss rate RIH,Continue to drift (3.125"), P/U and RIH with bridge plug on 5" drill pipe from 890' to 5077'. PUW 119K, SOW 70K. Calc displacement 27.7 bbls, Actual 14.4 bbls. Lost 13.3 bbls.,Service rig: grease crown, blocks, top drive, wash pipe, drawworks, iron roughneck and handling equipment. Check oil in top drive and inspect weld on cradle.,Continue to drift (3.125"), P/U and RIH with bridge plug on 5" drill pipe from 5077' to 9106'. PUW 160K, SOW 55K. Calc displacement for entire trip 86.2 bbls, Actual 42.5 bbls. Lost 43.7 bbls.,Break circulation. Drop 1.75" ball and pump down at 3 bpm, observe ball on depth at 83 bbls. Pressure up to 3500 psi, felt tool shift at 2400 psi but no pressure drop. Bleed off pressure and attempt x 3. Daily disposal to G&I 57 bbls, total= 1311 bbls. Daily water from 6 mile lake 50 bbls total= 1510 bbls. Daily Metal 0 lbs, total=0 lbs. Daily fluid lost 123 bbls, total= 508 bbls. 5/7/2021 Attempt to shear off CIBP @ 9106', with test pump pressure DP to 4000 psi, bleed to 1000 psi, set down 10k to confirm plug set, P/U to 160k then to 220k @ 60k overpull, work pipe several times observing release at 220k, pressure did not drop, P/U to 9085'. R/U and attempt to reverse circulate, pressure to 500 psi, bleed off press. PU 158K, SO 54K,PJSM, R/U test equipment, close annular, pump down kill line testing CIBP to 1600 psi for 10 minutes charted, good test, bleed off, open annular. 2.4 bbls pumped, 2 bbls bled back,L/D single, blow down top drive, choke and kill lines, TOOH on elevators from 9085' to 4254' racking back stands 5'' DP in derrick, pulling wet, use continuous hole fill with trip tank,Change out hydraulic hose on pipe spinner, service and inspect iron roughneck, Continue to TOOH on elevators from 4254' to 630' racking back stands 5'' DP in derrick, pulling wet, Correct displacement.,Drift, P/U and single in with 24 joints 5'' DP from 630' to 1393', TOOH, inspect and L/D setting tool, Note: nothing visual seen wrong with setting tool- send to WFD shop to be tore down and inspected. Correct displacement,Clear and clean rig floor, PJSM, drift, P/U and RIH with 8-6 1/4'' drill collars and rack in derrick,Drain stack, de-energize accumulator. Change out 7.625" solid body UPR's with 2-7/8" x 5.5" VBR's. Energize accumulator.,BOLDS, pull wear bushing. Install test plug.,Pick up 5" test joint. Flood stack and purge air. Test UPR's 250/3000 psi with 5" test joint. L/D test joint and B/D kill line.,Pull test plug. Install wear bushing: 9" ID, 10.75" OD, 38" long.,M/U whipstock BHA: Tri-mill, flex joint, watermelon mill, float sub, DM collar, TM collar. Measure RFO MWD to whipstock face: 3.27"/5.5" = 214.03°. M/U single, RIH and shallow pulse test - good. L/D single and B/D top drive. P/U and M/U whipstock with 40K shear bolt and 6K trip anchor.,RIH with whipstock assembly on 5" drill pipe from 91' to 6766'. PUW 126K, SOW 61K. Calculated displacement. Sim Ops: load and process 5" drill pipe in pipe shed. Daily disposal to G&I 215 bbls, total= 1526 bbls. Daily water from 6 mile lake 70 bbls total= 1580 bbls. Daily Metal 0 lbs, total=0 lbs. Daily fluid lost 15 bbls, total= 508 bbls. 5/8/2021 RIH with whipstock assembly on 5" drill pipe from 6766' to 7084'. RIH with 4 stds 6 1/4'' DCs to 7330' then 10 stds 5'' HWDP to 7670', continue RIH with stds 5'' DP to 9035', M/U std 128 and top drive. Correct displacement TIH. Sim Ops: load and process 5" drill pipe in pipe shed.,Break circulation, pump 415 gpm, 1020 psi. Work pipe 30' orienting WS 45 deg left, M/U single, continue to pump 415 gpm, verify 45 deg left. RIH tag BP @ 9104', continue to S/O setting 13k shearing anchor pin, P/U to 170k, P/U additional 2', set down confirm anchor set. Work pipe attempting to shear bolt PU 150K and SO to 30k. PU 170K, SO 83K. Note: Seen a fair amount of sand and crude oil @ BU, Max gas 521u,Pump and spot 40 bbl 7% NXS lube pill on backside, 415 gpm, 1020 psi. With pump off work pipe several more times setting down 10k and PU to 185k, P/U 40' to 8924', establish rotation 15 rpm @ 9500 free torque, L/D single M/U std and TD. Top WS @ 9073.02',Establish parameters, wash down tagging top of whipstock @ 9073', TOW. Mill 8.5" window in 9-5/8" casing T/ 9093' BOW and 20' of new hole to 9113' at 415 gpm, 1020 psi, 80 rpm, 9-13k tq, 2-5k wt on mill. Seeing a good amount of metal at shakers and on magnets. Pump 40 bbl hi vis sweep @ 9079' (20% increase), 9091'(20% increase), and 9110' (no increase). All sweeps back on time; increase in metal, some cement.,Circulate hole clean while working mills though window. Work through 3.5X with rotary/pumps, without rotary, and without rotary pumps 2-3K drag as bottom mill exits window. Flow check well, static. Max gas 130u. PU 160k, SO 102k, ROT 126K,Rig up and perform FIT. Flood and purge lines. Shut UPR's, Perform FIT to 12.0 ppg EMW with 10.05 ppg drilling fluid. Pumped 1.1 bbls, bled back 1.0 bbls. Blow down choke and kill lines.,Monitor well, static. POOH from 9073' to 8760', no indication of swabbing. Pump dry job. Continue to POOH to 7655'. PUW 162K, SOW 105K. Calculated displacement.,Cont. to POOH from 7655' to 62' with milling assembly, laying down drill collars. Calculated displacement observed.,L/D BHA; TM collar, DM collar, float sub, watermelon mill, flex joint, Tri-mill. Starter mill 1/8" under gauge, middle mill 1/16" under gauge, top mill in gauge.,Clean and clear rig floor. Pull wear ring.,Final report for Pre-Drill WBS. Swap to Drilling. Daily disposal to G&I 57 bbls, total= 1583 bbls. Daily water from 6 mile lake 80 bbls total= 1660 bbls. Daily Metal 145 lbs, total= 145 lbs. Daily fluid lost 0 bbls, total= 508 bbls. _____________________________________________________________________________________ Revised By: JNL 6/1/2021 SCHEMATIC Milne Point Unit Well: MPU J-29 Last Completed: 1/11/21 PTD: 220-070 TD =17,921’(MD) / TD =3,565’ (TVD) 20” CIBP Set @ 9104’ Orig. KB Elev.: 68.08’ / GL Elev.: 33.70’ 11 9-5/8” See Screen/ Solid Liner Detail Whipstock set @ 9073’ PBTD = 17,921’ (MD) / PBTD = 3,565’ (TVD) 9-5/8” ‘ES’ Cementer @ 2,406’ MD 4-1/2” Shoe @ 17,919’ 8 9 10 7 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 129.5 / X52 / Weld N/A Surface 147’ N/A 9-5/8" Surface 47 / L-80 / TXP 8.681 Surface 2,429’ 0.0758 9-5/8” Surface 40 / L-80 / TXP 8.835 2,429’ 9,318’ 0.0732 4-1/2” Liner 13.5 / L-80 / Hyd 625 3.920 9,152’ 17,921’ .0149 TUBING DETAIL OPEN HOLE / CEMENT DETAIL Driven 20” 12-1/4"Stg 1 Lead – 1015 sx / Tail – 400 sx Stg 2 Lead – 730 sx / Tail 270 sx 8-1/2” Cementless Screened Liner WELL INCLINATION DETAIL KOP @ 333’ Max Hole Angle = 96° @ 12,620’ MD TREE & WELLHEAD Tree Cameron 3-1/8" 5M w/ 3-1/8” 5M Cameron Wing Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API: 50-029-23688-00-00 Drilled and Completed by Doyon 14 1/11/21 JEWELRY DETAIL No. Top MD Item ID 6 9,073’ Whipstock 7 9,104’ CIBP 8 9,152’ BOT SLZXP LTP / Liner Hanger 7” x 9-5/8” (3,783’ TVD) 6.190” 9 9,154’ Locator Sub, 7” TXP Box x Box 6.180” 10 9,173’ 7” H563 x 4.5” TSH 625 XO 3.840” 11 17,919’ Shoe 3.950” 4-1/2” 250ђ SCREENS LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 207 9,327’ 3,786’ 17,882’ 3,566’ PERMAFROST DETAIL Bottom = 2,161’ MD / 1,955 TVD 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________ 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 17,921'None Casing Collapse Conductor N/A Surface 4,760psi Surface 3,090psi Tieback 6,890psi Liner 9,020psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Monty Myers Contact Name: Nathan Sperry Drilling Manager Contact Email: Contact Phone: 777-8450 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 9,152 MD/ 3,783 TVD Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 8,152' - 17,921' 9,165' 9,769' 3,648' - 3566 Tubing Size: Tubing Grade:Perforation Depth TVD (ft): 9,165' 6,889' Authorized Signature: April 25, 2021 3-1/2" Perforation Depth MD (ft): 9,327' - 17,882' 3,786' - 3,566' BOT SLZXP LTP 3,784' 2,429' 9,318' 4-1/2" 147' 20" 9-5/8" 9-5/8" 2,429' 7-5/8" 7,898' 3,795psi N/A 6,750psi 6,870psi 5,750psi Tubing MD (ft): 9.3# L-80 2,117' 3,786' PRESENT WELL CONDITION SUMMARY 1,477 None MPU J-29 147' 147' TVD BurstLength Size 3,566' 17,921' 3,566' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 025906, 025517, 025515 & 025514 220-070 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23688-00-00 Milne Point Field, Schrader Bluff Oil Pool Hilcorp Alaska LLC nathan.sperry@hilcorp.com COMMISSION USE ONLY Authorized Name: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.04.06 14:27:44 -08'00' Monty M Myers 4.6.2021 By Samantha Carlisle at 11:38 am, Apr 07, 2021 321-169 DLB 04/07/2021 DSR-4/7/21 X 10-407 BOPE test to 3000 psi. Annular test to 2500 psi. Variance to 20 AAC 25.112 (c) Well plugging requirements MGR13APR21 on Required? Yes 4/14/21 dts 4/14/2021 JLC 4/14/2021 RBDMS HEW 4/14/2021 Milne Point Unit (MPU) J-29 Sundry Program Version 1 March 18, 2021 Table of Contents 1.0 Well Summary ........................................................................................................................... 2 2.0 Management of Change Information ........................................................................................ 3 3.0 Tubular Program ....................................................................................................................... 4 4.0 Drill Pipe Information: .............................................................................................................. 4 5.0 Internal Reporting Requirements ............................................................................................. 5 6.0 Wellbore Schematics .................................................................................................................. 6 7.0 Drilling / Completion Summary ................................................................................................ 8 8.0 Mandatory Regulatory Compliance / Notifications .................................................................. 9 9.0 MIRU ....................................................................................................................................... 11 10.0 Pull 3-1/2” Upper Completion ................................................................................................. 12 11.0 Pull 7-5/8” Tieback .................................................................................................................. 13 12.0 Mill 8-1/2” Window and FIT ................................................................................................... 14 13.0 Innovation BOP Schematic ...................................................................................................... 17 14.0 Wellhead Schematic ................................................................................................................. 18 15.0 Formation Information ............................................................................................................ 19 16.0 Anticipated Drilling Hazards .................................................................................................. 20 17.0 Innovation Layout.................................................................................................................... 22 18.0 FIT Procedure .......................................................................................................................... 23 19.0 Innovation Choke Manifold Schematic ................................................................................... 24 20.0 8-1/2” Hole Section MASP ....................................................................................................... 25 21.0 Spider Plot (NAD 27) (Governmental Sections) ...................................................................... 26 22.0 Surface Plat (As Built) (NAD 27) ............................................................................................. 27 Page 2 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 1.0 Well Summary Well MPU J-29A Pad Milne Point “J” Pad Planned Completion Type ESP Target Reservoir(s) Schrader Bluff NB Sand Planned Well TD, MD / TVD 17,901’ MD / 3,575’ TVD PBTD, MD / TVD 17,901’ MD / 3,575’ TVD Surface Location (Governmental) 2609' FNL, 1896' FWL, Sec 28, T13N, R10E, UM, AK Surface Location (NAD 27 –Zone 4) X= 551934, Y= 6015068 Top of Productive Horizon (Governmental) 938' FSL, 1223' FWL, Sec 20, T13N, R10E, UM, AK TPH Location (NAD 27) X= 545847 Y= 6018575 BHL (Governmental) 699' FSL, 2576' FWL, Sec 24, T13N, R9E, UM, AK BHL (NAD 27) X= 536919, Y=6018286 Maximum Anticipated Pressure (Surface) 1,546 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1,923 psig Work String 5” 19.5# S-135 NC 50 KB Elevation above MSL: 26.5 ft + 33.0 ft = 59.5 ft GL Elevation above MSL: 33.0 ft BOP Equipment 13-5/8” x 5M Annular, (3) ea 13-5/8” x 5M Rams Page 3 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 2.0 Management of Change Information Page 4 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 3.0 Tubular Program Hole Section OD (in)ID (in) Drift (in) Conn OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) Cond 20” 19.25”---X-52Weld 12-1/4”9-5/8” 8.835”8.679”10.625”40.0 L-80 TXP 5,750 3,090 916 9-5/8” 8.681”8.525”10.625”47 L-80 TXP 6,870 4,750 1,086 Tieback 7-5/8” 6.875”6.750”7.625 29.7 L-80 Hyd 521 6,890 4,790 683 8-1/2”4-1/2” Screens 3.920 3.795 4.714 13.5 L-80 Hydril 625 9,020 8,540 279 4.0 Drill Pipe Information: Hole Section OD (in) ID (in)TJ ID (in) TJ OD (in) Wt (#/ft) Grade Conn M/U (Min) M/U (Max) Tension (k-lbs) Surface & Production 5”4.276” 3.250” 6.625” 19.5 S-135 DS50 36,100 43,100 560klb 5”4.276”3.250”6.625”19.5 S-135 NC50 30,730 34,136 560klb All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 5 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. x Report covers operations from 6am to 6am x Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area – this will not save the data entered, and will navigate to another data entry tab. x Ensure time entry adds up to 24 hours total. x Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. x Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Afternoon Updates x Submit a short operations update each work day to mmyers@hilcorp.com, pmazzolini@hilcorp.com ,nathan.sperry@hilcorp.com,jengel@hilcorp.com and joseph.lastufka@hilcorp.com 5.3 Intranet Home Page Morning Update x Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 5.4 EHS Incident Reporting x Health and safety: Notify EHS field coordinator. x Environmental: Drilling Environmental coordinator x Notify Drlg Manager & Drlg Engineer x Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally x Send final “As-Run” Casing tally to nathan.sperry@hilcorp.com and joseph.lastufka@hilcorp.com 5.6 Casing and Cement report x Send casing and cement report for each string of casing to nathan.sperry@hilcorp.com and joseph.lastufka@hilcorp.com 5.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmyers@hilcorp.com Drilling Engineer Nate Sperry 907-777-8450 907.301.8996 nathan.sperry@hilcorp.com Completion Engineer Ian Toomey 907.777.8434 907.903.3987 itoomey@hilcorp.com Geologist Seth Nolan 907.777.8308 907.519.8225 snolan@hilcorp.com Res. Engineer Reid Edwards 907.777.8421 907.250.5081 reedwards@hilcorp.com Drlg Environmental Coord Keegan Fleming 907.777.8477 907.350.9439 kfleming@hilcorp.com Safety Manager Carl Jones 907.777.8327 907.382.4336 cajones@hilcorp.com Drilling Tech Joe Lastufka 907.777.8400 907.227.8496 Joseph.Lastufka@hilcorp.com Page 6 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 6.0 Wellbore Schematics BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ĚŝƚĞĚǇ͗:E>ϭͬϮϲͬϮϬϮϭ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh:ͲϮϵ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭͬϭϭͬϮϭ Wd͗ϮϮϬͲϬϳϬ dсϭϳ͕ϵϮϭ͛;DͿͬdсϯ͕ϱϲϱ͛;dsͿ ϮϬ͟ KƌŝŐ͘<ůĞǀ͗͘ϲϴ͘Ϭϴ͛ͬ'>ůĞǀ͗͘ϯϯ͘ϳϬ͛ ϳͲϱͬϴ͟ ϵͲϱͬϴ͟ 6HH 6FUHHQ 6ROLG /LQHU 'HWDLO Wdсϭϳ͕ϵϮϭ͛;DͿͬWdсϯ͕ϱϲϱ͛;dsͿ ´µ(6¶ &HPHQWHU# ¶0' ϰͲϭͬϮ͟ ^ŚŽĞΛ ϭϳ͕ϵϭϵ͛ ϮͲϳͬϴ͟ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϮϬΗ ŽŶĚƵĐƚŽƌ ϭϮϵ͘ϱͬyϱϮͬtĞůĚ Eͬ ^ƵƌĨĂĐĞ ϭϰϳ͛ Eͬ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϳͬ>ͲϴϬͬdyW ϴ͘ϲϴϭ ^ƵƌĨĂĐĞ Ϯ͕ϰϮϵ͛ Ϭ͘Ϭϳϱϴ ϵͲϱͬϴ͟ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬdyW ϴ͘ϴϯϱ Ϯ͕ϰϮϵ͛ ϵ͕ϯϭϴ͛ Ϭ͘ϬϳϯϮ ϳͲϱͬϴ͟ dŝĞďĂĐŬ Ϯϵ͘ϳͬ>ͲϴϬͬ,ǇĚϱϮϭ ϲ͘ϴϳϱ ^ƵƌĨĂĐĞ ϵ͕ϭϲϱ͛ Ϭ͘Ϭϰϱϵ ϰͲϭͬϮ͟ >ŝŶĞƌϮϱϬђ^ĐƌĞĞŶƐ ϭϯ͘ϱͬ>ͲϴϬͬ,ǇĚϲϮϱ ϯ͘ϵϮϬ ϵ͕ϭϱϮ͛ ϭϳ͕ϵϮϭ͛ ͘Ϭϭϰϵ dh/E'd/> ϯͲϭͬϮΗ dƵďŝŶŐ ϵ͘ϯͬ>ͲϴϬͬhͲϴƌĚ Ϯ͘ϵϵϮ ^ƵƌĨĂĐĞ ϳ͕ϴϵϴ͛ Ϭ͘ϬϬϴϳ KWE,K>ͬDEdd/> ƌŝǀĞŶϮϬ͟ ϭϮͲϭͬϰΗ^ƚŐϭ>ĞĂĚʹϭϬϭϱƐǆͬdĂŝůʹϰϬϬƐǆ ^ƚŐϮ>ĞĂĚʹϳϯϬƐǆͬdĂŝůϮϳϬƐǆ ϴͲϭͬϮ͟ ĞŵĞŶƚůĞƐƐ^ĐƌĞĞŶĞĚ>ŝŶĞƌ t>>/E>/Ed/KEd/> <KWΛϯϯϯ͛ DĂǆ,ŽůĞŶŐůĞсϵϲΣΛϭϮ͕ϲϮϬ͛D dZΘt>>, dƌĞĞ ĂŵĞƌŽŶϯͲϭͬϴΗϱDǁͬϯͲϭͬϴ͟ϱDĂŵĞƌŽŶtŝŶŐ tĞůůŚĞĂĚ ĂŵĞƌŽŶϭϭ͟ϱ<ǆƐůŝƉůŽĐŬďŽƚƚŽŵǁͬ;ϮͿϮͲϭͬϭϲ͟ϱ<ŽƵƚƐ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϲϴϴͲϬϬͲϬϬ ŽŵƉůĞƚŝŽŶĂƚĞ͗ϭͬϭϭͬϮϭ ϰͲϭͬϮ͟^K>/>/EZd/> :ƚƐdŽƉ ;DͿ dŽƉ ;dsͿ ƚŵ ;DͿ ƚŵ ;dsͿ ϰ ϵ͕ϭϳϴ͛ ϯ͕ϳϴϱ͛ ϵ͕ϯϮϳ͛ ϯ͕ϳϴϲ͛ :t>Zzd/> EŽ͘ dŽƉD /ƚĞŵ / ϭ ϭϯϱ͛ ϯͲϭͬϮ͟ǆϭ͟'>DǁͬW^Ks Ϯ͘ϵϬϳ͟ Ϯ ϳ͕ϲϱϰ͛ ϯͲϭͬϮ͟ǆϭ͟'>DƵŵŵǇsĂůǀĞǁͬ<>ĂƚĐŚ Ϯ͘ϵϬϳ͟ ϯ ϳ͕ϳϳϰ͛ yEEŝƉƉůĞ͕Ϯ͘ϴϭϯ͟WƌŽĨŝůĞ͕Ϯ͘ϳϱ͟EŽ'Ž Ϯ͘ϳϲϬ͟ ϰ ϳ͕ϴϭϲ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚ͗ͬKWDWϱϭϯϯͲϭͬϮǆϴh ϱ ϳ͕ϴϭϳ͛ ĞŶŝƚŚWŽƌƚĞĚ^Ƶď͗WƌĞƐƐWŽƌƚϱϭϯͬϱϯϴW ϲ ϳ͕ϴϭϳ͛ WƵŵƉ͗ϱϯϴWD^yϮϳ&ůĞǆϮϳϭϯϱ&Z,ϲ ϳ ϳ͕ϴϰϱ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ͗ϱϯϴ'^d,ss,ϲ ϴ ϳ͕ϴϱϭ͛ hƉƉĞƌdĂŶĚĞŵ^ĞĂů͗'^,ϲ^ͬW&^ ϵ ϳ͕ϴϱϴ͛ >ŽǁĞƌdĂŶĚĞŵ^ĞĂů͗'^,ϲ^ͬW&^ ϭϬ ϳ͕ϴϲϰ͛ DŽƚŽƌ͗ϱϲϮyWʹϰϱϬ,Wͬϯϭϯϱsͬϴϴ ϭϭ ϳ͕ϴϵϯ͛ DŽƚŽƌ'ĂƵŐĞ͗ĞŶŝƚŚϳ ϭϮ ϳ͕ϴϵϲ͛ ĞŶƚƌĂůŝǌĞƌ͗ŽƚƚŽŵΛϳ͕ϴϵϴ͛D ϭϯ ϵ͕ϭϱϮ͛ Kd^>yW>dWͬ>ŝŶĞƌ,ĂŶŐĞƌϳ͟ǆϵͲϱͬϴ͟;ϯ͕ϳϴϯ͛dsͿϲ͘ϭϵϬ͟ ϭϰ ϵ͕ϭϱϰ͛ >ŽĐĂƚŽƌ^Ƶď͕ϳ͟dyWŽǆǆŽǆ ϲ͘ϭϴϬ͟ ϭϱ ϵ͕ϭϳϯ͛ ϳ͟,ϱϲϯǆϰ͘ϱ͟d^,ϲϮϱyK ϯ͘ϴϰϬ͟ ϭϲ ϭϳ͕ϵϭϵ͛ ^ŚŽĞ ϯ͘ϵϱϬ͟ ϰͲϭͬϮ͟^ZE^>/EZd/> :ƚƐdŽƉ ;DͿ dŽƉ ;dsͿ ƚŵ ;DͿ ƚŵ ;dsͿ ϮϬϳ ϵ͕ϯϮϳ͛ ϯ͕ϳϴϲ͛ ϭϳ͕ϴϴϮ͛ ϯ͕ϱϲϲ͛ Current Page 7 Version 1 March 2021 Milne Point Unit J-29A Sundry Application Completion MPU -29A - Sidetrack Page 8 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 7.0 Drilling / Completion Summary MPU J-29A is a sidetrack producer planned to be drilled in the Schrader Bluff NB sand. J-29 is part of a multi well program targeting the Schrader Bluff sand on J-Pad. This is a re-drill due to a suspected liner failure on the original J-29 well. An 8-1/2” lateral section will be drilled off of a 9-5/8” whipstock with the KOP at ~9,100’ MD. A 4-1/2” screen liner will be run in the open hole section and the well produced with an ESP upper completion. Innovation will be used to drill and complete the wellbore Drilling operations are expected to commence approximately April 28th, 2021, pending rig schedule. The whipstock will be set below the top of the Schrader Bluff such that this is an in-zone sidetrack. All cuttings & mud generated during drilling operations will be hauled to the Milne Point “B” pad G&I facility. General sequence of operations (will commence following operations detailed on sundry application): 1. MIRU, test BOPE 2. Circulate out freeze protect 3. Pull 3-1/2” Upper Completion 4. Pull 7-5/8” tieback 5. If necessary, perform cleanout run 6. RIH and set 9-5/8” CIBP 7. Run 9-5/8” whipstock, mill window 8. Drill 8-1/2” lateral to well TD 9. Run 4-1/2” production liner 10. Run 7-5/8” tieback 11. Run Upper Completion 12. ND BOP, NU Tree, RDMO Reservoir Evaluation Plan: 1. Production Hole: No mud logging. Wellsite geologist. LWD: GR + ADR (For geo-steering) Sundry 321-169 PTD for J-29A Page 9 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. x BOP’s shall be tested at 1 week intervals prior to initiating window milling and 2 week intervals during the drilling and completion of MPU J-29A thereafter. Provide AOGCC 24 hrs notice prior to testing BOPs. x The initial test of BOP equipment will be to 250/3000 psi & subsequent tests of the BOP equipment will be to 250/3000 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests).Confirm that these test pressures match those specified on the APD. x If the BOP is used to shut in on the well in a well control situation, notify AOGCC and test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. x All AOGCC regulations within 20 AAC 25.033 “Primary well control for drilling: drilling fluid program and drilling fluid system”. x All AOGCC regulations within 20 AAC 25.035 “Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements”. x Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. x Casing pressure test criteria in 20 AAC 25.030 (e) Casing and Cementing,“A casing pressure test must be performed if BOPE is to be installed on a casing. The casing must be tested to hold a minimum surface pressure equal to 50 percent of the casing internal yield pressure. The test pressure must show stabilizing pressure and may not decline more than 10 percent within 30 minutes. The results of this test and any subsequent tests of the casing must be recorded as required by 20 AAC 25.070(1)”. AOGCC Regulation Variance Requests: x There are no variance requests at this time. Page 10 Version 1 March 2021 Milne Point Unit J-29A Sundry Application Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure (psi) 8-1/2” x 13-5/8” x 5M Control Technology Inc Annular BOP x 13-5/8” x 5M Control Technology Inc Double Gate o Blind ram in btm cavity x Mud cross w/ 3” x 5M side outlets x 13-5/8” x 5M Control Technology Single ram x 3-1/8” x 5M Choke Line x 3-1/8” x 5M Kill line x 3-1/8” x 5M Choke manifold x Standpipe, floor valves, etc Initial Test: 250/3,000 Subsequent Tests: 250/3,000 Primary closing unit: Control Technology Inc. (CTI), 6 station, 3,000 psi, 220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an electric triplex pump on a different electrical circuit and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: x Well control event (BOPs utilized to shut in the well to control influx of formation fluids). x 24 hours notice prior to spud. x 24 hours notice prior to testing BOPs. x 24 hours notice prior to casing running & cement operations. x Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Email:jim.regg@alaska.gov Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Email:Victoria.loepp@alaska.gov Mel Rixse / Petroleum Engineer / (O): 907-793-1231 / (C): 907-223-3605 / Email:melvin.rixse@alaska.gov Primary Contact for Opportunity to witness:AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format:http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 11 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 9.0 MIRU All the work up through laying down the milling assembly will be on the PRE AFE code. There is restricted communication to the lateral due to fill. This is an in-zone sidetrack to replace the failed liner. The existing lateral will be isolated via a plug set above the liner top. Operational Steps: 9.1 Ensure Sundry, PTD, and drilling program are posted in the rig office and on the rig floor. 9.2 Level pad and ensure enough room for layout of rig footprint and R/U. 9.3 Ensure rig mats cover entire footprint of rig. 9.4 MIRU Innovation. Ensure rig is centered over the wellhead to prevent any wear to BOPE or wellhead. 9.5 N/U 13-5/8” x 5M BOP as follows: x BOP configuration from top down: 13-5/8” x 5M annular / 13-5/8” x 5M double gate / 13- 5/8” x 5M mud cross / 13-5/8” x 5M single gate x Double gate ram should be dressed with 2-7/8” x 5” VBRs in top cavity,blind ram in bottom cavity. x Single ram can be dressed with 7-5/8” FBRs x N/U bell nipple, install flowline. x Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to mud cross). x Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual valve 9.6 Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. x Install test dart in BPV. x Test VBR’s with 3-1/2” and 5” test joints x Test FBR’s with 7-5/8” test joint x Confirm test pressures with PTD x Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug x Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 9.7 R/D BOP test equipment. Pull test dart and BPV. Page 12 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 10.0 Pull 3-1/2” Upper Completion Notes: x Upper completion was installed by Doyon 14 in January 2021 using a 33.1’ air gap (per tally). There is a 6.6’ shift to our 26.5’ Innovation air gap. hank x Recent attempts to establish communication with the reservoir have had mixed results. On 3/23/2021, service coil was unable to circulate to surface inside the tubing but was able to bullhead into the formation. Slickline had no trouble running to 7654’ MD the following day. x On 3/24/2021, slickline reported a fluid level at 1,406’ MD and pulled the lowermost DGLV from Station 1 (7654’ D14 MD). Station 2 (135’ MD) has a one way valve from the IA to the tbg. x Slickline bailing runs recovered a sandy/heavy oil mixture from the tubing on 3/21/2021. Operational Steps: 10.1 RU to circulate the well to seawater. Flowcheck and be prepared to swap to 10.0ppg KCl/NaCl brine if necessary. x The tubing has 60/40 freeze protect and the IA has diesel freeze protect. x Service coil filled the well with freeze protect and slickline found the fluid level at 1,406’ MD the next day so the well may not support a full column of 10.0ppg brine despite the 9.8ppg pore pressure prediction. 10.2 RU ESP spooler and associated equipment in preparation for pulling the upper completion. 10.3 Back out lock down screws. 10.4 Pull tubing hanger with landing joint/XO to the floor. Have appropriate protectors ready. 10.5 Note and record PU weight required to pull the tubing from cut. Final PU/SO weight from Doyon 14 was 95k / 60k. 10.6 Pull and lay down the tubing. The plan is to re-run this completion after sidetracking (confirm w/ Operations Engineer). Page 13 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 11.0 Pull 7-5/8” Tieback Operational Steps: 11.1 Ensure 7-5/8” x 9-5/8” annulus is bled to zero. Bleed each tour. 11.2 Ensure annulus is circulating clean prior to laying down 7-5/8” tieback. 130 bbls of inhibited brine and 41 bbls of diesel are in the annulus. 11.3 Verify LD screws are free. Pull packoff. PU landing joint recover the casing hanger. 11.4 Pull hanger with landing joint/XO to the floor. x Note and record PU weight required to pull the casing. x Doyon 14 landed the hanger with 185k PU weight / 105k SO weight on 1/9/2021. x Circulate at least 1.5X BU and pump at least one high vis sweep surface to surface to clean out 11.5 Pull and lay down the casing. 11.6 Run wear ring. 11.7 If necessary, MU cleanout BHA w/ 8-1/2” bit and RIH to the liner top. CBU as necessary to ensure casing is clean. 11.8 MU a 9-5/8” CIBP on 5” DP and RIH to set it within a couple of feet of the top of the liner. Perform assurance test on the CIBP to 1500 psi for 10 minutes. Page 14 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 12.0 Mill 8-1/2” Window and FIT Note: All following operations will be covered under the PTD for J-29A 12.1 Whipstock Set Depth Information: x The top ~2,400’ of 9-5/8” is 47# x Top of Schrader Bluff is 8,978’ MD Innovation RKB (8,984’ D14 RKB) x Planned TOW: ~9,114’ MD (may need to shift closer to collar to accommodate CIBP) x Collars should be at 9,066’ and 9,108’ and 9,150’ Innovation RKB x Top of baffle adapter is 9,150’ MD Innovation RKB (9,156’ D14 RKB) x Top of liner is at 9,145’ Innovation RKB (9,151’ D14 RKB) x Whipstock is the Wellbore Integrity Solutions Trackmaster Elite x Verify shear bolt strength with WIS rep. 12.2 MU 8-1/2” mill/whipstock assembly as per fishing rep’s tally x Ensure magnets are in trough, under shakers, and flow area to capture metal shavings circulated 12.3 Install MWD. Rack back mill assembly. 12.4 Verify offset between MWD and whipstock tray, witnessed by Drilling Supervisor, MWD/DD and fishing rep. Document and record offset in well file. 12.5 Slowly run in the hole as per fishing rep. Run extremely slow through the BOP & wear bushing to prevent damaging the shear bolt. 12.6 Run in hole at 1 ½ to 2 minutes per double, or as per fishing rep. Ensure work string is stationary prior to setting the slips, and removed slowly as well. These precautions are to avoid weakening the shear bolt and prematurely setting the anchor. 12.7 Stop at least 30-45’ above planned set depth and obtain survey with MWD. 12.8 Milling fluid will be 10.0-10.2 ppg viscosified fluid (Baradrill-N or brine). 12.9 With the bottom of the whipstock 30 – 45’ above the set depth, work torque out of string, measure and record P/U and S/O weights. Obtain good survey to orient whipstock face. 12.10 Orient whipstock to desired direction by turning DP in ¼ round increments. P/U and S/O on DP to work all torque out after oriented. Target orientation is 60q ROHS. Page 15 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 12.11 Whipstock Orientation Diagram: Desired orientation of the whipstock face is 60R. Acceptable range is between 30R and 60R Hole Angle at window interval (9,122’ MD) is ~81°, Azimuth 267°. 12.12 Once whipstock is in desired orientation, set WS per fishing rep. 12.13 P/U 5-7K maximum overpull to verify anchor is set. The window mill can then be sheared off by slacking off weight on the whipstock shear bolt. 12.14 P/U 5-10’ above top of whipstock. 12.15 CBU and confirm consistent MW in/out x Ensure Mud properties are sufficient for transporting metal cuttings x Visc: 40-60, YP: 18-20 12.16 Record P/U, S/O weights, and free rotation. Slack off to top of whipstock and with light weight and low torque. Mill window as per fishing rep. Utilize 4 ditch magnets on the surface to catch metal cuttings. Pump high visc sweeps as necessary. 12.17 If possible, install catch trays in shaker underflow chute to help catch metal cuttings. 12.18 Clean catch trays and ditch magnets frequently while milling window. 12.19 Mill window until the uppermost mill has passed across the entire tray. Dress and polish window as needed. 12.20 With upper mill at the end of the tray, this will drill ~ 20’ of new hole. 12.21 After window is milled and before POOH, shut down pumps and work milling assembly through window watching for drag. Dress and polish window as needed. After reaming, shut off pumps and rotary (if hole conditions allow) and pass through window checking for drag. 12.22 Circulate bottoms up until even MW in/out and hole is clean of metal shavings. Reduce mud properties for drilling. 12.23 Pull back into 9-5/8” casing and perform FIT to 12.0 ppg EMW. Chart Test. 60R 30R Page 16 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 12.24 Flowcheck. POOH & LD milling BHA. Gauge mills for wear. 12.25 PU stack washer and wash BOPE stack. Function all rams to clear any potential milling debris. All operations following milling the window are detailed in the Permit to Drill. Page 17 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 13.0 Innovation BOP Schematic Typical Ram Configuration 7-5/8" for tie-back Page 18 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 14.0 Wellhead Schematic FMC Gen 5 Typical 2-7/8” Page 19 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 15.0 Formation Information MPU J Pad Data Sheet Page 20 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 16.0 Anticipated Drilling Hazards Window Exit: Tracking Casing The KOP is cemented. The risk of tracking casing is low. Production Hole Sections: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of > 300 gpm Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: There is at least (1) fault that will be crossed while drilling the well. There could be others and the throw of these faults is not well understood at this point in time. When a known fault is coming up, ensure to put a “ramp” in the wellbore to aid in kicking off (low siding) later. Once a fault is crossed, we’ll need to either drill up or down to get a look at the LWD log and determine the throw and then replan the wellbore. H2S: Treat every hole section as though it has the potential for H2S. J-pad does not have a history of high H2S. J-10 had a sample measure at 10 ppm in 2009 which was the highest sample measurement recorded for any J-pad well. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: Reservoir pressures are expected to be abnormal. Utilize MPD to mitigate any abnormal pressure seen. Page 21 Version 1 March 2021 Milne Point Unit J-29A Sundry Application Anti-Collision Take directional surveys every stand, take additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic interference with another well. Reference A/C report in directional plan. Well Specific: x M-43 has a 0.411 CF. M-43 is an active producer from the NB sands. A collision would result in drilling through an uncompleted section of M-43 (i.e. open hole in the rock below the shoetrack). Slight lost circulation might occur and there is no HSSE risk. x M-43PB3 has a 0.518 CF. This is an open hole PB. No risk. x J-29 has a 0.602 CF. There is no HSSE risk. The risk is financial (bit trip, OH sidetrack). Page 22 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 17.0 Innovation Layout Page 23 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 18.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 24 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 19.0 Innovation Choke Manifold Schematic Page 25 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 20.0 8-1/2” Hole Section MASP Page 26 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 21.0 Spider Plot (NAD 27) (Governmental Sections) Page 27 Version 1 March 2021 Milne Point Unit J-29A Sundry Application 22.0 Surface Plat (As Built) (NAD 27) DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23688-00-00Well Name/No. MILNE PT UNIT J-29Completion Status1-OILCompletion Date1/11/2021Permit to Drill2200700Operator Hilcorp Alaska, LLCMD17921TVD3566Current Status1-OIL2/25/2021UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:ROP, AGR, ABG, DGR, EWR, ADR MD & TVDNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF1/25/2021155 17921 Electronic Data Set, Filename: MPU J-29 LWD Final.las34611EDDigital DataDF1/25/20219305 17886 Electronic Data Set, Filename: MPU J-29 ADR Quadrants All Curves.las34611EDDigital DataDF1/25/2021 Electronic File: MPU J-29 LWD Final MD.cgm34611EDDigital DataDF1/25/2021 Electronic File: MPU J-29 LWD Final TVD.cgm34611EDDigital DataDF1/25/2021 Electronic File: MPU J-29_DSR.pdf34611EDDigital DataDF1/25/2021 Electronic File: MPU J-29_DSR.txt34611EDDigital DataDF1/25/2021 Electronic File: MPU J-29_DSR.xlsx34611EDDigital DataDF1/25/2021 Electronic File: MPU J-29_GIS.txt34611EDDigital DataDF1/25/2021 Electronic File: MPU J-29_Plan View.pdf34611EDDigital DataDF1/25/2021 Electronic File: MPU J-29_Section View.pdf34611EDDigital DataDF1/25/2021 Electronic File: MPU J-29 LWD Final MD.emf34611EDDigital DataDF1/25/2021 Electronic File: MPU J-29 LWD Final TVD.emf34611EDDigital DataDF1/25/2021 Electronic File: MPU_J-29_Geosteering.dlis34611EDDigital DataDF1/25/2021 Electronic File: MPU_J-29_Geosteering.ver34611EDDigital DataDF1/25/2021 Electronic File: MPU J-29 LWD Final MD.pdf34611EDDigital DataDF1/25/2021 Electronic File: MPU J-29 LWD Final TVD.pdf34611EDDigital DataDF1/25/2021 Electronic File: MPU J-29 LWD Final MD.tif34611EDDigital DataDF1/25/2021 Electronic File: MPU J-29 LWD Final TVD.tif34611EDDigital Data0 0 2200700 MILNE PT UNIT J-29 LOG HEADERS34611LogLog Header ScansThursday, February 25, 2021AOGCCPage 1 of 3MPU J-29 LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23688-00-00Well Name/No. MILNE PT UNIT J-29Completion Status1-OILCompletion Date1/11/2021Permit to Drill2200700Operator Hilcorp Alaska, LLCMD17921TVD3566Current Status1-OIL2/25/2021UICNoWell 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:1/11/2021Release Date:10/22/2020DF1/26/2021 Electronic File: MPU J-29 Customer Survey.xlsx34613EDDigital DataDF1/26/2021 Electronic File: MPU J-29 Geosteering End of Well Report.docx34613EDDigital DataDF1/26/2021 Electronic File: MPU J-29 Geosteering End of Well Report.pdf34613EDDigital DataDF1/26/2021 Electronic File: MPU J-29 Geosteering EOW Plot.emf34613EDDigital DataDF1/26/2021 Electronic File: MPU J-29 Geosteering EOW Plot.pdf34613EDDigital DataDF1/26/2021 Electronic File: MPU J-29 Geosteering EOW Plot.tif34613EDDigital DataDF1/26/2021 Electronic File: MPU J-29 Post-Well Geosteering X-Section Summary.pdf34613EDDigital DataDF1/26/2021 Electronic File: MPU J-29 Post-Well Geosteering X-Section Summary.pptx34613EDDigital Data0 0 2200700 MILNE PT UNIT J-29 LOG HEADERS34613LogLog Header ScansThursday, February 25, 2021AOGCCPage 2 of 3 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23688-00-00Well Name/No. MILNE PT UNIT J-29Completion Status1-OILCompletion Date1/11/2021Permit to Drill2200700Operator Hilcorp Alaska, LLCMD17921TVD3566Current Status1-OIL2/25/2021UICNoComments:Compliance Reviewed By:Date:Thursday, February 25, 2021AOGCCPage 3 of 3M. Guhl2/25/2021 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached:16. Well Name and Number: Surface: Top of Productive Interval:9. Ref Elevations: KB: 17. Field / Pool(s): GL: 33.70' BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD:19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5 Directional or Inclination Survey:Yes (attached) No 13. Water Depth, if Offshore:21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22.Logs Obtained: 23. BOTTOM 20" X-52 147' L-80 2117' L-80 3786' 7-5/8" L-80 3784' 4-1/2" L-80 3566' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 9-5/8"12-1/4" 1/4/2021 12/20/2020 ADL 025906, 025517, 025515 & 025514 88-005 N/AN/A None 17,921' / 3,566' ROP, AGR, ABG, DGR, EWR, ADR MD & TVD 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 4-1/2" Screen Liner 1/7/2021 9,327' - 17,882' 3,786' - 3,566' Water-Bbl: PRODUCTION TEST N/A Date of Test: Flow Tubing 129.5# 47# 147' 2429' 9318' Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 40# 9165' 2117' Surface DEPTH SET (MD) 9152' / 3783' PACKER SET (MD/TVD) Surface CASING WT. PER FT.GRADE 29.7# 545660 536921 TOP SETTING DEPTH MD Surface SETTING DEPTH TVD 6018174 BOTTOM TOP Surface HOLE SIZE AMOUNT PULLED 33.70' 50-029-23688-00-00 MPU J-29 551934 6015068 920' FSL, 936' FWL, Sec. 20, T13N, R10E, UM, AK CEMENTING RECORD 6018556 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 1/1/2021 2670' FSL, 3383' FEL, Sec. 28, T13N, R10E, UM, AK 587' FSL, 2574' FEL, Sec. 24, T13N, R09E, UM, AK 220-070 Milne Point Field, Schrader Bluff Oil Pool 68.08' 17,921' / 3,566' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas Driven 13.5# Surface 2429' Stg 1 L - 1015 sx / T - 400 sx 8-1/2"8152' 17921' Stg 2 L - 730 sx / T - 270 sx 3648' Surface 7898'3-1/2" 9.3# L-80 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, Uncemented TiebackTieback TUBING RECORD Uncemented Screen Liner Liner Top Packer Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 9:43 am, Jan 29, 2021 RBDMS HEW 2/1/2021 Completion Date 1/11/2021 HEW G DSR-2/1/21 SFD 2/2/2021 DLB 02/01/2021 2,161' / 1,956' MGR24FEB2021 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD 36' 36' 2161' 1956' Top of Productive Interval 9159' 3783' 1473' 1418' 2456' 2131' 7093' 3366' 8984' 3755' 9159' 3783' SB NB 9159' 3783' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Joe Lastufka Contact Email:joseph.lastufka@hilcorp.com Authorized Contact Phone: 777-8400 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: 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: Ugnu LA3 LOT / FIT Data Sheet, Drilling and Completion Reports, Definitive Directional Survey, Csg and Cmt Report, Wellbore Schematic Signature w/Date: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. INSTRUCTIONS 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 Schrader Bluff NA SV 5 SV 1 This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Schrader Bluff NB Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 1.29.2021Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.01.29 08:57:55 -09'00' Monty M Myers _____________________________________________________________________________________ Edited By: JNL 1/26/2021 SCHEMATIC Milne Point Unit Well: MPU J-29 Last Completed: 1/11/21 PTD: 220-070 TD =17,921’(MD) / TD =3,565’ (TVD) 4/5/6 20” Orig. KB Elev.: 68.08’ / GL Elev.: 33.70’ 7-5/8” 7/8/9 10 4 16 9-5/8” 1 2 3 See Screen/ Solid Liner Detail PBTD = 17,921’ (MD) / PBTD = 3,565’ (TVD) 9-5/8” ‘ES’ Cementer @ 2,406’ MD 4-1/2” Shoe @ 17,919’ 11 13 12 14 15 2-7/8” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 129.5 / X52 / Weld N/A Surface 147’ N/A 9-5/8" Surface 47 / L-80 / TXP 8.681 Surface 2,429’ 0.0758 9-5/8” Surface 40 / L-80 / TXP 8.835 2,429’ 9,318’ 0.0732 7-5/8” Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 9,165’ 0.0459 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hyd 625 3.920 9,152’ 17,921’ .0149 TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / EUE-8rd 2.992 Surface 7,898’ 0.0087 OPEN HOLE / CEMENT DETAIL Driven 20” 12-1/4"Stg 1 Lead – 1015 sx / Tail – 400 sx Stg 2 Lead – 730 sx / Tail 270 sx 8-1/2” Cementless Screened Liner WELL INCLINATION DETAIL KOP @ 333’ Max Hole Angle = 96° @ 12,620’ MD TREE & WELLHEAD Tree Cameron 3-1/8" 5M w/ 3-1/8” 5M Cameron Wing Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API: 50-029-23688-00-00 Completion Date: 1/11/21 4-1/2”SOLID LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 4 9,178’ 3,785’ 9,327’ 3,786’ JEWELRY DETAIL No. Top MD Item ID 1 135’ 3-1/2” x 1” GLM w/ DPSOV 2.907” 2 7,654’ 3-1/2” x 1” GLM Dummy Valve w/ BK Latch 2.907” 3 7,774’ XN Nipple, 2.813” Profile, 2.75” No Go 2.760” 4 7,816’ Discharge Head: B/O PMP 513 3-1/2 x 8 EUE 5 7,817’ Zenith Ported Sub: Press Port 513/538P 6 7,817’ Pump: 538PMSXD 27 Flex27 135 FER H6 7 7,845’ Gas Separator: 538GSTHVEV H6 8 7,851’ Upper Tandem Seal: GSBDB H6 SB/AB PFSA 9 7,858’ Lower Tandem Seal: GSBDB H6 SB/AB PFSA 10 7,864’ Motor: 562XP – 450HP / 3135V / 88A 11 7,893’ Motor Gauge: Zenith E7 12 7,896’ Centralizer: Bottom @ 7,898’ MD 13 9,152’ BOT SLZXP LTP / Liner Hanger 7” x 9-5/8” (3,783’ TVD) 6.190” 14 9,154’ Locator Sub, 7” TXP Box x Box 6.180” 15 9,173’ 7” H563 x 4.5” TSH 625 XO 3.840” 16 17,919’ Shoe 3.950” 4-1/2”SCREENS LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 207 9,327’ 3,786’ 17,882’ 3,566’ CASING AND LEAK-OFF FRACTURE TESTS Well Name:MPU J-29 Date:12/30/2020 Csg Size/Wt/Grade:9.625"40# x 47#, L-80 Supervisor:Sunderland/Demoski Csg Setting Depth:9318 TMD 3804 TVD Mud Weight:9.2 ppg LOT / FIT Press =553 psi . LOT / FIT =12.00 ppg Hole Depth =9345 md Fluid Pumped=1.4 Bbls Volume Back =1.0 bbls Estimated Pump Output:0.101 Barrels/Stroke LOT / FIT DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here ->00 ->00 ->170 ->5247 ->2190 ->10 469 ->3230 ->15 682 ->4250 ->20 878 ->5280 ->25 1081 ->6300 ->30 1290 ->7360 ->35 1514 ->8390 ->40 1709 ->9418 ->45 1903 ->10 445 ->51 2188 ->11 460 ->55 2343 ->12 490 ->60 2567 ->14 553 ->61 2604 Enter Holding Enter Holding Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here ->0553 ->0 2604 ->1538 ->5 2596 ->2511 ->10 2592 ->3506 ->15 2587 ->4503 ->20 2583 ->5491 ->25 2579 ->6486 ->26 2578 ->7484 ->27 2577 ->8481 ->28 2577 ->9480 ->29 2576 ->10 478 ->30 2576 ->11 -> ->12 -> -> -> -> -> -> 0 1 2 3 4 5 6 7 8 9 101112 14 0 5 10 15 20 25 30 35 40 45 51 55 6061 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 0 10203040506070Pressure (psi)Strokes (# of) LOT / FIT DATA CASING TEST DATA Pressure (psi) 553538511506503491486484481480478 2604 2596 2592 2587 2583 257925782577257725762576 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 0 5 10 15 20 25 30 35Pressure (psi)Time (Minutes) LOT / FIT DATA CASING TEST DATA Activity Date Ops Summary 12/19/2020 Load BHA into the shed and warm up same. Secure landings. Spot pump house, flush MP pop -off valves, prep in the pits, work on checklist N/U diverter stack, installing diverter line, perform Derrick inspection, continue to ready pits for mud, inspect saver sub and B/U dies, spot Beyond choke skid, cuttings tank, rock washer and 5 star. R/D company mans camp and move from I-pad to J-pad. Continue to work on checklist. Work on diverter, finish prepping pits and start load 580 bbls 8.8 spud mud, R/U rock washer, install riser, lay out cable for hi-line. Welder splice drilling line. Install both mouse holes. Install riser. Continue to work on acceptance checklist. Spot and setup company mans camp. Rig electrician test gas alarms, test PVT alarm function and NOV rep calibrate Totco sensors. Finish diverter system and acceptance checklist. Closest ignition source 95', light on production building. Finish load spud mud to pits. Adjust drag chains. Load and process 5" HWDP in shed. Clear ice plug from 90' mouse hole. Rig on High-Line @ 21:30 Cut and slip 46' drilling line. Calibrate blocks and service rig. Rig accepted @ 00:00 Perform diverter function test on 5" DP. AOGCC Rep. Jeff Jones waived witness @ 12:22, 12/19/2020. Knife valve open 17 sec & annular close 51 sec. 2950 PSI system pressure, 1750 PSI after closing, 200 PSI recovery in 36 sec, full recovery in 157 sec. 6 N2 bottle avg 2050 PSI. Mobilize BHA components to the rig floor. M/U 2 jts 5" HWDP and jars, and rack in the Derrick. Install proper nozzles in bit. M/U 12-1/4" Kymera bit, 8" mud motor with 1.5° AKO and XO sub to 36'. M/U stand of 5" HWDP to top drive. Hold pre spud meeting with all parties involved. Fill standpipe with water and pressure test high pressure mud line to 3000 PSI. good. Engage pumps and swap to spud mud, clear out ice plug at 36’. Wash down, f/ 36', tag at 92', clean out conductor to 125' pumping 450 gpm, 540 psi, 30 rpm, 1k tq, 1-2k WOB. Lots of sand and gravel by 110'. 12/20/2020 Continue to cleanout 20'' conductor f/ 125' to 147' 450 gpm, 540 psi 30 rpm, 1k tq, 1-2k WOB Drill 12-1/4"" surface hole f/ 147' t/ 220' (220' TVD), 73' drilled. 450 GPM, 550 PSI, 30 RPM, 1-2K TQ, 1-2K WOB. 50K PU / 50K SO / 50K ROT. BROOH f/ 220' t/ 147'. Pump out f/ 147' to 123', flow check- static. BD TD. POOH & inspect bit - good. PJSM for BHA. P/U GWD, EWR, ILS, DM and TM collars, UBHO sub to 101'. Perform offsets & UBHO orientation, DM-mtr offset = 14.7 deg, DM- GWD offset= 146.0 deg, Initialize MWD tools. Carry scribe up and orient UBHO sub. M/U 3 NMFCs to 187'. M/U stand of HWDP and pulse test MWD tools 450 GPM, 855 PSI - good. Ream to bottom with 40 RPM . Drill 12-1/4" surface hole f/ 220' t/ 423' (423' TVD) 203' drilled, 81.2'/hr AROP. 450 GPM, 1061 PSI, 30 RPM, 2K TQ, 2K WOB. MW 9.05 in / 9.1 out, vis 300 in / 300 out, 9.8 ECD. 60K PU / 65K SO / 63K ROT. Begin planned 3°/100' build at 350' An incorrect TF from gyro data was being used for Directional steering, out approx. 180° f/ 350' to 423', A Gyro survey confirmed. Consult with town team, create plan to correct, BR f/ 423' to 372' to reduce 3° DL. Use 20° TF and 4°/100' DL to get back to plan. Max separation from plan= 14.68' Drill 12-1/4" surface hole f/ 423' t/ 548' (548' TVD) 125' drilled, 83.33/hr AROP. 450 GPM, 1100 PSI, 30 RPM, 1K TQ, 3-10K WOB. MW 9.0 in / 9.0 out, vis 300 in / 300 out, 9.7 ECD. 70K PU / 60K SO / 70K ROT. Start 4°/100' DLR to get back to plan Drill 12-1/4" surface hole f/ 548' t/ 1090' (1072' TVD) 542' drilled, 90.33/hr AROP. 450 GPM, 1400 PSI, 30 RPM, 5K TQ, 10-15K WOB. MW 9.2 in / 9.3 out, vis 300 in / 300 out, 10.3 ECD. 82K PU / 85K SO / 83K ROT. Continue 4°/100' DLR to get back to plan until 900' then target 3.5° DLR Drill 12-1/4" surface hole f/ 1090' t/ 1613' (1541' TVD) 523' drilled, 87.16/hr AROP. 500 GPM, 1500 PSI, 60 RPM, 5K TQ, 10K WOB. MW 9.1 in / 9.2 out, vis 300 in / 300 out, 10.02 ECD. Max Gas: 25u. 95K PU / 95K SO / 95K ROT. Target 3.5°/100' DLR as per Wp Installed gas detector in possum belly at 1019’. Last survey at 1561.99' MD / 1496.81' TVD, 29.74° inc, 309.98° azm, 13.07' from plan, 8.84' high, 9.64' right. Losses: 0 bbls Daily / 0 bbls Total. H20 from 6-Mile: 1190 bbls Daily / 1340 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Cuttings/mud/cement to MPU G&I: 1036 bbls Daily / 1062 bbls Total. 12/21/2020 Drill 12-1/4" surface hole f/ 1613' t/ 2279' (2031' TVD) 658' drilled, 109.6/hr AROP. 500 GPM, 1500 PSI, 60 RPM, 5K TQ, 1-5K WOB. MW 9.4 in / out, vis 150in / 173 out, 10 ECD. Max Gas: 121u. 105K PU / 90K SO / 100K ROT. Continue to build 3.5°/100' BOPF came in at 2161' md, 1955' tvd Drill 12-1/4" surface hole f/ 2279' t/ 3070' (2336' TVD) 791' drilled, 131.83/hr AROP. 550 GPM, 2060 PSI, 80 RPM, 7K TQ, 5-12K WOB. MW 9.3 in / 9.4 out, vis 97 in / 212 out, 10.3 ECD. Max Gas: 152u. 105K PU / 85K SO / 92K ROT. UG4 Logged @ 3008’ Pump 30 bbl hi vis sweep @ 2527', back 300 stks early w/ 100% increase. Pump 30 bbl hi vis sweep @ 3030', back 400 stks early w/ 60% increase. Continue to build 3.5°/100' to 2838' then hold 75° tangent Drill 12-1/4" surface hole f/ 3070' t/ 3850’ (2530' TVD) 780' drilled, 130’/hr AROP. 550 GPM, 2170 PSI, 80 RPM, 10K TQ, 11K WOB. MW 9.2 in / 9.4 out, vis 93 in / 300 out, 10.2 ECD. Max Gas: 121u. 112K PU / 80K SO / 90K ROT Pump 30 bbl hi vis sweep @ 3604', back 300 stks early w/ 100% increase. Continue to hold 75° tangent Drill 12-1/4" surface hole f/ 3850' t/ 4551’ (2727' TVD) 701' drilled, 116.83’/hr AROP. 550 GPM, 2150 PSI, 80 RPM, 10K TQ, 10K WOB. MW 9.25 in / 9.25 out, vis 127 in / 215 out, 10.4 ECD. Max Gas: 89u. 125K PU / 80K SO / 95K ROT. Continue to hold 75° tangent. Pump 30 bbl hi vis sweep @ 4078', back on time early w/ 20% increase. Tight spot with slight packoff @ 4515’ while backreaming for connection. Work through 2x. Cleaned up. Last survey at 4510.73' MD / 2716.70' TVD, 74.76° inc, 301.52° azm, 4.89' from plan, 3.19' low, 3.70' right. Losses: 0 bbls Daily / 0 bbls Total. H20 from 6-Mile: 2215 bbls Daily / 3555 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Cuttings/mud/cement to MPU G&I: 2020 bbls Daily / 3082 bbls Total. 12/22/2020 Drill 12-1/4" surface hole f/ 4551' t/ 5217’ (2881' TVD) 666' drilled, 111’/hr AROP. 550 GPM, 2200 PSI, 80 RPM, 10-12K TQ, 5-12K WOB. MW 9.2 in / 9.3 out, vis 116 in / 220 out, 10.2 ECD. Max Gas: 121u. 135K PU / 76K SO / 98K ROT. Continue to hold 75° tangent. Pump 30 bbl hi vis sweep @ 4650', back on time with 10% increase Drill 12-1/4" surface hole f/ 5217' t/ 5884' (3078' TVD) 667' drilled, 111.17'/hr AROP. 550 GPM, 2220 PSI, 80 RPM, 16K TQ, 5-12K WOB. MW 9.3 in / 9.4 out, Vis 140 in / 226 out, 10.2 ECD, max gas 120u. 162K PU / 75K SO / 104K ROT. Pump 30 bbl hi vis sweep @ 5600', on time w/ 20% increase. Maintain 75° tangent. Ugnu Coal 1 at 5728' MD / 3030' TVD. Performed diverter function test after initial test failure at the request of the of AOGCC inspector Jeff Jones. Ream stand then place bit 30' off bottom. Drain stack beneath annular. Close 21-1/4" annular on 5" drill pipe. Knife valve opened in 23 sec and annular closed in 37 sec. Drill 12-1/4" surface hole f/ 5884' t/ 6365' (3190' TVD) 481' drilled, 87.45'/hr AROP. 550 GPM, 2210 PSI, 80 RPM, 18K TQ, 10-15K WOB. MW 9.3 in / 9.4 out, Vis 119 in / 203 out, 10.2 ECD, max gas 88u. 170K PU / 70K SO / 105K ROT. Maintain 75° tangent. After finishing a slide at 6301' picked up to rotate. 6' off bottom, stalled rotary & 650 PSI pressure increase. Established normal pressure & rotation then backed reamed slide interval. No further problems. Drill 12-1/4" surface hole f/ 6365' t/ 6932' (3342' TVD) 567' drilled, 94.5'/hr AROP. 550 GPM, 2450 PSI, 80 RPM, 18K TQ, 10-12K WOB. MW 9.3 in / 9.4 out, Vis 106 in / 217 out, 10.35 ECD, max gas 89u. 185K PU / 70K SO / 107K ROT. Pump 30 bbl hi vis sweep @ 6585', on time w/ 10% increase. Begin pre-treating mud with 0.5% ScreenKleen at 6700'. Last survey at 6605.61' MD / 3258.20' TVD, 72.91° inc, 300.82° azm, 8.41' from plan, 1.26' high and 8.32' left. Losses: 0 bbls Daily / 0 bbls Total. H20 from 6-Mile: 1950 bbls Daily / 5505 bbls Total. Cuttings/mud/cement to MPU G&I: 1492 bbls Daily / 4574 bbls Total. 12/20/2020Spud Date: Well Name: Field: MP J-29 Milne Point Hilcorp Energy Company Composite Report 50-029-23688-00-00API #: 12/23/2020 Drill 12-1/4" surface hole f/ 6932' t/ 7400' (3456' TVD) 468' drilled, 104'/hr AROP. 550 GPM, 2500 PSI, 80 RPM, 20K TQ, 5-8K WOB. MW 9.4 in / 9.5 out, Vis 122 in / 215 out, 10.1 ECD, max gas 309u. 190K PU / 74K SO / 114K ROT. Continue to hold 75° tangent Top Ugnu L-sands logged at 7094' md, 7300' start seeing oil at shakers, 7400' shakers blinding off and running wet Slow pump rate to 360 gpm, 1380 psi, 80 rpm, 20k tq working pipe 7400' to 7370' screening down shakers f/ 100 to 80 mesh screens. Transfer 150 bbls mud from rock washer back across shakers Drill 12-1/4" surface hole f/ 7400' t/ 7788' (3562' TVD) 388' drilled, 86.2'/hr AROP. 400 GPM, 1650 PSI, 80 RPM, 21K TQ, 5-10K WOB. MW in/ out 9.2 ppg, Vis in / out 160, ECD 10 ppg, max gas 277u. 204K PU / 70K SO / 117K ROT. Continue to hold 75° tangent Continue to deal with shakers blinding from heavy oil and sand, reduce pump rate to 400 gpm and ROP to 150 fph, Increase screen kleen to 1.5% and recycle the mud from rock washer back across shakers. Swap from Gyro to MWD surveys, last gyro survey at 7558'. Stop drilling, slow pump rate to 230 gpm, 630 psi, 30 rpm working pipe while W/O vac truck to empty rock washer and offload mud into pit 5, Rack stand back, work pipe f/ 7788' to 7728' Drill 12- 1/4" surface hole f/ 7788' t/ 7836' (3574' TVD) 48' drilled, 32'/hr AROP. 400 GPM, 1650 PSI, 80 RPM, 21K TQ, 5-10K WOB. MW 9.2 in / 9.4 out, Vis 113 in / 130 out, ECD 9.9 ppg, max gas 151u. 205K PU / 75K SO / 115K ROT. Continue to hold 75° tangent Drill 12-1/4" surface hole f/ 7836' t/ 8150' (3657' TVD) 314' drilled, 52.33'/hr AROP. 540 GPM, 2360 PSI, 80 RPM, 25K TQ, 5-10K WOB. MW 9.3 in / 9.4 out, Vis 120 in / 202 out, ECD 10.2 ppg, max gas 123u. 230K PU / 55K SO / 115K ROT. ESP pump tangent from 7558' to 7960'. Began 3.5° build & turn at 7960'. Fault #1 at 7815' w/ 37' DTW throw. Fault #2 at 7970' w/ 136' DTE throw. Logged Ugnu ME sand at 8123'. Drill 12-1/4" surface hole f/ 8150' t/ 8436' (3709' TVD) 286' drilled, 47.67'/hr AROP. 545 GPM, 2260 PSI, 80 RPM, 18K TQ, 5-7K WOB. MW 9.2 in / 9.25 out, Vis 74 in / 127 out, ECD 9.8 ppg, max gas 60u. 190K PU / 70K SO / 107K ROT. Added 0.25% 776 Lube at 8190' to help slide. Toolface control improved, better weight transfer to bit, torque down 7000 ft/lbs, PU down 40K and gained 15K SO. Logged Ugnu MF sand at 8271'. Last survey at 8276.53' MD / 3692.27' TVD, 80.20° inc, 292.64° azm, 15.7' from plan, 4.28' low & 15.11' right. Losses: 0 bbls daily / 0 bbls Total. H20 from 6-Mile: 1800 bbls Daily / 7305 bbls Total. Cuttings/mud/cement to MPU G&I: 1777 bbls Daily / 6351 bbls Total. 12/24/2020 Drill 12-1/4" surface hole f/ 8436' t/ 8845' (3748' TVD) 409' drilled, 68.17'/hr AROP. 550 GPM, 2490 PSI, 80 RPM, 21K TQ, 5K WOB. MW 9.3 in / 9.4 out, Vis 120 in / 230 out, ECD 10.4 ppg, max gas 88u. 200K PU / 60K SO / 105K ROT. Continue build and turn Drill 12-1/4" surface hole f/ 8845' t/ 9120' (3794' TVD) 275' drilled, 78.5'/hr AROP. 550 GPM, 2500 PSI, 80 RPM, 21K TQ, 10K WOB. MW 9.3 in / 9.4 out, Vis 76 in / 145 out, ECD 10.2 ppg, max gas 119u. 210K PU / 65K SO / 120K ROT. Continue build and turn. Add 0.25% LoTorq for 0.5% total lube. Schrader Bluff NA logged at 8983' At 15:20 Lost hi line power after making a connection and getting ready to slide 3' off bttm, start #1 and #3 generators while electrician investigate hi line issue in the SCR room, put generators online. 15:50 circulate 250 gpm, 750 psi, work pipe 10', electrician found several SCR 1 fuses failed causing the hi line breaker to trip out, warmup # 2 generator. DD, MWD and Geo reboot equipment, take survey to check equip, good. Ready to drill on gen power using 2 MP. Drill 12-1/4" surface hole f/ 9120' t/ 9145' (3804' TVD) 25' drilled, 25'/hr AROP. 400 GPM, 1450 PSI, 80 RPM, 25K TQ, 5-10K WOB. MW 9.3 in / 9.4 out, Vis 62 in / 138 out, ECD 9.8 ppg, max gas 150u. 210K PU / 65K SO / 120K ROT. Build and turn landing out in the NB sand While drilling rig electrician investigate SCR 1 issues and high line controller. Drill with one mud pump with only 3 SCRs. Schrader Bluff NB logged at 9134'. Drill 12-1/4" surface hole f/ 9145' to TD at 9325' (3809' TVD) 180' drilled, 60'/hr AROP. 550 GPM, 2320 PSI, 80 RPM, 22K TQ, 5-10K WOB. MW 9.2 in / 9.3 out, Vis 56 in / 95 out, ECD 10.1 ppg , max gas 560u. 185K PU / 68K SO / 115K ROT. Electrician changed pucks & fuses in SCR #1. Both pumps online at 18:15. C/O circuit board in highline cabinet. Back on highline power at 19:30. Last survey at 9227.22' MD / 3806.90' TVD, 88.33° inc, 265.92° azm, 8.98' from plan, 5.32' high, 7.23' right. Obtain final survey then pump 30 bbls high vis sweep w/ nut plug. Nut plug back on time, no increase in cuttings observed. 550 GPM, 2330 PSI, 80 RPM, 23K TQ, reciprocate f/ 9325' t/ 9250'. L/D single to 9311'. Flow check - well static. Downlink gyro into survey mode for trip out of the hole. BROOH f/ 9311' t/ 7180' at 5-10 min/stand, slowing as necessary. 550 GPM, 2160 PSI, 80 RPM, 21K TQ. Max gas 119u. Losses: 0 bbls Daily / 0 bbls Total. H20 from 6-Mile: 1650 bbls Daily / 8955 bbls Total. Cuttings/mud/cement to MPU G&I: 1715 bbls Daily / 8066 bbls Total. 12/25/2020 Continue BROOH f/ 7180' t/ 4955' at 5-10 min/stand, slowing as necessary, 550 GPM, 1830 PSI, 80 RPM, 15K TQ. Max gas 56u. No losses BR at this point BROOH f/ 4955' t/ 3020' at 5-10 min/stand, slowing as necessary, 550 GPM, 1650 PSI, 80 RPM, 10K TQ. Max gas 56u. No losses BR at this point BROOH f/ 3020' t/ 844', 550 GPM, 1455 PSI, 80 RPM, 8K at 5-10 min/stand, slowing as necessary. Pump out f/ 844' t/ 748' w/ 550 GPM, 1400 PSI @ 5'/min for 2 bottoms up, clumps of sand and clay (11.44 ECD). Pump out f/ 748' t/ 658' w/ 450 GPM, 950 PSI @ 10'/min until the cuttings diminished (9.93 ECD). POOH on elevators racking back HWDP from 658' to 185'. Blow down top drive after first stand pulled good. Flow check on last stand of HWDP - static. L/D 3 NMDC & UBHO sub to 97'. Read MWD tools - 100% data recovery. L/D remainder of BHA f/ 97'. Bit graded: 1-3-CT-A-E-2-WT-TD. No losses for trip. Motor stabilizer sleeve had wear from back reaming. Clean & clear right floor. Flush flow line of gravel & clay build-up. Monitor well - static Mobilize casing equip ment to the rig floor. R/U Doyon casing Volant tool and spiders. Losses:0 bbls Daily / 0 bbls Total. H20 from 6-Mile: 1580 bbls Daily / 10535 bbls Total. Cuttings/mud/cement to MPU G&I: 1135 bbls Daily / 9201 bbls Total. 12/26/2020 Continue to R/U 9 5/8'' handling equipment, Volante, bail extensions, single joint elevators, FOSV and XO. Monitor well, .5 bph static loss rate. PJSM, M/U 9-5/8" shoe track: round nose float shoe, Baker lock joint, install top hat after M/U FC joint. Ensure proper float operation - good. M/U baffle adapter & joint #4 to 161' Torque all connections to 21,000 ft/lbs w/ Volant tool, Two 9-5/8"" x 12-1/4"" centralizer & 4 stop rings on shoe joint, 1 free floating centralizer on Baker-Loc joint, 1 centrailizer w/ 2 stop rings on the float collar and baffle adapter joints. Run 9-5/8" 40# L-80 TXP-BTC casing f/ 161' t/ 1192' with 10k set down . Torque to 21,000 ft/lbs with the Volant tool. Install 9-5/8" x 12-1/4" bow spring centralizers on jts #5-25 then every other joint to jt 51. Fill casing on the fly & top off every 10 joints. Work thru tight spot f/ 1192', stage to 2-3 bpm, 70-90 psi, 10 rpm, wash and ream to 1210', start seeing a significant amount of sand at the shakers, let cleanup, continue to wash and ream setting up to 5k making a few inches ea. set down, thru tight spot at 1225', thru slide area. 30 bbl losses Continue to Run casing f/ 1225' t/ 2865'. Torque to 21,000 ft/lbs with the Volant tool. Install 9-5/8" x 12-1/4" bow spring centralizer on ea. jt to #25 then every other jt to jt 51, then every 3 jts, wash ea. jt down a 1-2 BPM, 150-200 psi until past the BOPF @ 2161' Then fill casing on the fly & top off every 10 joints. 81 bbl total losses at this point. PU 170K, SO 75K Circulate BU, Stage pumps to 5 bpm, 160 psi, 5 rpm, 14k torque, working pipe slow. 175K PU / 75K SO. No losses. Continue to run casing f/ 2865' t/ 6072' (joint #150). Torque to 21,000 ft/lbs with the Volant tool. Install 9-5/8" x 12-1/4" bow spring centralizer every 3rd joint. Fill casing on the fly and top off every 10 joints. 95 bbls losses to this point. Circulate BU, stage up pumps to 5.5 BPM, 130 PSI, 5 RPM, 20K TQ (only able to rotate on the down stroke). Reciprocate pipe 40'. 260K PU / 80K SO. 11.5 bbls lost while circulating. Continue to run casing f/ 6072' t/ 7329'. Torque to 21,000 ft/lbs with the Volant tool. Fill casing on the fly and top off every 10 joints. 113.5 bbls lost running casing including circulating losses. Install 9-5/8" x 12-1/4" bow spring centralizer every 3rd joint to #165. Every joint from #166 to 175 then every 3rd joint. ES cementer ( w/ 1 centralizer & 1 stop ring on each pup joint above & below) placed between joints #170 & 171. 47# casing began on #171. Losses: 85 bbls daily (midnight) / 85 bbls Total. H20 from 6-Mile: 425 bbls Daily / 10960 bbls Total. H2O from G&I Source Water: 300 bbls Daily / 300 bbls Total. Cuttings/mud/cement to MPU G&I: 399 bbls Daily / 9600 bbls Total. 12/27/2020 Continue to run 9 5/8'' 47# casing casing f/ 7239' t/ 8320'. Torque to 23,900 ft/lbs with the Volant tool. Fill casing on the fly and top off every 10 joints. Install 9-5/8" x 12-1/4" bow spring centralizer every 3rd joint. 119 bbls lost running casing, includes circulating Submit 24 hr BOP test notification to AOGCC @ 06:00 Work thru tight spot f/ 8320' to 8330', 10k set down at 8320', pump 2-3 bpm 330-380 psi, rot 2-3 rpm, rotation only while S/O, P/U and S/O working to 8330' in 1 hr tag hard, Continue to work pipe S/O off fast while rot, finally working to 8335', regain 50k S/O. PU 350K, SO 50K. 4 bbl losses Continue to run 9 5/8'' 47# casing casing f/ 8335' t/ 9170' at jt #56, tagging, 134 bbl. losses at this point Establish circulation at 2-3 bpm, 360 psi, able to rotate down only 2-3 rpm, 18k tq, work pipe pulling up to 400k and S/O fast beating pipe down slowly to 9225' at 5' in on joint #58 of the 47#. Seeing breakover @ 375k, pulling up to 400k. Stack riser pushed down from casing collar dislodging riser from flow box, shut down, drain stack, pull riser back into place, re-set lock ring, then able to circulate. 2 gallons drlg mud spilled outside containment onto the snow and 2 bbls into cellar box in containment. Reported release to ACS. Continue to wash and ream down with 47# casing, f/ 9225' to 9301', verify pipe count, M/U 20' pup jt, wash and ream to depth @ 9318' 229 total jts ran, 170 ea. 40# and 59 each 47#. 106 9-5/8" x 12-1/4" bow spring centralizers ran and 12 stop rings. 137 bbls total losses running casing and circulating. Cementers spot and R/U Circulate and condition mud prior to cement job, stage to 5 BPM, 210 psi ICP. Unable to rotate and work pipe up, pulling 400k, S/O 50k, FCP 150 psi, max gas 246u. MW 9.3 in /9.4 out, vis 47in / 60 out. YP 20, No losses circulating Break out volante, re-dope cup & M/U, BD top drive. R/U cement hose, close upper and lower IBOP, continue to circulate 5 bpm. Hold PJSM for 1st stage. Continue to circulate, ready 50 bbl desco/SAPP treatment, HES troubleshoot compressor issues. Pressure up pods, Pump desco/SAPP pill 5 bpm, 230 psi. Perform 1st stage cement job. HES fill lines with 5 bbls fresh water. PT lines to 1000 PSI low / 4000 PSI high. Pump 60 bbls 10 ppg Tuned Spacer w/ red dye & 5# Pol-E-Flake in 1st 10 bbls, 3.5 BPM, 240 PSI. D.rop bypass plug Mix & pump 420 bbls 12.0 ppg Lead Cement (1015 sks @ 2.347 ft^3/sk yield) at 5 BPM, 330 PSI. Mix & pump 82 bbls 15.8 ppg Tail Cement (400 sks @ 1.167 ft^3/sk yield) at 1.5 BPM, 160 PSI. Problems transferring tail cement from silo to pump truck, had to mix & pump at reduced rate. Drop shutoff plug. Pump 20 bbls 8.34 ppg fresh water @ 4.5 BPM, 220 PSI. No losses cementing. Displace w/ 9.4 ppg spud mud w/ rig @ 5 BPM, 149 PSI ICP, 460 PSI FCP for 484.5 bbls. Pump 80 bbls of 9.4 ppg Tuned Spacer w/ HES @ 4.5 BPM, 650 PSI. Continue to displace w/ 9.4 ppg spud mud w/ rig @ 5 BPM, 650 PSI ICP / 860 FCP. Slow to 3 BPM for last 10 bbls, 730 PSI. Observed Pol-E-Flake back at 613.08 bbls in displacement. Bumped plug at 5882 stks (694.08 bbls total displacement, 3.03 bbls over calculated) with 730 PSI. CIP @ 00:46. Pressure up to 1250 PSI, hold for 5 min., bleed off, check floats - holding. Pressure up, ES cementer shifted open at 2610 PSI. No losses during displacement. Circulate through ES cementer at 2410'. 5 BPM, 1170 PSI ICP. Observe spacer back at 1200 stks and cement back at 1600 stks to 1940 stks (34.34 bbls returned). Continued to circulate out spacer / mud interface at 3 BPM, 340 PSI to 5 BPM, 490 PSI. Continued to get clabbered mud to 3.7 bottoms up (5984 stks). Thick mud plugged off riser and flow line. Shut down to drain stack to the cellar. No losses circulating. Milne Operations requested rig to go off highline due excessive load to Tract 14 feeder. Take rig off highline and attempt to put on rig generators. #1 SCR blew the fuses. Contact rig electrician. Bring rig on generator power with SCR #2, 3 & 4. Jet and flush flow line. Circulate out clabbered mud which filled stack and had to dump the stack to the cellar one more time. Stage up pumps from 2 BPM, 150 PSI to 5 BPM, 460 PSI. Take returns back to the pits at 7179 stks (4.5 bottoms up). 580 bbls of mud dumped. Stage up to 6 BPM, 540 PSI. Continue to circulate and condition mud for 2nd stage cement job. No losses circulating. Sim-ops: dispose of mud returns and haul heated water for 2nd stage cement job. Losses: 130 bbls Daily (midnight) / 215 bbls Total. H20 from 6-Mile: 450 bbls Daily / 11410 bbls Total. H2O from G&I Source Water: 450 bbls Daily / 750 bbls Total. Cuttings/mud/cement to MPU G&I: 575 bbls Daily / 10175 bbls Total. 12/28/2020 Shut down pumps. Drain diverter stack. Disconnect knife valve accumulator lines. Flush stack with black water and fun ction annular to clean cement residue. Re- connect the knife valve accumulator lines. Ready pits for 2nd stage, Build black water pill in pill pit. Continue to circulate thru ESC at 2406' pumping 5 bpm while WOC, 600 psi, continue to see excessive thick mud returns, Slow pump as needed to not over run riser, dump as needed then treat returns, Pump numerous BU dealing with thick mud. FCP 350 psi. SCR 1 blower motor repaired, replace failed wire Crew change, Breakout volante, re-dope and M/U, blow air back to unit to verify clear. PJSM for 2nd stage. Perform 2nd stage cement job. Flood lines w/ 5 bbls water. Mix & pump 60 bbls of of 10.0 ppg Tuned Spacer 4.5 BPM, 400 PSI. Mix & pump 472 bbls of 10.7 ppg ArcticCem Lead Cement 2.944 ft^3/sk yield, 730 sks, 4.7 BPM, 620 PSI. Spacer returns back @ 220 bbls, dump to rock. Good cmt back @ 382 bbls. Mix and pump 56 bbls 15.8 ppg Premium G Tail Cement 1.169 ft^3/sk yield, 270 sks, 3.5 BPM, 500 PSI. Drop closing plug. HES pump 20 bbls water 5 BPM, 280 PSI. Displace w/ 9 ppg spud mud @ 5 BPM, 440 psi ICP / 850 psi FCP. Slow to 3 BPM, 700 PSI for last 10 bbls. Bump plug at 1548 stks (1.5 stks under calculated). Pressure up, ESC shifted close at 1900 PSI. CIP at 15:55. 262 bbls of cement to surface and 100 bbls of interface, 60 bbl spacer returned to surface. Full returns throughout 2nd stage Drain cement from the diverter stack to the cellar and flush with black water. Function annular 4 times. Vacuum out mud from landing joint. Pull both mouseholes. Remove and clean knife valve. Hoist diverter stack. Install 9-5/8" casing slips as per wellhead rep. Set with 100K on slips. Doyon rig welder cut 9-5/8" casing and L/D 20' pup and cut joint - 16.76' cut joint length. Set stack back down. N/D surface riser and diverter stack. Sim-ops: Finish N/D diverter line, R/D casing equipment, clear and clean rig floor and clean the mud pits. Doyon rig welder performed final cut of casing. Mobilize casing head, casing and tubing spools to the cellar. No access for loader behind rig and no matting board behind rig to slide equipment on. Remove diverter tee from the cellar. Sim-ops: continue to clean the mud pits. Install FMC SlipLoc head & test seals to 500 PSI low for 10 min & 3800 PSI high for 10 min - good test. Install FMC casing & tubing spools. N/U BOP stack & tighten all BOP flange bolts w/ Sweeny wrench. Install kill line, accumulator hoses, turnbuckles & riser. Sim-ops: continue to clean mud pits. Change upper rams from 7-5/8" solid to 2-7/8" x 5" VBR. Sim-ops: continue to clean the mud pits. and change top drive saver sub. Roads & pads moved the rock washer 6" away from the rig for better flow over the shaker from the conveyor. Losses: 38 bbls Daily / 253 bbls Total. H20 from 6-Mile: 825 bbls Daily / 12235 bbls Total. H2O from G&I Source Water: 450 bbls Daily / 1200 bbls Total. Cuttings/mud/cement to MPU G&I: 1615 bbls Daily / 11790 bbls Total. 12/29/2020 Rig up BOP test equipment. Install test plug and 3.5" test joint. R/U manifold and lines. Fill stack with fresh water and purge system of air. Test BOPs as per PTD, AOGCC & Hilcorp requirements. All tests performed with fresh water against a test plug. 250 PSI low / 3000 PSI high for all tests, held for 5 min & charted. AOGCC inspector Matthew Herrera waived right to witness testing at 05:07 1) Annular on 3-1/2" test joint, choke valves 1, 12, 13, 14, kill Demco 2) Upper 2-7/8" x 5" VBR on 3-1/2" test joint, choke valves 9, 11, kill HCR, 5" dart valve. 3) Lower 2-7/8" x 5" VBR on 3-1/2" test joint, 5" FOSV #1. 4) Upper 2-7/8" x 5" VBR on 5" test joint, choke valves 5, 8, 10, 5" FOSV #2 5) Upper 2-7/8" x 5" VBR on 5" test joint, choke valves 4, 6, 7, 3-1/2" dart valve. 6) Choke valve 2 & 3-1/2" FOSV. 7) HCR Choke, upper IBOP. 8) Manual Choke, lower IBOP. 9) Lower 2-7/8" x 5" VBR on 5" test joint. 10) Choke valve 3, blind rams. 11) Manual choke A. 12) Manual choke B Accumulator test: 3000 PSI initial, 1600 PSI after closure, 200 PSI recovery in 37 sec, full recovery in 186 sec. 6 nitrogen bottle average 2091 PSI. Rig down test equipment. L/D test joint and test plug. Set 9-1/8" wear bushing. Rig on highline power at 13:55 Service rig. Measure for new standpipe. Perform derrick inspection. Mobilize float subs & bit to the rig floor. PJSM for BHA. M/U used 8-1/2" XR+ mill tooth bit, 6-3/4" mud motor w/ 1.5° AKO & float sub to 35'. TIH w/ 5" HWDP & 5" drill pipe f/ 35' t/ 2397'. Tag cement w/ 5K. 105K PU / 85K SO / 105K ROT Drill cement f/ 2397' t/ 2407', drill ES cementer on depth f/ 2407' t/ 2413', 450 GPM, 880 PSI, 40 RPM, 6-8K TQ, 8-10K WOB. Ream 3x then work through w/o pumps or rotary w/ no issues. 105K PU / 85K SO / 105K ROT TIH w/ 5" drill pipe f/ 2413' t/ 5815'. Fill pipe every 20 stands. Lost slack-off weight, unable to trip in the hole. 170K PUW. Wash and ream f/ 5815' t/ 9185' just above baffle adapter at 9196', 210 GPM, 700 PSI, 40 RPM, 23K TQ. 275K PU / 100K SO. Thick, heavy (9.3 ppg) mud returns, treat returns with Desco, SAPP, Citric Acid & water. Circulate a bottoms up, 400 GPM, 1100 PSI, 40 RPM, 23K TQ, 275K PU / 115K ROT. Unable to slack off without rotation. Rotary stalled while picking up at 25K TQ. Reciprocate 90' f/ 9185' t/ 9095', rotating on the downstroke. 9.2 ppg MW in / out. L/D single to 9157'. Blow down top drive & R/U test equipment. Close upper pipe rams on 5" drill pipe & pump down kill line and drill pipe. Pressure test casing to 2500 PSI for 30 min. - good test. Pumped 6 bbls / bled off 6 bbls. Blow down & R/D test equipment. PJSM to slip on 1600' of new drilling line. Install FOSV & pup joint. Set string in slips & support blocks with the super tugger. Slip 800' of line onto the drum. 12/30/2020 Slip and Cut last 800' of 1600' total drilling line. Inspect Deadman, Service Top Drive, Function Crown-O-Matic, Calibrate block height. Wash down f/ 9157' and tag BA w/ 10K at 9196', drill 9-5/8" shoe track f/ 9196' to 9318', 500 GPM, 1730 PSI, 40 RPM, 23K TQ, 5K WOB. Drilled shoe track on depth, Baffle Adapter f/ 9196' t/ 9198', float collar f/ 9236' t/ 9238' & shoe f/ 9316' t/ 9318'. Ream each 2x times. 275K PU / no SO / 115K ROT. Drill 20' of new hole f/ 9325' t/ 9345', 510 GPM, 1575 PSI, 40 RPM, 23K TQ, 5K WOB, 275K PU / no SO / 115K ROT. Pump 8.4 ppg high vis sweep @ 9344’, 600 GPM, 2105 PSI, 40 RPM, 22K TQ on time w/ 100% increase. Preform good FIT to 12.0 ppg EMW with 9.2 ppg MW to 553 PSI @ 3804' TVD / 9318' MD. Perform flow check - static. Pump 10.2ppg dry job PUW=275K SOW=40K. Rig down test equip. Blow down Top Drive, Choke and Kill lines POOH racking pipe back F/9325' T/539'. L/D 5'' HWDP F/539' T/34'. L/D clean out BHA. Bit graded 1-1-WT-A-E-2-NO-BHA. 8 bbls lost on trip out of the hole. Clean and clear rig floor, replace master rotary bushings with split rotary bushings. PJSM for MU BHA #3. M/U 8.5'' BHA #3 with a 8.5'' SK616M-J1D bit, Geo Pilot, ADR, DGR, PWD, DM, TM & stabilizer T/ 91' Initialize MWD tools, 1 hr troubleshoot MWD communications. Initialize tools twice with errors, read tool, initialized good on 3rd attempt. 2 BPH static losses. Finish P/U BHA #3 with recorded Muscat resitivity tool, stabilizer, 3x NMDC & 2x float subs t/ 226'. TIH to 2223'. Shallow pulse test MWD 400 GPM, 540 PSI. Break-in Geo-Pilot seals, 5-50 RPM, 5- 6K TQ. 105K PU / 80K SO Continue TIH f/ 2223 t/ 7551', fill pipe every 20 stands. Lost slack off weight. 250K PU / no SO. 12/31/2020 Wash and ream f/ 7455' t/ 9265', 210 GPM, 290 PSI, 40 RPM, 22K TQ. 270K PU / 135K ROT. Blow down Top Drive, Drain Stack, install MPD bearing per Beyond Teck SOP Wash and ream f/ 9265' t/ 9345', 300 GPM, 710 PSI, 40 RPM, 23K TQ. 274K PU / 117K ROT. Displace well with 8.8 ppg Flo-pro NT W/ 0.5% lube 280 GPM, 850 PSI, 40 RPM, 16K TQ. 175K PU , 75K SO, 115K ROT. Monitor pressure build up via MPD. Sim-ops: Blow down Top Drive and MPD lines. Clean out possum belly and shaker beds of spud mud. Clean and clear rig floor Drill 8-1/2" production hole f/ 9345' t/ 9830' MD / 3754' TVD (485' drilled) 121.25'/hr AROP. 500 GPM, 1710 PSI, 120 RPM, 11K TQ, 7-15K WOB. MW in 8.8 / out 8.8, vis in 41 / out 55, ECD 10.72, max gas 650u. 140K PU / 75K SO / 103K ROT. MPD hold 150psi on connections Drill 8-1/2" production hole f/ 9830' t/ 10500' MD / 3756' TVD (670' drilled) 111.67/hr AROP. 550 GPM, 1980 PSI, 120 RPM, 15K TQ, 5- 7K WOB. MW in 8.8 / out 8.8, vis in 47 / out 49, ECD 10.97, max gas 718u. 150K PU / 68K SO / 103K ROT. Pumped high vis sweep @ 10,025'MD on time 100% Drilled out the top of NB sand @ 9,696' reentered NB sand @ 9,887' (191' Drilled above NB sand). MPD trap 200psi on connections build to 240psi Drill 8-1/2" production hole f/ 10500' t/ 11263' MD /3745' TVD (763' drilled) 127.17/hr AROP. 550 GPM, 2140 PSI, 120 RPM, 13K TQ, 5-13K WOB. MW in 8.7 / out 8.7+, vis in 44 / out 48, ECD 10.92, max gas 717u. 147K PU / 70K SO / 103K ROT. Pumped high vis sweep @ 11073'MD on time 100% MPD trap 250psi on connections build to 275psi. Last survey @ 11192.98' MD / 3745.23' TVD, 91.05° inc, 271.45° azm, 14.13' from plan, 12.31' low, 6.94' left. Drilled 16 concretions for a total thickness of 32' (1.7% of the lateral). Losses : 60bbls Daily / 60bbls Interval . H20 from 6-Mile: 590 bbls Daily / 13,490 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 1200 bbls Total. Cuttings/mud/cement to MPU G&I: 764 bbls Daily / 12,233 bbls Total. 1/1/2021 Drill 8-1/2" production hole f/ 11263' t/ 11335' MD ' 75' drilled. 550 GPM, 2140 PSI, 120 RPM, 13K TQ, 5-13K WOB. MW in 8.7 / out 8.7+, vis in 44 / out 48, ECD 10.8. 147K PU / 70K SO / 103K ROT. Ream out concretion 16° build DL. F/ 11335' T/ 11300'. Ream through at 0 deflection twice and then twice with 180 dn. Dropped DL to 3 deg drop. Drill 8-1/2" production hole F/ 11335' T/ 11738' MD ( 3730TVD) 403 ' drilled) @ 115 FPH average. 500 GPM, 1820 PSI, 120 RPM, 10.7K TQ, 5-15K WOB. MW in 8.7 / out 8.7, vis in 44 / out 48, ECD 10.6. 152K PU / 67K SO / 104K ROT. Started losing mud over shakers @ 12000'. Hold 11.0 PPG ECD while drilling and on connections to help oil in cuttings. Slow flow rate as needed down to 430 GPM. Add new 290 bbls mud to system. Start adding screen clean up to 2%. Change to clean screens. All this didn't help with losing mud. Drill 8-1/2" production hole F/ 11738' T/ 12407' MD ( 3708 TVD) 669' drilled) @ 111.5 FPH average. 500 GPM, 1930 PSI, 120 RPM, 11K TQ, 12K WOB. MW in 8.7 / out 8.7, vis in 44 / out 48, ECD 10.6. 146K PU / 63K SO / 104K ROT. Pumped High vis sweep @ 12,030' on time 50% increase Drill 8-1/2" production hole F/12407' T/ 12880' MD (3672TVD) 473' drilled) @ 79 FPH average. 515GPM, 2070 PSI, 120 RPM, 11K TQ, 12K WOB. MW in 8.8 / out 8.8, vis in 43 / out 46, ECD 11.11. 150K PU / 56K SO / 101K ROT. Pumped High vis sweep @ 13,080' not seen at shakers Crossed fault 3 @ 12,501(for est. 30' DTE trough) into NC base building @ 95.5° to reacquire NB sand. Crossed NC sand F/12,643' T/12,694'. Reentered NB sand @ 12,794'. MPD maintain 11ppg ECD while Drilling and holding 380 psi on connection for an 11ppg EMW no psi build up on connection Drill 8-1/2" production hole F/12880' T/ 13083' MD (3664TVD) 203' drilled) @ 135.33FPH average. 500GPM, 1991 PSI, 120 RPM, 13K TQ, 12K WOB. MW in 8.8 / out 8.8, vis in 43 / out 45, ECD 11.1. 150K PU / 55K SO / 101K ROT Drill 8-1/2" production hole F/ 13,083' T/ 13,118' (3664' TVD) 35' drilled, 5.83'/hr AROP. Drilled a concretion F/ 13,083' T/ 13,085'- vary drilling parameters from 425-525gpm, 50-120RPM, WOB 2-35k and work stand 20'. Pumped high vis sweep @ 13,085'. ROP increased before sweep made it to the bit. Last survey @ 12999.95' MD / 3666.54 TVD, 91.23° inc, 267.33° AZM, 5.87' from plan, 1.33' low, 5.72' right. Drilled 33 concretions for a total thickness of 76' (2.0% of the lateral). MPD maintain 11.0 ppg ECD while drilling and 11.0 ppg EWM w/ 380 PSI on connections. Losses to the well 39bbls Daily / 99bbls Interval Total. H20 from 6-Mile: 1,190 bbls Daily / 14,680 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 1200 bbls Total. Cuttings/mud/cement to MPU G&I: 1,055 bbls Daily / 13,288 bbls Total. 1/2/2021 Drill 8-1/2" production hole F/13118' T/ 13570' MD (3658TVD) 452' drilled @ 75.33 FPH average. 535GPM, 2450 PSI, 120 RPM, 12K TQ, 12K WOB. MW in 8.8 / out 8.8, vis in 43 / out 46, ECD 11.15, Max gas 376u. 145K PU / 54K SO / 101K ROT Pumped high vis sweep @ 13165' MD on time and 15% increase. Drilled out of the top of NB sand f/13336' t/13404'. Encountered Fault #4 at 13495' w/ 12' DTE throw f/ NB sand t/ NB clay. Drill 8-1/2" production hole F/13570' T/ 14095' MD (3647TVD) 525'drilled @ 87.5 FPH average. 500GPM, 2150 PSI, 120 RPM, 13K TQ, 12K WOB. MW in 8.8 / out 8.8, vis in 43 / out 43, ECD 11.44, Max gas 371u. 151K PU / no SO / 101K ROT. Lost SO @ 14023' Drill 8-1/2" production hole F/14095' T/ 14594' MD (3612TVD) 499'drilled @ 83.17 FPH average. 480GPM, 2160 PSI, 120 RPM, 14K TQ, 16K WOB. MW in 8.8 / out 8.8, vis in 43 / out 43, ECD 11.46, Max gas 344u. 155K PU / no SO / 95K ROT Pumped high vis sweep @ 14020' 400stks late and 10% @ shakers. Encountered Fault #5 at 14260' w/ 26' DTE throw f/ NC sand t/ NC clay. Drill 8-1/2" production hole F/14594' T/ 15165' MD (3584TVD) 571'drilled @ 95.17 FPH average. 490GPM, 2240 PSI, 120 RPM, 14K TQ, 8K WOB. MW in 8.9+ / out 9, vis in 42 / out 48, ECD 11.81, Max gas 529u. 160K PU / no SO / 96K ROT 14650' Dump and Dilute with 290bbls new mud due to higher ECD of 11.7ppg & MBT of 6.5ppb. Drilled NC sand f/14618' t/14790'. Encountered Fault #6 at 14825' W/ 5-10' DTW throw f/NB clay t/ NB clay. Currently in NC sand. Drilled 57 concretions for a total thickness of 182' (3.1% of the lateral). Last survey 15,001.76' MD / 3,601.88' TVD , 93.46° INC, 260.43°AZM, 23.75' from plan , 0.49' High, 23.7' Right. MPD wide open chokes while drilling, maintain 11ppg EMW with 350 psi Daily losses 10bbls / Interval 109bbls Total. H20 from 6-Mile: 1,295 bbls Daily / 15,975 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 1200 bbls Total. Cuttings/mud/cement to MPU G&I: 860 bbls Daily / 14,148 bbls Total. 1/3/2021 Drill 8-1/2" production hole F/15165' T/ 15500' MD (3587TVD) 335' drilled @ 74.44 FPH average. 440 GPM, 2060 PSI, 120 RPM, 17K TQ, 11K WOB. MW in 8.9+ / out 9, vis in 47 / out 52, ECD 11.81, Max gas 249u. 158K PU / no SO / 94K ROT 15,090'-15,313'NA-Clay: Silt and clay. 15,313'-15,508'NA-Sand: About 12' thick. BROOH while Geologist studied the drilling survey data to either pull back and side track or continue drilling ahead. BROOH F/15500' T/ 15292', 500 GPM, 2060 PSI, 105 RPM, 13K TQ. Geologist made the call to go back to drilling ahead. Washed back to bottom with 465 GPM, 2045 PSI, 2' of fill observed. Drill 8- 1/2" production hole F/15500' T/ 15927' MD (3576'TVD) 427' drilled @ 85.4 FPH average. 430 GPM, 2060 PSI, 120 RPM, 18K TQ, 13K WOB. MW in 8.9 / out 8.9+, vis in 47 / out 49, ECD 11.83, Max gas 102u. 165K PU / no SO / 94K ROT Drop angle at 4 Deg per 100 from 95 deg to 84 deg. Currently at 87.7 deg. ECDs running 11.8 with full open choke. 15,508'-15,773' Ugnu MF: Just drilled above the NA-Sand for a few feet.15,773'-15,898' NA-Sand Drill 8-1/2" production hole F/15927' T/ 16403' MD (3584'TVD) 476' drilled @ 79.33 FPH average. 406 GPM, 1820 PSI, 120 RPM, 18K TQ, 8K WOB. MW in 8.9 / out 8.9+, vis in 47 / out 50, ECD 11.92, Max gas 46u. 170K PU / no SO / 100K ROT Dump and dilute 580bbls @ 16230' while drilling ahead MBT was 7.5 ppb before dilution and 6.5 ppb after. 15,898'-16,160' NA-Clay. 16,160' reentered NB-sand Drill 8-1/2" production hole F/16403' T/ 17025' MD (3584'TVD) 622' drilled @ 103.67 FPH average. 460 GPM, 2150 PSI, 120 RPM, 20K TQ, 8-10K WOB. MW in 8.9+ / out 8.9+, vis in 43 / out 47, ECD 11.79, Max gas 403u. 176K PU / no SO / 100K ROT Last survey @ 16904.95' MD / 3586.31' TVD, 90.92° inc, 271.52° azm, 25.84' from plan, 24.64' low & 7.78'right. 4 faults were crossed in this lateral so far. We have drilled 85 concretions for a total thickness of 302' (4% of the lateral). MPD chokes wide open while drilling and reduce flow rate to maintain less than 12.0 ppg ECD. Trap 350 PSI for 11.0 ppg EMW on connections. Losses 0bbls Daily / 109bbls Interval Total. H20 from 6-Mile: 880 bbls Daily / 16,855 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 1200 bbls Total. Cuttings/mud/cement to MPU G&I: 1,925 bbls Daily / 16,073 bbls Total. 1/4/2021 Drill 8-1/2" production hole F/17025' T/ 17641' MD (3573'TVD) 616' drilled @ 102.67 FPH average. 500 GPM, 2410 PSI, 120 RPM, 20K TQ, 11K WOB. MW in 8.9 / out 8.9+, vis in 43 / out 47, ECD 11.69, Max gas 434u. 180K PU / no SO / 95K ROT Drill 8-1/2" production hole F/17641' T/ 17921' MD (3567'TVD) 280' drilled @ 140' FPH average. 525 GPM, 2470 PSI, 120 RPM, 21K TQ, 5-14K WOB. MW in 8.8+ / out 8.9, vis in 44 / out 48, ECD 12.05, Max gas 497u. 190K PU / no SO / 96K ROT 4 faults were crossed & 98 concretions were drilled in the lateral, for a total thickness of 331' (3.8%). Last survey @ 17831.16' MD / 3567.94' TVD, 91.48° inc, 269.82° azm, 34.76' from plan, 21.01' low and 27.69' right. Geo-Pilot tool failure, no RPM data from tool & corrupted ABI data, unable to deflect tool. Reciprocate and work pipe F/17921' T/17826' while troubleshooting MWD/BHA tools. 500 GPM, 2540 PSI, 120 RPM, 21K TQ, ECD 11.98. Pumped high vis sweep @ 17921' MD 0% increase and 1700 stks late BROOH F/17921' MD T/ 17642' pumping 1X BUS every stand, for a total of 4X BUS. 555 GPM, 2830 PSI, 120 RPM, 21K TQ, Max gas 58u. 175K PU / no SO / 100K ROT. Decision was made to call the well TD'd due to tool failure. Washed F/17,642' T/17,921', 300 GPM, 1170 PSI, 40 RPM, 15K TQ. Performed EMW test for kill weight fluid at the shoe. Trapped 100 psi with MPD and let it build for 5 mins four times. Build to 210 PSI each time with 8.9 ppg MW = 10.0 ppg EMW Pumped tandem sweeps 45 bbls 8.6 ppg low vis brine followed by 30 bbl high vis mud, 550 GPM, 2870 PSI, 100 RPM, 17K TQ, 175K PU / 100 ROT. Back 1750 stks late w/ 10% increase, 88u of gas. Rack back stand, continue to circulate while preparing for displacement racking back a stand each bottoms up. Began seeing 5 BPH losses when low vis sweep exited the bit. Ream back to bottom f/ 17730' t/ 17921', 300 GPM, 1250 PSI, 50 RPM, 17K TQ. PJSM. Displace to lubricated brine. Pump 30 bbl high vis spacer, 50 bbls seawater, 20 bbls SAPP pill #1, 50 bbls seawater, 20 bbls SAPP pill #2, 50 bbls seawater, 20 bbls SAPP pill #3 then chase with 350 bbls seawater. Pump 30 bbls high vis spacer then pump 250 b bls of 8.45 ppg 3% lubricated brine (1.5% lube 776 & 1.5% LoTorq). 7 BPM, 1025 PSI, 100 RPM, 24K TQ. MPD initially held 75 PSI to maintain 11.0 ppg ECD, currently holding 145 PSI. Displacement continues into the next report period. Losses: 8 bbls Daily / 117 bbls Total for Interval. H20 from 6-Mile: 0 bbls Daily / 15,475 bbls Total. H2O from L- Pad Lake: 1,035 bbls / 2,415 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 1200 bbls Total. Cuttings/mud/cement to MPU G&I: 1,402 bbls Daily / 17,475 bbls Total. 1/5/2021 Continued well displacement to vis lube brine w/ 28bbls of spacer followed by 1515bbls of 8.45 ppg viscosified lubricated 2% KCL/NaCL brine. 300 GPM, 1150 PSI, 60 RPM, 20-25k TQ, Reciprocated 90' slowed down RPM due to stick slip. Spacer and SAPP train was 2000 stks late, vis brine 212 bbls late Cont'd taking returns to the Rockwasher for 150 bbls until the vis lube brine cleaned up. Started taking returns to the pits cont'd circulate due to shakers over loading w/sand. 425- 500 GPM, 1460-1610 PSI, 60-100 RPM, 20-28k TQ reciprocating pipe 94'. Obtained SPR's BROOH F/ 17921' T/17450' at 5-10 mins a stand, L/D DP via 90' mousehole, MPD full open choke with ECD 10.6-10.7 while BROOH & Hold 270 - 300psi on connection. 500 GPM, 1770 PSI, 100 RPM, 24k TQ, 184K PU, no SO, 101K ROT. Losses @ 5-10 BPH BROOH F/ 17450' T/14882' at 5-10 mins a stand, L/D DP via 90'mousehole, MPD full open choke with ECD 10.6-10.7 while BROOH & Hold 270 - 300psi on connection. 500 GPM, 1545 PSI, 100 RPM, 24k TQ, 160K PU, no SO, 116K ROT. Losses @ 5-10 BPH BROOH F/ 14882' T/12216' at 5-10 mins a stand, L/D DP via 90'mousehole, MPD full open choke with ECD 10.6-10.7 while BROOH & Hold 270 - 300psi on connection. 510 GPM, 1660PSI, 100 RPM, 24k TQ, Max gas 843u. 170K PU, no SO, 115K ROT. Pull17 min/std f/12600' T/12513' to clean hole. Losses @ 2-7 BPH BROOH F/ 12216' T/9265' at 5-10 mins a stand, L/D DP via 90' mousehole, MPD full open choke with ECD 10.6-10.7 while BROOH & Hold 260 - 275psi on connection. 510 GPM, 1660PSI, 100 RPM, 24k TQ, Max gas 213u. 135K PU, 75K SO, 106K ROT. Losses @ 2-6 BPH Losses: 155 bbls Daily / 272 bbls Total for Interval. H20 from 6- Mile: 0 bbls Daily / 15,475 bbls Total. H2O from L-Pad Lake: 450 bbls / 2,865 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 1200 bbls Total. Cuttings/mud/cement to MPU G&I: 2,766 bbls Daily / 20,241 bbls Total. 1/6/2021 Pump 35bbls high vis sweep and circulate casing clean. No increase at the shakers from sweep. 550 GPM, 1840 PSI, 80 RPM, 8K TQ, 140K PU, 90K SO 106K ROT Pump 30bbls spacer pill, displace the casing from 8.5ppg vis lube brine to 10.2ppg vis NaCl/NaBr brine w/4% lube. 300 GPM, 680 PSI, 80 RPM, 5K TQ, reciprocated pipe 90' BD TD. Monitor well for flow. Initial flow back 2bph slowing to .3bph in 20mins and static after 1hr. Remove MPD bearing and install trip nipple. Slip and cut 85' Drilling line and rig service. Monitoring well at trip tank, static loss rate @ 2bph Pump Dry Job and Blow down TD. POOH laying down 5'' DP to pipe shed f/9263' t/4032'. Continue POOH racking remaining 39 stands in Derrick. Drop 2.47" drift f/ std #14. 0.5-2 BPH Losses. Flow check before pulling BHA, slight losses. L/D jar stand, float subs, NMFCs, IBS and Muscat Collar to 97'. Recover drift on wire. Download MWD data L/D remaining BHA. Bit grade= 3-2-BT-C-X-I-CT-DTF. 29 bbl losses TOOH f/ shoe 5 mounting head bolts were discovered on top of the MWD pulsur poppet. Inspection of the Geo-Pilot revealed significant wear to the complete reference stabilizer assembly including the cutters, extended reach arms, and mounting block assemblies, indicative of sustained housing roll. The ILS on the ADR-DGR-PWD was DBR, all blades significantly undercut. The 7 7/8" NM IBS was undercut, and the 8 3/8" NM IBS sustained wear to the blades. Clear and clean rig floor. Load tools to rig floor. R/U 4 1/2'' handling equipment and power tongs. Ready Safety joint in mouse hole. Losses @ 3 BPH Hold PJSM on picking up/running liner. P/U round nose shoe w/ XO jt, and run 4-1/2'', 13.5#, L-80 H625 lower screen completion as per tally to 3340'. Torque to 9600 ft/lb with Doyon double stack tongs. Losses @ 3 BPH Losses: 52 bbls Daily / 324 bbls Total for Interval. H20 from 6-Mile: 0 bbls Daily / 15,475 bbls Total. H2O from L-Pad Lake: 100 bbls / 2,965 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 1200 bbls Total. Cuttings/mud/cement to MPU G&I: 1,129 bbls Daily / 21,370 bbls Total. 1/7/2021 Run 4-1/2'', 13.5#, L-80 H625 lower screen completion as per tally to 8743'. Torque to optimum @ 9600 ft/lbs. 110K PU / 80K S O On blank jts- install 1- 4 1/2'' x 7 1/4'' straight vane centralizer w/ 1- stop ring free floating on each joint. 4 blank joints, 41 Halliburton 250 micron screens, 166 Baker 200 micron screens. 4 bph loss rate, 27 bbls lost running liner. M/U Baker 7"x9-5/8" SLZXP liner top packer at 8743'. Pump 10 bbls to ensure clear flow path through Baker tools, 100 GPM, 135 PSI. Obtain parameters: 120K PU / 85K SO Run 4-1/2" lower production completion on 5" DP from the derrick (drifting to 2.43'' as needed) F/ 8782' T/ 10875'. 122K PU / 88K SO @ shoe 9310'. Single in the hole w/ 5"" HWDP f/ 10875' t/ 13001'. 2.43” drift used for HWDP. 197K PU / 115K SO. 3BPH loss rate Continue single in the hole w/ 5" HWDP F/ 13001' T/ 17866'. 2.43” drift used for HWDP. 197K PU / 40K SO , No down weight started floating pipe in the hole from 17210' 3BPH loss rate M/U a stand 5" DP. Work tight spot F/ 17866' T/ 17875'. 290k PU, stacking out @ 40k DN. String break free and continue run in hole t/ 17921'. Tag up w/ 20k. 240K PU / 150K SO Dropped the .906 vinolic setting ball and chased it with high vis spacer. Set SLZXP packer as per Baker rep. Hold 300 psi pump psi on drill string while pulling out of the SLZXP packer. Test SLZXP Packer to 1500psi for 10mins charted. Pressure up 1650psi @ 2.5 bbls and bled back 2.5 bbls to pits Pump BUS with sweep around and cont pumping until hole cleaned up. 650-250 GPM,1800-650 PSI. While working the stand no rotation. Reduce pump rate due to losses over shakers. Max gas 182u with BU. Free travel 230K PU, 160K SO Displace well from vis 10.2ppg KCl/NaCl/NaBr brine to clean 10.2ppg KCl/NaCl/NaBr brine. 620-275 GPM, 2400-970 PSI. Take partial returns to pits initially, reduce flow rate when divert full returns to rockwasher. Losses to the well 75bbls Daily / 399bbls Interval Total. H20 from 6-Mile: 0 bbls Daily / 15,475 bbls Total. H2O from L-Pad Lake: 50 bbls / 3,015 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 1200 bbls Total. Cuttings/mud/cement to MPU G&I: 171 bbls Daily / 21,541 bbls Total. 1/8/2021 Finish Displacing Well to clean 10.2ppg KCl/NaCl/NaBr brine 297-540 GPM, 940-2550 PSI, reciprocating string 45'. Obtain SPR's with new mud, B/D TD and observe well for flow. Slight losses POOH LD all 5'' HWDP f/ 9099' t/ 2103' 140K PU, 130K SO. Continue POOH L/D 5'' DP f/2103'. Inspect, Break down & lay down liner setting tool as per Baker Rep. 1 BPH loss rate. LD the remaining 16 stands of DP from Derrick via 90' mousehole. Change to Completions AFE @ 18:00. See MPU J-29 completions report for details Losses to the well 197 bbls Daily / 596 bbls Interval Total. H20 from 6-Mile: 0 bbls Daily / 15,475 bbls Total. H2O from L-Pad Lake: 50 bbls / 3,065 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 1200 bbls Total. Cuttings/mud/cement to MPU G&I: 792 bbls Daily / 22,333 bbls Total. Activity Date Ops Summary 1/8/2021 Refer to last drilling report for details.,Drain BOP stack and pull wear bushing. Wash stack with stack washing tool. Break down safety joint and lay down both mouseholes. Load tools to rig floor, R/U 7 5/8'' handling equipment, power tongs,,M/U 7-5/8” test joint and plug, set in hole. C/O upper 2-7/8”x5” VBR to 7-5/8” SBR. Test 7-5/8'' solid body rams 250/ 3000 psi, 5min each charted. R/D test equipment,Perform dummy run with 7-5/8" hanger. W H Tech verify. C/O split bushings for solid body master bushing,Finish R/U 7-5/8'' handling equipment. M/U FOSV to XO. Hold PJSM on running 7-5/8" Tie-Back,P/U Baker bullet seal assy w/ 8.25" O.D. locator to 17'. Run 7-5/8" 29.7# L-80 Hydril 521 tie back f/ 17' t/ 4787’ at jt #118. Torque to 10100 ft/lbs with Doyon casing double stack tongs. 1.5 BPH losses.,Losses to the well 197 bbls Daily / 596 bbls Interval Total. H20 from 6-Mile: 0 bbls Daily / 15,475 bbls Total. H2O from L-Pad Lake: 50 bbls / 3,065 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 1200 bbls Total. Cuttings/mud/cement to MPU G&I: 792 bbls Daily / 22,333 bbls Total. 1/9/2021 Run 7.625 29.7# L-80 liner F/ 4787' T/ 9093'.,M/U Joint 227 & no go out on LT at 9157'. Saw good seal engagement of 10K wt loss. L/D joints 227,226,225,224,223 and change out joint 223 with Joint 226. M/U joint 224 then 6 space out pups under Joint 225. M/U Hanger and landing joint and land out same. UP/DN 185/105.,R/U to reverse circ. Pressure up to 300 psi on the annulus against the bag. P/U until pressure dumps exposing 4 1'' ports.,PJSM, Spot corrosion inhibeted brine and diesel freeze protect. Test lines to 2K. Good. Pump 130 BBL corrosion inhibeted brine with 1% concor 303. BD mud pump to prevent flash freezing while pumping diesel. Chase with 41 bbl diesel for freeze protect. 350 psi. differential when done freeze protect. Strip in and land hanger. 65K set on hanger.,Bleed off pressure on OA. R/D reverse circulating lines, L/D landing jt, M/U running tool and install pack off as per WHR, RILDS, L/D running tool, test pack off to 500 psi for 5 min, 5000 psi for 10 min, good,R/U and test 9 5/8'' x 7 5/8'' annulus to 1000 psi for 30 charted minutes, good test, bleed off pressure. Blow down and R/D injection lines, and flush mud pumps w/ hot water.,PJSM, R/U ESP spooler, Doyon 3.5'' handling equipment and baker ESP equipment. Hang sheave in Derrick, String ESP cable and secure at rig floor. Hold PJSM for running ESP completion, review well control procedure. Monitor well with trip tank, 1.5bph static loss rate,P/U, M/U & service ESP/Motor and seal assy. Connect ESP cable, 85' control line discharge, to motor and gauge assembly. Install 3 bolt on clamps to motor assy connections, 4 on seals. Perform tests on ESP cable. Good test P/U and install 6 pump clamps onto the pump assy.,RIH with ESP on 3-1/2"" 9.3# L-80 EUE Tubing F/ 81' to 624'. Torque to 3130 ft/lbs with Doyon double stack tongs, Install cannon clamp every connection for first 10 jts. Install cannon clamp every other connection from jt #10 and above & below GLM body. Losses @ 1.5BPH,Losses Daily 29 bbls / 625 bbls Interval Total. H20 from 6-Mile: 0 bbls Daily / 15,475 bbls Total. H2O from L-Pad Lake: 50 bbls / 3,115 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 1200 bbls Total. Cuttings/mud/cement to MPU G&I: 257 bbls Daily / 22,590 bbls Total. 1/10/2021 RIH with ESP on 3-1/2" 9.3# L-80 EUE Tubing F/ 624' to 3836'. Torque to 3130 ft/lbs, Install cannon clamp every other connection. Test cable connection every 2000’. 67K PU / 57K SO. Losses @ 0.5 BPH,RIH with ESP on 3-1/2" 9.3# L-80 EUE Tubing F/ 3836' to 7863'. Torque to 3130 ft/lbs, Install cannon clamp every other connection. Test cable connection every 2000’. 95K PU / 60K SO 135 total cross cannon clamps. 8.5 bbls total loss while running completion tubing. Rig Gen power @ 18:00,Verify tubing count in pipe shed. Install BPV in Hanger on Rig Floor. Rig up landing joint with cross overs to Hanger and M/U to tubing.,Centrilift terminate ESP cable to tbg hanger, meg test cable, good. Drain stack, land hanger with 20k on hanger, ESP centralizer @ 7897.87'. RILDS as per WHR, L/D landing joint. SIMOP's Rigging down 3.5'' running equipment while terminating ESP cable, Offload and clean in pits. Loss rate 0.5 bph,Remove MPD trip nipple, N/D BOPE, Hoist stack and rack on moving stump. WHR install dart in BPV. N/U tree and adaptor, WHR test hanger void to 500 psi for 5 min, 5000 psi for 15 min, good. N/U Tree and adaptor. Centrilift take final readings. 3.2 OHM phase to phase, 3.55 G Phase to Ground, PI = 1898.9 psi, PD = 1896.3 psi, TI = 74.3 deg, TM = 73.8, VX =.007 vib, VZ = .000, CT = 10,R/U test equipment, test tree with diesel to 250 /5000 psi 5 min each, good, WHR pull BPV and dart. R/D test equipment.,PJSM, R/U to reverse circulate diesel though the tree to freeze protect well. Flood surface lines and pressure test lines to 3000PSI good test. Pump 85 bbls diesel down I/A, ICP 2 bpm, 310 psi – FCP 2 bpm, 430 psi. Blow down and line up to bullhead freeze protect down tubing. Losses: 8 bbls Daily / 633 bbls Total for Interval. H20 from 6-Mile: 0 bbls Daily / 15,475 bbls Total. H2O from L-Pad Lake: 50 bbls / 3,165 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 1200 bbls Total. Cuttings/mud/cement to MPU G&I: 257 bbls Daily / 22,847 bbls Total. 1/11/2021 Flood lines and PT 3000psi. Bullhead 25bbls of diesel down the 3.5'' tbg. ICP 940psi @ 1BPM FCP 1130psi @ 0.7BPM. B/D surface lines and pumps of diesel. Flushed fresh H2O through the pumps and surface lines. B/D surface lines and pump,Rig down cellar and secure tree. Cut and cap 90' mousehole. Move rockwasher & Skid rig floor into moving position. Rig released @ 12:00,See MPU J-30 Drilling report for details.,H20 from 6-Mile: 0 bbls Daily / 15,475 bbls Total. H2O from L-Pad Lake: 50 bbls / 3,215 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 1200 bbls Total. Recycle to ORT: 250 bbls Daily / 250 bbls Total. Cuttings/mud/cement to MPU G&I: 242 bbls Daily / 23,089 bbls Total. 12/20/2020Spud Date: Well Name: Field: MP J-29 Milne Point Hilcorp Energy Company Composite Report 50-029-23688-00-00API #: 06 January, 2021 Milne Point M Pt J Pad MPU J-29 500292368800 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt J Pad Definitive Survey Report Well: Wellbore: MPU J-29 MPU J-29 Survey Calculation Method:Minimum Curvature Actual @ 68.08usft Design:MPU J-29 Database:NORTH US + CANADA MD Reference:Actual @ 68.08usft North Reference: Well MPU J-29 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Milne Point, ACT, MILNE POINT Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: MPU J-29 usft usft 0.00 0.00 6,015,068.010 551,934.080 33.70Wellhead Elevation:usft0.50 70° 27' 6.869 N 149° 34' 34.512 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU J-29 Model NameMagnetics IFR 1/1/2021 15.71 80.86 57,357.00000000 Phase:Version: Audit Notes: Design MPU J-29 1.0 ACTUAL Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:34.38 270.000.000.0034.38 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 1/5/2021 Survey Date 3_Gyro-MWD90+Sag H065Ga: UNVALIDATED : based on GYD_GW240.20 1,372.61 MPU J-29 Gyro MWD Tie-on (MPU J-29)12/11/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa1,426.42 9,227.22 MPU J-29 Surface MWD+IFR2+MS+Sag 12/23/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa9,288.52 17,831.16 MPU J-29 Production MWD+IFR2+MS+S 12/30/2020 MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 34.38 0.00 0.00 34.38 0.00 0.00-33.70 6,015,068.01 551,934.08 0.00 0.00 UNDEFINED 240.20 0.44 163.90 240.20 -0.76 0.22172.12 6,015,067.25 551,934.30 0.21 -0.22 3_Gyro-MWD90+Sag (1) 301.69 0.35 155.80 301.69 -1.16 0.36233.61 6,015,066.86 551,934.45 0.17 -0.36 3_Gyro-MWD90+Sag (1) 332.63 0.62 171.13 332.63 -1.41 0.43264.55 6,015,066.60 551,934.52 0.96 -0.43 3_Gyro-MWD90+Sag (1) 426.86 0.79 214.47 426.85 -2.45 0.14358.77 6,015,065.56 551,934.23 0.58 -0.14 3_Gyro-MWD90+Sag (1) 522.23 2.47 13.24 522.20 -0.99 0.24454.12 6,015,067.02 551,934.32 3.38 -0.24 3_Gyro-MWD90+Sag (1) 612.94 6.95 21.35 612.58 6.03 2.68544.50 6,015,074.06 551,936.72 4.98 -2.68 3_Gyro-MWD90+Sag (1) 707.55 9.51 18.53 706.20 18.77 7.25638.12 6,015,086.83 551,941.20 2.74 -7.25 3_Gyro-MWD90+Sag (1) 800.65 12.50 17.65 797.58 35.67 12.75729.50 6,015,103.76 551,946.58 3.22 -12.75 3_Gyro-MWD90+Sag (1) 897.68 17.61 15.35 891.25 59.85 19.83823.17 6,015,127.99 551,953.49 5.30 -19.83 3_Gyro-MWD90+Sag (1) 993.11 20.51 7.25 981.46 90.36 25.76913.38 6,015,158.54 551,959.21 4.11 -25.76 3_Gyro-MWD90+Sag (1) 1,088.62 22.89 355.09 1,070.24 125.49 26.281,002.16 6,015,193.67 551,959.48 5.31 -26.28 3_Gyro-MWD90+Sag (1) 1/6/2021 7:53:59PM COMPASS 5000.15 Build 91E Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt J Pad Definitive Survey Report Well: Wellbore: MPU J-29 MPU J-29 Survey Calculation Method:Minimum Curvature Actual @ 68.08usft Design:MPU J-29 Database:NORTH US + CANADA MD Reference:Actual @ 68.08usft North Reference: Well MPU J-29 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 1,181.44 23.49 343.99 1,155.60 161.27 19.631,087.52 6,015,229.40 551,952.58 4.75 -19.63 3_Gyro-MWD90+Sag (1) 1,276.76 26.58 331.65 1,242.01 198.34 4.251,173.93 6,015,266.35 551,936.95 6.35 -4.25 3_Gyro-MWD90+Sag (1) 1,372.61 25.61 323.55 1,328.12 233.88 -18.251,260.04 6,015,301.74 551,914.20 3.85 18.25 3_Gyro-MWD90+Sag (1) 1,426.42 26.03 318.78 1,376.56 252.12 -32.941,308.48 6,015,319.87 551,899.39 3.94 32.94 3_MWD+IFR2+MS+Sag (2) 1,517.47 27.94 311.64 1,457.72 281.33 -62.061,389.64 6,015,348.88 551,870.07 4.13 62.06 3_MWD+IFR2+MS+Sag (2) 1,612.69 31.82 311.08 1,540.26 312.66 -97.661,472.18 6,015,379.95 551,834.25 4.09 97.66 3_MWD+IFR2+MS+Sag (2) 1,708.03 33.69 312.39 1,620.44 347.01 -136.141,552.36 6,015,414.03 551,795.54 2.10 136.14 3_MWD+IFR2+MS+Sag (2) 1,803.07 37.78 313.18 1,697.57 384.72 -176.861,629.49 6,015,451.45 551,754.56 4.33 176.86 3_MWD+IFR2+MS+Sag (2) 1,896.72 41.17 312.36 1,769.85 425.13 -220.561,701.77 6,015,491.55 551,710.58 3.66 220.56 3_MWD+IFR2+MS+Sag (2) 1,993.87 45.20 312.95 1,840.67 470.18 -269.441,772.59 6,015,536.25 551,661.39 4.17 269.44 3_MWD+IFR2+MS+Sag (2) 2,088.51 46.26 312.44 1,906.73 516.13 -319.251,838.65 6,015,581.85 551,611.27 1.18 319.25 3_MWD+IFR2+MS+Sag (2) 2,184.66 49.88 310.11 1,970.98 563.27 -373.021,902.90 6,015,628.61 551,557.18 4.17 373.02 3_MWD+IFR2+MS+Sag (2) 2,279.38 51.22 307.55 2,031.17 609.11 -430.001,963.09 6,015,674.05 551,499.89 2.52 430.00 3_MWD+IFR2+MS+Sag (2) 2,373.98 55.35 305.11 2,087.72 653.98 -491.102,019.64 6,015,718.49 551,438.49 4.83 491.10 3_MWD+IFR2+MS+Sag (2) 2,469.07 60.52 303.78 2,138.18 699.53 -557.542,070.10 6,015,763.57 551,371.73 5.56 557.54 3_MWD+IFR2+MS+Sag (2) 2,563.90 64.38 302.07 2,182.04 745.19 -628.112,113.96 6,015,808.74 551,300.85 4.37 628.11 3_MWD+IFR2+MS+Sag (2) 2,659.73 66.17 300.61 2,222.12 790.46 -702.452,154.04 6,015,853.48 551,226.20 2.32 702.45 3_MWD+IFR2+MS+Sag (2) 2,752.14 71.31 298.89 2,255.62 833.16 -777.202,187.54 6,015,895.65 551,151.16 5.83 777.20 3_MWD+IFR2+MS+Sag (2) 2,849.75 73.36 299.01 2,285.24 878.17 -858.592,217.16 6,015,940.09 551,069.48 2.10 858.59 3_MWD+IFR2+MS+Sag (2) 2,946.15 76.29 299.65 2,310.47 923.75 -939.692,242.39 6,015,985.10 550,988.07 3.11 939.69 3_MWD+IFR2+MS+Sag (2) 3,039.29 76.07 300.33 2,332.72 968.95 -1,018.022,264.64 6,016,029.75 550,909.43 0.75 1,018.02 3_MWD+IFR2+MS+Sag (2) 3,135.65 76.22 300.76 2,355.79 1,016.50 -1,098.592,287.71 6,016,076.73 550,828.54 0.46 1,098.59 3_MWD+IFR2+MS+Sag (2) 3,229.16 75.46 301.68 2,378.67 1,063.49 -1,176.132,310.59 6,016,123.18 550,750.68 1.25 1,176.13 3_MWD+IFR2+MS+Sag (2) 3,324.52 74.93 302.48 2,403.04 1,112.46 -1,254.252,334.96 6,016,171.59 550,672.23 0.98 1,254.25 3_MWD+IFR2+MS+Sag (2) 3,419.88 74.26 301.67 2,428.37 1,161.28 -1,332.152,360.29 6,016,219.86 550,594.00 1.08 1,332.15 3_MWD+IFR2+MS+Sag (2) 3,515.44 74.70 301.10 2,453.94 1,209.23 -1,410.752,385.86 6,016,267.26 550,515.07 0.74 1,410.75 3_MWD+IFR2+MS+Sag (2) 3,610.83 75.01 300.94 2,478.86 1,256.68 -1,489.662,410.78 6,016,314.16 550,435.84 0.36 1,489.66 3_MWD+IFR2+MS+Sag (2) 3,706.37 75.27 300.07 2,503.36 1,303.55 -1,569.222,435.28 6,016,360.47 550,355.97 0.92 1,569.22 3_MWD+IFR2+MS+Sag (2) 3,802.21 78.13 298.73 2,525.41 1,349.33 -1,650.472,457.33 6,016,405.67 550,274.41 3.28 1,650.47 3_MWD+IFR2+MS+Sag (2) 3,897.18 75.91 297.35 2,546.74 1,392.83 -1,732.142,478.66 6,016,448.60 550,192.44 2.73 1,732.14 3_MWD+IFR2+MS+Sag (2) 3,991.16 73.28 297.33 2,571.70 1,434.44 -1,812.622,503.62 6,016,489.64 550,111.69 2.80 1,812.62 3_MWD+IFR2+MS+Sag (2) 4,086.95 74.36 297.83 2,598.39 1,477.03 -1,894.162,530.31 6,016,531.66 550,029.86 1.23 1,894.16 3_MWD+IFR2+MS+Sag (2) 4,181.16 73.93 300.03 2,624.14 1,520.87 -1,973.472,556.06 6,016,574.94 549,950.25 2.29 1,973.47 3_MWD+IFR2+MS+Sag (2) 4,276.46 73.86 301.11 2,650.57 1,567.43 -2,052.302,582.49 6,016,620.95 549,871.10 1.09 2,052.30 3_MWD+IFR2+MS+Sag (2) 4,371.09 74.36 301.50 2,676.48 1,614.72 -2,130.072,608.40 6,016,667.69 549,793.02 0.66 2,130.07 3_MWD+IFR2+MS+Sag (2) 4,466.21 74.95 301.64 2,701.65 1,662.75 -2,208.222,633.57 6,016,715.17 549,714.54 0.64 2,208.22 3_MWD+IFR2+MS+Sag (2) 4,561.65 75.90 301.05 2,725.67 1,710.80 -2,287.102,657.59 6,016,762.66 549,635.33 1.16 2,287.10 3_MWD+IFR2+MS+Sag (2) 4,655.18 77.56 299.52 2,747.14 1,756.70 -2,365.712,679.06 6,016,808.01 549,556.41 2.38 2,365.71 3_MWD+IFR2+MS+Sag (2) 4,750.03 76.47 298.46 2,768.45 1,801.49 -2,446.552,700.37 6,016,852.23 549,475.27 1.58 2,446.55 3_MWD+IFR2+MS+Sag (2) 4,847.36 75.47 299.30 2,792.05 1,847.09 -2,529.232,723.97 6,016,897.25 549,392.28 1.33 2,529.23 3_MWD+IFR2+MS+Sag (2) 1/6/2021 7:53:59PM COMPASS 5000.15 Build 91E Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt J Pad Definitive Survey Report Well: Wellbore: MPU J-29 MPU J-29 Survey Calculation Method:Minimum Curvature Actual @ 68.08usft Design:MPU J-29 Database:NORTH US + CANADA MD Reference:Actual @ 68.08usft North Reference: Well MPU J-29 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 4,942.74 76.02 297.76 2,815.54 1,891.24 -2,610.452,747.46 6,016,940.83 549,310.77 1.67 2,610.45 3_MWD+IFR2+MS+Sag (2) 5,036.00 77.16 296.19 2,837.16 1,932.39 -2,691.292,769.08 6,016,981.41 549,229.65 2.04 2,691.29 3_MWD+IFR2+MS+Sag (2) 5,133.29 76.71 296.62 2,859.16 1,974.53 -2,776.182,791.08 6,017,022.96 549,144.48 0.63 2,776.18 3_MWD+IFR2+MS+Sag (2) 5,228.15 75.90 297.62 2,881.62 2,016.55 -2,858.212,813.54 6,017,064.39 549,062.17 1.33 2,858.21 3_MWD+IFR2+MS+Sag (2) 5,324.35 74.31 298.78 2,906.34 2,060.47 -2,940.142,838.26 6,017,107.74 548,979.94 2.02 2,940.14 3_MWD+IFR2+MS+Sag (2) 5,419.39 73.90 298.93 2,932.37 2,104.58 -3,020.192,864.29 6,017,151.29 548,899.59 0.46 3,020.19 3_MWD+IFR2+MS+Sag (2) 5,514.90 73.66 300.26 2,959.05 2,149.87 -3,099.942,890.97 6,017,196.02 548,819.54 1.36 3,099.94 3_MWD+IFR2+MS+Sag (2) 5,609.91 72.06 301.75 2,987.05 2,196.63 -3,177.752,918.97 6,017,242.23 548,741.41 2.25 3,177.75 3_MWD+IFR2+MS+Sag (2) 5,705.26 71.77 302.54 3,016.65 2,244.86 -3,254.502,948.57 6,017,289.92 548,664.33 0.84 3,254.50 3_MWD+IFR2+MS+Sag (2) 5,800.70 73.00 302.47 3,045.53 2,293.74 -3,331.212,977.45 6,017,338.26 548,587.29 1.29 3,331.21 3_MWD+IFR2+MS+Sag (2) 5,895.98 73.40 301.24 3,073.07 2,341.88 -3,408.683,004.99 6,017,385.85 548,509.49 1.31 3,408.68 3_MWD+IFR2+MS+Sag (2) 5,990.72 76.67 299.68 3,097.54 2,388.26 -3,487.573,029.46 6,017,431.68 548,430.29 3.80 3,487.57 3_MWD+IFR2+MS+Sag (2) 6,086.17 77.17 299.01 3,119.14 2,433.82 -3,568.613,051.06 6,017,476.67 548,348.94 0.86 3,568.61 3_MWD+IFR2+MS+Sag (2) 6,181.97 77.96 298.14 3,139.77 2,478.57 -3,650.773,071.69 6,017,520.84 548,266.48 1.21 3,650.77 3_MWD+IFR2+MS+Sag (2) 6,276.77 78.49 298.23 3,159.11 2,522.40 -3,732.573,091.03 6,017,564.09 548,184.38 0.57 3,732.57 3_MWD+IFR2+MS+Sag (2) 6,372.48 74.40 298.30 3,181.54 2,566.45 -3,814.503,113.46 6,017,607.57 548,102.15 4.27 3,814.50 3_MWD+IFR2+MS+Sag (2) 6,466.04 73.58 298.76 3,207.35 2,609.40 -3,893.513,139.27 6,017,649.96 548,022.86 1.00 3,893.51 3_MWD+IFR2+MS+Sag (2) 6,561.09 73.32 300.27 3,234.42 2,654.29 -3,972.803,166.34 6,017,694.29 547,943.27 1.55 3,972.80 3_MWD+IFR2+MS+Sag (2) 6,656.87 74.00 301.15 3,261.37 2,701.23 -4,051.823,193.29 6,017,740.67 547,863.93 1.13 4,051.82 3_MWD+IFR2+MS+Sag (2) 6,752.20 75.07 301.70 3,286.79 2,749.13 -4,130.223,218.71 6,017,788.02 547,785.20 1.25 4,130.22 3_MWD+IFR2+MS+Sag (2) 6,847.82 75.88 301.43 3,310.77 2,797.58 -4,209.093,242.69 6,017,835.92 547,706.01 0.89 4,209.09 3_MWD+IFR2+MS+Sag (2) 6,943.51 77.49 300.38 3,332.81 2,845.41 -4,288.983,264.73 6,017,883.18 547,625.79 1.99 4,288.98 3_MWD+IFR2+MS+Sag (2) 7,038.26 77.31 300.10 3,353.48 2,891.98 -4,368.873,285.40 6,017,929.19 547,545.59 0.35 4,368.87 3_MWD+IFR2+MS+Sag (2) 7,130.55 75.41 300.65 3,375.24 2,937.32 -4,446.243,307.16 6,017,973.99 547,467.91 2.14 4,446.24 3_MWD+IFR2+MS+Sag (2) 7,228.48 75.79 300.45 3,399.59 2,985.54 -4,527.933,331.51 6,018,021.63 547,385.90 0.44 4,527.93 3_MWD+IFR2+MS+Sag (2) 7,321.34 76.29 300.17 3,422.00 3,031.01 -4,605.723,353.92 6,018,066.56 547,307.79 0.61 4,605.72 3_MWD+IFR2+MS+Sag (2) 7,417.96 75.69 299.75 3,445.39 3,077.83 -4,686.943,377.31 6,018,112.81 547,226.26 0.75 4,686.94 3_MWD+IFR2+MS+Sag (2) 7,513.65 74.24 298.42 3,470.21 3,122.76 -4,767.703,402.13 6,018,157.16 547,145.20 2.02 4,767.70 3_MWD+IFR2+MS+Sag (2) 7,607.55 73.92 298.23 3,495.97 3,165.60 -4,847.183,427.89 6,018,199.45 547,065.42 0.39 4,847.18 3_MWD+IFR2+MS+Sag (2) 7,646.81 74.18 298.52 3,506.75 3,183.54 -4,880.403,438.67 6,018,217.15 547,032.09 0.97 4,880.40 3_MWD+IFR2+MS+Sag (2) 7,702.53 73.78 298.78 3,522.13 3,209.22 -4,927.403,454.05 6,018,242.50 546,984.92 0.85 4,927.40 3_MWD+IFR2+MS+Sag (2) 7,798.84 73.47 299.24 3,549.28 3,254.03 -5,008.213,481.20 6,018,286.74 546,903.80 0.56 5,008.21 3_MWD+IFR2+MS+Sag (2) 7,894.46 73.40 299.11 3,576.55 3,298.71 -5,088.233,508.47 6,018,330.86 546,823.48 0.15 5,088.23 3_MWD+IFR2+MS+Sag (2) 7,989.55 74.30 298.78 3,603.00 3,342.91 -5,168.163,534.92 6,018,374.50 546,743.25 1.00 5,168.16 3_MWD+IFR2+MS+Sag (2) 8,085.22 73.16 297.55 3,629.80 3,386.26 -5,249.123,561.72 6,018,417.28 546,662.00 1.72 5,249.12 3_MWD+IFR2+MS+Sag (2) 8,180.80 75.71 295.42 3,655.45 3,427.31 -5,331.523,587.37 6,018,457.75 546,579.32 3.42 5,331.52 3_MWD+IFR2+MS+Sag (2) 8,276.53 80.20 292.64 3,675.42 3,465.40 -5,417.013,607.34 6,018,495.24 546,493.58 5.48 5,417.01 3_MWD+IFR2+MS+Sag (2) 8,370.94 81.45 289.56 3,690.48 3,498.94 -5,503.953,622.40 6,018,528.17 546,406.42 3.48 5,503.95 3_MWD+IFR2+MS+Sag (2) 8,466.03 84.33 284.33 3,702.26 3,526.42 -5,594.173,634.18 6,018,555.02 546,316.01 6.24 5,594.17 3_MWD+IFR2+MS+Sag (2) 8,560.15 85.98 279.63 3,710.21 3,545.87 -5,685.893,642.13 6,018,573.83 546,224.17 5.28 5,685.89 3_MWD+IFR2+MS+Sag (2) 1/6/2021 7:53:59PM COMPASS 5000.15 Build 91E Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt J Pad Definitive Survey Report Well: Wellbore: MPU J-29 MPU J-29 Survey Calculation Method:Minimum Curvature Actual @ 68.08usft Design:MPU J-29 Database:NORTH US + CANADA MD Reference:Actual @ 68.08usft North Reference: Well MPU J-29 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 8,655.77 85.23 274.48 3,717.54 3,557.58 -5,780.473,649.46 6,018,584.88 546,129.52 5.43 5,780.47 3_MWD+IFR2+MS+Sag (2) 8,750.70 85.68 269.75 3,725.07 3,561.07 -5,875.013,656.99 6,018,587.71 546,034.97 4.99 5,875.01 3_MWD+IFR2+MS+Sag (2) 8,844.94 82.70 265.80 3,734.61 3,557.44 -5,968.673,666.53 6,018,583.43 545,941.35 5.23 5,968.67 3_MWD+IFR2+MS+Sag (2) 8,940.66 81.57 264.29 3,747.71 3,549.25 -6,063.133,679.63 6,018,574.58 545,846.95 1.96 6,063.13 3_MWD+IFR2+MS+Sag (2) 9,036.52 79.07 264.50 3,763.83 3,540.03 -6,157.163,695.75 6,018,564.70 545,752.99 2.62 6,157.16 3_MWD+IFR2+MS+Sag (2) 9,131.17 80.44 265.59 3,780.66 3,531.98 -6,249.953,712.58 6,018,556.01 545,660.27 1.84 6,249.95 3_MWD+IFR2+MS+Sag (2) 9,227.22 88.33 265.92 3,790.05 3,524.91 -6,345.203,721.97 6,018,548.28 545,565.08 8.22 6,345.20 3_MWD+IFR2+MS+Sag (2) 9,288.52 94.38 265.36 3,788.60 3,520.26 -6,406.283,720.52 6,018,543.20 545,504.04 9.91 6,406.28 3_MWD+IFR2+MS+Sag (3) 9,384.09 93.96 264.48 3,781.65 3,511.82 -6,501.223,713.57 6,018,534.10 545,409.17 1.02 6,501.22 3_MWD+IFR2+MS+Sag (3) 9,479.80 91.23 263.40 3,777.32 3,501.72 -6,596.293,709.24 6,018,523.34 545,314.19 3.07 6,596.29 3_MWD+IFR2+MS+Sag (3) 9,575.00 92.84 263.75 3,773.94 3,491.08 -6,690.833,705.86 6,018,512.04 545,219.73 1.73 6,690.83 3_MWD+IFR2+MS+Sag (3) 9,670.01 94.14 263.44 3,768.16 3,480.50 -6,785.073,700.08 6,018,500.80 545,125.58 1.41 6,785.07 3_MWD+IFR2+MS+Sag (3) 9,764.96 92.09 263.16 3,763.00 3,469.44 -6,879.223,694.92 6,018,489.09 545,031.51 2.18 6,879.22 3_MWD+IFR2+MS+Sag (3) 9,860.59 89.56 262.81 3,761.62 3,457.76 -6,974.123,693.54 6,018,476.75 544,936.71 2.67 6,974.12 3_MWD+IFR2+MS+Sag (3) 9,955.61 89.38 263.01 3,762.50 3,446.03 -7,068.413,694.42 6,018,464.37 544,842.51 0.28 7,068.41 3_MWD+IFR2+MS+Sag (3) 10,051.30 89.51 263.35 3,763.43 3,434.67 -7,163.423,695.35 6,018,452.34 544,747.59 0.38 7,163.42 3_MWD+IFR2+MS+Sag (3) 10,146.03 91.36 263.65 3,762.71 3,423.95 -7,257.533,694.63 6,018,440.97 544,653.57 1.98 7,257.53 3_MWD+IFR2+MS+Sag (3) 10,239.70 90.68 263.07 3,761.04 3,413.12 -7,350.563,692.96 6,018,429.49 544,560.63 0.95 7,350.56 3_MWD+IFR2+MS+Sag (3) 10,335.05 91.17 262.42 3,759.50 3,401.08 -7,445.133,691.42 6,018,416.79 544,466.15 0.85 7,445.13 3_MWD+IFR2+MS+Sag (3) 10,431.08 90.68 262.07 3,757.95 3,388.12 -7,540.273,689.87 6,018,403.17 544,371.11 0.63 7,540.27 3_MWD+IFR2+MS+Sag (3) 10,525.61 91.30 261.21 3,756.32 3,374.38 -7,633.783,688.24 6,018,388.78 544,277.71 1.12 7,633.78 3_MWD+IFR2+MS+Sag (3) 10,621.85 91.05 262.51 3,754.34 3,360.76 -7,729.033,686.26 6,018,374.50 544,182.57 1.38 7,729.03 3_MWD+IFR2+MS+Sag (3) 10,716.70 90.68 263.44 3,752.91 3,349.16 -7,823.163,684.83 6,018,362.24 544,088.53 1.06 7,823.16 3_MWD+IFR2+MS+Sag (3) 10,811.73 90.92 264.82 3,751.58 3,339.44 -7,917.683,683.50 6,018,351.87 543,994.09 1.47 7,917.68 3_MWD+IFR2+MS+Sag (3) 10,907.10 91.30 266.49 3,749.74 3,332.22 -8,012.753,681.66 6,018,343.98 543,899.08 1.80 8,012.75 3_MWD+IFR2+MS+Sag (3) 11,002.81 90.86 267.86 3,747.93 3,327.50 -8,108.323,679.85 6,018,338.60 543,803.55 1.50 8,108.32 3_MWD+IFR2+MS+Sag (3) 11,097.14 90.68 269.57 3,746.66 3,325.39 -8,202.623,678.58 6,018,335.83 543,709.28 1.82 8,202.62 3_MWD+IFR2+MS+Sag (3) 11,192.98 91.05 271.45 3,745.22 3,326.24 -8,298.443,677.14 6,018,336.01 543,613.47 2.00 8,298.44 3_MWD+IFR2+MS+Sag (3) 11,288.68 90.06 272.85 3,744.29 3,329.83 -8,394.063,676.21 6,018,338.94 543,517.83 1.79 8,394.06 3_MWD+IFR2+MS+Sag (3) 11,383.58 88.70 273.28 3,745.32 3,334.90 -8,488.823,677.24 6,018,343.35 543,423.05 1.50 8,488.82 3_MWD+IFR2+MS+Sag (3) 11,479.43 91.61 274.08 3,745.06 3,341.05 -8,584.463,676.98 6,018,348.83 543,327.38 3.15 8,584.46 3_MWD+IFR2+MS+Sag (3) 11,574.27 92.72 275.56 3,741.48 3,349.02 -8,678.893,673.40 6,018,356.14 543,232.90 1.95 8,678.89 3_MWD+IFR2+MS+Sag (3) 11,669.67 91.85 277.25 3,737.67 3,359.65 -8,773.623,669.59 6,018,366.11 543,138.11 1.99 8,773.62 3_MWD+IFR2+MS+Sag (3) 11,765.31 91.48 278.59 3,734.89 3,372.82 -8,868.303,666.81 6,018,378.62 543,043.35 1.45 8,868.30 3_MWD+IFR2+MS+Sag (3) 11,860.12 91.98 277.22 3,732.03 3,385.86 -8,962.173,663.95 6,018,391.00 542,949.40 1.54 8,962.17 3_MWD+IFR2+MS+Sag (3) 11,955.24 92.41 275.78 3,728.39 3,396.62 -9,056.603,660.31 6,018,401.10 542,854.90 1.58 9,056.60 3_MWD+IFR2+MS+Sag (3) 12,050.68 91.91 274.32 3,724.79 3,405.01 -9,151.603,656.71 6,018,408.83 542,759.86 1.62 9,151.60 3_MWD+IFR2+MS+Sag (3) 12,143.29 91.91 273.42 3,721.70 3,411.26 -9,243.953,653.62 6,018,414.43 542,667.48 0.97 9,243.95 3_MWD+IFR2+MS+Sag (3) 12,239.94 93.96 272.93 3,716.75 3,416.60 -9,340.323,648.67 6,018,419.11 542,571.08 2.18 9,340.32 3_MWD+IFR2+MS+Sag (3) 12,335.76 92.84 272.31 3,711.07 3,420.98 -9,435.873,642.99 6,018,422.81 542,475.51 1.34 9,435.87 3_MWD+IFR2+MS+Sag (3) 1/6/2021 7:53:59PM COMPASS 5000.15 Build 91E Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt J Pad Definitive Survey Report Well: Wellbore: MPU J-29 MPU J-29 Survey Calculation Method:Minimum Curvature Actual @ 68.08usft Design:MPU J-29 Database:NORTH US + CANADA MD Reference:Actual @ 68.08usft North Reference: Well MPU J-29 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 12,430.28 94.08 272.52 3,705.37 3,424.95 -9,530.133,637.29 6,018,426.13 542,381.24 1.33 9,530.13 3_MWD+IFR2+MS+Sag (3) 12,523.94 93.89 272.66 3,698.86 3,429.17 -9,623.473,630.78 6,018,429.70 542,287.88 0.25 9,623.47 3_MWD+IFR2+MS+Sag (3) 12,619.60 95.94 271.82 3,690.66 3,432.90 -9,718.703,622.58 6,018,432.76 542,192.64 2.31 9,718.70 3_MWD+IFR2+MS+Sag (3) 12,712.84 94.07 269.72 3,682.53 3,434.14 -9,811.573,614.45 6,018,433.36 542,099.77 3.01 9,811.57 3_MWD+IFR2+MS+Sag (3) 12,808.68 95.57 269.18 3,674.47 3,433.23 -9,907.063,606.39 6,018,431.78 542,004.30 1.66 9,907.06 3_MWD+IFR2+MS+Sag (3) 12,905.27 91.35 266.45 3,668.65 3,429.55 -10,003.373,600.57 6,018,427.43 541,908.02 5.20 10,003.37 3_MWD+IFR2+MS+Sag (3) 12,999.95 91.23 267.33 3,666.51 3,424.41 -10,097.893,598.43 6,018,421.64 541,813.55 0.94 10,097.89 3_MWD+IFR2+MS+Sag (3) 13,093.58 90.92 268.67 3,664.76 3,421.15 -10,191.443,596.68 6,018,417.72 541,720.03 1.47 10,191.44 3_MWD+IFR2+MS+Sag (3) 13,191.00 91.54 270.99 3,662.67 3,420.86 -10,288.833,594.59 6,018,416.75 541,622.66 2.46 10,288.83 3_MWD+IFR2+MS+Sag (3) 13,286.51 92.35 272.44 3,659.42 3,423.71 -10,384.243,591.34 6,018,418.94 541,527.24 1.74 10,384.24 3_MWD+IFR2+MS+Sag (3) 13,380.07 91.48 271.84 3,656.30 3,427.20 -10,477.683,588.22 6,018,421.78 541,433.78 1.13 10,477.68 3_MWD+IFR2+MS+Sag (3) 13,477.35 89.07 271.29 3,655.83 3,429.86 -10,574.923,587.75 6,018,423.76 541,336.54 2.54 10,574.92 3_MWD+IFR2+MS+Sag (3) 13,573.10 90.49 271.51 3,656.20 3,432.20 -10,670.633,588.12 6,018,425.43 541,240.82 1.50 10,670.63 3_MWD+IFR2+MS+Sag (3) 13,668.46 87.71 272.74 3,657.70 3,435.74 -10,765.913,589.62 6,018,428.30 541,145.54 3.19 10,765.91 3_MWD+IFR2+MS+Sag (3) 13,763.57 89.51 273.20 3,660.00 3,440.66 -10,860.863,591.92 6,018,432.57 541,050.56 1.95 10,860.86 3_MWD+IFR2+MS+Sag (3) 13,859.12 92.91 273.28 3,657.99 3,446.06 -10,956.223,589.91 6,018,437.30 540,955.17 3.56 10,956.22 3_MWD+IFR2+MS+Sag (3) 13,954.00 92.72 273.34 3,653.33 3,451.53 -11,050.833,585.25 6,018,442.11 540,860.54 0.21 11,050.83 3_MWD+IFR2+MS+Sag (3) 14,049.48 91.54 270.16 3,649.78 3,454.44 -11,146.183,581.70 6,018,444.36 540,765.18 3.55 11,146.18 3_MWD+IFR2+MS+Sag (3) 14,143.70 92.91 269.92 3,646.12 3,454.51 -11,240.333,578.04 6,018,443.77 540,671.04 1.48 11,240.33 3_MWD+IFR2+MS+Sag (3) 14,239.42 94.64 268.93 3,639.82 3,453.55 -11,335.833,571.74 6,018,442.15 540,575.56 2.08 11,335.83 3_MWD+IFR2+MS+Sag (3) 14,334.70 93.83 265.80 3,632.78 3,449.18 -11,430.743,564.70 6,018,437.12 540,480.69 3.38 11,430.74 3_MWD+IFR2+MS+Sag (3) 14,430.52 94.32 261.01 3,625.97 3,438.21 -11,525.653,557.89 6,018,425.48 540,385.86 5.01 11,525.65 3_MWD+IFR2+MS+Sag (3) 14,523.80 93.52 259.77 3,619.59 3,422.67 -11,617.413,551.51 6,018,409.31 540,294.23 1.58 11,617.41 3_MWD+IFR2+MS+Sag (3) 14,620.03 94.14 257.34 3,613.16 3,403.62 -11,711.513,545.08 6,018,389.61 540,200.27 2.60 11,711.51 3_MWD+IFR2+MS+Sag (3) 14,716.70 91.60 255.67 3,608.32 3,381.10 -11,805.383,540.24 6,018,366.42 540,106.57 3.14 11,805.38 3_MWD+IFR2+MS+Sag (3) 14,812.13 90.80 256.03 3,606.32 3,357.77 -11,897.893,538.24 6,018,342.46 540,014.23 0.92 11,897.89 3_MWD+IFR2+MS+Sag (3) 14,905.43 90.55 258.62 3,605.22 3,337.30 -11,988.903,537.14 6,018,321.36 539,923.37 2.79 11,988.90 3_MWD+IFR2+MS+Sag (3) 15,001.76 93.46 260.43 3,601.85 3,319.80 -12,083.563,533.77 6,018,303.20 539,828.85 3.56 12,083.56 3_MWD+IFR2+MS+Sag (3) 15,095.37 94.08 261.60 3,595.70 3,305.21 -12,175.813,527.62 6,018,287.97 539,736.71 1.41 12,175.81 3_MWD+IFR2+MS+Sag (3) 15,192.89 95.32 263.04 3,587.71 3,292.22 -12,272.133,519.63 6,018,274.31 539,640.49 1.94 12,272.13 3_MWD+IFR2+MS+Sag (3) 15,287.91 94.88 264.99 3,579.26 3,282.36 -12,366.253,511.18 6,018,263.79 539,546.45 2.10 12,366.25 3_MWD+IFR2+MS+Sag (3) 15,383.18 95.01 265.18 3,571.05 3,274.22 -12,460.823,502.97 6,018,255.00 539,451.95 0.24 12,460.82 3_MWD+IFR2+MS+Sag (3) 15,476.96 96.24 265.06 3,561.85 3,266.29 -12,553.813,493.77 6,018,246.41 539,359.03 1.32 12,553.81 3_MWD+IFR2+MS+Sag (3) 15,572.45 92.65 264.81 3,554.45 3,257.88 -12,648.623,486.37 6,018,237.35 539,264.29 3.77 12,648.62 3_MWD+IFR2+MS+Sag (3) 15,667.84 88.82 264.85 3,553.23 3,249.29 -12,743.603,485.15 6,018,228.10 539,169.38 4.02 12,743.60 3_MWD+IFR2+MS+Sag (3) 15,763.17 84.99 264.73 3,558.38 3,240.65 -12,838.383,490.30 6,018,218.79 539,074.67 4.02 12,838.38 3_MWD+IFR2+MS+Sag (3) 15,858.40 84.18 265.61 3,567.36 3,232.66 -12,932.853,499.28 6,018,210.15 538,980.27 1.25 12,932.85 3_MWD+IFR2+MS+Sag (3) 15,952.50 84.07 266.46 3,577.00 3,226.19 -13,026.233,508.92 6,018,203.03 538,886.95 0.91 13,026.23 3_MWD+IFR2+MS+Sag (3) 16,047.70 85.05 266.60 3,586.02 3,220.45 -13,120.823,517.94 6,018,196.64 538,792.40 1.04 13,120.82 3_MWD+IFR2+MS+Sag (3) 16,142.99 88.09 267.21 3,591.72 3,215.32 -13,215.793,523.64 6,018,190.84 538,697.48 3.25 13,215.79 3_MWD+IFR2+MS+Sag (3) 1/6/2021 7:53:59PM COMPASS 5000.15 Build 91E Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt J Pad Definitive Survey Report Well: Wellbore: MPU J-29 MPU J-29 Survey Calculation Method:Minimum Curvature Actual @ 68.08usft Design:MPU J-29 Database:NORTH US + CANADA MD Reference:Actual @ 68.08usft North Reference: Well MPU J-29 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 16,238.26 90.74 266.34 3,592.69 3,209.96 -13,310.903,524.61 6,018,184.82 538,602.43 2.93 13,310.90 3_MWD+IFR2+MS+Sag (3) 16,332.70 90.37 265.63 3,591.78 3,203.35 -13,405.103,523.70 6,018,177.55 538,508.28 0.85 13,405.10 3_MWD+IFR2+MS+Sag (3) 16,426.80 90.68 266.87 3,590.92 3,197.20 -13,498.993,522.84 6,018,170.74 538,414.44 1.36 13,498.99 3_MWD+IFR2+MS+Sag (3) 16,522.77 90.31 268.12 3,590.09 3,193.00 -13,594.873,522.01 6,018,165.88 538,318.61 1.36 13,594.87 3_MWD+IFR2+MS+Sag (3) 16,617.86 90.31 269.26 3,589.57 3,190.83 -13,689.933,521.49 6,018,163.05 538,223.58 1.20 13,689.93 3_MWD+IFR2+MS+Sag (3) 16,712.40 90.37 269.68 3,589.01 3,189.95 -13,784.463,520.93 6,018,161.51 538,129.06 0.45 13,784.46 3_MWD+IFR2+MS+Sag (3) 16,809.09 90.99 270.38 3,587.86 3,190.00 -13,881.143,519.78 6,018,160.89 538,032.39 0.97 13,881.14 3_MWD+IFR2+MS+Sag (3) 16,904.95 90.92 271.52 3,586.27 3,191.59 -13,976.983,518.19 6,018,161.81 537,936.56 1.19 13,976.98 3_MWD+IFR2+MS+Sag (3) 17,000.11 90.18 271.93 3,585.35 3,194.46 -14,072.093,517.27 6,018,164.01 537,841.44 0.89 14,072.09 3_MWD+IFR2+MS+Sag (3) 17,095.85 91.23 271.93 3,584.18 3,197.68 -14,167.763,516.10 6,018,166.57 537,745.75 1.10 14,167.76 3_MWD+IFR2+MS+Sag (3) 17,190.97 91.23 272.33 3,582.13 3,201.22 -14,262.803,514.05 6,018,169.44 537,650.70 0.42 14,262.80 3_MWD+IFR2+MS+Sag (3) 17,286.88 90.92 271.46 3,580.33 3,204.39 -14,358.643,512.25 6,018,171.94 537,554.85 0.96 14,358.64 3_MWD+IFR2+MS+Sag (3) 17,382.04 90.55 269.50 3,579.11 3,205.18 -14,453.783,511.03 6,018,172.08 537,459.71 2.10 14,453.78 3_MWD+IFR2+MS+Sag (3) 17,475.21 90.68 268.82 3,578.11 3,203.82 -14,546.933,510.03 6,018,170.06 537,366.58 0.74 14,546.93 3_MWD+IFR2+MS+Sag (3) 17,572.38 91.54 271.25 3,576.23 3,203.88 -14,644.083,508.15 6,018,169.45 537,269.45 2.65 14,644.08 3_MWD+IFR2+MS+Sag (3) 17,666.93 91.73 272.86 3,573.53 3,207.27 -14,738.533,505.45 6,018,172.18 537,174.99 1.71 14,738.53 3_MWD+IFR2+MS+Sag (3) 17,762.45 92.28 271.33 3,570.19 3,210.76 -14,833.923,502.11 6,018,175.00 537,079.58 1.70 14,833.92 3_MWD+IFR2+MS+Sag (3) 17,831.16 91.48 269.82 3,567.94 3,211.44 -14,902.593,499.86 6,018,175.21 537,010.92 2.49 14,902.59 3_MWD+IFR2+MS+Sag (3) 17,921.00 91.48 269.82 3,565.62 3,211.16 -14,992.403,497.54 6,018,174.30 536,921.12 0.00 14,992.40 PROJECTED to TD Approved By:Checked By:Date: 1/6/2021 7:53:59PM COMPASS 5000.15 Build 91E Page 7 Chelsea Wright Digitally signed by Chelsea Wright Date: 2021.01.06 10:58:03 -09'00'Benjamin Hand Digitally signed by Benjamin Hand Date: 2021.01.07 10:12:27 -09'00' TD Shoe Depth: PBTD: No. Jts. Returned RKB RKB to BHF RKB to THF Jts. 1 2 1 1 1 167 1 1 1 58 1 Yes X No Yes X No 5.2 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?Yes X No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: Casing (Or Liner) Detail Shoe Casing Cut Joint 10 3/4 50.0 687.53 34511.74SECOND STAGERig 15:55 Cement to surface Rotate Csg Recip Csg Ft. Min. PPG9.4 Shoe @ 9318 FC @ Top of Liner #N/A9,236.00 Floats Held 557.88 1030 296.34 733.66 Spud Mud CASING RECORD County State Supv.D. Yessak / C. Demoski Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.MP J-29 Date Run 26-Dec-20 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top TXP BTC-SR Innovex 1.58 9,318.00 9,316.42 22.74 55.879 5/8 47.0 L-80 TXP BTC-SR Tenaris Csg Wt. On Hook:140,000 Type Float Collar:Innovex No. Hrs to Run:30 9.4 5 1900 10 10.7 472 4.7 100 730 Bump Plug?FIRST STAGE10Tuned Spacer 60 15.8 700 3.5 95 156.35/156.5 694.08/691.05 1250 34.34 Rig 15.8 82 Bump press Returns to surface Bump Plug? Y 0:46 12/28/2020 2,410 2410.12 9,318.009,325.00 9,101.00 CEMENTING REPORT Csg Wt. On Slips:100,000 Spud Mud Tuned Spacer 730 2.94 Stage Collar @ 60 Bump press 100 262 ES Cementer Closure OK 5208.34 56 12 420 Fresh Water 34.38 RKB to CHF Type of Shoe:Innovex Casing Crew:Doyon No. Jts. Delivered 247 No. Jts. Run 229 18 Length Measurements W/O Threads Ftg. Delivered 10,024.71 Ftg. Run 9,278.98 Ftg. Returned 745.73 Ftg. Cut Jt.16.76 Ftg. Balance 22.74 www.wellez.net WellEz Information Management LLC ver_04818br 4.5 208.34Fresh Water 1.5 ArcticCEM Lead Type 106 total 9-5/8" x 12-1/4" bowspring centralizers with 10 stop rings ran. 2 on joint #1, 1 on joints #2 to 25, every other joint #27 to 51 then every 3rd to #165. Every joint #166 to 170 below ES cementer, one one each pup joint above & below ES cementer. Casing 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 78.46 9,316.42 9,237.96 Float Collar 10 3/4 50.0 TXP BTC-SR Innovex 1.32 9,237.96 9,236.64 Casing 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 38.66 9,236.64 9,197.98 Baffle Adapter 10 3/4 50.0 TXP BTC-SR HES 1.39 9,197.98 9,196.59 Casing 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 6,767.55 9,196.59 2,429.04 Pup Joint 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 18.92 2,429.04 2,410.12 ES Cementer 10 3/4 TXP BTC-SR HES 3.73 2,410.12 2,406.39 Pup Joint 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 18.45 2,406.39 2,387.94 Casing 9 5/8 47.0 L-80 TXP BTC-SR Tenaris 2,332.07 2,387.94 55.87 Type I/II Lead 1015 2.35 Premium G Tail 400 1.17 5 Premium G Tail 270 1.17 12/28/2020 38 Spud Mud David Douglas Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or fax to 907 777-8510. Received By: Date: Date: 01/26/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU J-29 (PTD 220-070) FINAL EOW REPORT – GEOSTEERING LOGS (12/20/2020 to 01/06/2021) SFTP Transfer - Data Folders: Please include current contact information if different from above. PTD: 2200700 E-Set: 34613 Received by the AOGCC 01/26/2021 Abby Bell 01/26/2021 David Douglas Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or fax to 907 777-8510. Received By: Date: Date: 1/25/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU J-29 (PTD 220-070) FINAL LWD FORMATION EVALUATION LOGS (12/20/2020 to 01/06/2021) •ROP, DGR, AGR, ABG, ADR, EWR-M5, Wellbore Profile (2” & 5” MD/TVD Color Logs) •Final Definitive Directional Survey SFTP Transfer - Data Folders: Please include current contact information if different from above. PTD: 2200700 E-Set: 34611 Received by the AOGCC 01/25/2021 Abby Bell 01/25/2021 THE STXI'E "'ALASKA GOVERNOR MIKL DUNLLAVY January 15, 2021 Mr. Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH 2O-062 Notice of Violation - Closeout Doyon Rig 14 Milne Point Unit J-29 (PTD 2200700) Dear Mr. Myers: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov The Alaska Oil and Gas Conservation Commission (AOGCC) reviewed Hilcorp Alaska LLC (Hilcorp)'s January 5, 2021 explanation regarding continued drilling operations without addressing the diverter performance test failure (packing element close time). Drilling operations were suspended after an AOGCC Inspector contacted the Rig Supervisor on December 23, 2020 and the diverter was retested with passing results. An AOGCC Inspector witnessed a subsequent passing diverter test on January 12, 2021 after Doyon 14 was moved to Milne Point Unit J-30. AOGCC considers this enforcement action closed. Sincerely, v v Jeremy M. Price Chair, Commissioner cc: P. Brooks AOGCC Inspectors Chad Helgeson, Hilcorp Operations Manager — MPU (chel eg songhilcorp.com) Hilcorp Alaska, LLC Monty Myers Drilling Manager 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 January 5, 2021 Commissioners Jeremy Price and Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Docket Number: OTH-20-062 Dear Commissioners Price and Chmielowski, RECEIVED JAN 1 1 2021 AOGCC Doyon 14 operations: On 12/19/2020 at 19:30 hrs. the 21 %" annular was put into the cellar to pre - warm up the element. At 08:00 hrs. On 12/20/2020 we started nippling up the diverter system and the diverter system was rigged up by 12:00 hrs. We began performing the diverter function test at 01:00 hrs on 12/21/2020. After rig up was complete we closed & opened the annular approximately 6 times on a joint of 5" drill pipe attempting to warm up the element. We performed our timed diverter system test and the knife valve opened in 17 seconds and the diverter annular closed in 51 seconds. The test was submitted with these results. We rigged down test equipment and began picking up the BHA to drill surface hole. While drilling surface hole at 5884' we were contacted by Jeff Jones of the failing status of the diverter test. We shut down operations, drained the stack and re -tested the diverter at 18:00 hrs on 12/23/2020. The knife valve opened in 23 seconds and the diverter annular closed in 37 seconds. An email was sent to the AOGCC with the results and a video was also attached. Drilling operations proceeded ahead. Our plan of action to prevent this failure of occurring again is to: • Reiterate to all personnel involved in the diverter function what the passing criteria is for response times for packing elements, for all sizes. • We have sent out a field wide bulletin to all Operations Managers in Kenai, Cook Inlet, Milne Point and Prudhoe Bay, reminding them of the regulation. • The individuals that were responsible for missing the regulation have been put on notice that complying with the regulations is a condition of their employment with Hilcorp. • Going forward we will spend additional time warming the element after installation to achieve a passing result prior to drilling ahead. Hilcorp Alaska does not take violations of regulations lightly and we have and will continue spreading the message to all of our personnel in the office and in the field. Should you have any questions, please do not hesitate to call me at 907-777-8431. Sincerely, Ci tall d by M-ty MM— MontyM o Hi.,AIK A. Dnl LLC, u Technical Myers email=mmyera@hilc',com Reason. am approving this document Date 2021 01 06 1125'. 20-09'00' Monty Myers Hilcorp Alaska, LLC 1"HE STATE "'ALASKA GOVI;RNOR MIK1 1)UNLLAVY December 28, 2020 CERTIFIED MAIL — RETURN RECEIPT REQUESTED 7015 0640 0003 5321 5178 Mr. Monty Myers Drilling Manager Hilcorp Alaska LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH-20-062 Notice of Violation Milne Point Unit J-29 (PTD 2200700) Dear Mr. Myers: Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 9950 1-357 2 Main: 907.279.1433 Fax: 907.276.7542 WWW.aogcc.alaska.gov On December 20, 2020, the Alaska Oil and Gas Conservation Commission (AOGCC) received a report for a diverter system test completed earlier that same day. The test was performed on Doyon Rig 14 while preparing to drill Milne Point Unit J-29 — AOGCC witness was waived. The report included the 21 I/4 -inch diverter packing element (annular) showing the close time of 51 seconds as a passing test. By email dated December 21, 2020 AOGCC sent Hilcorp Alaska LLC (Hilcorp) the following correction: Close time for Annular is within 45 seconds for diverter of 20 inches and larger (API Standard 64, Section 12.6). Test result is "F"" For comparison, API Spec 16D, Control Systems for Drilling Well Control Equipment and Control Systems for Diverter Equipment, Section 10.2 (Diverter Control Systems); 3`d Edition, November 2018 includes the following regarding Response Times: "A diverter control system shall be capable of completing the diverting sequence in 45 seconds or less." The API documents are deemed to be good oilfield engineering practices. Prior to the start of drilling operations, Hilcorp needed to demonstrate a closure response time for the diverter packing element which was compliant with the provisions outlined in the API documents. Hilcorp provided neither evidence of repairs to the diverter control systems nor the results of a retest prior ' API Standard 64 Yd Edition (August 2017) replaces rescinded API Recommended Practice 64 which is incorporated by reference in AOGCC regulations at 20 AAC 25.527. The relevant section in API RP 64 is 5.8.2.2. Standard 64 reads as follows: "The primary diverter closing system shall be capable of operating the overboard line, flow line valves, auxiliary valves and closing the annular packing element on the pipe within 45 seconds." ■ Complete items 1, 2, and 3. ■ Print your name and address on the reverse so that we can return the card to you. ■ Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: A. Signature �J X �/ LJ Addressee B. Received ky rinted N3m-e) C. Date of Delivery D. Is delivery address different from item ? ❑ Yes If YES, enter delivery address below: 'E�40 Domestic N 3. Service Type For delivery information, II at U-1 IIII visit our website www.usps.corn". I III IIII I II IIII rl.l Certified Mail Fee II I III M $ ❑Adult Signature O Registered Mail' -D U7 Extra Services & Fees (check box, add fee as appropriate) F] Return Receipt (hardcopy) $ M Q E]Return Recelpt (electronic) $ Postmark a ❑ Certified Mall Restricted Delivery $ Here a ❑ Adult Signature Required $ 9590 9402 4351 8190 1882 46 ❑ Adult Signature Restricted Delivery $ ED ❑ Collect on Delivery Postage 2. Article Number (Transfer from service label) ❑ Collect on Delivery Restricted Delivery 0 Signature Confirmation - C3 Total Postage and Fees O Signature Confirmation 7 015 0640 0003 5321 517 8 Istricted Delivery Restricted Delivery L" r:/ Sent To (/ / 1 ---------- --- ----------- ----- ------------ Street and A . No., or PO ox r ----S------ tate,-------------------------- City, ZIP+4® ---- -- ------P ----------------- ■ Complete items 1, 2, and 3. ■ Print your name and address on the reverse so that we can return the card to you. ■ Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: A. Signature �J X �/ LJ Addressee B. Received ky rinted N3m-e) C. Date of Delivery D. Is delivery address different from item ? ❑ Yes If YES, enter delivery address below: 'E�40 PS Form 3811, July 2015 PSN 7530-02-000-9053 Domestic Return Receipt 3. Service Type ❑ Priority Mail Express® II I �III'I IIII I'I I III IIII I II IIII I II I SII II II I III ❑Adult Signature O Registered Mail' -D Adult Signature Restricted Delivery ❑ Registered Mail Restricted 9590 9402 4351 8190 1882 46 ertified Mail® 150"Certified Mail Restricted Delivery � DD} Ilvery Return Receipt for ❑ Collect on Delivery �� TMvlerctiandise 2. Article Number (Transfer from service label) ❑ Collect on Delivery Restricted Delivery 0 Signature Confirmation - 0 Insured Mail O Signature Confirmation 7 015 0640 0003 5321 517 8 Istricted Delivery Restricted Delivery PS Form 3811, July 2015 PSN 7530-02-000-9053 Domestic Return Receipt AOGCC Docket 20-062 December 28, 2020 Page 2 of 2 to the start of drilling operations. Continued operation after failure of a critical safety component is a violation of AOGCC regulations.2 Within 14 days of receipt of this letter, you are requested to provide the AOGCC with a written description of how this occurred and what has or will be done in the future to prevent its recurrence at Hilcorp-operated drilling rigs in Alaska. Information requested in this notice is in accordance 20 AAC 25.300; failure to comply with this request will be an additional violation. The AOGCC reserves the right to pursue additional enforcement action in connection with this Notice of Violation. Questions regarding this letter should be directed to Jim Regg at (907) 793- 1236 (email: jim.regg@alaska.gov). Sincerely, Jeremy,, Digitally signed by Jeremy M.Price Price Date: 2020.12.27 11:13:51 -09'00' Digitally signed by Jessie L. Jessie L. Chmielowski CIIm1eIOWSki Date: 2020.12.24 15:21:36-07'00' Jeremy M. Price Jessie L. Chmielowski Commissioner, Chair Commissioner cc: Chad Helgeson, Hilcorp Operations Manager — MPU (chel eg svn( hilcorp.com) Phoebe Brooks, AOGCC 2 On December 22, 2020 AOGCC learned that Hilcorp was in the process of drilling the surface casing section of Milne Point Unit J-29 without addressing the failed diverter component test. AOGCC instructed Hilcorp's representative on the rig to suspend drilling operations, make the necessary repairs and retest the diverter system. A video of the annular retest was provided indicating a close time of 37 seconds. Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty M Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU J-29 Hilcorp Alaska, LLC Permit to Drill Number: 220-070 Surface Location: 2670' FSL, 3383' FEL, Sec 28, T13N, R10E, UM, AK Bottomhole Location: 556' FSL, 1085' FWL, Sec 24, T13N, R09E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of October, 2020. y JMPi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a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y Jody Colombie at 11:37 am, Oct 16, 2020 '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 220-070 BOPE test to 3000 psi. Annular to 2500 psi. X X X 029-23688-00-00 X DLB 10/20/2020 X X DSR-10/16/2020 X DLB 1934 O.K. 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2020-13:48COMPASSPage 4 of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evised 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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