The URL can be used to link to this page

Home My WebLink About219-0761a. 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): Trading Bay North Unit GL: N/A BF: N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22. Logs Obtained: 23. BOTTOM 7" L-80 5,571' 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 ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD N/A SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 8-1/2" L- 63 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 4/10/2022 1602' FSL, 570' FEL, Sec 4, T9N, R13W, SM, AK 909' FSL, 1272' FEL, Sec 35, T10N, R13W, SM, AK 219-076 / 322-052 Tyonek G / Hemlock Prospect 101' 8,325' MD / 5,571' TVD HOLE SIZE AMOUNT PULLED 50-733-20064-01-00 TBU A-10RD 218864 2523116 N/A CEMENTING RECORD N/A SETTING DEPTH TVD 2527468 BOTTOM TOP 4,106' CASING WT. PER FT.GRADE N/A 228823 TOP SETTING DEPTH MD 5,528' Per 20 AAC 25.283 (i)(2) attach electronic information DEPTH SET (MD) PACKER SET (MD/TVD) 29# 8,325' (TOW) Gas-Oil Ratio:Choke Size:Water-Bbl: PRODUCTION TEST N/A Date of Test: Flow Tubing Oil-Bbl: suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A N/A Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: October 3, 2019 July 25, 2019 ADL018731, 393693, 018776 N/A N/A 8,325' MD / 5,571' TVD66 N/A 16,212' MD / 10,375' TVD WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 2:16 pm, Jun 03, 2022 Abandoned 4/10/2022 MDG xG RBDMS 6/3/2022 MDG SFD 8/12/2022 DSR-6/6/22BJM 7/3/22 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval N/A Hemlock 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Contact Email:cdinger@hilcorp.com Authorized Contact Phone: 777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: Wellbore Schematic, P&A Reports Signature w/Date: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. INSTRUCTIONS The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). 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. No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 6.3.2022 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2022.06.03 13:46:27 -08'00' Monty M Myers _____________________________________________________________________________________ Updated By: CJD 6-3-22 P&A Schematic Trading Bay Unit Well: A-10RD PTD: 219-076 API: 50-733-20064-01-00 CASING DETAIL Size Wt Grade Conn ID Top Btm 20”Conductor Pile Surface ~264’ 13-3/8”61 K-55 BTC 12.515”Surface 1,095’ 9-5/8”47 L-80 DWC/C 8.681”Surface 5,818’ 7” 29 L-80 CDC HTQ 6.184” 5,528’ 8,325’ (TOW) TUBING DETAIL 2-7/8”6.4 L-80 IBT 2.441”15,215’16,212’ JEWELRY DETAIL No Depth (MD) Depth (TVD)Item 2 8,325’5,571’WIS 7” Hydraulic Whipstock 3 8,342’5,581’7” CIBP 4 11,685’7,338 7” CIBP w/ 25ft of cement (TOC ~11,419’) 5 14,324’9,563’TOC plug (Tagged) 6 15,215’9,601’3-1/2” BHK Disconnect sub 5 15,218’9,603’2-7/8” 6.4# L-80 tubing string Cement plug was dumped ~240' above CIBP due to paraffin in the hole. - bjm Activity Date Ops Summary 2/23/2022 AK Eline crew fly to platform, inventory equipment and unit. Meet with operations, decision made to skid rig over wellhead for operations.,Conduct PJSM, operations skidded rig over A-10RD.,Spotted E-Line unit, prepped equipment and tools to start cement dump bailing work Thursday (2/24) morning. Ops bled 40 psi off well (~20 gal of FIW) to tank, SI well for overnight buildup, 0 Psi gain. 2/24/2022 Morning meeting, initiate permit, RU Eline & MU 40ft of 2" bailer (OAL = 44', OAW = 200lb, Max OD = 2"),Check tools, Arm bailer bottom, load cement in bailer. RIH, stopped at 10,000 ft to check weight, unable to get going, PU to 2800'. RBIH to 11,444' tagged several times. Determined CIBP depth and dumped 5.6 gal of cement. POOH, at surface tool covered in paraffin, clean rewire hot check and reload cement.,RIH w/run #2 and dump 5.6 gal of cement. Make 5 more runs of cement dumping on top of CIBP. Total cement dumped 39.2 gal of cement (25ft). TOC = 11,419'.,PU logging tool string w/ GR/CCL. RIH to 8,990 and make up pass at 60fpm from 8,990 to 7,500. POOH with tools. Rig Down Eline. 2/26/2022 RU test pump on top of dryhole tree, test lines, Pump 3 bbls of FIW to fill well. Pressure up to 3,683 psi. Shut off pump and held flat for 50 min. start test pressure 3,683 and end pressure 3,679 psi. Bled down fluid, RD pump. 3/30/2022 Repair #2 pump discharge piping and bottle bank leaks on accumulator. Calibrate PVT w/Canrig. P/U test assy and RIH to Hanger and attempt to M/U to 3.5"EUE 8rd hanger, un-able to make up. R/D MPD iron and BOP stack secure chains, blow down BOPE taking returns t/trip tank. (well A-10 pressure@1100hrs 0 psi),N/D BOP bell nipple and riser t/wellhead, l/d mouse hole. P/U stack and riser, inspect threads in hanger clean and chase same. Threads in good condition, wait on pup to verify thread condition. Derrickman assist Canrig flushing pits w/85deg. water and moving from pit t/pit. M/U 3.5"EUE 8rd pup t/test assy., RIH and m/u t/hanger. N/U BOP and riser t/wellhead.,Pre-Test 13-5/8 5k BOPE w/2-7/8"EUE 8rd test jt., fill stack w/filtered inlet water. observe leak on choke line w/filling stack, re-torqued choke line. Test all equipment t/250low/2500high.,Cont. Pre-Test 13-5/8 5k BOPE w/2-7/8"EUE 8rd test jt., test all equipment t/250low/2500high. 3/31/2022 Cont. pre-test of BOPE w/2-7/8"test jt., repair/replace fittings, whitey and unloader valve on test pump.,Koomey draw down test-repair #2 triplex on koomey, function koomey 5x-no leaks. Finish pre-test of BOPE w/2-7/8"test jt.. Install MWD stand pipe transducer. Install bell nipple, mouse hole.,P/U landing jt. M/U into hanger, R/U t/pump dwn the tbg. taking returns t/production. start pumping 1BPM, 50psi, 15.3bbl pumped, approx. 5BBL oil @ surface. Back out LDS, pull hanger t/floor and L/D same. L/D 2-7/8"IBT kill string-approx.. 505ft/16jts..,Circ. trip tank to remove crude residue. Pre-job on P/U 4"DP, adjust link tilt f/mouse hole. P/U 2jts. HWDP and M/U wear ring and running tool, set wear ring and run in LDS X4. L/D running tool. 4/1/2022 Continue P/up rack back 4 std of 4" S-135 XT-39 HWDP and cull jts with tool joints longer then 28" ( driller did set dn on stump and damaged saver sub and bell guide while attempting p/up jt out of mouse hole).,Adjust Kelly hose and Repair link tilt adjustment bolt / adjust link tilt kick out limit for both board Clarence / work on camera control mount / re-install re built ST-80 gauge in drillers console.,Prep pipe rack and P/up and rack back 4" S-135 14# XT-39 DP / work boat / shut power off to rig and Swap 480 volt power from production to drilling generators.,Shut dn operations and Drill crew responded to 12 gal diesel spill from E-line unit to secondary containment that just came off boat SO-1 has been completed.,Resume p/up racking back 4" S-135 14# XT-39 DP, total of 14stds picked up. monitor hole on the trip tank. install drip pan under Beyond Head.,Shut down due to Hydraulic leak on unit, repair and clean up.,Move pipe around in derrick w/air hoist. simop-set Geo-skids in place and plumb t/stand pipe and flow line.,Resume p/up racking back 4" S-135 14# XT-39 DP, total of 30stds picked up. monitor hole on the trip tank. R/D 4" equipment and R/U 5" equipment, simop-C/O Trip Tank pump. p/up racking back 5" 19.5# 4.5IF DP, total of 7stds picked up. monitor hole on the trip tank.,Lower top drive and inspect saver sub.,Remove bell guide, dress threads on saver and file burr on bell guide. remove swivel pack and rebuild, reinstall swivel pack. Install test cap on saver and test upper and lower IBOP's t/250/5000psi. simop-install 22.5deg goose neck between S-pipe/Kelly hose. 4/2/2022 R/U test sub on upper and lower IBOP, trouble shoot leaks on service loop at bridle in derrick and repair same. C/O fittings on service loop bridle. Change oil in degasser. build and treat WBM as per Haliburton Mud Engineer. Organize and re-hang tarp in cellar. prep-test equipment for upper and lower IBOP. Install camera remote panel and bracket at driller console.,(note: well A-10, 13-5/8 x 9-5/8 @92psi, 20 x 13-5/8 @90psi at 1100hrs).,Attempt test on upper and lower IBOP's- both failed. Swivel packing leaking.,Remove swivel packing and saver sub. C/O upper and lower IBOP's. Install new swivel packing, Upper and lower IBOP's, saver sub. torque all to spec. 44k on connections, 185ft# on compression rings and safety wired all bolts. (new upper IBOP ser-# 37024464-01, new lower IBOP ser# 13LK14T036).,Build 450bbl of 8.8ppgmud and transfer to RPM tanks.,Test upper and lower IBOP t/250/5000psi 5min. charted-good, fix leaks on test manifold.,Fill stand pipe, kill line, Kelly hose and found Geo-skid return valve open t/flow line. closed valve cont. filling lines and shell test t/5000psi f/5min. charted. Grease choke manifold valves, kill and choke line valves on mud-X. Cont. mixing mud.,Drain stack, M/U wear ring running tool and pull wear ring. R/U test jt.s and set test plug, fill stack. n (LAT/LONG): evation (RKB): 50-733-20064-02-00API #: Well Name: Field: County/State: TBN A-10RD2 Trading Bay North Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: 221-00021 $1,250,000 Job Name:221-00021 TBN A-10RD2 PreDrill Spud Date: Pressure up to 3,683 psi. Shut off pump and held flat for 50 min. f Determined CIBP depth and dumped 5.6 gal pp of cement. Make 5 more runs pg of cement dumping on top of CIBP. Total cement dumped 39.2 gal of cement (25ft). gggg gg POOH, at surface tool covered in paraffin, clean rewire hot check and reload cement.,RIH w/run #2 and dump 5.6 gal of cement. p p jp p g y Finish pre-test of BOPE w/2-7/8"test jt.. TOC = 11,419'. ) RBIH to 11,444' tagged several times. gg gg p L/D 2-7/8"IBT kill string-approx.. 505ft/16jts. Activity Date Ops Summary 4/3/2022 Continue r/up test equipment for bope test / AOGCC Mr. Guy Cook on board @ 07:30 hrs Platform orientation / DSM tour inspector around sub base and cellar and inspected Bopes / go to rig floor inspect equipment meet driller and pusher discuss testing and state man wanted start w/ koomey test.;Time closing of each each component all good except annular, Inspector time for bag to close was 47sec. repeated test 3 times w/ best inspector time @ 37 sec test Pre charge pressure of all bottles all with in 10% except one @ 875psi and charge same / shorten both feed and return lines to;annular by 50' and retest only gained 4 sec to 43 sec . Inspector wanted terminate testing operation tell tell bag closure time is resolved Inspector left location.;Locate and borrowed two 50' 1-1/2" Koomey hoses from rig #151 and transported to rig and prep to install same.;Plumb in and install 1-1/2" Koomey hoses from bag to Koomey unit. Clean all screens on accumulator and purge air from new hoses and pumps. Install 22.5deg. pup on TDS S-pipe.;Test annular closing time as per inspector parameters x5-closing times-25,24,22,21 sec. on 5" and 4" jts respectively.;9-5/8" x 13-3/8" = 92 psi / 13-3/8" x 20" = 90 psi;R/D 5" test jt. and R/U Jagger pump to drain stack. P/U wear ring running tool and set wear ring. Run in 4 LDS. Install new torque gauge on ST-80.;P/U 5" 19.5#DP , torqued t/35k and rack in derrick. 12jts picked up total.;cont. P/U 5" 19.5#DP , torqued t/35k and rack in derrick. 4/4/2022 Cont. P/U 5" 19.5# S-135 IF DP , torqued t/35k and rack back in derrick. 43 std total. while changing out Blatter In kommey bottle #16.;Aline torque tube and center TDS over rotary table and secure same / chk torque on TDS , Iron rough neck and tongs against each other IR and tong same w/ TDS just a little +- 600 lbs more / NOV Rep. held connection and TYD function training w/ night driller.;Pull wear ring and set test plug w/ 5" test jt and r/up test equipment and warm koomey unit while waiting on AOGCC inspector.;AOGCC Mr. Guy Cook on board @ 13:30 hrs. performed accumulator draw down and tested annular closing time, inspector time was 29 sec Pass / Continue testing BOPE, 250L / 5000H and Annular @ 250L/3500H 5/5min on chart as per regulations.;Cont. testing BOPE, multiple failure on testing equipment (test manifold). leak on gland nut on well head, tightened-retested-good. Failure on CMV#2, service valve-failed, move on to next test while rebuilding valve #2.;L/D 5" test jt. and P/U 4" test jt.. Continue test w/4"jt. Rebuild choke manifold valve #2 while testing w/4"jt. and will re-test CMV#2 w/blinds-good. Valve #6 fail. Cont. trouble shoot testing.;9-5/8" x 13-3/8" = 92 psi / 13-3/8" x 20" = 90 psi 4/5/2022 Continue w/BOPE test after replacing seal in CMV #6, test 13-5/8 5m bop t/250low and 5k high, annular t/250low 3.5k high. Test of valve #2 and #6-good.;Pre- spud meeting with all crews.;Test stand pipe manifold, stand pipe and Kelly hose. t/250 low -5k high for 5min. Function test mud pumps. L/D test jt and test equipment.;Repair leak on Beyond trip nipple, pump out the stack, install drain hoses on MPD drip pan and clean up cellar.;Replace bolts on torque tube and center up over rotary.;P/U running tool M/U landing jt. and install wear bushing. Run in LDS x4. Function- Blind rams, choke HCR while out of the hole.;P/U drift/clean out BHA #1 w/7" scraper, RIH out of derrick w/4"DP t/944ft. monitor well on trip tank.;Re-adjust Kelly hose on TDS, blocking the rotary and stump.;RIH out of derrick w/4"DP t/2000ft. monitor well on trip tank.;R/U circulating sub on stump t/standpipe, break circulation at 2BPM, work pump up to 80spm/8bpm 800psi. No noticeable returns changes at bottoms up, just dark stink water. R/D circ. sub.;Bell Nipple H2S alarms sound during circulation, crews responded by evacuating and off tour personnel mustered in galley for roll call; Drilling communicated with production operator, slowed pumps to bring H2S reading t/ a non- alarm level. Finished circulation at reduced rate.;RIH w/4"DP out of the derrick f/2000md. t/2880md.;9-5/8" x 13-3/8" = 92 psi 13-3/8" x 20" = 90 psi 4/6/2022 Continue to P/U 4'' DP F/ 2881' T/ 3130'. M/U Scraper 9 5/8 assembly. P/U 4'' DP F/ 3136' T/ 4000'. Getting the correct pipe displacement.;M/U circ hose to stump & Break circ staging up to 5 BPM. Monitoring H2S levels. While getting dirty fluid back ShakerH2S alarms went off and monitors screens showing 20 PPM. Areas were evacuated and hands mustered in the Primary muster area for roll call. Production verified the 0 reading.;Production called the all clear and operation proceeded at a reduced rate. No solids in returns or oil residue. Just dirty water.;Continue P/U 4''dp F/ 4000' T/ 7107'. Change handling equipment to 5''. P/U 5''dp F/ 7107' T/ 8410', Tag TOL @5560'md (DP) with 9-5/8 scraper. We notified the state of the H2S readings over 20 PPM in email at 6:59 4-6- 2022.;M/U circ hose to stump & Break circ @2bpm, 110psi, staging up to 5 BPM. Monitoring H2S levels. Pump 20bbl soap pill followed by 20bbl hi-vis pill, rotate and reciprocate @10rpm, trq=5.8-6k, 5bpm, 500psi, flow=20%. No solids or oil residue in returns.;Fill Trip Tank, Break out top drive, monitor well for 10minutes. POOH w/14 stds of 5", c/o handling equipment T/4", POOH w/4"dp to 9-5/8" scraper, L/D 4-1/2IF x XT39 XO. P/U WWT NRP's and equipment to rig floor.;RIH w/5"dp installing NRP's as per WWT rep. F/2900' T/ 3400'. Installing one NRP per joint. 4/7/2022 RIH w/5"dp installing NRP's as per WWT rep. F/2900' T/ 3400'. Installing one NRP per joint on stands 4-24, install two centralizers per joint on stands 25-57. Make TD connection on last stand. RIH & TD would not break out.;Trouble shoot TD. Get stand broke out 30' up. Decide to adjust torque rail as per NOV. Notice service loop was wearing on Torque rail. Remove 45 deg from Kelley hose and adjust 22 deg to get kelly hose riding better and off of serve loops.;Found coolant drip on service loop at board. Tighten fitting. Test TD break out at floor. Good. Check TD connections. Good.;Change handling equipment & RIH to tag LT on 4'' dp. Tag with 9 5/8 scraper at 5532'md dp measurement.;Circ hole clean with clean FIW 2bpm/80psi, stage up t/4bpm/250psi, called clean as per Haliburton Mud Engineer. Monitor well, fill trip tank.;POOH (strapping out w/SLM) F/ 8285 T/3750. re-locating NRP's as per MPD rep. while POOH f/ std #39-25.;Pull trip nipple and install MPD bearing, low test MPD equipment 450psi and high test 1250psi. Train crews on trapping pressure on connections. 4/8/2022 Pump through MPD putting 450 PSi on on the well to test rot bearing with NRPs. Train Crews. Mud releasing out upper seal while pulling NRPs through. Make containment plan. POOH with 5'' DP & stand bearing back on last stand. Install Trip nipple. Fix leak at air boot.;L/D scraper BHA, Clean and clear floor.;Prep for wire line coming on boat. Work boat. R/U Wire line & test CCL. Remove camera from derrick board to replace with shaker camera. Start choke valve #2 replacement.;RIH with wire line & tri point 7'' CIBP. Set depth at rig floor. RIH to 8420 & make two logging passes. Log collars at 8348' & 8306'. Put plug on depth 6' above collar at 8348. Set plug at 8342'. Good indication of release with 200 psi of line wt drop off. POOH with Eline & R/D same.;Continue changing out #2 choke manifold valve. Welder installing stop plates on torque rail plate. Modified camera mounts & install camera at board and handrail for shakers. cleaning pits. Test CMV#2 and upper/lower IBOP's 250/5000psi.;Pre-job w/WIS and Haliburton, P/U whipstock BHA#2 as per WIS & Haliburton. Shallow test MWD w/250gpm/500psi at 150ft. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: TBN A-10RD Trading Bay North Hilcorp Energy Company Composite Report , Alaska 4/10/2022 Contractor AFE #: AFE $: Job Name:221-00021 TBN A-10RD2 Drilling Spud Date: g ;RIH with wire line & tri point 7'' CIBP. Put plug on p depth 6' above collar at 8348. Set plug at 8342'. p ;Continue changing out pg #2 choke manifold valve. Welder p ypg We notified the state of the H2S readings over 20 PPM in email Finished circulation at reduced rate.;R pp ppp p p ;Bell Nipple H2S alarms sound during circulation, crews responded by pgpj evacuating and off tour personnel mustered in galley for roll call; pg test 13-5/8 5m bop t/250low and 5k high, annular t/250low 3.5k high. g pp p ShakerH2S alarms went off and monitors screens showing 20 pggp g ggy PPM. Areas were evacuated and hands mustered in the Primary muster area for roll call. 4/9/2022 M/U Whipstock to mills. RIH with whipstock T/ 3600'. Fill pipe. RIH with whipstock To top of liner at 5528'. Didn' see top of liner but seen drag at 5590'. 4K. Work pipe & drag fell off. Kelley up and fill pipe. RIH T/ 8250'. Fill pipe and orientate to 35 LHHS. RIH & set down on CIBP at 8346'.;Set Whipstock as per WIS. . Work set down wt in 5K set downs to 45K. Didn't see clear indication of shear pin but picked up free. Prep for displacement to mud.;Btm of whipstock set @ 8345', Top of whipstock set @8325.5'; Help Pre-job w/crew, production and Mud Engineers on displacing the hole t/8.8ppg LSND, walked down the line.;Pumped 20bbl soap pill followed by 20bbl hi-vis pill. Displace hole volume @2bpm/90psi, staged up pumps t/4.5bpm/590psi with returns t/pit #3, t/production header and down pipeline t/trading bay. 416bbls total pumped.;Clean pits #2 and #3 and sand trap. flange off shute t/totes, build spray bar for over board shute and install same. 4/10/2022 Start up wash bar and overboard line plugged. Attempts to free with Conduit and air. No luck. Remove blinds and dump shoot to tote in Sack Room. Unable to get to Plug. Pull apart over board line in pump room and remove plug. Reassemble lines and test. Good.;Start pumps and establish circ. #3 pit inspection hatch Leaking. Tighten same. Take slow pump rates & Start milling operations.;Mill window F/ 8325' T/ 8335' at 80-100 RPM, 250 GPM 8-12 K TQ, MW at 8.7 +. Cont. drilling 20ft new hole f/8335' t/8355', sweep hole as needed with hi-vis pill.;TOW @8325', BOW @8335', 5571TVD, up wt.=152k, dwn wt.=125k, rot wt.=140k, 275gpm, 1000psi, 100rpm, 2-4 WOB, 10-13k trq. SPR's @8325' #1pmp=20spm/190psi, 30spm/275psi, 40spm/470psi. #2pmp=20/200, 30/280, 40/450, 8.7ppg mud wt.;Sweep hole @8355' w/hi-vis sweeps. adding barite t/mud system t/ get 8.9ppg in and out.;R/U and purge kill line, choke manifold. Isolate on pit #1, line up bleed to Trip Tank, strap same. Perform FIT t/14.7ppg. 1665psi, 4.1bbl pumped, 3.4bbl bleed back, shut in @1665psi stabilized t/ 1272psi in 13min.;Monitor well f/10min. POOH f/8320' t/7585'. q@ ppp p p adding barite t/mud system t/ get 8.9ppg in and out. pg RIH & set down on CIBP at 8346'.;Set Whipstock as per WIS. pp pp ;Mill window F/ 8325' T/ 8335' at 80-100 RPM, 250 GPM 8-12 K TQ, MW at 8.7 +. Cont.gg p drilling 20ft new hole f/8335' t/8355', pp p p p production and Mud Engineers on displacing the hole t/8.8ppg LSND, ggp mud wt.p Perform FIT t/14.7ppg. 1665psi, g Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 4/20/2022 To: Department of Natural Resources Resource Evaluation 550 W 7th Ave, Suite 1100 Anchorage, AK 99501 DATA TRANSMITTAL TBF A-10RD (PTD 219-076) CIBP 4/08/2022 Please include current contact information if different from above. PTD:219-076 T36582 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.11 11:56:40 -08'00' P.I. SupvComm:Rig Coil Tubing Unit? NoRig Contractor Rig RepresentativeOperator Contractor RepresentativeWell Permit to Drill # 219-076 Sundry Approval # 322-052Operation Inspection LocationWorking Pressure, W/H Flange P Pit Fluid Measurement P Working Pressure PP Flow Rate Sensor P Operating Pressure FPP Mud Gas Separator P Fluid Level/Condition PP Degasser P Pressure Gauges PP Separator Bypass P Sufficient Valves PP Gas Detectors P Regulator Bypass PP Alarms Separate/Distinct P Actuators (4-way valves) PP Choke/Kill Line Connections PBlind Ram Handle Cover PP Reserve Pits P Control Panel, Driller PP Trip Tank P Control Panel, Remote PPFirewallPP2 or More Pumps PP Kelly or TD Valves P Independent Power Supply PP Floor Safety Valves P N2 Backup PP Driller's Console P Condition of Equipment FPPFlow MonitorPFlow Rate Indicator PPit Level Indicators P Valves PPPE P Gauges P Remote Hydraulic Choke PWell Control Trained P Gas Detection Monitor P FOV Upstream of Chokes PHousekeeping P Hydraulic Control Panel P Targeted Turns PWell Control Plan P Kill Sheet Current P Bypass Line PFAILURES:8CORRECT BY:Monopod PlatformMUD SYSTEMTBU A-10RDWorkover CLOSING UNITALASKA OIL AND GAS CONSERVATION COMMISSIONRIG INSPECTION REPORTHCR Valve(s)Manual ValvesAnnular PreventerWorking Pressure, BOP StackStack AnchoredChoke LineKill LineTargeted TurnsPipe RamsBlind RamsShane HauckBryan LafleurLocking Devices, RamsBOP STACKGuy Cook4/4/2022INSPECT DATEAOGCC INSPECTOR56Enterprise Offshore DrillingHilcorp Alaska LLCMISCELLANEOUSFlange/Hub ConnectionsDrilling Spool OutletsFlow NippleControl LinesRIG FLOORCHOKE MANIFOLD2022-0404_Rig_Hilcorp56_TB_State_A-10RD_gc rev. 5-8-189999999999VHH&RPPHQWVQH[WSDJH-%5 COMMENTSVisual rig inspection was initially started on 4/03/22 and finished on 4/4/22. The annular failed its recovery time; best time 44 sec after 1"x75' hoses were swapped out with 1"x25' hoses. The hoses were replaced again with 1 1/4"x 25' hoses and the recovery time improved. The passing recovery times were: Annular 29 sec, UPR 9 sec, LPR 9.7 sec, Blinds (simulated with UPR) 9 sec, HCR Choke 2 sec, HCR Kill 3.34 sec. Charge bottle #16 was found to have a pre-charge of 780 psi and was filled to 1000 psi. The bottle was checked again later by the rig crew (after I had left location) and the pre-charge was low again so the bottle was rebuilt and charged up to 1000 psi. All other bottles were found to have between 940 psi to 1100 psi. Test equipment performed poorly with a long list of problems including: Leaking quick connect test fitting on the hose supplying test fluid to the test joint, four leaking needle valves on the test manifold, a 1/4 turn valve on the test manifold with a broken handle that wasn't being used because of the broken handle. This 1/4 turn valve was for double blocking in the test pump. They replaced the handle with a new one from a new 1/4 turn valve, at my request, and the valve was used to stop pressure from bleeding back to the test pump. Two of the leaking needle valves were replaced as they would not hold DP and the other two were leaking out of the stem packing and had to be tightened up to work. The entire test manifold is old and the valves and fittings all appear to be in rough shape. At least one of the valves on this manifold is froze up from corrosion and cannot be utilized blocking off an entire flow path that could be used if needed. I have informed the company reps and the tool pushers that this test manifold needs to be rebuilt/replaced for future testing. 2022-0404_Rig_Hilcorp56_TB_State_A-10RD_gc rev. 5-8-185LJ,QVSHFWLRQ+LOFRUS5LJ0RQRSRG3ODWIRUP-5HJJstarted on 4/03/22 and finished on 4/4/22.annular failed its recovery time; ()Charge bottle #16 was found to have a pre-charge of 780 psi and was filled to 1000 psi. gTest equipment performed poorly Leaking quick connect test fitting four leaking needleygvalves on the test manifold, 1/4 turn valve on the test manifold ggygtest manifold is old and the valves and fittings all appear to be in rough shape. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Monopod Trading bay State A-10 RD (H2S notification) Date:Wednesday, April 6, 2022 10:09:02 PM PTD 2190760 Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Sloan Sunderland <ssunderland@hilcorp.com> Sent: Wednesday, April 6, 2022 6:59 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>; Monty Myers <mmyers@hilcorp.com>; Steve Dambacher - (C) <Steve.Dambacher@hilcorp.com> Subject: Monopod Trading bay State A-10 RD Well- Trading Bay State A-10RD Mr Regg, We are informing you that we had our H2S alarms sound during our first circulation at 2000’. The time was 0400 4-6-2022. The returns were old 3% KCL left in the hole. We had an audible alarm sound from the bell nipple and pits sensors. Sensors were showing 50 PPM at the highest. The pumps were shut down and readings went to zero. Hands mustered in primary muster area and production verified the zero reading. Pumps were started again at a slower rate for the remainder of the circulation. Operations continued on. We again circulated at 4000’ staging in and again the alarms went off but this time only to 20 PPM. At 1030 Operations were shut down again and readings went to 0. Hands mustered in primary muster area. Production again verified the 0 reading and the circulation was finished. Sloan Sunderland Hilcorp Alaska LLC Sr Drilling Forman Cookinlet Offshore Office 776-7970 Cell Phone 907-715-0591 From:Shane Hauck To:Regg, James B (OGC) Cc:Brooks, Phoebe L (OGC); Steve Dambacher - (C); Bryan Lafleur - (C); Sean McLaughlin Subject:RE: [EXTERNAL] RE: Monopod A-10rd bope test report Date:Monday, April 4, 2022 8:38:04 PM Attachments:BOP Hilcorp56 3-31-2022 revised.xlsx Mr. Regg Thanks, I have reviewed and accurate and completed finished time @ 18:00 hrs Thanks Shane R Hauck Hilcorp DSM Rig 907-776-7970 From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Monday, April 4, 2022 1:40 PM To: Shane Hauck <shauck@hilcorp.com> Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: RE: [EXTERNAL] RE: Monopod A-10rd bope test report Attached is a revised report – please review and make sure it is accurate. Changes include PTD, added Sundry #, Operation (Workover); MASP, 4 failures, and shortened remarks to fit space when printed. Still need Test Finish time. Thank you. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Shane Hauck <shauck@hilcorp.com> Sent: Monday, April 4, 2022 1:07 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL] RE: Monopod A-10rd bope test report Mr. Regg 3-31-22 2500 psi test was complete and IBOPs were chg out and tested just after midnight on 4-3- 22 Thanks Shane Trading Bay State A-10RD PTD 2190760 jbr CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Monday, April 4, 2022 11:24 AM To: Shane Hauck <shauck@hilcorp.com> Subject: [EXTERNAL] RE: Monopod A-10rd bope test report When did you finish the test prior to pulling the kill string? [does 3/31 represent when the IBOPs were replaced and retested?] Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Shane Hauck <shauck@hilcorp.com> Sent: Sunday, April 3, 2022 7:28 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Cook, Guy D (OGC) <guy.cook@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>; Steve Dambacher - (C) <Steve.Dambacher@hilcorp.com>; Bryan Lafleur - (C) <Bryan.Lafleur@hilcorp.com> Subject: Monopod A-10rd bope test report Mr. Regg Here is our Pre-test report for the pull for the 2-7/8” Kill string Not sure if I needed to send it in? but thought I be safe then sorry Thanks Shane R Hauck Hilcorp DSM Rig 907-776-7977 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor:Rig No.:56 DATE:3/31/22 Rig Rep.:Rig Phone:907-776-6677 Operator:Op. Phone:907-776-7970 Rep.:E-Mail Well Name:PTD #2190760 Sundry #322-052 Operation:Drilling:Workover:X Explor.: Test:Initial:Weekly:Bi-Weekly:Other:X Rams:250-2500 Annular:250-2500 Valves:250-2500 MASP:2955 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1 F Housekeeping P Rig P Lower Kelly 1 F PTD On Location P Hazard Sec.P Ball Type 1 P Standing Order Posted P Misc.NA Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8 5m P Pit Level Indicators P P #1 Rams 1 2 7/8 x 5 1/2 vbr P Flow Indicator P P #2 Rams 1 Blind P Meth Gas Detector P P #3 Rams 1 2-7/8 x 5 1/2 vbr P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8 manual P Inside Reel valves 0 NA HCR Valves 2 3 1/8 CIW P Kill Line Valves 2 " demco 3-1/8 CIW P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)3075 P CHOKE MANIFOLD:Pressure After Closure (psi)1275 P Quantity Test Result 200 psi Attained (sec)38 P No. Valves 16 FP Full Pressure Attained (sec)239 P Manual Chokes 2 P Blind Switch Covers:All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles # & psi (Avg.):6@2400 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures:4 Test Time:23.0 Hours Repair or replacement of equipment will be made within 3 days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3-29-09:00am Waived By Test Start Date/Time:3-30-22 @ 19:00 hrs (date)(time)Witness Test Finish Date/Time:3/31/2022 18:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Hilcorp approved to perform bope test before pulling the 2-7/8" kill string to 2500 psi w/ 2-7/8" test jt. Jim Regg waived witness; coordinate timing for witness of the 5000 psi test w/Guy Cook. All gas sensors tested good 3-29-22. FPs on CMV #2 & #7; service and retest ok. Upper & lower IBOPs failed high test - will repair once kill string is layed down and before 5000 psi test. Both IBOP chg out; HP mud line & kelly hose tested 250L and 5000H 5/5min on chart 4/3/22. Bryan Lafleur / Anthony Boyd Hilcorp Alaska Shane Hauck / Steve Dambac Trading Bay State A-10RD Test Pressure (psi): shauck@hilcorp.com Form 10-424 (Revised 02/2022)2022-0331_BOP_Hilcorp56_TB_State_A-10RD          J. Regg; 4/5/2022 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 3/08/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MRU A-10RD (PTD 219-076) Cement Dump 2/25/2022 Please include current contact information if different from above. 219-076 T36407 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.08 14:02:59 -09'00' 1Guhl, Meredith D (OGC)From:Sean Mclaughlin <Sean.Mclaughlin@hilcorp.com>Sent:Monday, February 14, 2022 3:02 PMTo:McLellan, Bryan J (OGC)Cc:Chad HelgesonSubject:RE: [EXTERNAL] TBU A-10RD (PTD 219-076)Bryan, There shouldn’t be any implications for the sidetrack or the P&A due to the lack of cement. Reservoir isolation was completed when the well was suspended in 2019. There are no hydrocarbon bearing zones behind the 7” casing. The risk of tracking casing will be mitigated and there is a lot of running room with respect to the kick tolerance volume. Regards, sean 2 ‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐ 3 ‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐ From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, February 14, 2022 1:22 PM To: Chad Helgeson <chelgeson@hilcorp.com> Cc: Sean Mclaughlin <Sean.Mclaughlin@hilcorp.com> Subject: RE: [EXTERNAL] TBU A‐10RD (PTD 219‐076) OK thanks. Do you think the lack of cement behind 7” has any implications for the sidetrack or P&A? Bryan McLellan Senior Petroleum Engineer 4Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Thursday, February 10, 2022 7:26 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] TBU A‐10RD (PTD 219‐076) Bryan, We do not have a CBL for cement on the 7” casing. When the 7” became stuck on bottom (11,782’) and we weren’t able to get circulation, we RIH and set the packer on the 7” at 5,528’. Then we went in with a cement retainer inside the 7” and squeezed 17bbls of cement at the bottom of the 7” shoe. Then the cement retainer and cement were drilled up for the production hole section. Chad From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, February 9, 2022 1:47 PM To: Chad Helgeson <chelgeson@hilcorp.com> Subject: [EXTERNAL] TBU A‐10RD (PTD 219‐076) Chad, What do you know about cement outside the 7” casing. Do you have a CBL, or any indication where TOC might be? It sounds like they were not able to circulate after the 7” casing became stuck. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250‐9193 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 5The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will notadversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate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a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a a a 3HUIRUDWLRQ'HSWK0'IW 6HH6FKHPDWLF 6HH6FKHPDWLF 0DUFK /LQHU7RS3NU=;31$ 3 W N V )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Samantha Carlisle at 1:30 pm, Feb 03, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH 9DULDQFH WR $$&E DSSURYHG ZLOO GXPS EDLO FHPHQW RQ H[LVWLQJ SOXJ ; '65 '/%%-0 ,QLWLDO %23 WHVW WR SVL 5DWHG :RUNLQJ 3UHVVXUH IRU ILUVW %23 WHVW RI WKH VHDVRQ ; dts 2/10/2022 JLC 2/10/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.02.10 15:47:24 -09'00' RBDMS SJC 021122 tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůů͗dƌĂĚŝŶŐĂǇ^ƚͲϭϬZ ĂƚĞ͗ϮͬϭͬϮϬϮϮ tĞůůEĂŵĞ͗dhͲϭϬZW/EƵŵďĞƌ͗ϱϬͲϳϯϯͲϮϬϬϲϰͲϬϭͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^ƵƐƉĞŶĚĞĚtĞůů>ĞŐ͗Eͬ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗DĂƌĐŚϭϱ͕ϮϬϮϮZŝŐ͗DŽŶŽƉŽĚZŝŐηϱϲ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍ϰϬϯĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ŽŶŶĂŵďƌƵǌ;ϴϯϬϱͿWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϭϵͲϬϳϲ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶ;ϵϬϳͿϳϳϳͲϴϰϬϱ;KͿ;ϵϬϳͿϮϮϵͲϰϴϮϰ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗^ĞĂŶDĐůĂƵŐŚůŝŶ;ϵϬϳͿϮϮϯͲϲϳϴϰ;DͿ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ϯ͕ϯϴϮƉƐŝΛϳ͕ϲϱϮ͛ds ϴ͘ϱƉƉŐ&/tĐƵƌƌĞŶƚůǇŝŶǁĞůů DĂǆǆƉĞĐƚĞĚ,W͗ϯ͕ϴϱϰƉƐŝΛϴ͕ϳϬϬ͛ds ϴ͘ϱƉƉŐŽƌŝŐŝŶĂůŐƌĂĚŝĞŶƚƉƌĞƐƐƵƌĞ DĂǆWŽƚĞŶƚŝĂů^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ͗ Ϯ͕ϵϱϱƉƐŝ hƐŝŶŐϬ͘ϭƉƐŝͬĨƚŐƌĂĚŝĞŶƚϮϬϮϱ͘ϮϴϬ;ďͿ;ϰͿ DĂǆ/ŶĐůŝŶĂƚŝŽŶϲϮ͘ϱΣĂƚϲ͕Ϭϳϰ͛D DĂǆŽŐůĞŐ͗ϳ͘ϲΣͬϭϬϬĨƚĂƚϭ͕ϭϴϮ͛D ƌŝĞĨtĞůů^ƵŵŵĂƌǇ ͲϭϬZǁĂƐĚƌŝůůĞĚĂƐĂƐŝĚĞƚƌĂĐŬŝŶϮϬϭϵĨƌŽŵDŽŶŽƉŽĚͲϭϬǁĞůůƚĂƌŐĞƚŝŶŐĂŶĞǆƉůŽƌĂƚŝŽŶƚĂƌŐĞƚƚŚĂƚǁĂƐƵŶƐƵĐĐĞƐƐĨƵů͘ ƚƚŚĞĐŽŶĐůƵƐŝŽŶŽĨƚŚĞĚƌŝůůŝŶŐǁŽƌŬƚŚĞǁĞůůǁĂƐůĞĨƚƐƵƐƉĞŶ ĚĞĚǁŝƚŚĂĐĞŵĞŶƚƉůƵŐĂŶĚ/W͘dŚĞǁĞůůŝƐĐƵƌƌĞŶƚůǇ ƉůƵŐŐĞĚďĂĐŬǁŝƚŚĐŽŵƉůĞƚĞĚǁŝƚŚĂϱϰϵ͛ŬŝůůƐƚƌŝŶŐŝŶƚŚĞǁĞůů͘ dŚĞƉƵƌƉŽƐĞŽĨƚŚŝƐƐƵŶĚƌǇŝƐƚŽƉƌĞƉĂƌĞƚŚĞĐƵƌƌĞŶƚǁĞůůďŽƌĞĂŶĚƐĞƚƵƉĨŽƌƐŝĚĞƚƌĂĐŬĂŶĚƌĞĚƌŝůůŶĞǁǁĞůů͘ ,ŝůĐŽƌƉƌĞƋƵĞƐƚƐĂǀĂƌŝĂŶĐĞƚŽϮϬϮϱ͘ϭϭϮ;ďͿĨŽƌƐĞƚƚŝŶŐĐĞŵĞŶƚƐĞŐƌĞŐĂƚŝŶŐƵŶĐĂƐĞĚĂŶĚĐĂƐĞĚƉŽƌƚŝŽŶƐŽĨƚŚĞ ǁĞůůďŽƌĞ͘dŚĞǁĞůůǁĂƐƐƵƐƉĞŶĚĞĚŝŶϮϬϭϵǁŝƚŚĂĐĞŵĞŶƚƉůƵŐŝƐŽůĂƚŝŶŐƚŚĞŽƉĞŶŚŽůĞŚǇĚƌŽĐĂƌďŽŶďĞĂƌŝŶŐǌŽŶĞƐŝŶ ĂĐĐŽƌĚĂŶĐĞǁŝƚŚϮϬϮϱ͘ϭϭϮ;ĂͿĂŶĚĂ/WƐĞƚĂďŽǀĞƚŚĞĐĂƐŝŶŐƐŚŽĞĂĐĐŽŵƉůŝƐŚĞƐƚŚĞƌĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬ Ϯϱ͘ϭϭϮ;ĐͿ΀KŶĐĞϮϱĨƚŽĨĐĞŵĞŶƚŝƐĚƵŵƉĞĚŽŶƚŚĞƉůƵŐ΁͘ tĞůůďŽƌĞEŽƚĞƐ͗ xWůƵŐŐĞĚƉĞƌϮϬϮϱ͘ϭϭϮ;ĂͿ;ϭͿ;ͿǀŝĂĚŝƐƉůĂĐĞŵĞŶƚǁŝƚŚƚŽƉŽĨĐĞŵĞŶƚĂƚϭϰ͕ϯϮϰ͛͘dŽƉŽĨŚǇĚƌŽĐĂƌďŽŶ ďĞĂƌŝŶŐǌŽŶĞŝƐϭϱ͕ϴϮϳ͛͘ x/WƐĞƚĂƚϭϭ͕ϲϴϱ͛ŝŶϳ͟ŽŶϭϬͬϳͬϮϬϭϵ xtĞůůŝƐĐƵƌƌĞŶƚůǇĨŝůůĞĚǁŝƚŚ&/t;ϴ͘ϱƉƉŐͿ xĂƐŝŶŐĂŶĚůŝŶĞƌƚĞƐƚĞĚƚŽϮ͕ϱϬϬƉƐŝϭϬͬϳͬϭϵƵŶĚĞƌWdϮϭϵͲϬϳϲ WƌĞͲƌŝŐǁŽƌŬ͗ xWƌĞƐƐƵƌĞƚĞƐƚǁĞůůͬĐĂƐŝŶŐƚŽϯ͕ϱϬϬƉƐŝ͕ĐŚĂƌƚĨŽƌϯϬŵŝŶ x^ůŝĐŬůŝŶĞͬůŝŶĞZ/,ĂŶĚƚĂŐďŽƚƚŽŵ͕ĐŽůůĞĐƚ'Zͬ> xůŝŶĞZ/,ĂŶĚĚƵŵƉϮϱĨƚ;ϯϵŐĂůΛϭ͘ϱϲŐĂůͬĨƚͿŽĨĐĞŵĞŶƚŽŶ/WĂƚϭϭ͕ϲϴϱ͛;ƐƚŝŵĂƚĞǁŽƌŬƐƚĂƌƚŝŶŐŽŶ WƌŽĐĞĚƵƌĞ͗ ϭ͘WƌĞƉDŽŶŽƉŽĚZŝŐϱϲĨŽƌǁŽƌŬĂŶĚĚƌŝůůŝŶŐ Ϯ͘^ŬŝĚZŝŐŽǀĞƌͲϭϬZĂŶĚƌŝŐƵƉ ϯ͘/ŶƐƚĂůůWs͕EƚƌĞĞ͕EhKW ϰ͘dĞƐƚKW ¾dĞƐƚKWƚŽϮϱϬͬϱϬϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘dĞƐƚĂŶŶƵůĂƌƚŽϮϱϬͬϮϱϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘;EŽƚŝĨǇ K'ϰϴŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨƚĞƐƚƚŽĂůůŽǁƚŚĞŵƚŽǁŝƚŶĞƐƐƚĞƐƚͿ͘ ΀KŶĐĞϮϱĨƚŽĨĐĞŵĞŶƚŝƐĚƵŵƉĞĚŽŶƚŚĞƉůƵŐ΁ 9DULDQFH DSSURYHG EMP ůƚĂƌŐĞƚŝŶŐĂŶĞǆƉůŽƌĂƚŝŽŶƚĂƌŐĞƚƚŚĂƚǁĂƐƵŶƐƵĐĐĞƐƐĨƵů͘ dŚĞƉƵƌƉŽƐĞŽĨƚŚŝƐƐƵŶĚƌǇŝƐƚŽ ƉƌĞƉĂƌĞƚŚĞĐƵƌƌĞŶƚǁĞůůďŽƌĞĂŶĚƐĞƚƵƉĨŽƌƐŝĚĞƚƌĂĐŬĂŶĚƌĞĚƌŝůůŶĞǁǁĞůů͘ƐĞƚƵƉĨŽƌƐŝĚĞƚƌĂĐŬĂŶĚƌĞĚƌŝůůŶĞǁǁĞůů͘ tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůů͗dƌĂĚŝŶŐĂǇ^ƚͲϭϬZ ĂƚĞ͗ϮͬϭͬϮϬϮϮ ¾ŶƐƵƌĞƚŽůĞĂǀĞ͟͞ƐĞĐƚŝŽŶƐŝĚĞŽƵƚůĞƚǀĂůǀĞƐŽƉĞŶĚƵƌŝŶŐKWƚĞƐƚŝŶŐƐŽƉƌĞƐƐƵƌĞĚŽĞƐŶŽƚ ďƵŝůĚƵƉďĞŶĞĂƚŚƚŚĞWs͘ŽŶĨŝƌŵƚŚĞĐŽƌƌĞĐƚǀĂůǀĞƐĂƌĞŽƉĞŶĞĚ͊͊͊ ¾dĞƐƚsZƐŽŶϰ͟ĂŶĚϱ͟ƚĞƐƚũŽŝŶƚ;ϱŬƚĞƐƚŽŶůĂƌŐĞƐƚĂŶĚƐŵĂůůĞƐƚWͿ ¾dĞƐƚŶŶƵůĂƌŽŶϮͲϳͬϴ͟ƚĞƐƚũŽŝŶƚ;ϮϱϬϬƉƐŝͿ ¾ZĞͲƚĞƐƚƵƉƉĞƌsZ͛ƐŽŶϮͲϳͬϴ͟ƚŽϮϱϬϬƉƐŝ;ĨŽƌƉƵůůŝŶŐŬŝůůƐƚƌŝŶŐͿ ¾ŶƐƵƌĞŐĂƐŵŽŶŝƚŽƌƐĂƌĞĐĂůŝďƌĂƚĞĚĂŶĚƚĞƐƚĞĚŝŶĐŽŶũƵŶĐƚŝŽŶǁͬKW͘ ¾/ĨƚŚĞKWŝƐƵƐĞĚƚŽƐŚƵƚŝŶŽŶƚŚĞǁĞůůŝŶĂǁĞůůĐŽŶƚƌŽůƐŝƚƵĂƚŝŽŶŽƌŝĨKWĞƋƵŝƉŵĞŶƚĐŽƵůĚ ďĞĐŽŵƉƌŽŵŝƐĞĚ͕>>KWĐŽŵƉŽŶĞŶƚƐƵƚŝůŝǌĞĚĨŽƌǁĞůůĐŽŶƚƌŽůŽƌĐŽŵƉƌŽŵŝƐĞĚŵƵƐƚďĞ ƚĞƐƚĞĚƉƌŝŽƌƚŽƚŚĞŶĞǆƚƚƌŝƉŝŶƚŽƚŚĞǁĞůůďŽƌĞ͘ ϱ͘WƵůůWs ϲ͘WƵůůŚĂŶŐĞƌĂŶĚ>Εϱϰϵ͛ŽĨϮͲϳͬϴ͟/dŬŝůůƐƚƌŝŶŐ ¾ϯͲϭͬϮ͟hϴƌĚůŝĨƚƚŚƌĞĂĚ ϳ͘^ĞƚǁĞĂƌďƵƐŚŝŶŐŝŶǁĞůůŚĞĂĚ͘ŶƐƵƌĞ/ŽĨǁĞĂƌďƵƐŚŝŶŐхϲͲϭͬϴ͟ ϴ͘^Ğƚϳ͟/WĂƚϴ͕ϯϮϬ͛ ϵ͘DĂŬĞƵƉƚŚĞt/^ϳ͟ŵĞĐŚĂŶŝĐĂůƐĞƚtŚŝƉƐƚŽĐŬ ϭϬ͘d/,ǁŝƚŚWƚŽƚŚĞǁŚŝƉƐƚŽĐŬƐĞƚƚŝŶŐĚĞƉƚŚ͘ǆĞƌĐŝƐĞĐĂƵƚŝŽŶǁŚĞŶZ/,ͬƐĞƚƚŝŶŐƐůŝƉƐǁŝƚŚǁŚŝƉƐƚŽĐŬ ĂƐƐĞŵďůǇ ¾&ŝůůƚŚĞĚƌŝůůƉŝƉĞĂŵŝŶŝŵƵŵŽĨĞǀĞƌǇϮϬƐƚĂŶĚƐŽŶƚŚĞƚƌŝƉŝŶƚŚĞŚŽůĞǁŝƚŚƚŚĞǁŚŝƉƐƚŽĐŬ ĂƐƐĞŵďůǇ͘tŝƚŚ&/t͘ ¾ǀŽŝĚƐƵĚĚĞŶƐƚĂƌƚƐĂŶĚƐƚŽƉƐǁŚŝůĞƌƵŶŶŝŶŐƚŚĞǁŚŝƉƐƚŽĐŬ͘ ¾ZĞĐŽŵŵĞŶĚƌƵŶŶŝŶŐŝŶƚŚĞŚŽůĞĂƚĂŵĂǆŝŵƵŵŽĨϵϬͲϭϮϬƐĞĐŽŶĚƐƉĞƌƐƚĂŶĚƚĂŬŝŶŐĐĂƌĞŶŽƚ ƚŽƐƉƵĚŽƌĐĂƚĐŚƚŚĞƐůŝƉƐ͘ŶƐƵƌĞƌƵŶŶŝŶŐƐƚƌŝŶŐŝƐƐƚĂƚŝŽŶĂƌǇƉƌŝŽƌƚŽŝŶƐĞƌƚŝŽŶŽĨƚŚĞƐůŝƉƐĂŶĚ ƚŚĂƚƐůŝƉƐĂƌĞƌĞŵŽǀĞĚƐůŽǁůǇǁŚĞŶƌĞůĞĂƐŝŶŐƚŚĞǁŽƌŬƐƚƌŝŶŐƚŽZ/,͘dŚĞƐĞƉƌĞĐĂƵƚŝŽŶƐĂƌĞ ƌĞƋƵŝƌĞĚƚŽĂǀŽŝĚĂŶǇǁĞĂŬĞŶŝŶŐŽĨƚŚĞǁŚŝƉƐƚŽĐŬƐŚĞĂƌŵĞĐŚĂŶŝƐŵƐĂŶĚͬŽƌƚŽĂǀŽŝĚƉĂƌƚͬ ƉƌĞƐĞƚŽŶƚŚĞƉĂĐŬĞƌ͘ ϭϭ͘KƌŝĞŶƚǁŚŝƉƐƚŽĐŬĂƐĚŝƌĞĐƚĞĚďǇƚŚĞĚŝƌĞĐƚŝŽŶĂůĚƌŝůůĞƌ͘dŚĞĚŝƌĞĐƚŝŽŶĂůƉůĂŶƐƉĞĐŝĨŝĞƐϯϬĚĞŐ>K,^͘ ϭϮ͘^ĞƚƚŚĞƚŽƉŽĨƚŚĞǁŚŝƉƐƚŽĐŬĂƚΕϴ͕ϯϬϬ͛D͘ ¾ZĞĨůŽŐ͗EŽĐĂƐĞĚŚŽůĞůŽŐƐĂǀĂŝůĂďůĞ͕'Zͬ>ůŽŐƚŽďĞƌƵŶƉƌĞͲƌŝŐ ϭϯ͘ŝƌĐƵůĂƚĞŽƵƚ&/tǁĞůůǁŝƚŚϵ͘ϮƉƉŐŵƵĚ ΎΎΎZĞŵĂŝŶŝŶŐWƌŽĐĞĚƵƌĞƚŽďĞŝŶĐůƵĚĞĚŽŶƚŚĞWĞƌŵŝƚƚŽƌŝůůĨŽƌƚŚĞƌĞĚƌŝůůƐƚĂƌƚŝŶŐĂƚƐĞĐƚŝŽŶϭϮ͘ϴΎΎΎ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘tĞůů^ĐŚĞŵĂƚŝĐƵƌƌĞŶƚ Ϯ͘tĞůů^ĐŚĞŵĂƚŝĐWƌŽƉŽƐĞĚ ϯ͘ƵƌƌĞŶƚtĞůůŚĞĂĚ^ĐŚĞŵĂƚŝĐ ϰ͘KWƌĂǁŝŶŐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗:ϭϭͬϬϳͬϭϵ ^ĐŚĞŵĂƚŝĐ dƌĂĚŝŶŐĂǇhŶŝƚ tĞůů͗ͲϭϬZ Wd͗ϮϭϵͲϬϳϲ W/͗ϱϬͲϳϯϯͲϮϬϬϲϰͲϬϭ ^/E'd/> ^ŝǌĞtƚ'ƌĂĚĞŽŶŶ/dŽƉƚŵ ϮϬ͟ŽŶĚƵĐƚŽƌWŝůĞ^ƵƌĨĂĐĞΕϮϲϰ͛ ϭϯͲϯͬϴ͟ϲϭ<ͲϱϱdϭϮ͘ϱϭϱ͟^ƵƌĨĂĐĞϭ͕Ϭϵϱ͛ ϵͲϱͬϴ͟ϰϳ>ͲϴϬtͬϴ͘ϲϴϭ͟^ƵƌĨĂĐĞϱ͕ϴϭϴ͛ ϳ͟Ϯϵ>ͲϴϬ,dYϲ͘ϭϴϰ͟ϱ͕ϱϮϴ͛ϭϭ͕ϳϱϰ͛ dh/E'd/> ϮͲϳͬϴ͟ϲ͘ϰ>ͲϴϬ/dϮ͘ϰϰϭ͟^ƵƌĨĂĐĞϱϰϵ͛ ϮͲϳͬϴ͟ϲ͘ϰ>ͲϴϬ/dϮ͘ϰϰϭ͟ϭϱ͕Ϯϭϱ͛ϭϲ͕ϮϭϮ͛ :t>Zzd/> EŽĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ/ƚĞŵ ϭϰϬ͛ϰϬ͛,ĂŶŐĞƌ Ϯϭϭ͕ϲϴϱ͛ϳ͕ϯϯϴϳ͟/W ϯϭϰ͕ϯϮϰ͛ϵ͕ϱϲϯ͛dKƉůƵŐ;dĂŐŐĞĚͿ ϰϭϱ͕Ϯϭϱ͛ϵ͕ϲϬϭ͛ϯͲϭͬϮ͟,<ŝƐĐŽŶŶĞĐƚƐƵď ϱϭϱ͕Ϯϭϴ͛ϵ͕ϲϬϯ͛ϮͲϳͬϴ͟ϲ͘ϰη>ͲϴϬƚƵďŝŶŐƐƚƌŝŶŐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗,ϭͲϮϴͲϮϮ WZKWK^ dƌĂĚŝŶŐĂǇhŶŝƚ tĞůů͗ͲϭϬZ Wd͗ϮϭϵͲϬϳϲ W/͗ϱϬͲϳϯϯͲϮϬϬϲϰͲϬϭͲϬϬ Wd͗ ϭϭ͕ϲϴϱ͛ d͗ϭϲ͕ϮϭϮ͛ ´ <ƚŽD^>сϭϬϭ͛D^>ƚŽDƵĚůŝŶĞсϲϲ͛ ϳ͟ ϭϯͲϯͬϴ͟ ϵͲϱͬϴ͟ ϲͲϭͬϴ͟ŚŽůĞ ^/E'd/> ^ŝǌĞ tƚ 'ƌĂĚĞ ŽŶŶ / dŽƉ ƚŵ ϮϬ͟ ŽŶĚƵĐƚŽƌWŝůĞ ^ƵƌĨĂĐĞ ΕϮϲϰ͛ ϭϯͲϯͬϴ͟ ϲϭ <Ͳϱϱ d ϭϮ͘ϱϭϱ͟ ^ƵƌĨĂĐĞ ϭ͕Ϭϵϱ͛ ϵͲϱͬϴ͟ ϰϳ >ͲϴϬ tͬ ϴ͘ϲϴϭ͟ ^ƵƌĨĂĐĞ ϱ͕ϴϭϴ͛ ϳ͟ Ϯϵ >ͲϴϬ ,dY ϲ͘ϭϴϰ͟ ϱ͕ϱϮϴ͛ ϭϭ͕ϳϱϰ͛ dh/E'd/> ϮͲϳͬϴ͟ ϲ͘ϰ >ͲϴϬ /d Ϯ͘ϰϰϭ͟ ϭϱ͕Ϯϭϱ͛ ϭϲ͕ϮϭϮ͛ :t>Zzd/> EŽ ĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ /ƚĞŵ ϭϰϬ͛ ϰϬ͛,ĂŶŐĞƌ Ϯ цϴ͕ϯϬϬ͛ цϱ͕ϱϰϵ͛t/^ϳ͟,ǇĚƌĂƵůŝĐtŚŝƉƐƚŽĐŬ ϯ цϴ͕ϯϮϬ͛ цϱ͕ϱϮϵ͛ϳ͟/W ϰ ϭϭ͕ϲϴϱ͛ ϳ͕ϯϯϴ ϳ͟/W ǁͬϮϱĨƚŽĨĐĞŵĞŶƚ ϱ ϭϰ͕ϯϮϰ͛ ϵ͕ϱϲϯ͛ dKƉůƵŐ;dĂŐŐĞĚͿ ϲ ϭϱ͕Ϯϭϱ͛ ϵ͕ϲϬϭ͛ ϯͲϭͬϮ͟,<ŝƐĐŽŶŶĞĐƚƐƵď ϱ ϭϱ͕Ϯϭϴ͛ ϵ͕ϲϬϯ͛ ϮͲϳͬϴ͟ϲ͘ϰη>ͲϴϬƚƵďŝŶŐƐƚƌŝŶŐ 0RQRSRG3ODWIRUP $5'&XUUHQW sĂůǀĞ͕DĂƐƚĞƌ͕/tͲ&>^͕ ϯϭͬϴϱD&͕,tK͕ƚƌŝŵ ,d͕ŽǁĞŶ͕ϯϭͬϴϱDy Ϯ͘ϱŽǁĞŶƋƵŝĐŬƵŶŝŽŶ dƵďŝŶŐŚĂŶŐĞƌ͕^ĞĂďŽĂƌĚ ^DͲͲ>͕ϭϯϱͬϴǆϯЪh ϴƌĚůŝĨƚĂŶĚƐƵƐƉ͕ǁͬϯΖ͛ƚǇƉĞ ,WsƉƌŽĨŝůĞ͕ϯͲЪ͛͛ŶƉƚ ĐŽŶƚƌŽůůŝŶĞƉŽƌƚƐ͕ƐƉĞĐƐ DŽŶŽƉŽĚWůĂƚĨŽƌŵ ͲϭϬZ ϭϯϯͬϴǆϵϱͬϴǆϮϳͬϴ DƵůƚŝͲďŽǁů͕^ĞĂďŽĂƌĚ ^DͲϮϮ͕ϭϯϱͬϴϱD&ƚŽƉǆ ϭϯϯͬϴϯD&ďŽƚƚŽŵ͕ ǁͬϰͲϮϭͬϭϲϱD^^K ĂƐŝŶŐŚĞĂĚ͕^ŚĂĨĨĞƌ< ϭϯϱͬϴϯDǆϭϯϯͬϴΖ͛^Kt͕ ǁͬϮͲϮΖ͛>WK ϭϯϯͬϴΖ͛ ϵϱͬϴΖ͛ ϮϳͬϴΖ͛ d&DŽŶŽƉŽĚͲϭϬZ ϬϭͲϭϰͲϮϮ KW &DUOLVOH6DPDQWKD-2*& )URP&KDG+HOJHVRQFKHOJHVRQ#KLOFRUSFRP! 6HQW7KXUVGD\-DQXDU\30 7R0F/HOODQ%U\DQ-2*& 6XEMHFW5(>(;7(51$/@7%6W$5'37'SOXJIRUUHGULOOVXQGU\ Ž/ŶĞĞĚƚŽĂĚĚĂƌĞƋƵĞƐƚŝŶƚŚĞƉƌŽĐĞĚƵƌĞĨŽƌĂǀĂƌŝĂŶĐĞĨƌŽŵϮϱ͘ϭϭϮ;ďͿĨŽƌĐĞŵĞŶƚĂĐƌŽƐƐƚŚĞƐŚŽĞ͍ /ĂĚĚĞĚĂůŝŶĞŝŶƉƌĞƌŝŐǁŽƌŬƚŽĚƵŵƉĐĞŵĞŶƚŽŶ/WƚŽƚŚĞƉƌŽĐĞĚƵƌĞ͘dŚĞƐĐŚĞŵĂƚŝĐĂůƌĞĂĚǇƐŚŽǁĞĚĐĞŵĞŶƚŽŶƚŚĞ ƉůƵŐ͕ƐŽ/ĚŽŶ͛ƚŶĞĞĚƚŽƵƉĚĂƚĞƚŚĂƚ͘ /ĚŽŶ͛ƚůŝŬĞƐĞĞŝŶŐƉĂŐĞƐĂůůĐƌŽƐƐĞĚŽƵƚŝŶƚŚĞĂƉƉƌŽǀĞĚƐƵŶĚƌŝĞƐ͕ĂŶĚƌĞƉůĂĐĞĚ͕ƐŽŝĨŝƚŝƐŶ͛ƚƚŽŽŵƵĐŚǁŽƌŬŽŶǇŽƵƌĞŶĚ͕ ǁĞǁŝůůũƵƐƚƌĞƐƵďŵŝƚƚŚĞǁŚŽůĞƉĂĐŬĂŐĞ͕ďƵƚ/ŬŶŽǁƚŚĞŶŝƚǁŝůůŚĂǀĞƚŽŐŽďĂĐŬƚŚƌŽƵŐŚ'ĞŽƌĞǀŝĞǁ͕ĞƚĐ͘ ŚĂĚ &ƌŽŵ͗DĐ>ĞůůĂŶ͕ƌǇĂŶ:;K'ͿфďƌǇĂŶ͘ŵĐůĞůůĂŶΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗dŚƵƌƐĚĂǇ͕:ĂŶƵĂƌǇϮϳ͕ϮϬϮϮϭϬ͗ϰϰD dŽ͗ŚĂĚ,ĞůŐĞƐŽŶфĐŚĞůŐĞƐŽŶΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗Z͗΀ydZE>΁d^ƚͲϭϬZ;WdϮϭϵͲϬϳϲͿƉůƵŐĨŽƌƌĞĚƌŝůůƐƵŶĚƌǇ zŽƵĐĂŶƐĞŶĚŵĞǇŽƵƌƉůĂŶĂŶĚ/͛ůůĂƚƚĂĐŚŝƚƚŽƚŚĞĐƵƌƌĞŶƚ^ƵŶĚƌǇŝĨƚŚĂƚŝƐĞĂƐŝĞƌĂŶĚŶŽƚƚŽŽŵĞƐƐǇ͘KƌǇŽƵĐĂŶ ƌĞƐƵďŵŝƚ͘tŚĂƚĞǀĞƌǇŽƵƉƌĞĨĞƌŝƐĨŝŶĞǁŝƚŚŵĞŝŶƚŚŝƐĐĂƐĞ͘ ZĞŐĂƌĚƐ ƌǇĂŶDĐ>ĞůůĂŶ ^ĞŶŝŽƌWĞƚƌŽůĞƵŵŶŐŝŶĞĞƌ ůĂƐŬĂKŝůΘ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ ϯϯϯtϳƚŚǀĞ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϭ ƌǇĂŶ͘ŵĐůĞůůĂŶΛĂůĂƐŬĂ͘ŐŽǀ нϭ;ϵϬϳͿϮϱϬͲϵϭϵϯ &ƌŽŵ͗ŚĂĚ,ĞůŐĞƐŽŶфĐŚĞůŐĞƐŽŶΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗dŚƵƌƐĚĂǇ͕:ĂŶƵĂƌǇϮϳ͕ϮϬϮϮϭϬ͗ϬϱD &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH dŽ͗DĐ>ĞůůĂŶ͕ƌǇĂŶ:;K'ͿфďƌǇĂŶ͘ŵĐůĞůůĂŶΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗Z͗΀ydZE>΁d^ƚͲϭϬZ;WdϮϭϵͲϬϳϲͿƉůƵŐĨŽƌƌĞĚƌŝůůƐƵŶĚƌǇ tŚĞŶ/ǁĂƐƌĞĂĚŝŶŐƚŚĞƌĞŐƵůĂƚŝŽŶƐ/ǁĂƐĂƉƉůǇŝŶŐϮϱ͘ϭϭϮ;ĂͿ͕ďƵƚĚŝĚŶ͛ƚƌĞĂĚƚŚĞŵƚŚĂƚ/ŶĞĞĚĞĚƚŽĚŽĂ͕ď͕ĂŶĚĐ͘/ ĨŝŐƵƌĞĚŝĨǁĞŵĞƚĂ͕ǁĞǁŽƵůĚŶ͛ƚŶĞĞĚƚŽƐĞƚƉůƵŐƐĨŽƌďĂŶĚĐƚŽŽ͘/ƚǁĂƐĚĞĨŝŶŝƚĞůǇĂǁĞŝƌĚǁĂǇŝƚǁĂƐůĞĨƚ͘ tŽƵůĚǇŽƵůŝŬĞŵĞƚŽƐƵďŵŝƚĂŶĞǁƉƌŽĐĞĚƵƌĞǁŝƚŚƚŚĞƉůĂĐŝŶŐƚŚĞƌĞƋƵŝƌĞĚϮϱ͛ŽĨĐĞŵĞŶƚŽŶƉůƵŐǁŝƚŚĂĚƵŵƉďĂŝůĞƌĂƚ ϭϭ͕ϲϴϱ͍͛/ĐĂŶĞŝƚŚĞƌƌĞƐƵďŵŝƚƚŚĞǁŚŽůĞƉĂĐŬĂŐĞƚŽǇŽƵŽƌƵƉĚĂƚĞƚŚĞƉƌŽĐĞĚƵƌĞ͘>ĞƚŵĞŬŶŽǁǇŽƵƌƉƌĞĨĞƌĞŶĐĞ͘ ŚĂĚ &ƌŽŵ͗DĐ>ĞůůĂŶ͕ƌǇĂŶ:;K'ͿфďƌǇĂŶ͘ŵĐůĞůůĂŶΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗tĞĚŶĞƐĚĂǇ͕:ĂŶƵĂƌǇϮϲ͕ϮϬϮϮϲ͗ϭϭWD dŽ͗ŚĂĚ,ĞůŐĞƐŽŶфĐŚĞůŐĞƐŽŶΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗΀ydZE>΁d^ƚͲϭϬZ;WdϮϭϵͲϬϳϲͿƉůƵŐĨŽƌƌĞĚƌŝůůƐƵŶĚƌǇ ŚĂĚ͕ dŚĞƉƌŽƉŽƐĞĚǁĞůůďŽƌĞĚŝĂŐƌĂŵŝŶǇŽƵƌƐƵŶĚƌǇĂƉƉůŝĐĂƚŝŽŶƐŚŽǁƐĂĐĞŵĞŶƚĐĂƉŽŶƚŽƉŽĨƚŚĞďƌŝĚŐĞƉůƵŐĂƚϭϭϲϴϱ͕͛ďƵƚ ƚŚĞƌĞŝƐŶŽĚŝƐĐƵƐƐŝŽŶŽĨƉůĂĐŝŶŐĐĞŵĞŶƚŽŶƚŽƉŽĨƚŚĞƉůƵŐŝŶƚŚĞƉƌŽĐĞĚƵƌĞ͘ >ŽŽŬŝŶŐďĂĐŬĂƚƚŚĞŚŝƐƚŽƌǇ͕'ƵǇ^ĐŚǁĂƌƚǌĂůůŽǁĞĚƚŚĞĐĞŵĞŶƚĐĂƉƚŽďĞŽŵŝƚƚĞĚĂƚƚŚĞƚŝŵĞƚŽĨĂĐŝůŝƚĂƚĞƐĞƚƚŝŶŐĂ ǁŚŝƉƐƚŽĐŬŽŶƚŽƉŽĨŝƚ͘^ŝŶĐĞǇŽƵƌƉůĂŶƐŚĂǀĞĐŚĂŶŐĞĚĂŶĚƚŚĞǁŚŝƉƐƚŽĐŬǁŝůůďĞƐĞƚŵƵĐŚŚŝŐŚĞƌ͕ŽŶƚŽƉŽĨĂŶŽƚŚĞƌ /W͕ǇŽƵƐŚŽƵůĚƉůĂŶƚŽƉůĂĐĞĐĞŵĞŶƚŽŶƚŽƉŽĨƚŚĞĞǆŝƐƚŝŶŐďƌŝĚŐĞƉůƵŐĂƚϭϭϲϴϱ͛ŵĚƚŽŝƐŽůĂƚĞƚŚĞĐĂƐĞĚŚŽůĞĨƌŽŵƚŚĞ ŽƉĞŶŚŽůĞƉĞƌϮϬϮϱ͘ϭϭϮ;ďͿ͘/ƌĞĐŽŐŶŝǌĞƚŚĂƚǇŽƵĐĂŶ͛ƚĞĂƐŝůǇƉůĂĐĞĐĞŵĞŶƚϱϬ͛ďĞůŽǁƚŚĞƐŚŽĞ͕ƐŽĂĐĂƉŽŶƚŽƉŽĨƚŚĞ ƉůƵŐǁŝůůďĞĂĐĐĞƉƚĂďůĞ͘ ZĞŐĂƌĚƐ ƌǇĂŶDĐ>ĞůůĂŶ ^ĞŶŝŽƌWĞƚƌŽůĞƵŵŶŐŝŶĞĞƌ ůĂƐŬĂKŝůΘ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ ϯϯϯtϳƚŚǀĞ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϭ ƌǇĂŶ͘ŵĐůĞůůĂŶΛĂůĂƐŬĂ͘ŐŽǀ нϭ;ϵϬϳͿϮϱϬͲϵϭϵϯ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arlisle, Samantha J (OGC) From:Donna Ambruz <dambruz@hilcorp.com> Sent:Friday, January 28, 2022 12:53 PM To:Carlisle, Samantha J (OGC); McLellan, Bryan J (OGC) Cc:Chad Helgeson Subject:A-10RD AOGCC 10-403 PTD 219-076 Submitted 01-17-22 - Sundry Application WITHDRAWAL Bryan ‐ Please withdraw/cancel the above‐referenced sundry per today’s teleconference with Chad Helgeson.. We will re‐submit a new Sundry Application shortly. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 ‐ Direct dambruz@hilcorp.com From: Carlisle, Samantha J (OGC) <samantha.carlisle@alaska.gov> Sent: Tuesday, January 18, 2022 8:55 AM To: Donna Ambruz <dambruz@hilcorp.com> Cc: Chad Helgeson <chelgeson@hilcorp.com> Subject: [EXTERNAL] RE: A‐10RD AOGCC 10‐403 PTD 219‐076 Submitted 01‐17‐22 ‐ Sundry Application Received for processing From: Donna Ambruz <dambruz@hilcorp.com> Sent: Monday, January 17, 2022 9:06 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Chad Helgeson <chelgeson@hilcorp.com> Subject: A‐10RD AOGCC 10‐403 PTD 219‐076 Submitted 01‐17‐22 ‐ Sundry Application Application for Sundry Approval Thank you. Donna Ambruz CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe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a a /HQJWK 6L]H / 79'%XUVW SVL 0' SVL SVL a 35(6(17:(//&21',7,216800$5< 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 $33/,&$7,21)25681'5<$33529$/6 $$& $'/$'/$'/ &HQWHUSRLQW'U6XLWH$QFKRUDJH$. +LOFRUS$ODVND//& 1RUWK7UDGLQJ%D\)LHOG8QGHILQHG7\RQHN*DQG+HPORFN3URVSHFW 6WDWHZLGH6SDFLQJ 7UDGLQJ%D\6W$5' 7XELQJ*UDGH/7XELQJ0'IW 0' 79'1$1$ 3HUIRUDWLRQ'HSWK79'IW7XELQJ6L]H.LOO6WULQJ ,KHUHE\FHUWLI\WKDWWKHIRUHJRLQJLVWUXHDQGWKHSURFHGXUHDSSURYHGKHUHLQZLOOQRWEHGHYLDWHGIURPZLWKRXWSULRUZULWWHQDSSURYDO $XWKRUL]HG1DPHDQG 'LJLWDO6LJQDWXUHZLWK'DWH $2*&&86(21/< 'DQ0DUORZH2SHUDWLRQV0DQDJHU a 3 W N V )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Samantha Carlisle at 8:52 am, Jan 18, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH DSR-1/18/22 10-407 Initial BOP and annular tests to RWP (5000 psi). Subsequent tests to 3500 psi. DLB 01/20/2022 WITHDRAWN BY OPERATOR 012822 tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůů͗dƌĂĚŝŶŐĂǇ^ƚͲϭϬZ ĂƚĞ͗ϭͬϭϮͬϮϬϮϮ tĞůůEĂŵĞ͗dhͲϭϬZW/EƵŵďĞƌ͗ϱϬͲϳϯϯͲϮϬϬϲϰͲϬϭͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^ƵƐƉĞŶĚĞĚtĞůů>ĞŐ͗Eͬ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗DĂƌĐŚϭϱ͕ϮϬϮϮZŝŐ͗DŽŶŽƉŽĚZŝŐηϱϲ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍ϰϬϯĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ŽŶŶĂŵďƌƵǌ;ϴϯϬϱͿWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϭϵͲϬϳϲ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶ;ϵϬϳͿϳϳϳͲϴϰϬϱ;KͿ;ϵϬϳͿϮϮϵͲϰϴϮϰ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗^ĞĂŶDĐůĂƵŐŚůŝŶ;ϵϬϳͿϮϮϯͲϲϳϴϰ;DͿ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ϯ͕ϯϴϮƉƐŝΛϳ͕ϲϱϮ͛ds ϴ͘ϱƉƉŐ&/tĐƵƌƌĞŶƚůǇŝŶǁĞůů DĂǆǆƉĞĐƚĞĚ,W͗ϯ͕ϴϱϰƉƐŝΛϴ͕ϳϬϬ͛ds ϴ͘ϱƉƉŐŽƌŝŐŝŶĂůŐƌĂĚŝĞŶƚƉƌĞƐƐƵƌĞ DĂǆWŽƚĞŶƚŝĂů^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ͗ Ϯ͕ϵϱϱƉƐŝ hƐŝŶŐϬ͘ϭƉƐŝͬĨƚŐƌĂĚŝĞŶƚϮϬϮϱ͘ϮϴϬ;ďͿ;ϰͿ DĂǆ/ŶĐůŝŶĂƚŝŽŶϲϮ͘ϱΣĂƚϲ͕Ϭϳϰ͛D DĂǆŽŐůĞŐ͗ϳ͘ϲΣͬϭϬϬĨƚĂƚϭ͕ϭϴϮ͛D ƌŝĞĨtĞůů^ƵŵŵĂƌǇ ͲϭϬZǁĂƐĚƌŝůůĞĚĂƐĂƐŝĚĞƚƌĂĐŬŝŶϮϬϭϵĨƌŽŵDŽŶŽƉŽĚͲϭϬǁĞůůƚĂƌŐĞƚŝŶŐĂŶĞǆƉůŽƌĂƚŝŽŶƚĂƌŐĞƚƚŚĂƚǁĂƐƵŶƐƵĐĐĞƐƐĨƵů͘ ƚƚŚĞĐŽŶĐůƵƐŝŽŶŽĨƚŚĞĚƌŝůůŝŶŐǁŽƌŬƚŚĞǁĞůůǁĂƐůĞĨƚƐƵƐƉĞŶĚĞĚǁŝƚŚĂĐĞŵĞŶƚƉůƵŐĂŶĚ/W͘dŚĞǁĞůůŝƐĐƵƌƌĞŶƚůǇ ƉůƵŐŐĞĚďĂĐŬǁŝƚŚĐŽŵƉůĞƚĞĚǁŝƚŚĂϱϰϵ͛ŬŝůůƐƚƌŝŶŐŝŶƚŚĞǁĞůů͘ dŚĞƉƵƌƉŽƐĞŽĨƚŚŝƐƐƵŶĚƌǇŝƐƚŽƉƌĞƉĂƌĞƚŚĞĐƵƌƌĞŶƚǁĞůůďŽƌĞĂŶĚƐĞƚƵƉĨŽƌƐŝĚĞƚƌĂĐŬŽĨŶĞǁǁĞůů͘ tĞůůďŽƌĞEŽƚĞƐ͗ xWůƵŐŐĞĚƉĞƌϮϬϮϱ͘ϭϭϮ;ĂͿ;ϭͿ;ͿǀŝĂĚŝƐƉůĂĐĞŵĞŶƚǁŝƚŚƚŽƉŽĨĐĞŵĞŶƚĂƚϭϰ͕ϯϮϰ͛͘dŽƉŽĨŚǇĚƌŽĐĂƌďŽŶ ďĞĂƌŝŶŐǌŽŶĞŝƐϭϱ͕ϴϮϳ͛͘ x/WƐĞƚĂƚϭϭ͕ϲϴϱ͛ŝŶϳ͟ŽŶϭϬͬϳͬϮϬϭϵ xtĞůůŝƐĐƵƌƌĞŶƚůǇĨŝůůĞĚǁŝƚŚ&/t;ϴ͘ϱƉƉŐͿ xĂƐŝŶŐĂŶĚůŝŶĞƌƚĞƐƚĞĚƚŽϮ͕ϱϬϬƉƐŝϭϬͬϳͬϭϵƵŶĚĞƌWdϮϭϵͲϬϳϲ WƌĞͲƌŝŐǁŽƌŬ͗ xWƌĞƐƐƵƌĞƚĞƐƚǁĞůůͬĐĂƐŝŶŐƚŽϯ͕ϱϬϬƉƐŝ͕ĐŚĂƌƚĨŽƌϯϬŵŝŶ x^ůŝĐŬůŝŶĞͬůŝŶĞZ/,ĂŶĚƚĂŐďŽƚƚŽŵ͕ĐŽůůĞĐƚ'Zͬ> WƌŽĐĞĚƵƌĞ͗ ϭ͘WƌĞƉDŽŶŽƉŽĚZŝŐϱϲĨŽƌǁŽƌŬĂŶĚĚƌŝůůŝŶŐ Ϯ͘^ŬŝĚZŝŐŽǀĞƌͲϭϬZĂŶĚƌŝŐƵƉ ϯ͘/ŶƐƚĂůůWs͕EƚƌĞĞ͕EhKW ϰ͘dĞƐƚKW ¾dĞƐƚKWƚŽϮϱϬͬϱϬϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘dĞƐƚĂŶŶƵůĂƌƚŽϮϱϬͬϮϱϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘;EŽƚŝĨǇ K'ϰϴŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨƚĞƐƚƚŽĂůůŽǁƚŚĞŵƚŽǁŝƚŶĞƐƐƚĞƐƚͿ͘ ¾ŶƐƵƌĞƚŽůĞĂǀĞ͟͞ƐĞĐƚŝŽŶƐŝĚĞŽƵƚůĞƚǀĂůǀĞƐŽƉĞŶĚƵƌŝŶŐKWƚĞƐƚŝŶŐƐŽƉƌĞƐƐƵƌĞĚŽĞƐŶŽƚ ďƵŝůĚƵƉďĞŶĞĂƚŚƚŚĞWs͘ŽŶĨŝƌŵƚŚĞĐŽƌƌĞĐƚǀĂůǀĞƐĂƌĞŽƉĞŶĞĚ͊͊͊ ¾dĞƐƚsZƐŽŶϰ͟ĂŶĚϱ͟ƚĞƐƚũŽŝŶƚ;ϱŬƚĞƐƚŽŶůĂƌŐĞƐƚĂŶĚƐŵĂůůĞƐƚWͿ ¾dĞƐƚŶŶƵůĂƌŽŶϮͲϳͬϴ͟ƚĞƐƚũŽŝŶƚ;ϮϱϬϬƉƐŝͿ ¾ZĞͲƚĞƐƚƵƉƉĞƌsZ͛ƐŽŶϮͲϳͬϴ͟ƚŽϮϱϬϬƉƐŝ;ĨŽƌƉƵůůŝŶŐŬŝůůƐƚƌŝŶŐͿ ¾ŶƐƵƌĞŐĂƐŵŽŶŝƚŽƌƐĂƌĞĐĂůŝďƌĂƚĞĚĂŶĚƚĞƐƚĞĚŝŶĐŽŶũƵŶĐƚŝŽŶǁͬKW͘ Initial BOP and annular test to 5000 psi RWP, unless this rig has been working continuously on another well prior to moving to A-11. -bjm dŽƉŽĨŚǇĚƌŽĐĂƌďŽŶ ďĞĂƌŝŶŐǌŽŶĞŝƐϭϱ͕ϴϮϳ͛͘ Subsequent BOP tests to 3500 psi. -bjm tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůů͗dƌĂĚŝŶŐĂǇ^ƚͲϭϬZ ĂƚĞ͗ϭͬϭϮͬϮϬϮϮ ¾/ĨƚŚĞKWŝƐƵƐĞĚƚŽƐŚƵƚŝŶŽŶƚŚĞǁĞůůŝŶĂǁĞůůĐŽŶƚƌŽůƐŝƚƵĂƚŝŽŶŽƌŝĨKWĞƋƵŝƉŵĞŶƚĐŽƵůĚ ďĞĐŽŵƉƌŽŵŝƐĞĚ͕>>KWĐŽŵƉŽŶĞŶƚƐƵƚŝůŝǌĞĚĨŽƌǁĞůůĐŽŶƚƌŽůŽƌĐŽŵƉƌŽŵŝƐĞĚŵƵƐƚďĞ ƚĞƐƚĞĚƉƌŝŽƌƚŽƚŚĞŶĞǆƚƚƌŝƉŝŶƚŽƚŚĞǁĞůůďŽƌĞ͘ ϱ͘WƵůůWs ϲ͘WƵůůŚĂŶŐĞƌĂŶĚ>Εϱϰϵ͛ŽĨϮͲϳͬϴ͟/dŬŝůůƐƚƌŝŶŐ ¾ϯͲϭͬϮ͟hϴƌĚůŝĨƚƚŚƌĞĂĚ ϳ͘^ĞƚǁĞĂƌďƵƐŚŝŶŐŝŶǁĞůůŚĞĂĚ͘ŶƐƵƌĞ/ŽĨǁĞĂƌďƵƐŚŝŶŐхϲͲϭͬϴ͟ ϴ͘^Ğƚϳ͟/WĂƚϴ͕ϯϮϬ͛ ϵ͘DĂŬĞƵƉƚŚĞt/^ϳ͟ŵĞĐŚĂŶŝĐĂůƐĞƚtŚŝƉƐƚŽĐŬ ϭϬ͘d/,ǁŝƚŚWƚŽƚŚĞǁŚŝƉƐƚŽĐŬƐĞƚƚŝŶŐĚĞƉƚŚ͘ǆĞƌĐŝƐĞĐĂƵƚŝŽŶǁŚĞŶZ/,ͬƐĞƚƚŝŶŐƐůŝƉƐǁŝƚŚǁŚŝƉƐƚŽĐŬ ĂƐƐĞŵďůǇ ¾&ŝůůƚŚĞĚƌŝůůƉŝƉĞĂŵŝŶŝŵƵŵŽĨĞǀĞƌǇϮϬƐƚĂŶĚƐŽŶƚŚĞƚƌŝƉŝŶƚŚĞŚŽůĞǁŝƚŚƚŚĞǁŚŝƉƐƚŽĐŬ ĂƐƐĞŵďůǇ͘tŝƚŚ&/t͘ ¾ǀŽŝĚƐƵĚĚĞŶƐƚĂƌƚƐĂŶĚƐƚŽƉƐǁŚŝůĞƌƵŶŶŝŶŐƚŚĞǁŚŝƉƐƚŽĐŬ͘ ¾ZĞĐŽŵŵĞŶĚƌƵŶŶŝŶŐŝŶƚŚĞŚŽůĞĂƚĂŵĂǆŝŵƵŵŽĨϵϬͲϭϮϬƐĞĐŽŶĚƐƉĞƌƐƚĂŶĚƚĂŬŝŶŐĐĂƌĞŶŽƚ ƚŽƐƉƵĚŽƌĐĂƚĐŚƚŚĞƐůŝƉƐ͘ŶƐƵƌĞƌƵŶŶŝŶŐƐƚƌŝŶŐŝƐƐƚĂƚŝŽŶĂƌǇƉƌŝŽƌƚŽŝŶƐĞƌƚŝŽŶŽĨƚŚĞƐůŝƉƐĂŶĚ ƚŚĂƚƐůŝƉƐĂƌĞƌĞŵŽǀĞĚƐůŽǁůǇǁŚĞŶƌĞůĞĂƐŝŶŐƚŚĞǁŽƌŬƐƚƌŝŶŐƚŽZ/,͘dŚĞƐĞƉƌĞĐĂƵƚŝŽŶƐĂƌĞ ƌĞƋƵŝƌĞĚƚŽĂǀŽŝĚĂŶǇǁĞĂŬĞŶŝŶŐŽĨƚŚĞǁŚŝƉƐƚŽĐŬƐŚĞĂƌŵĞĐŚĂŶŝƐŵƐĂŶĚͬŽƌƚŽĂǀŽŝĚƉĂƌƚͬ ƉƌĞƐĞƚŽŶƚŚĞƉĂĐŬĞƌ͘ ϭϭ͘KƌŝĞŶƚǁŚŝƉƐƚŽĐŬĂƐĚŝƌĞĐƚĞĚďǇƚŚĞĚŝƌĞĐƚŝŽŶĂůĚƌŝůůĞƌ͘dŚĞĚŝƌĞĐƚŝŽŶĂůƉůĂŶƐƉĞĐŝĨŝĞƐϯϬĚĞŐ>K,^͘ ϭϮ͘^ĞƚƚŚĞƚŽƉŽĨƚŚĞǁŚŝƉƐƚŽĐŬĂƚΕϴ͕ϯϬϬ͛D͘ ¾ZĞĨůŽŐ͗EŽĐĂƐĞĚŚŽůĞůŽŐƐĂǀĂŝůĂďůĞ͕'Zͬ>ůŽŐƚŽďĞƌƵŶƉƌĞͲƌŝŐ ϭϯ͘ŝƌĐƵůĂƚĞŽƵƚ&/tǁĞůůǁŝƚŚϵ͘ϮƉƉŐŵƵĚ ΎΎΎZĞŵĂŝŶŝŶŐWƌŽĐĞĚƵƌĞƚŽďĞŝŶĐůƵĚĞĚŽŶƚŚĞWĞƌŵŝƚƚŽƌŝůůĨŽƌƚŚĞƌĞĚƌŝůůƐƚĂƌƚŝŶŐĂƚƐĞĐƚŝŽŶϭϮ͘ϴΎΎΎ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘tĞůů^ĐŚĞŵĂƚŝĐƵƌƌĞŶƚ Ϯ͘tĞůů^ĐŚĞŵĂƚŝĐWƌŽƉŽƐĞĚ ϯ͘ƵƌƌĞŶƚtĞůůŚĞĂĚ^ĐŚĞŵĂƚŝĐ ϰ͘KWƌĂǁŝŶŐ Proposed diagram shows cement on plug. Need to place cement cap on top of CIBP at 11685' md. BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗:ϭϭͬϬϳͬϭϵ ^ĐŚĞŵĂƚŝĐ dƌĂĚŝŶŐĂǇhŶŝƚ tĞůů͗ͲϭϬZ Wd͗ϮϭϵͲϬϳϲ W/͗ϱϬͲϳϯϯͲϮϬϬϲϰͲϬϭ ^/E'd/> ^ŝǌĞtƚ'ƌĂĚĞŽŶŶ/dŽƉƚŵ ϮϬ͟ŽŶĚƵĐƚŽƌWŝůĞ^ƵƌĨĂĐĞΕϮϲϰ͛ ϭϯͲϯͬϴ͟ϲϭ<ͲϱϱdϭϮ͘ϱϭϱ͟^ƵƌĨĂĐĞϭ͕Ϭϵϱ͛ ϵͲϱͬϴ͟ϰϳ>ͲϴϬtͬϴ͘ϲϴϭ͟^ƵƌĨĂĐĞϱ͕ϴϭϴ͛ ϳ͟Ϯϵ>ͲϴϬ,dYϲ͘ϭϴϰ͟ϱ͕ϱϮϴ͛ϭϭ͕ϳϱϰ͛ dh/E'd/> ϮͲϳͬϴ͟ϲ͘ϰ>ͲϴϬ/dϮ͘ϰϰϭ͟^ƵƌĨĂĐĞϱϰϵ͛ ϮͲϳͬϴ͟ϲ͘ϰ>ͲϴϬ/dϮ͘ϰϰϭ͟ϭϱ͕Ϯϭϱ͛ϭϲ͕ϮϭϮ͛ :t>Zzd/> EŽĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ/ƚĞŵ ϭϰϬ͛ϰϬ͛,ĂŶŐĞƌ Ϯϭϭ͕ϲϴϱ͛ϳ͕ϯϯϴϳ͟/W ϯϭϰ͕ϯϮϰ͛ϵ͕ϱϲϯ͛dKƉůƵŐ;dĂŐŐĞĚͿ ϰϭϱ͕Ϯϭϱ͛ϵ͕ϲϬϭ͛ϯͲϭͬϮ͟,<ŝƐĐŽŶŶĞĐƚƐƵď ϱϭϱ͕Ϯϭϴ͛ϵ͕ϲϬϯ͛ϮͲϳͬϴ͟ϲ͘ϰη>ͲϴϬƚƵďŝŶŐƐƚƌŝŶŐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗,ϭͲϭϮͲϮϮ WZKWK^ dƌĂĚŝŶŐĂǇhŶŝƚ tĞůů͗ͲϭϬZ Wd͗ϮϭϵͲϬϳϲ W/͗ϱϬͲϳϯϯͲϮϬϬϲϰͲϬϭͲϬϬ ^/E'd/> ^ŝǌĞtƚ'ƌĂĚĞŽŶŶ/dŽƉƚŵ ϮϬ͟ŽŶĚƵĐƚŽƌWŝůĞ^ƵƌĨĂĐĞΕϮϲϰ͛ ϭϯͲϯͬϴ͟ϲϭ<ͲϱϱdϭϮ͘ϱϭϱ͟^ƵƌĨĂĐĞϭ͕Ϭϵϱ͛ ϵͲϱͬϴ͟ϰϳ>ͲϴϬtͬϴ͘ϲϴϭ͟^ƵƌĨĂĐĞϱ͕ϴϭϴ͛ ϳ͟Ϯϵ>ͲϴϬ,dYϲ͘ϭϴϰ͟ϱ͕ϱϮϴ͛ϭϭ͕ϳϱϰ͛ dh/E'd/> ϮͲϳͬϴ͟ϲ͘ϰ>ͲϴϬ/dϮ͘ϰϰϭ͟ϭϱ͕Ϯϭϱ͛ϭϲ͕ϮϭϮ͛ :t>Zzd/> EŽĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ/ƚĞŵ ϭϰϬ͛ϰϬ͛,ĂŶŐĞƌ Ϯцϴ͕ϯϬϬ͛цϱ͕ϱϰϵ͛t/^ϳ͟,ǇĚƌĂƵůŝĐtŚŝƉƐƚŽĐŬ ϯцϴ͕ϯϮϬ͛цϱ͕ϱϮϵ͛ϳ͟/W ϰϭϭ͕ϲϴϱ͛ϳ͕ϯϯϴϳ͟/W ϱϭϰ͕ϯϮϰ͛ϵ͕ϱϲϯ͛dKƉůƵŐ;dĂŐŐĞĚͿ ϲϭϱ͕Ϯϭϱ͛ϵ͕ϲϬϭ͛ϯͲϭͬϮ͟,<ŝƐĐŽŶŶĞĐƚƐƵď ϱϭϱ͕Ϯϭϴ͛ϵ͕ϲϬϯ͛ϮͲϳͬϴ͟ϲ͘ϰη>ͲϴϬƚƵďŝŶŐƐƚƌŝŶŐ 0RQRSRG3ODWIRUP $5'&XUUHQW sĂůǀĞ͕DĂƐƚĞƌ͕/tͲ&>^͕ ϯϭͬϴϱD&͕,tK͕ƚƌŝŵ ,d͕ŽǁĞŶ͕ϯϭͬϴϱDy Ϯ͘ϱŽǁĞŶƋƵŝĐŬƵŶŝŽŶ dƵďŝŶŐŚĂŶŐĞƌ͕^ĞĂďŽĂƌĚ ^DͲͲ>͕ϭϯϱͬϴǆϯЪh ϴƌĚůŝĨƚĂŶĚƐƵƐƉ͕ǁͬϯΖ͛ƚǇƉĞ ,WsƉƌŽĨŝůĞ͕ϯͲЪ͛͛ŶƉƚ ĐŽŶƚƌŽůůŝŶĞƉŽƌƚƐ͕ƐƉĞĐƐ DŽŶŽƉŽĚWůĂƚĨŽƌŵ ͲϭϬZ ϭϯϯͬϴǆϵϱͬϴǆϮϳͬϴ DƵůƚŝͲďŽǁů͕^ĞĂďŽĂƌĚ ^DͲϮϮ͕ϭϯϱͬϴϱD&ƚŽƉǆ ϭϯϯͬϴϯD&ďŽƚƚŽŵ͕ ǁͬϰͲϮϭͬϭϲϱD^^K ĂƐŝŶŐŚĞĂĚ͕^ŚĂĨĨĞƌ< ϭϯϱͬϴϯDǆϭϯϯͬϴΖ͛^Kt͕ ǁͬϮͲϮΖ͛>WK ϭϯϯͬϴΖ͛ ϵϱͬϴΖ͛ ϮϳͬϴΖ͛ d&DŽŶŽƉŽĚͲϭϬZ ϬϭͲϭϰͲϮϮ KW From:Cody Dinger To:Guhl, Meredith D (CED) Subject:RE: [EXTERNAL] PTD 219-076, Trading Bay St A-10RD, Confidentiality Expiring Date:Thursday, November 4, 2021 9:28:08 AM Hi Meredith, Thanks for checking in, Hilcorp does not plan on filing for a confidentiality extension for A-10RD. Always appreciate the heads up. Have a great day! Cody Dinger Hilcorp Alaska, LLC Drilling Tech 907-777-8389 From: Guhl, Meredith D (CED) <meredith.guhl@alaska.gov> Sent: Thursday, November 4, 2021 9:14 AM To: Cody Dinger <cdinger@hilcorp.com> Subject: [EXTERNAL] PTD 219-076, Trading Bay St A-10RD, Confidentiality Expiring Hi Cody, Just a note to confirm Hilcorp is aware that Trading Bay St A-10RD, PTD 219-076, is due for release to the public after November 12, 2021. I checked with DNR and they have not received a request for extended confidentiality. Thanks, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Frank, Kevin J (DNR) To:Guhl, Meredith D (CED) Subject:RE: Hilcorp Trading Bay St A-10RD: Extended Confidentiality? Date:Thursday, November 4, 2021 9:11:45 AM Hi Meredith, I have not received any request for requested extended confidentiality for Trading Bay St A- 10RD, PTD 219-076 from Hilcorp. I extended the inquiry last week and have not heard from anybody else that has received a request. I will let you know if I hear anything. Thanks for checking. Cheers, Kevin Kevin Frank Petroleum Geologist Resource Evaluation Section Manager SOA-Dept. of Natural Resources Division of Oil and Gas 550 West 7th. Suite 1100 Anchorage, AK 99501-3560 (907) 269-8791 kevin.frank@alaska.gov CONFIDENTIAL and PROPRIETARY pursuant to AS 38.05.020(b)(10),(11), and (12) and other applicable laws: This email message including any attachments is for the sole use of the intended recipient(s) and may contain confidential, privileged, or proprietary information also protected under AS 43.05.230 and AS 40.25.100 or other applicable law; any release of this information without proper approval is not authorized. If you are not the intended recipient, any unauthorized disclosure, copying, distribution or action in reliance on the contents of this document is prohibited. If you have received this document in error, please inform the sender immediately and destroy all copies of the original message. From: Guhl, Meredith D (CED) <meredith.guhl@alaska.gov> Sent: Tuesday, November 2, 2021 11:02 AM To: Frank, Kevin J (DNR) <kevin.frank@alaska.gov> Subject: Hilcorp Trading Bay St A-10RD: Extended Confidentiality? Hi Kevin, Has Hilcorp requested extended confidentiality for Trading Bay St A-10RD, PTD 219-076, due for release after November 12, 2021? Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD V6'-. Operator Hilcorp Alaska, LLC API No. 50-733-20064-01-00 MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP Current Status SUSP UIC No REQUIRED INFORMATION / ; Mud Log Yes Samples Yes V Directional Survey Yes n 1a DATA INFORMATION List of Logs Obtained: Dr Dyn, Ann Press, MPR, COMP NEU POR, GR, PB1 Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No ED C 31454 Digital Data ED C 31454 Digital Data ED C 31454 Digital Data ED C 31454 Digital Data ED C 31454 Digital Data ED C 31454 Digital Data ED C 31454 Digital Data ED C 31454 Digital Data ED C 31454 Digital Data ED C 31454 Digital Data ED C 31454 Digital Data ED C 31454 Digital Data (from Master Well Data/Logs) Interval OH / Start Stop CH Received Comments 952 16212 11/18/2019 Electronic Data Set, Filename: Hilcorp Alaska _Monopod_A-10RD_0.5_Digital Data MEM.las 952 16212 11/18/2019 Electronic Data Set, Filename: Hilcorp Alaska _Monopod_A-10R D_1 _Digital Data MEM.las 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD_2MD_FE_MEM.cgm 11/18/2019 Electronic File: Hilcorp Alas ka_Monopod_A- 10RD_2TVD_FE_MEM.cgm 11/18/2019 Electronic File: Hilcorp Alas ka_Monopod_A- 10RD_5MD_FE_MEM.cgm 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD_5TVD_FE_MEM.cgm 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD_MD_VSS_MEM.cgm 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD_TI ME_VSS_MEM.cgm 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD_2MD_FE_MEM.PDF 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD_2TVD_FE_MEM.PDF 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD_5MD_FE_MEM.PDF 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD_5TVD_FE_MEM.PDF AOGCC Page 1 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-10RD Operator Hilcorp Alaska, LLC API No. 50-733-20064-01-00 MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP Current Status SUSP UIC No ED C 31454 Digital Data 11/18/2019 Electronic File: Hilcorp Alas ka_Monopod_A- 10RD_MD_VSS_MEM.PDF ED C 31454 Digital Data 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD_TIME_VSS_MEM.PDF ED C 31454 Digital Data 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD_SURVEYS.csv ED C 31454 Digital Data 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD 2MD FE MEM Color.tif ED C 31454 Digital Data 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD 2TVD FE MEM Color.tif ED C 31454 Digital Data 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD 5MD FE MEM Color.tif ED C 31454 Digital Data 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD 5TVD FE MEM Color.tif ED C 31454 Digital Data 11/18/2019 Electronic File: Hilcorp Alas ka_Monopod_A- 10RD MD VSS MEM Color.tif ED C 31454 Digital Data 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD TIME VSS MEM Color.tif ED C 31455 Digital Data 952 6930 11/18/2019 Electronic Data Set, Filename: Hilcorp Alaska_Monopod_A-10RD PB1_0.5_Digital Data MEM.las ED C 31455 Digital Data 952 6929 11/18/2019 Electronic Data Set, Filename: Hilcorp Alaska_Monopod_A-1ORD P61_1_Digital Data MEM.las ED C 31455 Digital Data 11/18/2019 Electronic File: Hilcorp Alas ka_Monopod_A- 10RD PB1_2MD_FE_MEM.cgm ED C 31455 Digital Data 11/18/2019 Electronic File: Hilcorp Alas ka_Monopod_A- 10RD PB1_2TVD_FE_MEM.cgm ED C 31455 Digital Data 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD PB1_5MD_FE_MEM.cgm ED C 31455 Digital Data 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD PB1_5TVD_FE_MEM.cgm ED C 31455 Digital Data 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD PB1_MD_VSS_MEM.cgm ED C 31455 Digital Data 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD PB1_TIME_VSS_MEM.cgm AOGCC Page 2 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-10RD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31455 Digital Data ED C 31455 Digital Data ED C 31455 Digital Data ED C 31455 Digital Data ED C 31455 Digital Data ED C 31455 Digital Data ED C 31455 Digital Data ED C 31455 Digital Data ED C 31455 Digital Data ED C 31455 Digital Data ED C 31455 Digital Data ED C 31455 Digital Data ED C 31455 Digital Data ED C 31681 Digital Data 950 16250 ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD PB1_2MD_FE_MEM.PDF 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD P61 2TVD FE MEM.PDF 11/18/2019 Electronic File: Hilcorp Alas ka_Monopod_A- 10RD P131_5MD_FE_MEM.PDF 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD PB1_5TVD_FE_MEM.PDF 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD PB1_MD_VSS_MEM.PDF 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD PB1_TIME_VSS_MEM.PDF 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD PB1_Surveys.csv 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD PB1 2MD FE MEM Color.tif 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD PB1 2TVD FE MEM Color.tif 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD PB1 5MD FE MEM Color.tif 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD PB1 5TVD FE MEM Color.tif 11/18/2019 Electronic File: Hilcorp Alas ka_Monopod_A- 10RD PB1 MD VSS MEM Color.tif 11/18/2019 Electronic File: Hilcorp Alaska_Monopod_A- 10RD P131 TIME VSS MEM Color.tif 12/13/2019 Electronic Data Set, Filename: A-10RD.las 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1110'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1130'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1140'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1150'.jpg AOGCC Page 3 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 1oRD 1160'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1170'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1180'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1190'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1200'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1210'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1220'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1230'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1245'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1260'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1275'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1290'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1300'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1320'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1350'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1410'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1440'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1470'.jpg AOGCC Page 4 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1500'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1515'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1530'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1560'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1600' Coal Sub-Bitumen.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1600' Degassing Coal.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1620'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1650'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1680'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1710'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1740'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1770'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1785'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1800'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1830'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1855'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1890'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1900'.jpg AOGCC Page 5 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-10RD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1920'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1935'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1950'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1965'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1980'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2000'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2010'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2040'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2060'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2070'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2100'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2105'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2125'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2130'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2145'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2170'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2190'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2210'.jpg AOGCC Page 6 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2230'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2250'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2260'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2280'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2310'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2330'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2370'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2400'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2490'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2520'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2550'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2580'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2600' Coal Bituminous.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2640'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2670'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2700'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2725'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2730'.jpg AOGCC Page 7 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2745'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2765'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2770'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2790'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2800'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2820'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2835'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2850'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2870'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2880'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2890'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2910'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2930'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2940'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2948'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2965'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2975'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2990'.jpg AOGCC Page 8 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3000'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3015'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3020'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3030'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3045'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3060'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3070'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3082'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3090'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3120'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3150.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3180'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3210'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3240'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3270'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3540'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3570'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3600'.jpg AOGCC Page 9 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3630'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3660'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3690'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3720'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3750'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3780'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3810'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3840'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3870'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3900'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3915'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3930'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3960'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3980'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3990'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4005'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4020'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4025'.jpg AOGCC Page 10 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4050'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4060'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4080'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4095'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4100'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4140'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4150'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4170'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4200'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4230'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4260'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4290'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4310'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4320'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4380.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4410'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4440'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4470'.jpg AOGCC Page I I of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4500'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4530'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4560'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4590'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4620'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4640' Coal Laminae.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4640.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4650'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4680'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4710'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4740'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4770'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4800'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4830'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4860'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4870'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4890'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4920'.jpg AOGCC Page 12 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4950'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4962'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4970'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5005'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5020'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5040'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5050'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5062'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5090'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5100'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5120'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5130'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5140'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5152'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5164'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5190'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5195'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5215'.jpg AOGCC Page 13 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5225'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5232'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5250'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5280'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5310'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5340'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5351'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5357'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5370'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5380'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5390'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5400'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5408'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5420'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5430'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5450'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5460'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5490'.jpg AOGCC Page 14 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5520'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5534'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5540'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5550'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5571'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5580'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5595'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5610'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5625'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5640'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5655'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5670'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5700'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5720'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5730'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5760' .jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5775'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5790 Cong.jpg AOGCC Page 15 of 69 Tuesday, Septeinber 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5790'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5810'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5835.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5850'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5865.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5880'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5895'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5910'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5925'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5940'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5955.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5970'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6000'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6015'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6030'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6045'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6060'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6080'.jpg AOGCC Page 16 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6090'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6110'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6123'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6130'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6148'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6162'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6180'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6195'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6205'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6210'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6225' 35x.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6225'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6240'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6255'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6270'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6300'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6330'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6360'.jpg AOGCC Page 17 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6375'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6390'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6405'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6420'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6435'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6450'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6475'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6478'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6505'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6510'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6528'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6539'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6553'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6567'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6570'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6590'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6600.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6620'.jpg AOGCC Page t 8 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6630'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6650'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6660'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6680'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6710'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6717'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6728'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6740'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6750'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6760'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6770'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6780'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6790'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6798'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6815'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6830'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6840'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6855'.jpg AOGCC Page 19 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6865'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6875'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6879'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6886'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6900'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6920'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6940'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6950' SS.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD Coal -2600' Bituminous.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD Coal 1600' Sub-Bitumen.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD Coal.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD Degassing Coal 1600'.jpg 12/13/2019 Electronic File: Monopod A-10RD Morning Report 10-1-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 10-2-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 10-3-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 10-4-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 10-5-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 10-6-19.pdf AOGCC Page 20 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 10-7-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 7-25-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 7-26-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 7-27-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 7-28-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 7-29-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 7-30-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 7-31-19.pdf 12/13/2019 Electronic File: Monopod A-1 ORD Morning Report 8-10-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-11-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-1-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-12-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 8-13-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-14-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-15-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-16-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 8-17-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-18-19.pdf AOGCC Page 21 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-19-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-20-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 8-21-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-2-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-22-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 8-23-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-24-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-25-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 8-26-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-27-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-28-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-29-19.pdf 12/13/2019 Electronic File: Monopod A-1 ORD Morning Report 8-30-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 8-31-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-3-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 8-4-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 8-5-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 8-6-19.pdf AOGCC Page 22 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-10RD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-7-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-8-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 8-9-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 9-10-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 9-11-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 9-1-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 9-12-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 9-13-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 9-14-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 9-15-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 9-16-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 9-17-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 9-18-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 9-19-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 9-20-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 9-21-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 9-2-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 9-22-19.pdf AOGCC Page 23 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data AOGCC Page 24 of 69 API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 9-23-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 9-24-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 9-25-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 9-26-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 9-27-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 9-28-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 9-29-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 9-30-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 9-3-19.pdf 12/13/2019 Electronic File: Monopod A-10RD Morning Report 9-4-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 9-5-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 9-6-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 9-7-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 9-8-19.pdf 12/13/2019 Electronic File: Monopod A-1ORD Morning Report 9-9-19.pdf 12/13/2019 Electronic File: A-10RD.dbf 12/13/2019 Electronic File: a-10rd.hdr 12/13/2019 Electronic File: A-10RD.mdx 12/13/2019 Electronic File: A-10RD_SCL.DBF 12/13/2019 Electronic File: A-10RD_SCL.MDX Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC API No. 50-733-20064-01-00 MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP Current Status SUSP UIC No ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD TVD.DBF ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD TVD.mdx ED C 31681 Digital Data 12/13/2019 Electronic File: a-10rdr.dbf ED C 31681 Digital Data 12/13/2019 Electronic File: a-10rdr.mdx ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD Final Well Report.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - 5in Drilling Dynamics Log MD.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - 5in Drilling Dynamics Log TVD.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - 5in Formation Log MD.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - 5in Formation Log TVD.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - 5in Gas Ratio Log MD.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - 5in Gas Ratio Log TVD.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - 5in LWD Combo Log MD.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - 5in LWD Combo Log TVD.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - Drilling Dynamics Log MD.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - Drilling Dynamics Log TVD.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - Formation Log MD.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - Formation Log TVD.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-1ORD - Gas Ratio Log MD.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - Gas Ratio Log TVD.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-1ORD - LWD Combo Log MD.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - LWD Combo Log TVD.pdf AOGCC Page 25 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC API No. 50-733-20064-01-00 MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP Current Status SUSP UIC No ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - 5in Drilling Dynamics Log MD.tif ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - 5in Drilling Dynamics Log TVD.tif ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - 5in Formation Log MD.tif ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - 5in Formation Log TVD.tif ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - 5in Gas Ratio Log MD.tif ED C 31681 Digital Data 12/13/2019 Electronic File: A-1 ORD - 5in Gas Ratio Log TVD.tif ED C 31681 Digital Data 12/13/2019 Electronic File: A-1 ORD - 5in LWD Combo Log MD.tif ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - 5in LWD Combo Log TVD.tif ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - Drilling Dynamics Log MD.tif ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - Drilling Dynamics Log TVD.tif ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - Formation Log MD.tif ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - Formation Log TVD.tif ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - Gas Ratio Log MD.tif ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - Gas Ratio Log TVD.tif ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD - LWD Combo Log MD.tif ED C 31681 Digital Data 12/13/2019 Electronic File: A-1ORD - LWD Combo Log TVD.tii ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10010'.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10050'.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10060'.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10080'.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10110'.jpg AOGCC Page 26 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC API No. 50-733-20064-01-00 MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP Current Status SUSP UIC No ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10140'.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10155'.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10170'.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10200'.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10230'.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10250'.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10254'.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10256'.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10272'.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10290'.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10308'.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10345'.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10354'.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10367'.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10410.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10440.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10470.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10500.jpg AOGCC Page 27 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10530.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10542.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10560.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10590.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10620.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10650.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10680.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10710.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10740.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10770.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10800.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10830.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10860.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 10890.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11010'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11040'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11070'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11090'.jpg AOGCC Page 28 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-10RD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11100'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11130'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11160'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11170'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11190'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11215'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11244'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11280'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11310'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11340'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11370'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11400'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11430'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11455'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11490'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11520'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11545'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11580'.jpg AOGCC Page 29 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11610'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11640'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11670'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11700'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11730'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11820.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11850.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11880.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11910.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11940.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 11970.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12000.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12030.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12060.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12090.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12120.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12150.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12180.jpg AOGCC' Page 30 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12210.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12240.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12270.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12300.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12310.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12330.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12360.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12390.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12420.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12450.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12480.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12500.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12510.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12540.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12560.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12570.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12590.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12600.jpg AOGCC Page 31 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC API No. 50-733-20064-01-00 MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP Current Status SUSP UIC No ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12630.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12640.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12660.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12690.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12720.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12750.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12755.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12770.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12780.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12810.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12840.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12855.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12870.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12885.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12900.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12930.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12940.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12960.jpg AOGCC Page 32 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-10RD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12990.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 12995.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13020.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13030.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13050.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13080.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13110.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13120.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13130.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13140.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13155.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13170.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13185.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13200.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13210.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13220.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13245.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13260.jpg AOGCC Page 33 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-10RD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13290.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13300.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13310.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13320.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13350.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13380.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13400.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13440.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13455.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13470.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13500.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13530.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13560.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13580.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13590.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13620.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13650.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13670.jpg AOGCC Page 34 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC API No. 50-733-20064-01-00 MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP Current Status SUSP UIC No ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13710.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13740.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13752.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13770.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13800.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13830.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13860.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13890.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13920.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13950.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 13970.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14010.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14040.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14070.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14100.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14130.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14160.jpg ED C 31681 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14175.jpg AOGCC Page 35 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14190.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14220.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14250.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14280.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14310.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14340.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14370.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14400.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14430.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14460.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14480.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14490.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14520.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14540.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14550.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14580.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14610.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14640.jpg AOGCC Page 36 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14660.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14680.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14700.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14720.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14730.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14760.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14790.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14820.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14850.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14851.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14880.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14881.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14910.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14935.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 14970.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15000.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15020.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15060.jpg AOGCC Page 37 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15075.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15090.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15100.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15120.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15180.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15210.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15240.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15252.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15270.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15300.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15325.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15335.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15360.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15390.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15420.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15430.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15440.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15450.jpg AOGCC Page 38 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1 ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15455.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15465.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15480.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15480-B.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15483.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15495.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15510.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15540.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15555.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15570.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15575.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15600.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15630.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15640.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15650.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15660.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15670.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15680.jpg AOGCC Page 39 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15690.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15700.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15710.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15711.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15720.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15735.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15745.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15750.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15760.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15780.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15790.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15820.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15832.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15840.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15850.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15860.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15870.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15870-B.jpg AOGCC Page 40 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15880.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15890.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15900.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15930.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15960.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15990.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 15991.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 16020.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 16020-B.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 16050.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 16060.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 16070.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 16110.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 16140.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 16155.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 16170.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 16190.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 16212.jpg AOGCC Page 41 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5750.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6070'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6093'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6870'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6900'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6930'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6960'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6990'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7020'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7050'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7080'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7110'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7130'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7140'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7150'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7170'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7185'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7200'.jpg AOGCC Page 42 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 1oRD 7230'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7260'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7275'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7290'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7315'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7347'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7378'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7406'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7435'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7470'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7480'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7500'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7513'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7525'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7527'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7534'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7540'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7555'.jpg AOGCC Page 43 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7565'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7582'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7605'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7620'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7646'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7653'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7675'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7707'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7710'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7711'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7740'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7770.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7830.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7860.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7920'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7950'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 7980.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8010.jpg AOGCC Page 44 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8040.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8070.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8100.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8130.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8160.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8190.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8220.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8250.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8280.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8310.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8370.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8400.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8430.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8460.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8490.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8520.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8550.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8580'.jpg AOGCC Page 45 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8610'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8635'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 1oRD 8655'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8670'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8700'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8730'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8740'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8760'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8790'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8805'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8817'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8820'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8833'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8845'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8848'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8865'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8890'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8910'.jpg AOGCC Page 46 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8940'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 8970'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9000'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9030'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9060.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9085'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9099'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9120'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9130'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9150'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9240.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9270.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9300.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9340.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9360.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9390.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9420.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9450.jpg AOGCC Page 47 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data ED C 31681 Digital Data AOGCC Page 48 of 69 API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9480.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9510.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9540.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9570.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9600.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9630.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9660.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9690.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9720.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9780.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9810'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9840'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9870'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9900'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9930'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9947'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 9985'.jpg 12/13/2019 Electronic File: A-10RD_Show 1_1256-1323.pdf 12/13/2019 Electronic File: A-10RD_Show 10_2302-2510.pdf Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC API No. 50-733-20064-01-00 MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP Current Status SUSP UIC No ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 11_2791-2805.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 12_2912-3125.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 13_3145-3234.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 14_3276-3470.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 15_3568-3654.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 16_4065-4120.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 17_4284-4300.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 18_4330-4435.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 19_4460-4505.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 2_1385-1515.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 20_4567-4647.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 21_4791-4844.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 22_5009-5023.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 23_5054-5081.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 3_1570-1624.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 4_1719-1790.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 5_1806-1951.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 6_1979-1984.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 7_2007-2023.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 8_2093-2130.pdf ED C 31681 Digital Data 12/13/2019 Electronic File: A-10RD_Show 9_2193-2292.pdf ED C 31682 Digital Data 950 6985 12/13/2019 Electronic Data Set, Filename: A-10_PB1.las ED C 31682 Digital Data 12/13/2019 Electronic File: A-10RD_PB1.dbf ED C 31682 Digital Data 12/13/2019 Electronic File: a-10rd_P131.hdr ED C 31682 Digital Data 12/13/2019 Electronic File: A-10RD_PB1.mdx ED C 31682 Digital Data 12/13/2019 Electronic File: A-10RD_PB1_SCL.DBF ED C 31682 Digital Data 12/13/2019 Electronic File: A-10RD_PB1_SCL.MDX ED C 31682 Digital Data 12/13/2019 Electronic File: A-10RD_PB1_tvd.dbf ED C 31682 Digital Data 12/13/2019 Electronic File: A-10RD_PB1_tvd.mdx AOGCC Page 49 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data AOGCC Page 50 of 69 API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: a-10rd PB1r.dbf 12/13/2019 Electronic File: a-10rd PB1r.mdx 12/13/2019 Electronic File: A-10RD P61 - 5in Drilling Dynamics Log MD.pdf 12/13/2019 Electronic File: A-10RD P61 - 5in Drilling Dynamics Log TVD.pdf 12/13/2019 Electronic File: A-10RD P61 - 5in Formation Log MD.pdf 12/13/2019 Electronic File: A-10RD PB1 - 5in Formation Log TVD.pdf 12/13/2019 Electronic File: A-10RD PB1 - 5in Gas Ratio Log MD.pdf 12/13/2019 Electronic File: A-1ORD PB1 - 5in Gas Ratio Log TVD.pdf 12/13/2019 Electronic File: A-10RD PB1 - 5in LWD Combo Log MD.pdf 12/13/2019 Electronic File: A-10RD PB1 - 5in LWD Combo Log TVD.pdf 12/13/2019 Electronic File: A-10RD P61 - Drilling Dynamics Log MD.pdf 12/13/2019 Electronic File: A-10RD P131 - Drilling Dynamics Log TVD.pdf 12/13/2019 Electronic File: A-10RD PB1 - Formation Log MD.pdf 12/13/2019 Electronic File: A-10RD P61 - Formation Log TVD.pdf 12/13/2019 Electronic File: A-10RD P131 - Gas Ratio Log MD.pdf 12/13/2019 Electronic File: A-1 ORD PB1 - Gas Ratio Log TVD.pdf 12/13/2019 Electronic File: A-10RD P61 - LWD Combo Log MD.pdf 12/13/2019 Electronic File: A-10RD P61 - LWD Combo LogTVD.pdf 12/13/2019 Electronic File: A-1ORD PB1 - 5in Drilling Dynamics Log MD.tif Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-10RD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: A-10RD P61 - 5in Drilling Dynamics Log TVD.tif 12/13/2019 Electronic File: A-10RD P131 - 5in Formation Log MD.tif 12/13/2019 Electronic File: A-10RD P61 - 5in Formation Log TVD.tif 12/13/2019 Electronic File: A-10RD PB1 - 5in Gas Ratio Log MD.tif 12/13/2019 Electronic File: A-1 ORD P61 - 5in Gas Ratio Log TVD.tif 12/13/2019 Electronic File: A-10RD P131 - 5in LWD Combo Log MD.tif 12/13/2019 Electronic File: A-10RD P61 - 5in LWD Combo Log TVD.tif 12/13/2019 Electronic File: A-10RD P131 - Drilling Dynamics Log MD.tif 12/13/2019 Electronic File: A-10RD P131 - Drilling Dynamics Log TVD.tif 12/13/2019 Electronic File: A-10RD P61 - Formation Log MD.tif 12/13/2019 Electronic File: A-10RD PB1 - Formation LogTVD.tif 12/13/2019 Electronic File: A-10RD P61 - Gas Ratio Log MD.tif 12/13/2019 Electronic File: A-10RD PB1 - Gas Ratio Log TVD.tif 12/13/2019 Electronic File: A-10RD P131 - LWD Combo Log MD.tif 12/13/2019 Electronic File: A-10RD P61 - LWD Combo Log TVD.tif 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1110'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1130'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1140'.jpg AOGCC Page 51 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1150'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1160'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1170'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1180'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1190'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1200'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1210'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1220'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1230'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1245'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1260'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1275'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1290'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1300'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1320'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1350'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1410'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1440'.jpg AOGCC Page 52 of 69 Tuesday, September 29. 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1470'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1500'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1515'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1530'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1560'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1600' Coal Sub-Bitumen.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1600' Degassing Coal.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1620'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1650'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1680'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1710'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1740'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1770'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1785'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1800'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1830'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1855'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1890'.jpg AOGCC Page 53 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1900'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1920'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1935'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1950'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1965'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 1980'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2000'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2010'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2040'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2060'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2070'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2100'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2105'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2125'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2130'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2145'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2170'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2190'.jpg AOGCC Page 54 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2210'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2230'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2250'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2260'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2280'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2310'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2330'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2370'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2400'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2490'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2520'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2550'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2580'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2600' Coal Bituminous.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2640'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2670'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2700'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2725'.jpg AOGCC Page 55 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2730'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2745'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2765'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2770'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2790'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2800'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2820'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2835'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2850'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2870'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2880'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2890'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2910'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2930'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2940'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2948'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2965'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2975'.jpg AOGCC Page 56 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 2990'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3000'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3015'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3020'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3030'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3045'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3060'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3070'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3082'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3090'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3120'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3150.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3180'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3210'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3240'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3270'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3540'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3570'.jpg AOGCC Page 57 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3600'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3630'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3660'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3690'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3720'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3750'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3780'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3810'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3840'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3870'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3900'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3915'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3930'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3960'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3980'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 3990'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4005'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4020'.jpg AOGCC Page 58 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4025'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4050'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4060'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4080'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4095'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4100'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4140'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4150'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4170'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4200'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4230'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4260'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4290'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4310'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4320'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4380.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4410'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4440'.jpg AOGCC Page 59 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC API No. 50-733-20064-01-00 MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP Current Status SUSP UIC No ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4470'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4500'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4530'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4560'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4590'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4620'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4640' Coal Laminae.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4640.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4650'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4680'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4710'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4740'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4770'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4800'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4830'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4860'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4870'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4890'.jpg AOGCC Page 60 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC API No. 50-733-20064-01-00 MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP Current Status SUSP UIC No ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4920'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4950'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4962'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 4970'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5005'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5020'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5040'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5050'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5062'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5090'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5100'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5120'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5130'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5140'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5152'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5164'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5190'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5195'.jpg AOGCC Page 61 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5215'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5225'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5232'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5250'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5280'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5310'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5340'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5351'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5357'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5370'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5380'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5390'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5400'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5408'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5420'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5430'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5450'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5460'.jpg AOGCC Page 62 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5490'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5520'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5534'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5540'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5550'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5571'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5580'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5595'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5610'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5625'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5640'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5655'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5670'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5700'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5720'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5730'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5760' .jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5775'.jpg AOGCC Page 63 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC API No. 50-733-20064-01-00 MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP Current Status SUSP UIC No ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5790 Cong.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5790'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5810'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5835.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5850'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5865.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5880'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5895'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5910'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5925'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5940'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5955.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 5970'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6000'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6015'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6030'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6045'.jpg ED C 31682 Digital Data 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6060'.jpg AOGCC Page 64 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6080'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6090'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6110'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6123'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6130'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6148'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6162'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6180'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6195'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6205'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6210'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6225' 35x.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6225'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6240'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6255'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6270'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6300'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6330'.jpg AOGCC Page 65 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6360'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6375'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6390'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6405'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6420'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6435'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6450'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6475'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6478'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6505'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6510'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6528'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6539'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6553'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6567'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6570'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6590'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6600.jpg AOGCC Page 66 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6620'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6630'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6650'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6660'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6680'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6710'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6717'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6728'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6740'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6750'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6760'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6770'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6780'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6790'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6798'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6815'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6830'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6840'.jpg AOGCC Page 67 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-1ORD Operator Hilcorp Alaska, LLC MD 16212 TVD 10375 ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data ED C 31682 Digital Data Well Cores/Samples Information: Name Cuttings Cuttings INFORMATION RECEIVED Completion Date 10/12/2019 Completion Status SUSP Interval Start Stop 6060 16212 990 6590 API No. 50-733-20064-01-00 Current Status SUSP UIC No 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6855'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6865'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6875'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6879'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6886'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6900'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6920'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6940'.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD 6950' SS.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD Coal —2600' Bituminous.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD Coal 1600' Sub-Bitumen.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD Coal.jpg 12/13/2019 Electronic File: Hilcorp Alaska LLC Monopod A- 10RD Degassing Coal 1600'.jpg Sample Set Sent Received Number Comments 10/10/2019 1725 Mainbore 10/10/2019 1726 P61 AOGCC Page 68 of 69 Tuesday, September 29, 2020 DATA SUBMITTAL COMPLIANCE REPORT 9/29/2020 Permit to Drill 2190760 Well Name/No. TRADING BAY ST A-10RD Operator Hilcorp Alaska, LLC API No. 50-733-20064-01-00 MD 16212 TVD 10375 Completion Date 10/12/2019 Completion Status SUSP Current Status SUSP UIC No Completion Report 0 Directional / Inclination Data 6 Mud Logs, Image Files, Digital Data / NA Core Chips Y /@ Production Test Information Y Mechanical Integrity Test Information/YNA Composite Logs, Image, Data Files 0 Core Photographs Y / 6 Geologic Markers/Tops l_/ '�/ Daily Operations Summary / Y) Cuttings Samples DNA Laboratory Analyses Y NA COMPLIANCE HISTORY Completion Date: 10/12/2019 Release Date: 11/12/2021 Description Date Comments Comments: Compliance Reviewed Date: 2 ( 2 AOGCC Page 69 of 69 Tuesday, September 29, 2020 219076 Hilenrp Alamka, U.C: DATE: 12/12/2019 De— a Oudean Hilcorp Alaska, LLL GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: AOGCC Natural Resources Technician 333 W. 7th Ave. Ste# 100 Anchorage, AK 99501 FINAL MUDLOG DATA A-10 PB1 Logs and Data Daily Reports DML Data Final Well Report LAS Data Log PDFs Log TIFFs Sample Photography Show Reports 31681 DPr we� 132019 A OGcC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: 1\ I _1 _ ° V,--� r, V Y I Date: A, L 2190 76 Hileurli alw-ka. UA; DATE: 12/12/2019 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: AOGCC Natural Resources Technician 333 W. 7th Ave. Ste# 100 Anchorage, AK 99501 Elm BF A -LORD A -LORD P61 PTD 219-076 FINAL MUDLOG DATA F_!, A-10 M Logs and Data Daily Reports DML Data Final Well Report LAS Data 7; Log PDFs Log TIFFS Sample Photography Show Reports 31682 'a t �. 13 !+ AOGcC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: 1\ I _j _ V, --� I Y I Date: A, 219076 DeL,, a Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 if Tele: 907 777-8337 Hilriirp Ala:.ka. UA; Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE: 11/15/2019 To: AOGCC Natural Resources Technician 333 W. 7t" Ave. Ste# 100 Anchorage, AK 99501 A-10RD / A -LORD PB1 MPR, Compensated Neutron Porosity, Compensated Bulk Density, GR, LWD Memory Log Drilling Dynamics, Annular Pressure LWD Memory Log Gamma Ray, MPR LWD Memory Log Survey 3 145 4 RECEIVED NOV 18 2019 Please include current contact information if different from above. OGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: /1�� Date: 2`9076 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 fiilmrpALLPLia.idd: Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE: 11/15/2019 To: AOGCC Natural Resources Technician 333 W. 7tn Ave. Ste# 100 Anchorage, AK 99501 BF A-10RD A -LORD PB1 (PTD 219-076) A-10RD / A-10RD PB1 MPR, Compensated Neutron Porosity, Compensated Bulk Density, GR, LWD Memory Log Drilling Dynamics, Annular Pressure LWD Memory Log Gamma Ray, MPR LWD Memory Log Survey Please include current contact information if different from above. AOGCC 3 145 5 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: �'�� /�� Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑✓ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG[:] WDSPL ❑ No. of Completions: 0 lb. Well Class: Development ❑ Exploratory Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp. Susp. or ^c. Aband.: (D Itz /zolq 14. Permit to Drill Number / Sundry: + 219-076 / 319-456 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: F July 25, 2019 15. API Number: + 50-733-20064-01-00 4a. Location of Well (Governmental Section): Surface: 1602' FSL, 570' FEL, Sec 4, T9N, R13W, SM, AK + Top of Productive Interval: N/A Total Depth: 909' FSL, 1272' FEL, Sec 35, T10N, R13W, SM, AK ` 8. Date TD Reached: October 3, 2019 16. Well Name and Number: --1E j,4� A-1 ORD 9. Ref Elevations: KB: 101' + GL: 0 BF: 40' 17. Field / Pool(s): Tyonek G / Hemlock Prospect 10. Plug Back Depth MQ/TVD: 11,685' MD / 7,313' TVD 18. Property Designation: ADL018731, ADL393693, ADL018776 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 218864 y- 2523116 Zone- 4 TPI: x- N/A y- Zone- Total Depth: x- 228823 y- 2527468 + Zone- 4 11. Total Depth MD/TVD: 16,212' MD / 10,375' TVD 19. DNR Approval Number: N/A 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: N/A 5. Directional or Inclination Survey: Yes ✓ (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 66 + (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 1,095' MD / 1,068' TVD 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs 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 DRILLING DYNAMICS, ANNULAR PRESSURE / MPR, COMP NEUTRON POROSITY, GR / PB1 NOV 0 8 2019 A 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 9 5/8" 47# L-80 Surface 5,818' Surface 4,267' 12-1/4" 1 L - 300 sx / T - 450 sx 185 bblsace Stg 2 L - 630 sx 7" 29# L-80 5,528' 11,754' 4,106' 7,349' 8-1/2" L- 63 sx 24. Open to production or injection? Yes ❑ No Q If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): sS AT �0(22aiq —VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) I PACKER SET (MD/TVD) 2-7/8" 549' MD IN/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Test Period Oil-Bbl: Gas-MCF: Water-BbI: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate Oil-BbI: Gas-MCF: Water-BbI: Oil Gravity - API (corr): 3°)1. Form 10-407 Revised 5/2017 ji Z ( C TI UED ON PAGE 2 Submit ORIGINI L only /�" �;q rIBDMS ± NOV 18 2019 �,� 12/1119 28. CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No Q 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 Q If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base N/A N/A Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval N/A N/A information, including reports, per 20 AAC 25.071. MID_KENAI_B_41_8ST 3282 2956 ` TYONEK_D_COAL 9206 6023 • COAL_46-6 12515 7737 ' TYONEK_F 13047 8014 ' COAL_39 15446 9779 ' TOP_TYONEK_G 15855 10092 COAL_59 15998 10202 ' TOP HEMLOCK 16061 10250 Formation at total depth: Hemlock 31. List of Attachments: Wellbore Schematic, Drilling Reports, Definitive Directional Surveys, Csg and Cmt Report 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. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Monty Myers Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: cdln er NLW .COm Authorized Contact Phone: 777-8389 Signature: — - Date: ' (� INSTRUCTIONS 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 1 a: 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 1 b: 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 and printed logs 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 5/2017 Submit ORIGINAL Only Hllcoru Alaska. LLC KB to MSL =101' MSL to Mudline = 66' 1 20" 13-3/8' 9-5/8- FS 475 L Gip hole P9TD-11,685' 14 -/it' 3 ' A TD:16,212' Schematic CASING DETAIL Trading Bay Unit Well: A-10RD PTD:219-076 API: 50-733-20064-01 Size Wt Grade Conn ID Top Btm 20" Conductor Pile Surface —264' 13-3/8" 61 K-55 BTC 12.515" Surface 1,095' 9-5/8" 47 L-80 DWC/C 8.681" Surface 5,818' 7" 29 L-80 CDC HTQ 6.184" 5,528' 11,754' TUBING DETAIL `b 2-7/8" 6.4 L-80 IBT 2.441" Surface 549' �Y� 2-7/8" 6.4 L-80 IBT 2.441" 15,215' 1.6,212' l xv 1 JEWELRY DETAIL No Depth (MD) Depth (TVD) Item 1 40' 40' Hanger 2 11,685' 7,338 7" CIBP 1 C7 Zv/G 3 14,324' 9,563' TOC plug (Tagged) 4 15,215' 9,601' 3-1/2" BHK Disconnect sub 5 15,218' 9,603' 2-7/8" 6.4# L-80 tubing string C';' C�e / u - ,— P"— Updated By: OD 11/07/19 Hilcorp Energy Company Composite Report Well Name: TBN A-10RD Field: Trading Bay North County/State: , Alaska (LAT/LONG): 3vation (RKB): API #: Spud Date: Job Name: 1910558D A-10RD Drilling Contractor Monopod 56 AFE #: AFE $: J Ch1F[#;t dC ops Summary 7/18/2019 Finish split hatch welding project, Prep and measure flowline for welder. Welders fabricate service loop guard and lock plate for top drive.;Finish welding service loop guard, paint and install same. Install steel flow line. Dress shakers with 120 and 80 screens. Mix first batch of premix.; Pick up 87 jts. of 5" drill pipe w/mouse hole, stand back in derrick.. Transfer list batch of premix mud to reserve tank and mix 2nd batch. 7/19/2019 Pick up 5" drill pipe, total of 46 stands/138 joints in derrick. Mix pre -mix fluid.;Transfer a batch of pre -mix fluid to storage tank. Transfer 350 bbls. of LVT from ISO's to LVT storage tank and offload mud product from boat.;Mix a batch of pre -mix fluid. Pick up 5" drill pipe and build stands - total of 70 stands/210 joints in derrick.;Start to mix weighted mud. Pick up 5" drill pipe, total of 85 stands / 255 joints. Offload mud product and BOPE from boat. Start to install deck drain plugs around rig. 7/20,12019 Continue picking up 5" drill pipe, ST-80 has issues, troubleshoot and find broken die block. Set up power washer for cleaning shakers with LVT.; Build and weight up MOBM in pits to 9.Oppg, Install 90 degree ducting on hopper fan output. Install manual kill and choke valves on the mud cross. Hook up HPU and Hawkjaw and adjust same. Install LVT manifold for pressure washer.;Transfer 9.0 ppg MOBM from pits to the reserve and pill pits. Finish picking up 5" drill pipe, have a total of 106 stands in the derrick. Assist the crane crew offloading mud product from the boat.;Nipple down the dry hole tree, nipple up the Multi Bowl well head , nipple up riser, dress mud cross, install strong back on single gate. Transfer 340 bbls. of LVT from 3 ISO's to the Rain for Rent tank. 7/21/2019 Nipple up the BOP stack, welder modify the drilling nipple, install same. Align stack and secure same. Assist crane crew offloading mud product and directional drilling tools. Weight mud up in pits and condition same.;Remove 9' bales and install 11' bales. Install sensor on top of gooseneck for Baker MWD. Assist crane crew with lifting hatch and storing Barite in lower level. Hook up Koomey hoses and function test. Seal rig floor with Sikaflex. R/U transfer hose from pits to the .trip tank. 7/22/2019 Function test BOPE, had Hyd leak on Kill HCR changed out same, R/U water to MP #1 to fill surface eq for test, m/u 5" TJ, Rig up scaffolding for Rain to Rent tank access. M/U target 90's on mud cross. Assist crane crew with offloading boat. DD & MWD prep BHA.;Commission Centrifuge with rep, had to flip Hyd motor that had been installed incorrectly.;Choke manifold valve #16 failed shell test, isolated valve and continued shell test. Start to remove #16 while waiting for AOGC Rep., Bench test 3 mud pump pop offs, install and set same. Bring mud weight up to 9.0 ppg in active pits.;Test BOPE as per Hilcorp & AOGCC requirements. Test witnessed by inspector Adam Earl, tested with 5" test joint, 250/2500 Annular, 250/4000 all other tests, tested gas alarms & PVT system good, super choke failed & CMV#16.;Remove CMV #16, dress flanges and install new valve. M/ U manifold and hoses to drain stack. 7/2312019 Cont. c/o CMV 16 & flush super choke, test CMV 15 & 16 250/4000 good, test super choke good.;Close Blinds, test casing tf500 psi 30 min good.;Cont work on punch list, r/u lines for fluid displacement, spot cutting tank in mud room at chute, R/U vac to mud room, install wear bushing, rig down test tools.;Continue circulating active system. Install panic line. Strap HWDP. Run communication line for directional drillers. Install DD screen on driller console. Repair ST-80 and rig down Hawkjaws. Adjust link tilt to clear monkey board. Assist crane crew offloading work boat.; Prep rig floor for picking up BHA.; Roll the premix tank. Trouble shoot pill pit hopper, take apart and inspect - OK, Remove and inspect discharge check valves - OK. Make new gaskets and assemble hopper. Silicone the cuttings chute flange and bolt up. WOBaker communication gear, tool communication failure, replacement gear coming.;Roll the active mud system. Install the hopper and test run the pill pit mix pumps. Test vacuum placement for cuttings box. Redo hopper and fix leak. 7/24,2019 Assist Baker directional driller in rig up of BPA. Troubleshoot and repair pill pit hopper. Run rig floor drains to slop tank in cellar.;Mix GELTONE spacer in the pill pit, get ready to pick up BHA.;Make up 12 1/4" BHA as per the Directional Driller, orient the mud motor, sync up the MWD tools.;Run in hole out of derrick F/ 629' and tag cement at 1014'. Make up top drive and prepare to swap hole over to OBM.;The lights in the derrick went out, had to have electrician dry out a junction box and get lights back on, line up to displace brine.;Pump 15 bbl spacer followed by 8.9 ppg OBM at 1.5 to 3 bpm, displace brine to production. at 82 bbls pumped, take returns to cuttings totes until OBM cleans up, about 50 bbls.; Repair leaking pop off, repair trip tank valve leak, condition mud. 7/25/2019 Mud pump PRV's not functioning properly. Spare PRV having same issue. Sent 3 hands to Steelhead Platform to pull those PRV's and gather up spare parts. Repair leaking air actuated valve to trip tank. Replaced conduit junction cap in derrick.;Change out PRV on mud pump #2. Test HP lines to rig floor and PRV's on both pumps to 3000 psi. Rig down test equipment.; Establish parameters: P/U 81 K, S/O 79 K, Rot 81 at 38 RPM/3 K torque. 560 GPM/1280 psi. Drill cement from 1015' to 1125' with 10 K WOB and 20 - 95 FPR/ROP. Cement very firm.;Circulate and condition mud at 555 GPM/1150 psi until 9.15 ppg mud in and out. Set back one stand.;Perform FIT to 13.0 ppg EMW with 9.15 ppg mud at 1080' TVD, pump .5 bbl and get .5 bbl back.;Establish parameters: P/U 85 K, S/O 83 K, 550 GPM/1200 psi. Slide directional drill from 1125to 1178' with 2 K WOB and 20 FPH/ROP.;Slide drill from 1178' to 1196' at 550 gpm/1125 psi, P/U 84 K, S/O 80 K, WOB 5 K. ROP 15 ft/hr.;Rotary drill from 1196to 1227' at 40 rpm/3K TRQ, WOB 5K, ROP 45.;Slide drill from 1227' to 1292' at 550 gpm/1150 psi, WOB 10 K.;Rotary drill from 1292' to 1324' at 550 gpm/ 1200 psi, 40 rpm/4K trq. Circulate while a -line rigs up to Gyro.;Single shot survey with Pollard a -line in string.; Daily fluid loss: 0 bbls. Total fluid loss: 0 bbls 13 3/8 x conductor annulus: 0 psi 7/26/2019 Directional drill from 1324' to 1511'. 90 P/U ,85 S/O , 87 Rot, 65 RPM, 4 -5 torque, 5 - 15 WOB, 545 GPM/1250 psi. 31.2 ROP avg. Max gas 211 units. Gyro surveys at 1275'1373'.;Directional drill from 151 V to 1666'. 92 P/U ,87 S/O , 90 Rot , 55 RPM , 4 -5 torque, 5 - 15 WOB, 800 GPM/2200 psi. 51.6 ROP avg. Max gas 182 units. Pumped 20 bbl sweep at 1565' bringing back 10% excess in cuttings.; Perform clean up cycle at 800 GPM/2150 psi while rotating at 70 RPM and reciprocating full stand. Brought back +-15 bbis of cuttings.; Directional drill from 1666' to 1761'. 92 P/U, 87 S/O, 90 Rot, 55 RPM, 4 5 torque, 5 - 15 WOB, 800 GPM/2200 psi. 47.5 ROP avg. Max gas 330 units.; Directional drill from 1761'to 1855'. 92 P/U, 87 S/O, 90 Rot, 55 RPM, 4 -5 torque, 5 - 10 WOB, 800 GPM/2200 psi. 94 ROP avg. Max gas 160 units.; Perform cleanup cycle at 800 GPM/2150 psi while rotating at 70 RPM and reciprocating full stand. Brought back +-14 bbls of cuttings.; Directional drill from 1855'to 2043'. 92 P/U, 87 S/O, 90 Rot, 55 RPM, 4 -5 torque, 5 - 10 WOB, 800 GPM/2175 psi. 62.6 ROP avg. Max gas 400 units.; Perform cleanup cycle at 800 GPM/2175 psi while rotating at 70 RPM and reciprocating full stand. Brought back +-15 bbis of cuttings.; Directional drill from 2043' to 2,252' 110 P/U, 100 S/O, 105 Rot, 70 RPM, 4 K torque, 5 - 10 WOB, 800 GPM/2300 psi. 69.6 ROP avg. Max gas 1163 units.; Perform cleanup cycle at 800 GPM/2275 psi while rotating at 70 RPM and reciprocating full stand. Brought back +-20 bbis of cuttings.; Directional drill from 2,252' to 2,331 112 P/U, 105 S/O, 108 Rot, 70 RPM, 4 K torque, 5 - 10 WOB, 800 GPM/2300 psi. 39.5 ROP avg. Max gas 550 units.; Daily fluid loss: 0 bbis. Total fluid loss: 0 bbls 13 3/8 x conductor annulus: 0 psi Distance to Plan: 2168 MD/2116.13 TVD 30 H 8 R 7/27/2019 Directional drill from 2331'to 2517'. 120 P/U, 102 S/O, 110 Rot, 70 RPM, 4 K torque, 5 - 10 WOB, 800 GPM/2300 psi. 46.5 ROP avg. Max gas 550 units. Pumped 40 bbl sweep at 2430'. Sweep back on time with 25% increase in cuttings.; Service rig. Grease crown and TDS.;Circulate and condition mud while rotating at 70 RPM and reciprocating pipe a full stand. 800 GPM/2250 psi.;Continue circulating and cleaning hole while waiting on more cuttings totes. Rotating at 70 RPM and reciprocating pipe a full stand. 560 GPM/1280 psi.;Offload work boat while continuing to circulate and drain LVT to rig tanks.; Directional drill from 2517'to 2637'. 120 P/U, 102 S/O, 110 Rot, 70 RPM, 8 K torque, 5 - 10 WOB, 800 GPM/2300 psi. 48 ROP avg. Max gas 418 units.; Directional drill from 2637'to 2882'. 125 P/U, 105 S/O, 112 Rot, 70 RPM, 5 K torque, 5 - 20 WOB, 800 GPM/2350 psi. 54 ROP avg. Max gas 650 units.;Use MP#1 to pump sweep at 2880', MP#2 PRV popped with no pressure build up, Circulate and reciprocate at 442 GPM/900 psi, 40 rpm / 5K Torque while changing out PRV.; Directional drill from 2882'to 2894'. 125 P/U, 105 S/O, 112 Rot, 70 RPM, 5 K torque, 12K WOB, 800 GPM/2380 psi. 48 ROP avg. Max gas 50 units.; Directional drill from 2894'to 3051'. 126 P/U, 103 S/O, 112 Rot, 70 RPM, 6 K torque, 12K WOB, 800 GPM/2350 psi. 45 ROP avg. Max gas 308 units.;Fix rod wash hose on MP#1, circulate and reciprocate at 450 GPM/1070 PSI.; Directional drill from 3051'to 3116' 126 P/U, 103 S/O, 112 Rot, 70 RPM, 6 K torque, 12K WOB, 800 GPM/2350 psi. 32.5 ROP avg. Max gas 40 units.;Daily fluid loss: 0 bbls. Total fluid loss: 0 bbls 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 2924 MD/2753.67 TVD, 17 H, 13 R 7/28/2019 Directional drill from 3116' to 3275' 126 P/U, 103 S/O, 112 Rot, 70 RPM, 9 K torque, 12K WOB, 800 GPM/2450 psi. 53 ROP avg. Max gas 256 units. Pumped 40 bbl weighted sweep coming back 31 bbls late with no increase in cuttings.; Perform clean up cycle. Pump at 800 GPM/2400 psi. 70 RPM/8.5 K torque. Reciprocating full stand.; Directional drill from 3275' to 3368' 134 P/U, 100 S/O, 113 Rot, 70 RPM, 10 K torque, 12K WOB, 800 GPM/2450 psi. 37.2 ROP avg. Max gas 521 units.;After connection MP #1 would not come on. Troubleshoot issue. Found fuse microswitch was loose in SCR panel.; Directional drill from 3368' to 3652' 140 P/U, 98 S/O, 114 Rot, 70 RPM, 17 K torque, 20 K WOB, 800 GPM/2450 psi. 35.5 ROP avg. Max gas 447 units. Pumped tandem sweep at 3525' coming back with no increase in cuttings and 35 bbls late.; Directional drill from 3652'to 3745' 140 P/U, 98 S/O, 115 Rot, 70 RPM, 9 K torque, 25 K WOB, 800 GPM/2650 psi. 46.5 ROP avg. Max gas 53 units.;Perform clean up cycle. Pump at 800 GPM/2450 psi. 70 RPM/8 K torque. Reciprocating full stand.; Directional drill from 3745'to 4031' 145 P/U, 100 S/O, 118 Rot, 70 RPM, 9 K torque, 25 K WOB, 800 GPM/2750 psi. 46.5 ROP avg. Max gas 160 units.;Perform clean up cycle. Pump at 800 GPM/2450 psi. 70 RPM/8 K torque. Reciprocating full stand.; Directional drill from 4031'to 4300' 160 P/U, 100 S/O, 120 Rot, 70 RPM, 9 K torque, 10-25 K WOB, 800 GPM/2750 psi. 67.25 ROP avg. Max gas 100 units.;Daily fluid loss: 0 bbls. Total fluid loss: 0 bbls 13 3/8 x conductor annulus: 0 psi Distance to Plan: 4059 MD/3370 TVD 1 H 5 7/29/2019 Directional drill from 4300' to 4406' 155 P/U, 100 S/O, 125 Rot, 70 RPM, 12 K torque, 10-25 K WOB, 800 GPM/2750 psi. 53 ROP avg. Max gas 50 units.;Perform clean up cycle. Pump at 800 GPM/2600 psi. 70 RPM/8 K torque. Reciprocating full stand. Pumped Hi-Vis sweep coming back 35 bbls late with no increase.; Directional drill from 4406' to 4537' 165 P/U, 100 S/O, 125 Rot, 70 RPM, 12 K torque, 10-25 K WOB, 800 GPM/2800 psi. 43.6 ROP avg. Max gas 615 units.; Directional drill from 4537' to 4691' 165 P/U, 100 S/O, 125 Rot, 70 RPM, 12 K torque, 10-25 K WOB, 800 GPM/2800 psi. 61.6 ROP avg. Max gas 326 units.;Perform clean up cycle. Pump at 800 GPM/2680 psi. 70 RPM/8 K torque. Reciprocating full stand. Pumped Hi-Vis sweep coming back 37.5 bbis late with no increase.; Directional drill from 4691' to 4840' 175 P/U, 100 S/O, 127 Rot, 70 RPM, 13 K torque, 10-25 K WOB, 800 GPM/2800 psi. 59.6 ROP avg. Max gas 345 units.; Directional drill from 4840' to 4974' 180 P/U, 100 S/O, 130 Rot, 70 RPM, 10-14 K torque, 14 K WOB, 800 GPM/2800 psi. 44.6 ROP avg. Max gas 345 units.;Perform clean up cycle. Pump at 800 GPM/2680 psi. 70 RPM/8 K torque. Reciprocating full stand. Pumped Hi-Vis sweep coming back 25 bbls late with <5% increase.;Service top drive. Tie up service loop cover.; Directional drill from 4974' to 5050' 182 P/U, 100 S/O, 132 Rot, 70 RPM, 10- 12 K torque, 12-14 K WOB, 800 GPM/2850 psi. 50.6 ROP avg. Max gas 155 units.; Directional drill from 5050' to 5258' 185 P/U, 100 S/O, 132 Rot, 70 RPM, 10- 12 K torque, 12-15 K WOB, 800 GPM/2800 psi. 34.6 ROP avg. Max gas 155 units.;Daily fluid loss: 0 bbls. Total fluid loss: 0 bbls 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 5098 MD/3911 TVD, 1 Low, 13 Left 7/30/2019 Perform clean up cycle at 5258'. Pump at 800 GPM/2680 psi. 70 RPM/8 K torque. Reciprocating full stand. Pumped Hi-Vis sweep coming back 25 bbls late with <5% increase; Directional drill from 5258' to 5351'. 188 P/U, 100 S/O, 132 Rot, 70 RPM, 10- 20 K torque, 12-15 K WOB, 800 GPM/2800 psi. 46.5 ROP avg. Max gas 155 units;Circulate Hi-Vis sweep and 2 times bottoms up.;BROOH from 5351' to 4587' without issue. 800 GPM/2600 psi. 70 RPM/9 K torque. 188 P/U, 100 S/O, 132 Rot,;Continue BROOH from 4587' to 3800'. Had slight pack -off and stalling issues.; Circulate at 800 GPM/2400 psi while rotating at 70 RPM/8 K torque and working full stand from 3900' to 3810'. Hole unloaded with fist size coal and fines (+-15 bbls). 105 units of gas;Continue BROOH from 3800' to 2950'. Had slight pack -off and stalling issues.; Circulate at 800 GPM/2400 psi while rotating at 70 RPM/8 K torque and working full stand from 3000' to 2900'. Hole unloaded with fist size coal and fines (+-13 bbls). 125 units of gas.;Continue BROOH from 2950' to 2610'. Pack -off and stalling issues. Lost circulation but was able to regain after RIH 1 stand.;Circulate at 800 GPM/2400 psi while rotating at 70 RPM/8 K torque and working full stand from 2750' to 2650'. Hole unloaded with fist size coal and fines (+-25 bbls). 605 units of gas.;Continue BROOH from 2650' to 2550'. Slight pack -off and stalling issues. Work stand until shakers clean up.;Continue BROOH from 2550' to 1480'. Slight pack -off and stalling issues. Work stands until shakers clean up;Wash from 1480' to 1090', get through the shoe with no issues.; Daily fluid loss: 0 bbls. Total fluid loss: 0 bbls 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 5288 MD/4005 TVD, 3.76 H, 13 Left 7/31/2019 Circulate bottoms up inside shoe at 1093' at 800 GPM/2100 psi.; POOH on elevators to BHA at 635'.;Work BHA. Rack back HWDP and jars. Change out XO's to stand back remainder of BHA except mud motor and bit. Down load MWD. (Prepare MP #2 for PRV change out. Assist welder as needed).;Cont. I/D BHA.;Clean & clear floor.;M/U Johnny Wacker & flush stack, Pump out stack, pull wear bushing.;M/U 5" Test it, RIH & set test plug, fill stack & surface eq. w/ test fluid.;Test BOPE as per Hilcorp & AOGCC requirements, witness was waived by inspector Guy Cook, test with 5" TJ, Annular 250/2500, test 250/4000 all other components.; Drain stack, pull test plug, install wear bushing, break down test joint & eq.;Service RIG, clean & clear floor, install PRV's on mud pumps, c/o saver sub, test m/p manifold's t/4k good.; Daily fluid loss: 0 bbls. Total fluid loss: 0 bbls 13 3/8 x conductor annulus: 0 psi distance to Plan: 0 5288 MD/4005 TVD 3.76 H 13 Left 8/1/2019 Pickup BHA #2: Mill tooth assembly. Load MWD and shallow hole test.;RIH with BHA assembly #2 to 1095'.;Circulate and condition mud. 650 GPM/1800 psi.; Run in open hole on elevators to 2606'. Wash and ream 2675' - 2796', 2965' - 2980' and 3088' - 3266'. 750 GPM/2800 psi. 70 RPM/9 K torque. P/U 125, S/O 90, Rot 100. Set downs of 50 K before washing and reaming. RIH on elevators to 3550'.;Cont. Run in open hole on elevators to 4043". Wash and ream 4043' - 4114', 4843' - 4874' and 5012' - 5050'. 750 GPM/3200 psi. 70 RPM/9-13K torque. P/U 175, S/O 110, Rot 125. Set downs of 50 K before washing and reaming. Wash down last 2 stands f/ 5060-5342'.;Pump 10 bbl high vis sweep, 750 GPM/3200 psi. 70 RPM/9-13K torque. P/U 175, S/O 110, Rot 125, rot & reciprocate. no significant cutting s with sweep.;Lost power, production troubleshoot & repair, monitor well while getting back on Iine.;Cont. CBU.;Make connection, get SPR, wash down & drill f/ 5351', t/5452' circ. 760gpm, 3400psi, rot 65rpm, 9k off, 11-13k on, rot wt 130k, up wt 180k, do wt 110k wob 12-17, rop 13-18.;Daily fluid loss: 64.3 bbls. Total fluid loss: 187.3 bbls 13 3/8 x conductor annulus: 0 psi Distance to Plan: 0 5374 MD/4046 TVD 7.28 H 13.23 Left 8/2/2019 Directional drill from 5452' to 5534' 180 P/U, 110 S/C, 130 Rot, 70 RPM, 11- 13 K torque, 12-14 K WOB, 765 GPM/3350 psi. 27.3 ROP avg. Max gas 30 units.;Perform clean up cycle. Pump at 750 GPM/3150 psi. 70 RPM/8 K torque. Reciprocating full stand. Pumped Barolift Forta super sweep bringing back 30% increase in cuttings. After 4x BU cuttings still coming back. Bring mud weight up to 9.0 ppg and black product up to 10 ppb.;Pump second sweep bringing back 60% increase in cuttings. Recovered 20 bbls cuttings.; POOH on elevators from 5534' to 4074'. P/U 180, S/O 100. Encounter over pull of 50K. Back ream 4074' to 4023'. 720 GPM/2700 psi. 85 RPM/12 K torque. POOH on elevators from 4023' to 3380'. Back ream 3380' to 3360'.;Cont. Back ream OOH f/3360 U 2602' (unable to pull on elevators) circ 7GPM, 2650 psi, rot 75 RPM, 7k tq, rot wt 112k, up wt 150k, do wt 98k.;Cont. POOH on elevators, f/ 2602% UBHA up wt 125k, do wt 100k.;Stand back BHA in derrick.; Plug in t/MWD tool & download data.;Clear floor & c/o BIT.; Daily fluid loss: 6.5 bbls. Total fluid loss: 193.8 bbls Magnet collections 11.5# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 5469 MD/4091 TVD, 12.28 H, 13.08 Left 8/3/2019 Finish making up BHA #3. RIH to shoe at 1080'. Shallow hole test tools.;Change out drive rollers on ST-80. Service rig. Perform operational test on top drive torque issues. Obtain measurements for guard on torque tube rail.;RIOH on elevators to 3020'. Wash and ream 3020' to 3170' (800 GPM/2700 psi). RIH on elevators 3170' to 3940'. W/R 3940' to 4010' at full drilling rate.;Circulate bottoms up at 800 GPM/2700 psi while working full stand with no noticeable change in cuttings.;RIOH on elevators from 4010' to 4275'. W/R 4275' to 4300' at full drilling rate. RICH on elevators from 4300' to 5063'.;Cont. RICH on elevators from 5063% U 5344'.;Wash & ream f/ 5344' t/5533', circ.800 GPM, 3250 psi, rot 70 rpm tq. 10k, up wt 187, do wt 95k, rot wt 125k.;Directional drill from 5533' t/5630', up wt 190k, do wt 100k, rot wt 128k, rot 75 rpm, tq 14k, wob 28k, slide drill 5630% t/ 5675', rotary drill f5675' t/5780'.;Daily fluid loss: 6.5 bbls. Total fluid loss: 134.6 bbls Magnet collections day 5.5# total 17# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 5657 MD/4091 TVD, 18.39 H. 13.81 Left 8/4/2019 Directional drill from 5780' to 5820' 180 P/U, 110 S/O, 130 Rot, 80 RPM, 11- 13 K torque, 12-14 K WOB, 800 GPM/3000 psi. 18 ROP avg. Max gas 30 units. Back ream 3 stands and RIH to bottom. Make connection and pump Barolift Flora super sweep.; Directional drill from 5820' to 5883' 200 P/U, 105 S/O, 135 Rot, 80 RPM, 11- 13 K torque, 27-30 K WOB, 800 GPM/3150 psi. 20 ROP avg. Max gas 177 units. Sweep came back 25 bbls late with 20% increase.; Directional drill from 5883' to 6015' 200 P/U, 105 S/O, 135 Rot, 80 RPM, 11- 13 K torque, 27-30 K WOB, 800 GPM/3150 psi. 22 ROP avg. Max gas 229 units.;Directional drill from 6015' t/6100' up wt, 200, do wt 105, 135 Rot, 80 RPM, 11- 13 K torque, 27-30 K WOB, 820 GPM/3200 psi. 28 ROP avg. Max gas 318 units. Pump Barolift sweep.;Back ream f/6100' t/ 6010' while circulating sweep out, had 75% increase, 35 bbls Iate.;Cont. Back ream out U5816, up wt, 200, do wt 105 , 135 Rot, 80 RPM, tq. 11- 13K, .800 GPM/3100 psi.;Service rig, c/o service loop deflection rail.;Wash to bottom, f/5816' t/6100', up wt, 200, do wt 105 , .800 GPM/3100 psi.; Directional drill from 6100' t/6175' up wt, 200, do wt 105 , 135 Rot, 80 RPM, 11- 13 K torque, 27-30 K WOB, 820 GPM/3200 psi. 28 ROP avg. Max gas 280 units.; Directional drill from 6175' t/6245' up wt, 200, do wt 105 , 135 Rot, 80 RPM, 11- 13 K torque, 27-30 K WOB, 820 GPM/3200 psi. 23 ROP avg. Max gas 365units.;Daily fluid Ioss:O bbls. Total fluid loss: 134.6 bbls Magnet collections day 3.8# total 20.8# 13 3/8 x conductor annulus: 15 psi (c/o Gauge ) Distance to Plan: @ 6135 MD/4437 TVD, 9.87 H, 14.45 Left 8/5/2019 Directional drill from 6245' t/6385' up wt, 208, do wt 105 , 144 Rot, 85 RPM, 11- 13 K torque, 27-30 K WOB, 800 GPM/3250 psi. 29 ROP avg. Max gas 365 units. Pumped Barolift sweep at 6345' coming back 12 bbls late with 60% increase in cuttings.;Back ream at full drilling rate from 6385' to 6290'.;4" Fig. 1002 gasket failed on standpipe just below floor manifold. Had to pull HP line apart from cellar flange up to rig floor to be able to change out gaskets. Reassemble and test line at 3000 psi.;Back ream at full drilling rate to 6198'. Wash and ream back to bottom at 6385' without issue.; Directional drill from 6385' t/6392' up wt, 208, do wt 105 , 144 Rot, 85 RPM, 11- 13 K torque, 27-30 K WOB, 800 GPM/3250 psi. 29 ROP avg. Max gas 65 units.;Begin having power limit issues. Troubleshoot with platform electrician and rig mechanic. Generators going down due to overheating and source water failure. Resolve problem.; Directional drill from 6392' t/6412' up wt, 208, do wt 105, 144 Rot, 85 RPM, 11- 13 K torque, 27-30 K WOB, 800 GPM/3250 psi. 19 ROP avg. Max gas 365 units.; Directional drill from 6412' t/6565' up wt, 208, do wt 105 , 144 Rot, 85 RPM, 11- 13 K torque, 27-30 K WOB, 800 GPM/3250 psi. 27 ROP avg. Max gas 390 units.; Begin having power limit issues. P/u & s/d to one pump, Troubleshoot with platform electrician and rig mechanic. Generator 1 going down due to low coolant from leak on flange, #2 went down on high heat, get #2 & #3 gen back on line, start pumping & swivel packing leaking, service same.; Directional drill from 6565 t/6570' up wt, 208, do wt 105, 144 Rot, 85 RPM, 11- 13 K torque, 27-30 K WOB, 800 GPM/3250 psi. swivel packing leaking.; Service swivel packing & tighten, come back on line with pumps & blew suction pop off, reset same & evaluate power issues.; Bring pumps back up to drilling speed & packing leaking , C/C same.; Directional drill from 6570 t/6575 up wt, 208, do wt 105, 144 Rot, 85 RPM, 11- 13 K torque, 27-30 K WOB, 700 GPM/2640 psi., stalled out 2x, tripped pop offs, repaired same.;Daily fluid Ioss:O bbls. Total fluid loss: 134.6 bbis Magnet collections day 3# total 23.8# 13 3/8 x conductor annulus: 15 psi Distance to Plan: @ 6414 MD/4588 TVD, 3.04 H, 16.3 Left 8/6/2019 Directional drill from 6575' t/6659' up wt, 208, do wt 105 , 144 Rot, 85 RPM, 11- 18 K torque, 27-30 K WOB, 800 GPM/3200 psi. 12 ROP avg. Pump Barolift sweep at 6625'. Came back 21 bbls late with 50% increase. Max gas 206 units.; Directional slide drill f/6659' t/6720' up wt, 208, do wt 105 , 27-30 K WOB, 700 GPM/2700 psi. 12 ROP avg.; Directional drill F/6720' T/6,801' up wt 220K, do wt 105K, Rot wt. 145K 27-30 K WOB, 700 GPM/2700 psi. 85 RPM - 12K TQ, 13.5 ROP avg. Max gas 298 units. Pump Barolift sweep at 6,751', came back with a 40% increase in cuttings.; Directional drill F/6801' T/6909' up wt 227K, do wt 107K, Rot wt. 147K 25-30 K WOB, 700 GPM12750 psi. 85 RPM - 12K TQ, 18 ROP avg. Max gas 318 units.;Daily fluid loss:0 bbls. Total fluid loss: 134.6 bbls Magnet collections day 3# total 27.8# 13 3/8 x conductor annulus: 20 psi Distance to Plan: 6 791' MD/4 791' TVD 6.65 Low, 15.14 Left 8/712019 Directional drill from 6909' to 6928', UW 225K, SO 107K, Rot Wt 147K, 700 GPM - 2750 Psi, 85 RPM = 11-12K TQ, 25-30K WOB, Max Gas=109 Units, 9.5 ROP.;Perform clean up cycle at 6859'. Pump at 700 gpm / 2575 psi, 85 rpm/11 to 14K TQ, Reciprocate full stand. Pump 2 HiVis sweeps.;Finish clean up cycle at 6859' with mud pump #2 at 428 gpm/1100psi, 85 rpm/12K torque, Reciprocate full stand. Tighten discharge flange on mud pump #1.;Pull out of hole to 6198'. BROOH from 6198' to 5990'. Pack off and stalling issues. UW 225K, 20 110K, ROT 145K.;Work through tight spot at 5990', establish circulation with both pumps at 700 gpm /2650 psi. 75 rpm / 10K torque, slight pack off and stalling issues to 5914'.;BROOH from 5914' to 5252'. 600 gpm / 2000 psi. 85 rpm / 10-12K torque. Slight pack off and stalling issues.;Daily fluid Ioss:88 bbls. Total fluid loss: 142.6 bbls Magnet collections day 0# total 27.8# 13 3/8 x conductor annulus: 20 psi Distance to Plan: Ca 6 929' MD/4 458' TVD 1.91 Low, 10.89 Left" 8/8/2019 Cont. BROOH addressing problem areas as needed f/ 5252'. t/ 4027'600 gpm / 2000 psi. 85 rpm / 10-12K torque.rot wt 127k up wt 150, do wt 95k Tight spots.;POOH on elevators f/4027', t/3306', up wt 150k, do wt, 95k.;BROOH f/ 3306'. t/ 2608% 630 gpm / 1880 psi. 85 rpm / 10-12K torque.rot wt 115k.;CBU clean @ 2608' at 640 gpm / 1800 psi, 75 rpm / 5K torque, reciprocate pipe, stage pumps up to 800 gpm / 2500 psi the last BUS. UW 130K, SO 100K, ROT 115K.;POOH from 2512' to 906' on elevators, slight overpull at 1793' and 1724'.;Trouble shoot Top Drive torque issues with NOV tech, download information to be analyzed.;POOH from 906to 622', handle BHA per Baker DD / MWD.;Daily fluid loss:45.7 bbls. Total fluid loss: 188.3 bbls Magnet collections day 2.0# total 29.8# 13 3/8 x conductor annulus: 20 psi Distance to Plan: CZD 6 929' MD/4 458' TVD 1.91 Low, 10.89 Left 8/9/2019 Clean and organize rig floor, make up tool and flush stack, blow down all lines and drain stack.;Rig up all equipment needed for testing, set test plug and fluid pack system.;Test BOPE per sundry to 250 psi low / 4000 psi high and chart each test 5 minutes. Test annular to 250psi low / 2500 psi high. AOGCC witness waived & extension granted By inspector Jim Regg.;Set wear ring, rig down all test equipment, drain stack and blow down all Iines.;Work with NOV tech and trouble shoot top drive torque parameters.; Perform a rig service from the crown down. Check accumulator bottles.;Lay down Directional BHA per Baker DD / MWD.;Make up clean out BHA and run in hole to 1025.83'.;Secure service loop cover.;"Daily fluid loss:0 bbls. Total fluid loss: 188.3 bbls Magnet collections day.0# total 29.8# 13 3/8 x conductor annulus: 20 psi Distance to Plan: @ 6,929' MD/4,458' TVD, 1.91 Low, 10.89 Left" 8/10/2019 Secure service loop sock and run in hole from 1025' to 1400'.;Observe a problem with the fast line sheave on the blocks, inspect same and troubleshoot problem.;Pull into casing from 1400' to 1025'.;Swap drilling line over to string up line. Unpin blocks and secure on the rig floor.;Start to unload 9 5/8" casing off the boat. Pull pin and sheaves out of the blocks, with 3rd party inspection, note all measurements and tolerances.;Continue to analyze problem with sheaves and off load 9 5/8" casing from boat. Drift and strap casing. Clean up block, sheaves and bearings, prepare for reassembly.; Daily fluid loss:0 bbls. Total fluid loss: 188.3 bbls Magnet collections day.0# total 29.8# 13 3/8 x conductor annulus: 20 psi Distance to Plan: @ 6,929' MD/4,458' TVD, 1.91 Low, 10.89 Left 8/11/2019 Continue to evaluate measurements pulled off block frame. Finish off loading 9 5/8" casing from boat, drift, strap and tally same. Fix air leak on draw works.;Change out bearings & seals on 2 sheaves, receive new spacers for block assembly, Assemble blocks, check tolerances as per NOV drawing/procedure #10738491 good, pin back on top drive. String up blocks and cut 100' of drill Iine.;Spool up 3/8" string up line. Adjust tq. tube, set block height. Clean & clear floor. check COM, find mount plate had cracked weld, wk on repair same. 8/12/2019 Cut out mounting bracket for crown saver, reinstall new, test same good.;TIH f/1023', t/2653' up wt 117k, do wt 83k.;Tag tight @ 2653' wash & ream, cleaning up, cont wash down t/2823' rot 7-10 dn, 75 up , stage pumps up t/ 830 gpm, 1625 psi.;TIH t/3860'.;Wash & ream f/3860 t/4230', rot 7-10 dn, 75 up , stage pumps up t/ 750 gpm, 1525 psi.;TIH to 4500', wash and ream to 4800', TIH to 5080', wash and ream to 5175', TIH to 5570', wash and ream to 5810', stage pumps to 600 gpm, 1600 psi.;Tight, back ream 5833' to 5793', clean up and pump bottoms up at 600 gpm / 1650 psi UW 205K, SO 100K, ROT 135K.;Tight 5810' to 6040', pack off problems at 6020', stage pumps and establish circulation at 580 q pm ! 1560 psi. 8/13/2019 Cont. stage pumps up t/800GPM, 2260 psi, rot 15 rpm, 7-8k Tq. rot wt 135k.;Wash & ream F/ 6040' t/6095' 15 rpm, 8k tq. 135k rot wt, up wt 205k , do wt 100k.;Start Packing off @6095' lost circ, wk pipe up trying to est circ t/5920' getting sporadic circ and unable to keep it for any length of time.;Continue work pipe ooh attempting to get and keep circ and rotation f/ 5920' t/ 5836'.;Work full stand up/Dn/Rot 205l105/ 133 f/ 5836' U 5746' and Stage up circ t/ 700 gpm @ 1800 psi and stage up rotation V 100 rpm @ 13.5 -14k torque w/ high gas of 362 units. Get 75 bbls. of cuttings back.;Assist the NOV tech with torque adjustment and parameter changes on the top drive.;Wash and ream from 5746' to 6200', tight, work through problem area's with pack off tendencies, stage up circulation and rotation.;Work full stand up/Dn/Rot 205/105/ 135 f/ 621 O' t/ 6120' and Stage up circ t/ 700 gpm @ 1800 psi and stage up rotation t/ 125 rpm @ 12-16k torque w/ high gas of 1,225 units. Get 20+- bbls. of cuttings back. pump 3rd bar -a -lift sweep @ 1/2 PPB w/ 70% increases and 95 bbls late and;Chase w/ Btm up to clean hole.;Daily fluid loss:55.8 Wis. Total fluid loss: 293 bbls Magnet collections day.0# total 29.8# 13 3/8 x conductor annulus: 0 psi Distance to Plan: 6 929' MD/4 458' TVD 1.91 Low, 10.89 Left 8/14/2019 Finish clean up cycle , circ. 2nd btm after 3rd sweep.;establish up/dn parameters w/ out pump , Service wash pipe and make Conn w/ tong back up for NOV rep to video.;Attempt rih on elevators w/ no joy . Wash and ream and work through pack -off issues f./ 6120' t/ 6504' (27' into next coal seam ) work pipe back above coal and regained rotation and circulation @ 6470'.;Stage up pumps V 711 gpm and rotation @ 120 rpm and establish full std working pipe window and pump 6504' V 6412' circ 4th 1/2 ppb bar-o-lift sweep around @ 40 bbls w/ 30% increase and 119 bbls Iate.;Attempt rih on elevators w/ no joy, Wash and ream t/ at tag btm at 6929' w/ no pack off issues and stage up V drilling rate @ 802 gpm 2342 psi and 120 rpm.;Drill f/ 6929' V 6950' to fit casing.;Circ. btm up w/ sample @ 60% sand and 40% silt stone / clay stone w/high gas of 833 units and pump 5th Bar-o- lift @ 1/2 PPB sweep around @ 812 gpm and 150 rpm, reciprocate between 6950' - 6885'.;Stand back 1 stand and circ. 2 BUS between 6885' and 6790'at 800 gpm / 2300 psi , 150 rpm / 10-12K Torque until shakers clean up. UW 220K, SO 107K, ROT 145K.;Attempt to pull from 6790' with pump off, no joy, Pump out of hole from 6790' to 5440' at 700 gpm / 1600 - 1800 psi, UW 190 - 250K, SO 107K.;Pump out of hole from 5440' to 4614' at 710 gpm / 1680 psi. Saw coals when going through them, never more than 20K over pull, wiped clean after 1 time through. Slight pack off at 4674', regain circulation immediately on slack off, work 2 times, cleaned up.;Change swab in MP#2, Work from 4614' to 4520' at 450 gpm / 660 psi.;Circulate hole clean F/ 4520' to 4427' at 800 gpm / 1800 psi, 150 rpm / 10-12K torque.;Daily fluid loss:17.8 bbls. Total fluid loss: 310.8 bbls Magnet collections day.4.0# total 35.8# 13 3/8 x conductor annulus: 0 psi Distance to Plan: 0 6,929' MD/4 458' TVD 1.91 Low, 10.89 Left 8/15/2019 Finish clean up cycle and Circulate hole clean F/ 4520' to 4427' at 800 gpm / 1800 psi, 150 rpm / 10-12K torque.;Resume Pumping out of hole F/ 4427' T/ 3765' at 700 gpm / 1300 - 1400 psi, UP 155- 165K - DN 105K, and work through tight spots attempting Not to pull over 25-35k without wiping area.; Rotate and reciprocate f/ 3860' V 3765' and preform clean up cycle and un load well @ 800 gpm 1700 psi and 100 rpm.;Resume Pumping ooh f/ 3765' V 3100' at 700 gpm / 1300, UP 165K - DN 105K, and work through tight spots attempting Not to pull over 25-35k without wiping area do to one MP continue pooh @ 420 gpm @ 500 psi up/160/dn 90k While chg valve and seat in #2MP pod #1 both suction and discharge sides.;Both pumps back on line preform clean up cycle and work full std at 700 gpm and 100 rpm f/ 3100' V 3010' and circ clean before pulling out of 60 Deg hole.;Resume Pumping ooh f/3010' t/1970' at 700 gpm / through curve and to get above coals.; Pooh on elevators F/1970' - T/555'. Pull through shoe with no drag or issues.;Stand back HWDP and jars, lay down drill collars, stabilizers and bit.;Change out upper pipe rams to 9 5/8" fixed bore rams. Tighten bolts on top of annular. Pull wear ring and build test joint. Remove drilling line from power spooler. Empty premix from Rain 4 Rent tank and reserve pit to 2 ISO's. Fill 1 ISO with OBM.;Replace seals on test plug. Test 9 5/8" Fixed bore upper pipe ram to 250 psi/3000 psi, chart 5 minutes each test. Rig down all test equipment.;Clean and organize rig floor, prep to run casing.;Rig up Weatherford 9 5/8" handling equipment.; Daily fluid Ioss:35.8 bbls. Total fluid loss: 346.6 bbls Magnet collections day.0.0# total 35.8# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 6,929' MD/4,458' TVD, 1.91 Low, 10.89 Left 8/16/2019 P/up 9-5/8" 47# L-80 shoe tract as per plan & test floats (ok) and install baffle.;Adjust torque rail east to center volant tool in csg and rehang tong on ODS and repair power tongs (fwd/rev pin sheered) all hands on board participated in Hilcorp random UA program wl two AAO failures.;Continue w/ UA for crew chg and Continue P/up m/up 9-5/8" 47# L-80 DWC/C casing as per drilling running tally filling on the fly and topping off every 4 jts V 1062' work boat fill 400 bbl water tank w/ potable water.;Brk circ with volant CRT and circ warm mud @ 272 gpm @ 200 psi Prep deck work boat bring on cmt unit and cmt tools and run four jts out door f/ 1062' V 1183' and resume circ while waiting on crane to reload door.;Resume p/up 9-5/8" 47# L-80 DWC/C casing f/ 1183' V 2476' as per drilling running tally filling on the fly topping off ever 4 jts.;Pump a bottoms up to at 272 gpm / 200 psi, at 2476', had 200 units of gas, good circulation UW 155K, SO 115K.;Resume p/up 9-5/8" 47# L-80 DWC/C casing f/ 2476' V 2670' as per drilling running tally filling on the fly topping off ever 4 jts UW 155K, SO 117K.;Resume p/up 9-5/8" 47# L-80 DWC/C casing f./ 2670' V 3058" as per drilling running tally filling on the fly topping off ever 4 jts Set down 20K, tryto work through with no joy.;Wash from 3058' to 3175' at 6.5 bpm / 273 gpm / 200 psi. UW 155-180K, SO 115-90K.;Resume p/up 9-5/8" 47# L-80 DWC/C casing f/ 3175' t/ 4198' as per drilling running tally filling on the fly topping off ever 4 jts UW 220K, SO 130K.;Pump a bottoms up at 272 gpm / 250 psi while reciprocating pipe. UW 220K, SO 130K.;Daily fluid loss:O bbls. Total fluid loss: 346.6 bbls Magnet collections day.0.0# total 35.8# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 6,929' MD/4,458' TVD, 1.91 Low, 10.89 Left 8/17/2019 Continue P/up 9-5/8" 47# L-80 DWC/C casing and Rih on elevators f/ 4198' V 5643' as per drilling running tally filling on the fly topping off ever 4 jts up 280k do 115k.;Work full jt and circ btm @ 6.5 bpm @ 320 psi @ 5643' up 280k do 145k crew chg.;Continue rih washing jts do and encountered tight spot @ 5833'.;Attempt work and wash and ream past and hung pipe w/ slight rotation and +- only 4' of movement Discuss options w/ town.;dump two bbls lube into mp suction and pump around shoe tract while working pipe also applied 130 psi to annulus and pump way 6 bbls w/ no joy continue work pipe and establish rotation.;Try to circulate while rotating, stalls , lose rotation, gain circulation and pack off when trying to rotate, work pipe until circulation can be established.; Stage pump rate up to 6.5 bpm, 360 psi. Circulate BUS x2, lots of fines coming over shakers.;Mix a 15 bbl. NXS Lube pill, pump and spot outside casing shoe. Stage rate up to 8.5 bpm / 450 psi, slow down to 2.0 bpm around corner.; Establish 2.5 bpm / 200 psi and rotate casing at 35 rpm / 28K torque. Stage pump up to 6.5bpm / 350 psi, Rotation up to 45 rpm / 29K torque. Try to work string, lose rotation and then pack off. Work pipe and able to establish circulation, start to stage up to 6.5 bpm.; Daily fluid Ioss:O bbls. Total fluid loss: 346.6 bbls Magnet collections day.0.0# total 35.8# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 6,929' MD/4,458' TVD, 1.91 Low, 10.89 Left 8/18/2019 Stage up pump rate t/ 7.5 bpm and attempt to sustain rate and work thru Pack off issues & prep for two stage cmt job ( Boats still un able to get into dock due to wind Borrow needed storage totes from Rig #151 r/dn casing tongs and r/up Cmt unit lines and hoses mix spacer.;Shut do Mud pump and remove Volant CRT & r/up Cmt head.;Resume circ and stage up V 6.5 bpm finish mixing mud push & prep for cmt job.;PJSM ; Pressure test cement Iines.;Pump Stage 1 cement job per plan; At 175 bbls. away on 2nd displacement with rig, pack off, attempt to work string 325K UW, 75 SO, no circulation. Keep pumping at 2 bpm, bump plug at 226 bbls away and 2300 psi.;Check floats - good. Load 2nd stage plug. Shear pins in cementer at 8 bbls pumped 12900 psi. Circulate through cementer at 7 bpm / 650 psi, Observe no mud push back.;Circulate while waiting on cement and boat at 7 bpm / 650 psi.;Daily fluid loss:97.7 bbls. Total fluid loss: 444.3 bbls Magnet collections day.0.0# total 35.8# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 5,818' MD/4,265' TVD, Low, Left 8/19/2019 Continue Ciro .through open ES cementer @ 3318' @ 7 bpm @ 650 psi and prep for 2nd stage cmt job, House cleaning and full rig service and maintenance MTU service go through MP fluid ends, chg/out and test crown-o-madic cylinder, inspect and adjust dwk brakes , Build mud push,;go through and service low torque valves on cmt manifold Work boat take on cement for 2nd stage, fill cement water tanks fill platform water tank, work cargo , back load equipment, fill Iso tanks w/ obm. Stage empty ISO on deck for spacer returns. Move mud in pits to make room for displacement.; Start stage 2 cement job on 9 5/8" casing. PT lines to 1073 psi / 4650 psi. Rig pumps 36 bbl clean spacer. Cementers pump 267 bbls, of 12 ppg Type 1/II cement at 5.5 bpm / 250 psi. Drop plug and pump 5 bbls of water. Rig pumps 245 bbls of 9.8 ppg OBM at 6.1 bpm, 550-780 psi.;Start seeing spacer back at 190 bbls pumped. Lower rate, plug does not bump, pump 40 bbls over. Consider cement in place at 23:30 hrs. Call town, strap pits and figure proper amount has been pumped. Get back 40 bbl spacer and 60 bbl cement.;Confirm that plug is stuck in cement head. Flush and drain stack. Clean flow line, trough and possum bellies. Clean pit #2 and flush lines. Pump contaminated fluid from ISO into cutting totes.;Daily fluid loss: 0 bbls. Total fluid loss: 444.3 bbls Magnet collections day.0.0# total 35.8# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 5,818' MD/4,265' TVD, Low, Left 8/20/2019 Continue WOC house clean, Pit cleaning and lines chg out seal and impeller and stuffing box on mix pump.;R/dn cmt head fluid level has drop in pipe t/ almost rig floor Verify Plug is just below fluid column. remove csg slips spider, Strip rotary table solid master bushing over csg stub clean out flow box and remove and strip 16" flow nipple over csg stub. Air drill two holes in csg 6' above annular;in 180 deg orientation install all thread through csg stub and secure in place w/ nuts and drain fluid through holes and secure Plug from going do hole. remove annular and rotate 90 deg w/ blocks and align lifting lugs w/ bridge cranes re -tighten annular.; Install bridge cranes in prep to split well head and lift stack to install emergency slips. Work string weight up to 180 K several times while cleaning out cement around casing stub. Install emergency slips.;Set down 85 K on hanger. R/U diamond cutter. Cut casing . Clean solids out of Pits #1 and #2. Back load cement into pods. Housekeeping in cellar and Koomey area.;Pull casing joint to rig floor and lay down. Install pack off. Nipple up BOP. Tested pack off 500 U3800 H.;Open ram doors and clean out cavities. Change top pipe rams to variables. Install flow nipple.;Daily fluid loss: 0 bbls. Total fluid loss: 444.3 bbls Magnet collections day.0.0# total 50.3# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 5,818' MD/4,265' TVD, Low, Left 8/21/2019 Continue open ram doors and clean out cavities. finish change top pipe rams to variables found mud seal on DS door of single gate sticking out meth. re - seated same and functioned piston (ok) Reinstall koomey lines r/dn bail extension and cleaning of pill pits;assist welder in cutting csg stub and retrieval of closing plug build 5" test it. R/up test equipment. Sparrow Crane inspector Inspected both cranes.;Re move fittings from csg spool and dress tbg spool. Fill stack w/ water purge air and shell test ok chg chart. work boat bring on 100 its 5" dp Repair CMV #5.;Test BOPE on 5" witness by AOGCC inspector Mr. Guy Cook. w/ no test failures but Test #6 had connection leak on XO to TDS had to chg out and retest ok Pull test joint to rig floor.;Perform injectivity test. Pumped a total of 7 bbls at .5 BPM and able to inject at 520 psi. Bled back 2.5 bbls. Consulted with engineer and decision made to proceed with picking up drilling assembly.; Break down test joint. Set empty spool on rotary table. Remove line guide rubbers. Hang blocks. Rig up to slip on new drill Iine.;Hold PJSM. Install drill line snakes. Spool new line through derrick without issue. Unspool drill line off of drawworks onto spool in rotary table. String new drill line into drum. Unhang blocks. Clear rig floor.;Daily fluid loss: 0 bbls. Total fluid loss: 444.3 bbls Magnet collections day.0.0# total 50.3# 13 3/8 x conductor annulus: 0 psi Distance to Plan: 0. 5 818' MD/4 265' TVD Low Left 8/22/2019 Remove hanging line and set and test crown -o- madic remove drill line spool of old line from rotary off rig floor. Service rig. Adjust torque tube to center TDS over hole. meth and mtr man work on CMV #5 (pressure locked) clean out DS pipe rack drain start strap dp P/up rabbit same.;Continue p/up rabbit and strap 5" 5-135 19.50# XT50 dp and rih 30 its while derrick man Dress out DS board continue house keeping and rig organization work boat Pooh and test rack dp on DS east pipe rack Strap pipe on deck and prep p/up BHA # 5.: Pick up BHA #5 as per DD's and 1 stand of drill pipe. Removed joint of bent HWDP and replaced. Laid down jars and replaced with new 6 1/2" jars.;Clean up and reorganize vac hoses. Clean and organize choke manifold area. Change out regulator on rig air multiplier.;RIH with BHA #5 picking up 5" S-135 19.50# XT50 drill pipe to 1755'. Shallow hole test MWD at 1500' (good).;Continue RIH picking up DP from 1755' to 3270'.;Tag ESC at 3319'. P/U 120, S/O 90. Set down 22K to 3324'. Shut in and pressure up to 750 psi with bleed off. Open bag. Set down 60 K and repeat with bleed off. Set down while circulating at 2 BPM and slight rotation. Saw indication of tool shift. Pressure uo to 1000 psi with annular shut and;hold for 5 minutes. Bleed off/open annular. PIU 3' and repeat pressure test to 1100 psi for 10 minutes (good test). Bleed off pressure/open annular.; Establish parameters: P/U 120, S/O 90, Rot 105. 335 GPM/950 psi. Drill ESC from 3323' to 3329' with 6 K WOB/9 K torque.;Daily fluid loss: 0 bbls. Total fluid loss: 444.3 bbls Magnet collections day.0.0# total 50.3# 13 3/8 x conductor annulus: 0 psi Distance to Plan: 5,818' MD/4 265' TVD Low Left 8/23/2019 Wash and ream from 3329' to 3470' to get past cmt stringers.;Rih on elevators f/ 3470' t/ 4429' up/dn 130/90k.;Circ and warm mud and stage up pump rate and rpm f/ 575 gpm @ 2700 psi and 120 rpm w/ 7k torque & circ clean (getting back a lot cmt ) 3X btm/up and work full std N 4429' t/ 4515'.;Rih on elevators f/ 4515' 5640' Kelly up.;wash and ream f/ 5640' t/ 5744' @ 525 gpm @ 2500 psi @ 120 rpm w/ 10k tq (work crew over crew chg late do to weather ).;Lost tds HPU trouble shoot same.;Continue wash and ream f/5744' t/ 5755'.;Rack back 2 std and r/up to test csg purge air and Test t/ 3299 psi >3166 psi in 30 min on chart r/dn test equipment wash in hole f/ 5658' U tag @ 5755'.;drill cmt and plugs f/ 5755' U top of float collar @ 5773' (lost MP #2 chg out bleeder valve?) continue w/ #1 mp @ 442 gpm @ 1800 psi @ 122 rpm @ 13-22k drill float collar and solid cmt U top shoe @ 5811442 MP back on line 579 gpm @ 2855b psi @ 100-125 @ 15-21 k.;Work full stand and circulate clean f/ 5814' while changing out CMV #5. Test same 250 U4000 H.;Drill float shoe from 5814' to 5818'. P/U 160, S/O 100, Rot 120/17 torque. 550 GPM/2650 psi.;Wash and ream with above parameters from 5818' to 5856'. +-10' of hard cement below shoe.;Work stuck pipe at 5856'. Had total pack -off and no rotation. Work pipe utilizing jars and pump with slack off to 90 K and staging jars up from 225 K to 300 K before working string free. Regain rotation and circulation. Pull up to 5850'. Set stand back and pick up working single.;Circulate and work pipe from 5800' to 5845' at full drilling rate. Hole continuing to unload quarter size pieces of coal. Wash and ream area from 5840' to 5877' experiencing pack -offs but able to pull up out of it. Hole continuing to unload cuttings while working pipe (>40 bbls). 550 GPM/2560 psi.;Continue working pipe from 5800' to 5877' cleaning hole and weighting up to 10.2 ppg.;Daily fluid loss: 0 bbls. Total fluid loss: 444.3 bbls Magnet collections day.0.0# total 58# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 5,818' MD/4,265' TVD, Low, Left 8/24/2019 Continue working pipe from 5800' to 5878' cleaning hole and weighting up to 10.2 ppg. (Coal cutting load has diminished and slight pack -off has disappeared ).;Rack back std w/ working single w/ bit in casing @ 5780'. Perform post jarring inspection of derrick and TDS. Service rig while continuing V circulate and weight up to 10.4+ ppg.;Circulate at 550 GPM/2500 psi while bringing mud weight up to 10.4 ppg.;Wash and ream in hole f/ 5780' to 5973' @ 550 GPM/2500 psi. 125 RPM w/ torque swings f10 V20 K.;Wash and ream in hole 5973' to 6067' @ 550 GPM/2500 psi. 150 RPM/ 12 K. Surveys show us to be 4 degrees above old hole with azimuth unchanged.; Drill from 6067' to 6103' (72' FPH/ ROP). Consult with engineer and decision made to stop here as this is'nevi hole.;Circulate clean up cycle and pump Barolift sweep while working stand. Sweep came back on time with 25% increase in cuttings. Continue circulating until shakers cleaned up. 10.4 ppg in/out.;BROOH at full drilling rate from 6103' to 5814' without issue.;Hole began unloading quarter size chunks of coal. Worked back through 5850' to 5860' area at 150 RPM/12 K torque, 500 GPM/ 2560 psi until shakers cleaned up. High gas of 460 units.;RIH in elevators to 6103'. Had 40 K set down at 5890' and washed and reamed through area until clean. POOH on elevators into shoe at 5816'.;Circulate and condition until mud was 10.4 ppg in and out.;Perform FIT to 13.7 ppg EMW.;Pump dry job. POOH with BHA #5.;Daily fluid loss: 49 bbls. Total fluid loss: 492 bbls Magnet collections day.0.0# total 58# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 6103 MD/4,411' TVD, Low, Left 8/25/2019 POOH with BHA #5, f/ 5800' V 4906'. Notice leak on flow nipple. Continue pulling 5 std V lower fluid level in flow nipple for air boot change out.;Change out air boot. Attempt POOH. Having air issues on clutch. Install oiler on air booster.;Resume POOH to BHA. Had mech look at brakes due to vibration. Adjust spring tension on brake band. Lay down BHA #5. Bit grade: 1,1,WT,AII, 1/16",BHA. Top stab had some chunking out damage and 1/16" out w/ heat checking. Bottom stab good. Calculated 58.1 bbls, actual = 62.6 bbls diff = 4.5 bbls.;Clear clean rig floor. Pull flow nipple. Check and install back up air boot rubbers.;Clear rig floor of BHA #5 components and prep to pick up BHA #6.;Pick up BHA #6 drilling assembly as per DD/MWD's.;RIH with BHA #6 to 630'.;Stage NPR's on rig floor. RIH to 2142' and shallow hole test .;POOH with 15 stands installing NRP's and standing back.;Service rig. Change dies in ST- 80.;RIH with BHA #6 to 5750' filling pipe and warming mud at 2650' and 5750'.;Warm mud and obtain SPR's before going into open hole.;Wash and ream at full drilling rate from 5818' to 5895'. P/U 123, S/O 1205 , 122 Rot, 125 RPM, 16 K torque, 500 GPM/2200 psi.;Daily fluid loss: 49 bbls. Total fluid loss: 492 bbls Magnet collections day.0.0# total 58# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 6103 MD/4,41 V TVD, Low, Left" 8/26/2019 Wash and ream at full drilling rate from 5895' to 6103'. P/U 123, S/O 1205 , 122 Rot, 125 RPM, 16 K torque, 500 GPM/2200 psi. tag btrn and down link w/ trip gas of 201 units.;Drill 8-1/2" dir. hole w/ auto trak f/ 6103' V 6328' P/U 185, S/O 95k , 125 Rot, 195 RPM, 11 - 12K torque, 550 GPM/2500 psi, WOB 15- 20k, MW in out @10.5 ppg, ECD @ 12.1 ppg , pump 35 bbl Barolift sweep every other std while drilling #1 @ 6240' Back on time w/ 50% w/ BBG 35 units.;Continue drilling 8-1/2" dir hole w/ auto trak F/ 6328' V6538" P/U 190, S/O 98k , 130 Rot, 180 RPM, 12K torque, 550 GPM/2500 psi, WOB 15-20k , MW in out @10.5 ppg, ECD @ 12.1 ppg , pump 35 bbl Barolift sweep every other std while drilling #2 @ 6428' Back on time w/ 25% max gas 472 units.;Mud loggers seeing log from old hole not lining up w/ new hole count pipe chk pipe tally (found tally to be off a single) Circulate and rotate and reciprocate for clean up cycle while MW D Recalibrate tools.; Directional drill 8 %" hole from 6506' t/6627'. P/U 195, S/O 98, 133 Rot, 190 RPM, 11- 13 K torque, 10-15 K WOB, 550 GPM/2400 psi. 80.7 ROP avg. Pumped sweep at 6580' coming back on time with 20% increase. Max gas 75 units.; Directional drill 8%" hole from 6627' t/6875'. P/U 200, S/O 98, 133 Rot, 200 RPM, 11- 13 K torque, 15-20 K WOB, 550 GPM/2450 psi. 41.3 ROP avg. Pumped sweep at 6772' coming back on time with 15% increase. Max gas 295 units.; Directional drill 8'/" hole from 6875' V7150'. P/U 200, S/O 98, 133 Rot, 200 RPM, 11- 13 K torque, 15-20 K WOB, 550 GPM/2450 psi. 68.8 ROP avg. Pumped sweep at 7100'. Max gas 295 units.;Sweep came back on time with 25% increase in cuttings. Continue to work full stand at full drilling rate to clean hole.;BROOH at full drilling rate from 7150' to 6960'.;Daily fluid loss: 0 bbls. Total fluid loss: 492 bbls Magnet collections total: 118# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 7116' MD/4934' TVD, 22 H, 3 Right 8/27/2019 BROOH at full drilling rate from 6960' to shoe shakers loaded the whole way.; Rotate and reciprocate work full stand unload csg.;Service rig and chg/out 1500 amp brk for SCR#3, production change out back pressure valve for source water.;POOH f/5827% V4599% installing NRP's, up wt 157k, do wt 103k.;TIH on elevators f/4599', V7056', up wt 190k, do wt 95k, wash & ream last stand down V7150', no fill pump 550 gpm, 2450psi.;Directional drill 8'/" hole from 7150' t/7400'. P/U 220, S/O 98, 136 Rot, 200 RPM, 11- 13 K torque, 15-20 K WOB, 550 GPM/2500 psi. 50.0 ROP avg. Pumped sweep at 7340' coming back on time with 30% increase. Max gas 350 units.; Directional drill 8 %" hole from 7400' V7715'. P/U 220, S/O 98, 136 Rot, 200 RPM, 11- 13 K torque, 15-20 K WOB, 550 GPM/2500 psi. 63.0 ROP avg. Pumped sweep at 7523' coming back on time with 30% increase. Max gas 215 units.;Noticed loose NRP on stand #75 while back reaming. Investigated that it had come loose from previous stand due to keeper pin not being installed properly. Replace both NRP's on top joint of stand #74. Wash pipe packing failed concurrently. Change out same.;Daily fluid loss: 0 bbls. Total fluid loss: 492 bbls Magnet collections total: 141# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 7588' MD/5250' TVD, 17 H, 7 Right 8/28/2019 Change out wash pipe packing.; Directional drill 8 W hole from 7716' V7905'. P/U 220, S/O 98, 136 Rot, 200 RPM, 11- 13 K torque, 15-20 K WOB, 550 GPM/2500 psi. 54 ROP avg. Pumped sweep at 7716coming back on time with 20% increase. Max gas 336 units.;Pump sweep, @ 550 gpm, 2600psi, back on time with 10% increase, cont CBU x2.;BROOH f/7905' V6390', 600gpm, 2600psi, rot wt 133k, 150rpm, tq. 11-13k, up wt 200k, do wt 95k.;lncrease of cuttings coming back, CBU @ 600 GPM, 2500psi, rot & reciprocate until cleaned up.;BROOH from 6390' into shoe at 5814'. 600 GPM/ 2400 psi, 150RPM/13 K torque, P/U 200 K, S/O 95 K, Hole unloading on each stand pulled. Pack -off and torque issues pulling into shoe. Work through several times until cleaned up. 195 units gas at bottoms up.;Circulate and work pipe inside shoe until shakers cleaned up. 600 GPM/2380 psi. 150 RPM/13 K torque.; Blow down top drive. Drain stack. Make up test joint. Change out choke manifold valve #3. Had difficulty draining stack due to annulus valve plugging off. Hang off string.;Fill stack with water and fluid pack choke. Rig up test manifold.;Daily fluid loss: 42.3 bbls. Total fluid loss: 534.3 bbls Magnet collections total: 151# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 7873' MD/5333' TVD, 14 H, 7 Right 276 K Revs 8/29/2019 Finish flushing & filling surface equipment w/test fluid, & setup test manifold.;Test BOPE as per Hilcorp & AOGCC expectations, Witness was waived by AOGCC inspector Jim Regg 8-28-19. Tested with 5" tubular 250/4000 as per sundry (annular 250/2500) good, Tested gas alarms & PVT good.;R/D test equipment. Pull test plug and lay down same.;Adjust torque. tube to center over hole, Change out saver sub. Service rig.;Pull 9 stands and install NPR's.;TIH from 4690' to 5733'.;RIOH on elevators from 5733' to 6865' without issue. Fill pipe. Noticed that IBOP actuator yoke was bent and one guide roller was out of track. (Photos in o-drive). Weighting up to 10.7 ppg.;Repair [BOP actuator yoke and function test same.;RIOH on elevators from 6865' to 7810' without issue.;Safety ream last stand from 7810' to 7905' at 150 RPM/13 K torque. 550 GPM/2650 psi. Had 30' of fill.; Directional drill 8 %" hole from 7905' to 8000'. P/U 220, S/O 98, 136 Rot, 200 RPM, 11- 13 K torque, 15-20 K WOB, 550 GPM/2650 psi. 47.5 ROP avg. Max gas 179 units.;Daily fluid loss: 0 bbls. Total fluid loss: 534.3 bbls Magnet collections total: 151# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 7873' MD/5333' TVD, 14 H, 7 Right 276 K Revs 8/30/2019 Directional drill 8%" hole from 8000' to 8375'. P/U 220, S/O 98, 136 Rot, 200 RPM, 11- 13 K torque, 15-20 K WOB, 550 GPM/2650 psi. 62 ROP avg. Max gas 420 units. pump sweep @ 8188', had 50% increase in cuttings.; Directional drill 8 Y" hole from 8375' to 8511', P/U 220, S/O 98, 136 Rot, 200 RPM, 11- 13 K torque, 15-20 K WOB, 550 GPM/2650 psi. 54 ROP avg. Max gas 332 units.;SCR room heated up power limit light came on, pick up & circulate while cooling room down.; Directional drill 8'W hole from 8511', to 8634'. P/U 225, S/O 105, 142 Rot, 200 RPM, 11- 13 K torque, 15-20 K WOB, 550 GPM/2650 psi. 49.2 ROP avg. Pumped sweep at 8567' coming back on time with 30% increase. Max gas 250 units.; Directional drill 8'/z' hole from 8634' to 8848'. P/U 230, S/O 105, 145 Rot, 200 RPM, 11- 13 K torque, 15-20 K WOB, 550 GPM/2650 psi. 35.6 ROP avg. ROP slowed down to +-7 FPH and torque dropped off to 12 K. Pumped sweep at 8760' coming back on time with 30% increase. Max gas 238 units.; Pump sweep and cleanup cycle while working string from 8848' to 8755'. Sweep came back on time with 30% increase. 600 GPM/3150 psi, 200 RPM/12 K torque.;BROOH from 8848' to 8000'. 600 GPM/3000 psi, 180 RPM/12 K torque. Cuttings increased substantially.; Pump sweep and perform clean up cycle while working stand at full drilling rate from 8000' to 7920'.;Daily fluid loss: 0 bbls. Total fluid loss: 534.3 bbls Magnet collections total: 172# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 8849' MD/5846' TVD, 4 H, 8 Left 446 K Rev 8/31/2019 Pump sweep and perform clean up cycle while working stand at full drilling rate from 8000' to 7920'. Sweep came back on time with 30% increase.;Cont. BROOH @ drilling rate, f/7920 t/7339'working through packoff issues as needed, pump sweep @ 7653' Sweep came back on time with 25% increase.;Cont. BROOH @ drilling rate, f/7339' U6385' working through packoff issues as needed.; Rack back stand. P/U single and work stuck pipe until free. CBU clean and L/D single.;Cont. BROOH @ drilling rate from 6385' to 5816' working through pack -off issues as needed. 550 GPM/2300 psi, 180 RPM/12 K torque. Circulate sweep at 5916' bringing back 35% increase and on time. Each stand back reamed from 6385' to shoe unloaded with quarter size pieces of coal.;Recovered 45 bbls of cuttings from 6385' to shoe. High gas 421 units.; Circulate bottoms up inside shoe while working string at full drill rate. Pump dry job.;POOH with BHA #6.;Daily fluid loss: 32.70 bbls. Total fluid loss: 566 bbls Magnet collections total: 186# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 8849' MD/5846' TVD, 4 H, 8 Left 446 K Revs 9/1/2019 Cont. stand back BHA in derrick, plug in & D/L MWD , bit was 1/16" under gauge, had a wash out on one jet.;Service rig, D/W, Blocks Crown, TDS. Remove absorbent that was blocking trip tank flow Iine.;M/U BHA #7.;TIH w/ BHA #7 to 1386'.;RIH from 1386' to 5724'. Shallow hole test tools at 1850' (good).;Service Rig, Cut & slip drill line (75').;RIOH on elevators from 5818' to 8270'. Set down 40 K. Wash and ream 8250' to 8280' and clean up area. RIOH on elevators to 8757'.;Wash and ream last stand from 8757' to 8848'. No fill. 550 GPM/3150 psi, 180 RPM/13 K torque. Obtain SPR's. Max gas at bottoms up 197 units.; Directional drill 8%" hole from 8848' to 9229'. P/U 225, S/O 110, 140 Rot, 200 RPM, 15 K torque, 15-20 K WOB, 550 GPM/3150 psi. 63.5 ROP avg. Pumped sweep at 8858' coming back on time with 15% increase. Max gas 257 units. Pumped sweep at 9037' coming back with 30% increase.;Daily fluid loss: 15 bbls. Total fluid loss: 581 bbls Magnet collections total: 186# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 9929' MD/6048' TVD, 3 H, 5 Left 22 K Revs 91,`2/2019 Directional drill 8 %" hole from 9229' to 9576'. P/U 255, S/O 110, 159 Rot, 200 RPM, 17 K torque, 15-20 K WOB, 550 GPM/3050 psi. 58 ROP avg. Pumped sweep at 9418' coming back on time with 20% increase. Max gas 421 units.; Directional drill 8 ''YV hole from 9576'.to 9736 P/U 255, S/O 110, 159 Rot, 200 RPM, 17 K torque, 15-20 K WOB, 550 GPM/3050 psi. 53 ROP avg. Pumped sweep every other stand.;CBU @ 550 psi, work pipe, while swapping Generators, ( had source water issue).; Directional drill 8'/" hole from 9736', to 9893' P/U 255, S/O 110, 159 Rot, 200 RPM, 17 K torque, 15-20 K WOB, 550 GPM/3050 psi. 63 ROP avg. Pumped sweep every other stand.; Directional drill 8 %" hole from 9893' to 10,272'. P/U 255, S/O 110, 159 Rot, 200 RPM, 17 K torque, 15-20 K WOB, 550 GPM/3050 psi. 63.2 ROP avg. Pumped sweep every other stand. Max gas 414 units.;Pump sweep and perform clean up cycle working pipe from 10,272' to 10,190' at 600 GPM/3500 psi, 200 RPM/17 K torque.; Directional drill 8 %" hole from 10,272' to 10,457'. P/U 255, S/O 110, 159 Rot, 200 RPM, 17 K torque, 15-20 K WOB, 550 GPM/3050 psi. 41 ROP avg. Pumped sweep every other stand. Max gas 250 units.; Daily fluid loss: 0 bbls. Total fluid loss: 581 bbls Magnet collections total: 194# 13 318 x conductor annulus: 0 psi Distance to Plan: @ 10457' MD/6680' TVD, 2 H, 3 Right 220 K Revs 9/3/2019 Directional drill 8 ''/i' hole from 10,457' to 10,647'. P/U 287, S/O 117, Rot 167, 200 RPM, 17 K torque, 15-20 K WOB, 550 GPM/3000 psi. 32.5 ROP avg. Pumped sweep every other stand. Max gas 301 units.; Directional drill 8%" hole from 10,647' to 11,064'. P/U 285, S/O 117, Rot 162, 200 RPM, 16 K torque, 15-20 K WOB, 550 GPM/3000 psi. 69.5 ROP avg. Pumped sweep every other stand. Max gas 520 units.; Directional drill 8 Y" hole from 11,064' to 11,451'. P/U 294, S/O 120, Rot 164, 200 RPM, 16 K torque, 15-20 K WOB, 550 GPM/3160 psi. 64.5 ROP avg. Pumped sweep every other stand. Max gas 486 units.; Directional drill 8%" hole from 11,451' to 11,760'. P/U 287, S/O 110, Rot 165, 200 RPM, 15-17K torque, 15-20 K WOB, 550 GPM/3100 psi. 51.5 ROP avg. Pumped sweep every other stand. Max gas 413 units.;Daily fluid loss: 0 bbls. Total fluid loss: 581 bbls Magnet collections total: 213# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 11,780' MD/7364' TVD, 4 H. 1 Right 432 K Revs 9/4/2019 Directional drill 8'/" hole from 11,760' to 11780', P/U 287, S/O 110, Rot 165, 200 RPM, 15-17K torque, 15-20 K WOB, 550 GPM/3100 psi. 51.5 ROP avg. Pumped sweep every other stand.;Run cleanout cycle, circ @ 560gpm, 3030psi, rot 200 rpm, 18-19k tq, CBU, pump 27 bbl Bara fiber sweep, came back on time w/ no increase.;BROOH at drilling rate, f/11780', U9880', working through tight & pack off areas as needed.;BROOH at drilling rate, f/9880'- U9130', working through tight & pack off areas as needed.;Run cleanout cycle, circ @ 590gpm, 3100psi, rot 200 rpm, 16-17k tq, CBU, pump 27 bbl Bara fiber sweep, came back on time w/ no increase.;BROOH at drilling rate, f/9130' t/8000' working through tight & pack off areas as needed.;Daily fluid loss: 48 bbls. Total fluid loss: 629 bbls Magnet collections total: 213# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 11,782' MD/7363' TVD, 4' H, 1' Right 444 K Revs 9/5/2019 BROOH at drilling rate, f/8000' t/7240' working through tight & pack off areas as needed.;Lost 200 psi pump pressure, troubleshoot, finding issue with #2 MP, Circulate & reciprocate pipe f/7240' t'7150' at 420 gpm, 1500psi, 125 rpm, 15-16K Torque while repairing pump.;BROOH at drilling rate, f/7150' t/6583' working through tight & pack off areas as needed.; Daily fluid loss: 18 bbls. Total fluid loss: 647 bbls Magnet collections total: 213# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 11,782' MD/7363' TVD, 4' H. 1' Right 444 K Revs 9/6/2019 BROOH at drilling rate, f/6583' t/5818' working through tight & pack off areas as needed.;Pump sweep while BROOH f/5818 t/ 5732' , pump 600 GPM, 2500 psi, rot 150rpm, tq 14-16, rot wt 125k, 28 bbI sweep comes back on time with 50% excess.;Cont. BROOH t/5544' CBU x2 @ 600 GPM, 2500 psi.; Build 5" test joint, drain stack, Hang string on test plug, change lower VBR to 7" rams.shell test equipment - good.;Test BOPE on 4", 5" and 7" test joints, Annular to 250/2500 psi, all other components to 250/4000 psi, and 7" casing rams to 250/3000psi. Strap and drift 7" liner as it comes off boat.;Daily fluid loss: 62 bbls. Total fluid loss: 709 bbls Magnet collections total: 226# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 11,782' MD/7363' TVD, 4' H, 1' Right 444 K Revs 9/7/2019 Cont. Test BOPE, as per Hilcorp & AOGCC requirements, witness waived by inspector Jim Regg, test gas alarms, change out lower rams t/ 2 7/8" x 5 1/2" variables.; Blow down stack & c/o test it t/5", test lower rams w/5" TJ 250/4000 good.; Blow down & r/d test eq., c/o IBOP actuator & test good, adjust tq. tube & re-tq. service top drive.;R/U & start BROOH f/5638', t/ 5071% DD/MWD open Navi drill & set to neutral position, circulate 550 gpm, 2075 psi, rot 125 rpm, tq 9-12k.;CBU while rot & reciprocate f/5166' t/ 5071' clean.; BROOH to 3654', at 4500' pump a 40 bbl Baro-lift sweep, came back on time with no excess.;Lay down 96 joints of 5"DP from 3654' to BHA at 630' Clean pipe and send to boat. Total of 50 joints on boat at 03:00 hrs.;Daily fluid loss: 0 bbls. Total fluid loss: 709 bbls Magnet collections total: 226# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 11,782' MD/7363' TVD, 4' H, 1' Right 444 K Revs 9/8/2019 Lay down BHA, down load data from MWD.;Clean rig floor, M/U 7" test joint, finish drifting 7" Iiner.;Land test plug and change LPR's to 7", Test LPR's to 250/3000 psi. Rig down test equipment.;Change oil and filter in top drive. Confirm measurements on bracing for torque tube.;Make up BHA #8 for inner string and stand back in derrick.;R/U handling equipment to run 7" liner. P/U and RIH to 665' with centralizer on every joint.;Air boot on riser leaking, change out 2 new air boots on same.; P/U and RIH w/7" liner f/665' t/ 3489', centralizer every joint and hole fill to trip tank. UW 117K, SO 100K.;Daily fluid loss: 0 bbls. Total fluid loss: 709 bbls Magnet collections total: 226# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 11,782' MD/7363' TVD, 4' H, 1' Right 444 K Revs 9/9/2019 P/U and RIH w/7" 29# L-80 liner f/3489' U5794', centralizer every joint and hole fill to trip tank. up wt, 163k, do wt 117K.;Circulate 1 1/2 liner volume & get paramaters, 2 BPM =225, 3 BPM 175psi, rot 10 rpm, tk 5-8, @ 20RPM- 5-8, @ 30RPM 5-8 Rot wt.;Cont. RIH t/5853', tagged up attempt to wk through no joy.;Wash & ream F/5853 t/ 6158' 1.5 BPM, 150psiwk ROT 20 RPM, tq 8-15k, wk through tight area F/5853- 5866', cont wash & ream down t/ 6158', up wt 230k, do wt 90k, P/U pup & HPQC, RIH U 6177'.;R/U U run 4" inner string, clear floor of 7" handling tools, p/u 4" tool's, r/u false table, r/u safety it, rih w/ 6 1/8" bit & motor assembly.;RIH with 4"DP inner string F/ 81' - T/4726.42', 147 joints plus BHA. Drift every joint.;Had hole fill discrepancy ,latch on & p/u, monitor well static set back up to run inner string.;Daily fluid loss: 0 bbls. Total fluid loss: 709 bbls Magnet collections total: 234# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 11,782' MD/7363' TVD, 4' H, 1' Right 444 K Revs 9/10,12019 Cont. P/U inner string 4" dp F/4726' t/6180', up wt 109k, do wt 80k.;Break down 4" running tools, space out for motor stickout of 7" liner=34.09', M/u HPQR to 4" & 7".;C/0 handling tools t/5" m/u first stand to liner assembly, p/u 280k, do I68k, fill pipe, attempt to circulate @ 2bpm, no Iuck.;Wk pipe attempting to get movement rot & circulation, able to get movement, Cont. working & regained rotation, cont. working on getting circulation.; RIH with 7" liner on 5"DP F/ 6235' - T/ 9160', work through coals and tight spots as needed, 25 rpm, 15-20K TQ. UW 300K, SO 115K Try to break circulation several times, unable to circulate.;RIH with 7" liner on 5"DP F/ 9160' - T/ 9970', work through coals and tight spots as needed, coal at 9950' causes problem getting through. 25 - 45 rpm, 15-26K TQ. UW 300K, SO 115K Try to break circulation several times, unable to circulate.; Daily fluid loss: 10 bbls. Total fluid loss: 719 bbls Magnet collections total: 274# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 11,782' MD/7363' TVD, 4' H, 1' Right 444 K Revs 9/11/2019 Continue work 7" liner on 5"DP through coal @ 9970' w/ no circ. before breaking through.; Continue RIH with 7" liner on 5"DP F/ 9970' - and tag btm working through coals and tight spots as needed t/ @ 11,782' also tried to break circulation several times in opportune areas, Still unable to circulate.;Attempt to break circulation again once on btm, with no luck. Dry drill f/ 11782' t/ 11,788' discuss options w/ town and decide to secondary off. work 10k left hand torque and sheer pins and free liner.;P/up 30' w/ bit just out side of 7" shoe @ 11,754' and Pump drill string volume @ slow rate then stage up and circ btm up w/ high gas of 1570 units and max pressure of 720 psi w/ 10.8ppg MW flow chk (ok) Pump dry job ETOL @ 5569'.;Pooh I/dn and vacuum ID wiper ball through 15 its 5" dp.;POOH , UD liner running tool , start to POOH with 4"DP, only had 7 joints. Start to plan fishing operation.; Drain stack, change lower pipe rams from 7" to 2 7/8" x 5 1/2" VBR'S„ change out 2 lower air boots on riser.;Test LPR's with 4" and 5" test joints to 250 / 4000 psi and chart 5 minutes each test. B/O and UD both test joints.;R/U Weatherford 7" power tongs, make up ZXP liner hanger per BOT rep, prep to RIH.;Troubleshoot riser air boots - fix leaking problem.; Run in hole with ZXP liner hanger on 5" DP,; Daily fluid loss: 0 bbls. Total fluid loss: 719 bbis Magnet collections total: 275# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 11,782' MD/7363' TVD, 4' H, 1' Right 444 K Revs 9/12/2019 Continue Rih w/ BOT ZXP prk having to Kelly up each stand to prevent flowing over top of dp. circ in last std tag @ 5565' start pressure up as seals Engauge pressure up t/ 1000 psi w/ no circ bleed pressure and push 70k do and 80k up Good.; Drop 1.75" Ball and let fall for 30 min, Pressure up to 4100 psi/hold 1 minute - bleed down to 1000 psi until observe ball shift V 500 psi P/U to 5520' and chk for release ok with UW 140K and expose dogs set do w/ two good indication's of set one @ 80k and one @ 62k do weight p/up rotate dn.;T. O. L @ 5528' Circulate bottoms up at 450 gpm / 800 psi, pump dry job and prep to POOH.;POOH F/ 5220' t/ surface, L/D running tools.;Prep to p/u 4" and 5"HWDP, Pick up and M/U 4" fishing assembly. Change out 3 suction valves and seats on MP#1, change out rod wash packing and clean both suction screens.;TIH f/ 786' t/ 5038'.;Cut and slip 60' of drilling line. Adjust brakes.;Daily fluid loss: 0 bbls. Total fluid loss: 719 bbls Magnet collections total: 275# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 11,782' MD/7363' TVD, 4' H, V Right 444 K Revs 9/13/2019 Finish cut slip (60') and adjust brakes.;service rig.;inspect saver sub and chg out same.;Trip in hole on elevators f/ 5038' did not see T.O.L wash do last std and tag fish @ 5829' space out.;Wash do and screw into fish @ 5829' w/ max torque of 16k before fish started turning stack 20k do weight first time and 30k do weight second time attempting to gain torque w/ no gain in torque attempt establish circ pressured up t/ 2500 psi and very little and sporadic circulation. Back ream.;the working single and pup 38' putting bit behind shoe cease rotation and straight pull wet and flowing over slightly w/ 50-70k extra weight ( having excessive slip stick while straight pulling and afraid of shaking fish loose) start slow rotation 20 rpm while pooh and smoothed out slip stick.;Continue pooh wet screwing into each stand and Back ream out w/ slow rotation to minimize slip stick to avoid shaking off under torqued fish and secure fish w/ slips @ 04:40 hrs, 5812'.;Change dies in ST-80, clean inside and outside of bad joint 4"DP, Lay down same.; Daily fluid loss: 7 bbls. Total fluid loss: 726 bbls Magnet collections total: 275# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 11,782' MD/7363' TVD, 4' H, 1' Right 444 K Revs 9/14/2019 Continue pooh wet w/ fish f/ 5812' V above T.O.L @ 5280'.;Surge and shake pipe and work pressure through pack off and establish circ and stage up rate t/ 7.2 bpm @ 2000 psi circ surface to surface w/ max gas 35 units. flow chk (ok) and pump dry job.;Resume pooh on elevators racking back fish inspecting pipe and connections w/ full recovery.;Milk mtr and I/dn bha, c/o alignment shims in motor to 0 degrees.; Perform injectivity test @ 1/2 bpm @ 1245 psi and 1 bpm @ 1730 psi, pumped 10 bbls. and bled back 6 bbls.;Clean rig floor and cellar, prep to run cement retainer.;Make up CICR, run in hole to 5324' UW 100K, SO 80K.;Make up 4" test joint, hang string off of test plug, flood stack and choke, prep to test BOPE.;Test annular on 4" test joint to 250/2500 psi, chart each test 5 minutes. Test all other BOPE to 250/4000 psi, chart each test 5 minutes.;Daily fluid loss: 6 bbls. Total fluid loss: 732 bbls Magnet collections total: 276# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 11,782' MD/7363' TVD, 4' H, 1' Right 444 K Revs 9/15/2019 Finish testing bopes as per regulations w/ no failures witness waived by Jim Regg. Break down test equipment.;Chg out double air boot body on top of annular.;Pull test plug & r/dn 5" test it while cleaning up cellar and sub base chg out handle equipment to 4" and reline bail clamps.;Change over handling equipment. Kelly up brk circ Pump dp volume.;Resume rih w/ BOT cmt retainer Bha #11 f/ 5324' t/11,702' did not see top of liner. Wash from 11,657' to 11,702' to clear setting area. UW 240K, SO 125K.;Set cast iron cement retainer at 11,700 top, 11,702' bottom., release from retainer.; Circulate a bottoms up at 5.5 bpm, 1200 psi, Get 575 units of gas back.;Test cement retainer to 2500 psi, hold 8 minutes, pumped 9 bbls and bled 7 bbis back.; Rig up to cementers, Pressure test lines and pump 17 bbls. of cement per plan , squeeze 7" shoe to provide coverage 500' +_ of 7" annulus, and 54' above shoe. Cement in place at 03:18 hrs.;UD cement head and single, pull 5 stands to get clear of residue.;Circulate a bottoms up at high rate, drop ball and circulate pipe and hole clean.; Daily fluid loss: 2 bbls. Total fluid loss: 734 bbls Magnet collections total: 276# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 11,782' MD/7363' TVD, 4' H, 1' Right 444 K Revs 9/1612019 Continue Circulate wiper ball to clean pipe @ 11,188'.;P/up brk do clean cmt head (measure out service loop for Mr. Connell).;Pooh I/dn 5" dp cleaning ID and OD, T/ 6272', UD total of 138 its. 5"DP. Leave 56 stands in derrick and 10 singles on deck. UD 12 joints 5"HWDP.;POOH w/ 4"DP F/ 6272' to surface.;Clean and UD running tool. Break out 3 pups used to set hanger liner. Organize deck to handle 4" HWDP.;P/U clean out BHA #12.;P/U 45 joints of 4"DP to 1843'.;Dailyfluid loss: 3 bbls. Total fluid loss: 737 bbis Magnet collections total: 276# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 11,782' MD/7363' TVD, 4' H, 1' Right 444 K Revs 9/17/2019 Continue p/up rabbit and strap 4" , S-135 XT-39 DP f/ 1843 t/ 2223' total 54 jts.;Fill pipe and brk circ and prep ST-80 for removal.; Remove ST-80 and install Hawk jaw pipe handler work through hyd/HPU issues power wash and clean brake cooling radiator and cleaning cellar and subbase.;Rih f/ 2223' t/ 8466' w/ 4" dp out of derrick and continue work through and resolve HPU issue. filling pipe every +- 2500' did not see TOL swap handing tools from 4" t/ 5".;Continue RIH out of derrick to 11,696' w/ 5" DP and NRP's maintenance rolled top to btm and chg out 1 and turned over 10.;Obtain parameters: S/O 117, P/U 210, Rot 125 at 75 RPM/10 K torque. 300 GPM/2000 psi. Slack off to 11,704' with minimal cement encountered.;Circulate and condition mud. At bottoms up had 12.5 ppg mud and had to reduce pump rate to prevent mud push/cement from running over shakers. Lost +- 7 bbls. Circulate until 10.9 ppg in and out.;Test casing on chart for 30 minutes. 3185 psi bled down to 3120 psi. Good test. 12 bbls pumped/10.5 bbls back. Bleed off and rig down test equipment.; Drill CIBP at 11,704' to 11,706'. Chase down hole to 11,788'. Saw no hard cement. Parameters : S/O 117, P/U 210, Rot 125 at 75 RPM/10 K torque. 7 - 15 K WOB. 300 GPM/2000 psi.;Drill on CIBP and new hole with various parameters from 11,788' to 11,801'.;Daily fluid loss: 0 bbls. Total fluid loss: 737 bbls Magnet collections total: 276# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 11,782' MD/7363' TVD, K Revs 9/18/2019 Drill on CIBP junk and new hole with various parameters from 11,801' to 11,808'.;Back ream up into shoe U 11,729' finish circ. Btm/up@ 7 bpm @ 2500 psi @ 50 rpm and 9k TQ and I/dn working single.;Preform F.I.T t/ 13.0 ppg w/ 765 psi of applied pressure w/ 11.00 ppg MW and 7350' TVD wl 2 bbls in and 1.8 bbl back.;Service top drive and clean out a rig floor drain.;Pump dry job and pooh on elevators f/ 11,729' t/ BHA wl cal hole fill of 58.2 bbls and actual 62.4 bbls.;Work BHA. Bit graded 3,3,WT,A,E,4,JD,BHA. Recovered 18.5 Ibs iron from junk basket and string magnet.;Pick up drilling BHA #13. Check communications with MWD tools. Load source. Flow check at 240'. P/U 38, S/O 38.;RIH with BHA #13 drilling assembly to 5574'. Fill pipe at 2500' intervals.;Had issues working past liner top with HPQC in 7". Stand back stand. Pick up single of 4" and 5" drill pipe. Work past area with pump and slight rotation. Lay down singles.;Continue RIH with BHA #13 to 5920'.;Daily fluid loss: 6 bbls. Total fluid loss: 743 bbls Magnet collections total: 291# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 11,782' MD/7363' TVD, K Revs 9/19/2019 Continue RIH with BHA #13 from 5920' to 8576' and fill pipe.;Swap handling tools t/ 5" continue RIH on elevators f/ 8576' tl 11,790' w/ no issues @ shoe but had issues getting some 5" dp out fingers on ODS stand pipe side used tugger to extract Kelly up having issue w/ TDS hyd.; Pull back into shoe t/ 11,693' and open turtle shell on TDS and adjust hyd set point on pressure switch as per NOV.;Establish drilling parameters and SPR and attempt do link trouble shoot MWD issues while reaming to btm drill ahead blind f/ 11,808' t' 11,820' and continue trouble shoot MWD.; Reestablished communications w/ tools. Down link and relog f/ 11,800' t/ 11,820'.;Directional drill 6-1/8" hole, Tangent section w/ Auto track- Ontrak - SDN f/ 11,820' t/ 11,980' as per DID and MWD and pump 35 bbl high vis sweep around while drilling @ 11,900 on time w/ 5% increase.; Directional drill 6 1/8" hole from 11,980' to 12,200'. P/U 250, S/O 115, 150 Rot, 150 RPM, 15 K torque, 10-15 K WOB, 250 GPM/2900 psi. 36.6 ROP avg. Pumped Barolift sweep at 12,075' on time with 15% increase. Max gas 38 units.; Directional drill 6 1/8" hole from 12,200' to 12,357'. P/U 250, S/O 112, 140 Rot, 150 RPM, 15 K torque, 10-15 K WOB, 250 GPM/3000 psi. 26.1 ROP avg. Pumped vis sweep at 12,262' on time with 10% increase. Max gas 218 units.; Daily fluid loss: 5 bbls. Total fluid loss: 748 bbls Magnet collections total: 297# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 12,300' MD/7634' TVD, 2 High, 10 Left 108 K Revs 9/2012019 Directional drill 6 1/8" hole from 12,357' to 12,565'. P/U 250, S/O 115, 148 Rot, 150 RPM, 14-15 K torque on & 13 k off, 10-15 K WOB, 250 GPM/3050 psi. 34.6 ROP avg. Pumped Barolift sweep at 12,452' on time with 10% increase. Max gas 218 units. and ECD @ 12.6 ppg.; Directional drill 6 1/8" hole from 12,565' to 12,683'. P/U 250, S/O 115, 148 Rot, 135 RPM, 14-15 K torque on & 13 k off, 10-15 K WOB, 260 GPM/3050 psi. 19.7 ROP avg. Pumped vis sweep at 12,642' on time with 0% increase. Max gas 68 units. and ECD @ 12.6 ppg.; Directional drill 6 1/8" hole from 12,683' to 12,737'. P/U 250, S/O 115, 148 Rot, 115 RPM, 14-15 K torque on & 13k off, 10-15 K WOB, 250 GPM/3050 psi. 9.0 ROP avg. Max gas 12 units and ECD @ 12.6 ppg.; Directional drill 6 1/8" hole from 12,737' to 12,830'. P/U 250, S/O 115, 148 Rot, 115 RPM, 14-15 K torque on & 13k off, 10-15 K WOB, 250 GPM/3050 psi. 16.9 ROP avg. Pumped Barolift sweep at 12,780' on time with 20% increase. Max gas 173 units and ECD @ 12.6 ppg.;Pump survey. Circulate bottoms up at 260 GPM/3050 psi before short trip.;Daily fluid loss: 0 bbls. Total fluid loss: 748 bbls Magnet collections total: 321# 133,18 x conductor annulus: 0 psi Distance to Plan: @ 12,803' MD/7896' TVD, 0 High, 17 Left 238 K Revs 9/21/2019 Circulate bottoms up at 260 GPM/3050 psi before short trip. Rotate and reciprocate full stand. SPR and flow chk (ok).;Short trip Pooh on elevators w/ no issues t/ inside 7" shoe @ 11,676'.;Circulate at drilling rate while servicing rig. Open TDS turtle shell and increase lube oil pressure setting.;Short trip RIH on elevators w/ no issues. Safety ream last stand to bottom no fill.;Make connection. do link Resume Directional drilling 6 1/8" hole w/ rotary steerable f/ 12,830' t/ 12,855' P/U 260, S/O 115. 148 Rot, 150 RPM, 14-15 K torque on & 13k off, 10-15 K WOB, 260 GPM/3100 psi. 16.6 ROP avg. ECD @ 12.78 max gas 18 units.;Pumped Barolift sweep at 12,850' on time with 30% increase.; Directional drill 6 1/8" hole from 12,855' to 12,934'. P/U 255, S/O 115. 155 Rot, 120 RPM, 14-15 K torque on & 13k off, 10-15 K WOB, 260 GPM/3100 psi. 13.2 ROP avg. Pumped Barolift sweep at 12,850' on time with 30% increase. Max gas 35 units and ECD @ 12.6 ppg.; Directional drill 6 1/8" hole from 12,934' to 13,000'. P/U 250, S/O 115, 148 Rot, 115 RPM, 14-15 K torque on & 13k off, 10-15 K WOB, 250 GPM/3050 psi. 11.0 ROP avg. Max gas 35 units and ECD @ 12.6 ppg.; Directional drill 6 1/8" hole from 13,000' to 13,130'. P/U 255, S/O 115, 155 Rot, 120 RPM, 14-15 K torque on & 13k off, 10-15 K WOB, 260 GPM/3100 psi. 21.6 ROP avg. Pumped Barolift sweep at 13,030' on time with 10% increase. Max gas 125 units and ECD @ 12.6 ppg.;Daily fluid loss: 17 bbls. Total fluid loss: 765 bbls Magnet collections total: 332# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 13,090' MD/8046' TVD, 1.4' Below, 4' Left 398 K Revs 9/22/2019 Directional drill 6 1/8" hole from 13,130' to 13,234'. P/U 255, S/O 115, 150 Rot, 135 RPM, 14 K torque on & 13k off, 10-15 K WOB, 260 GPM/3100 psi. 17.3 ROP avg. Pumped Barolift sweep at 13,210' on time with 10% increase. Max gas 118 units and ECD @ 12.46 ppg.;Directional drill 6 1/8" hole from 13,234' to 13,320' P/U 255, S/O 115, 150 Rot, 135 RPM, 14 K torque on & 13k off, 10-15 K WOB, 260 GPM/3100 psi. 28.6 ROP avg. Max gas 118 units and ECD @ 12.46 ppg.;Circ .btm /up while Ream f/ 13,120' t/ 13,190' to work out dog leg ( Near bit inc showing .6 over 5') chk shot survey and perform diagnostics check on tools.; Rack back stand. Flow check (ok). POOH on elevators t/ 12, 800' w/ no issues. Pump dry job. Continue POOH on elevators to inside shoe w/ no issue and continue POOH to 4" DP @ 8573'. Cal, hole fill 32 bbls/actual hole fill 36.6 bbls. Had hand from other crew do hawk jaw training with new crew.;Clear/clean rig floor. Prepare to make up 4" test joint.;Make up test joint and test plug to string. Had to change dies in Hawkjaw.;Shell test choke manifold at 2800 psi while torquing connections on test joint. Land string. Test BOPE at 250 L14000 H and annular failed (will need to be changed out) on 4" test joint. AOGCC (Jim Regg) waived witness at 19:15 hrs on 9-20-19.;Daily fluid loss: 14 bbls. Total fluid loss: 779 bbls Magnet collections total: 342# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 13,320' MD/8183' TVD, 3.7' Below, 1.6' Left 480 K Revs 9/23/2019 Clean flow box, remove flow nipple & mouse hole. Change out element in Shaffer/Axon annular w/ Nitrile NOV Serial # 7263-05-18, Part #10624006-001, w/ manufactured date of 5-08-18 also chg/out Axon top seal Part # 81657-10-01. torque cap bolts t/3100 ft/lbs, Re -install mouse hole , flow nipple.;lnstall test jt r/up lines. Run up pressure and Exercise bag @ 600, 800 & 1000psi. Reinstall turn buckles on stack & clean up.;Purge air and shell test t/ 2500 (ok) continue cleaning, Test bag on 4" test jt t/ 250L-2500H (ok).;Swap to 5" test it and purge air.;Test bag & upper and lower VBRs dart and IBOP's and chokes. Perform draw down test.;Lay down test joint. Rig down test equipment.;RIH with BHA #13 from 8573' to 11,695'.;Circulate and condition mud. 265 GPM/3200 psi. Service rig.;RIOH on elevators from 11,695' to 13,212' without issue. Change out 5 collars and 2 rubbers on NRP's on trip.;Wash and ream from 13,212' to 13,320' at 240 GPM/3000 psi. 75 RPM/14 K torque. No fill. After connection by-pass valve on MP #2 washed out. Isolate pump and use MP #1 while repairing same.; Directional drill 6 1/8" hole from 13,320' to 13,450'. P/U 255, S/O 115, 150 Rot, 135 RPM, 14 K torque on & 13k off, 10-20 K WOB, 260 GPM/3190 psi. 26.0 ROP avg. Pumped Barolift sweep at 13,320' on time with 20% increase. Max gas 118 units and ECD @ 12.46 ppg.;Daily fluid loss: 0 bbls. Total fluid loss: 779 bbls Magnet collections total: 342# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 13,370' MD/8216' TVD, 3.7' Below, 1.6' Left 480 K Revs 9/24/2019 Directional drill 6 1/8" hole from 13,320' to 13,681'. P/U 255, S/O 115, 150 Rot, 135 RPM, 14 K torque on & 13k off, 10-20 K WOB, 260 GPM/3050 psi. 40 ROP avg. Pumped Barolift sweep at 13,496' on time with 10% increase. Max gas 97 units and ECD @ 12.67 ppg.;Directional drill 6 1/8" hole from 13,681'to 13,735'. P/U 255, S/O 115. 150 Rot, 135 RPM, 14 K torque on & 13k off, 10-20 K WOB, 260 GPM/3050 psi. 18 ROP avg. Pumped Barolift sweep at 13,681' on time with 10% increase. Max gas 45 units and ECD @ 12.67 ppg.;Directional drill 6 1/8" hole from 13,735'to 13,752'. P/U 255, S/O 115, 150 Rot, 135 RPM, 14 K torque on & 13k off, 10-20 K WOB, 260 GPM/3050 psi. 11.3 ROP avg. ROP and torque dropped off dramatically. Stop drilling.;Circulate and clean hole while working pipe at full drilling rate.;POOH on elevators without issue from 13,752' to 13,395'. P/U 275, S/O 135. Pump dry job. Continue POOH on elevators without issue into shoe at 11,754'.;POOH with BHA #13 from 11,754' to 8550' (4" drill pipe).;Change slips and elevators. Pump second dry job. Continue POOH to BHA.;Daily fluid loss: 15 bbls. Total fluid loss: 794 bbls Magnet collections total: 352# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 13,752' MD/8490' TVD, 1.25' Below, 3.5' Left 610 K Revs 9/25/2019 L/D BHA, break out bit, had two plugged jets, broken blade and chipped cutters @ cone.;P/U 6 1/8" Varel PDC bit for BHA #' 14, cont. m/u BHA load sources & shallow test tools good.;P/U 63 its 4" xt-39 14# DP (1992.14').;Cont. TIH w/ stands 4" DP to 10,665'.;Hang blocks. Slip and cut 117' of drill line. Circulate at 30 SPM/1660 psi. Service rig. Quadco re -calibrated weight indicator.;RIH on elevators from 10,665' to 12,460' without issue.;Continue RIOH on elevators from 12,460' to 13,690' without issue. Fill pipe at 12,649'. Changed out 8 clamps and 2 rubbers on NRP's.;Wash and ream from 13,690' to bottom at 13,752' (no fill). Obtain SPR's and down link.; Directional drill 6 1/8" hole from 13,752' to 13,835'. P/U 255, S/O 115, 150 Rot, 130 RPM, 15 K torque, 10-20 K WOB, 260 GPM/3350 psi. 20.8 ROP avg. Pumped Barolift sweep at 13780' on time with 10% increase. Max gas 160 units and ECD @ 12.67 ppg.;Daily fluid loss: 3 bbls. Total fluid loss: 797 bbls Magnet collections total: 352# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 13,784' MD/8515' TVD, .3' Below, 1.0' Left 9.8 K Revs 9/2612019 Directional drill 6 1/8" hole from 13,835' to 13,974'. P/U 250, S/O 110, 150 Rot, 130 RPM, 15 K torque, 10-20 K WOB, 260 GPM/3350 psi. 23 ROP avg. Pumped Barolift sweep at 13,785' on time with 10% increase. Max gas 42 units and ECD @ 12.67 ppg.;Directional drill 6 1/8" hole from 13,974' to 14,147' P/U 250, S/O 110, 160 Rot, 130 RPM, 15 K torque, 10-20 K WOB, 260 GPM/3350 psi. 28' ROP avg. Pumped Barolift sweep at 13,975' on time with 10% increase. Max gas 42 units and ECD @ 12.67 ppg.;Directional drill 6 1/8" hole from 14,147' to 14,288' P/U 270, S/O 110, 150 Rot, 130 RPM, 15 K torque, 10-20 K WOB, 260 GPM/3250 psi. 23.5 ROP avg. Pumped Barolift sweep at 14,190' on time with 15% increase. Max gas 105 units and ECD @ 12.67 ppg.;Directional drill 6 1/8" hole from 14,288' to 14,445' P/U 270, S/O 110, 150 Rot, 130 RPM, 15 K torque, 10-20 K WOB, 260 GPM/3250 psi. 26.2 ROP avg. Pumped Barolift sweep at 14,351' on time with 10% increase. Max gas 156 units and ECD @ 12.67 ppg.;Daily fluid loss: 5 bbls. Total fluid loss: 782 bbls Magnet collections total: 364# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 14,380' MD/8972' TVD, .2' Below, 1.8' Right 179 K Revs 9/27/2019 Directional drill 6 1/8" hole from 14,445' to 14,642' P/U 280, S/O 115, 150 Rot, 130 RPM, 17K torque on 15k off, 10-20 K WOB, 260 GPM/3200. psi. 32 ROP avg. Pumped Barolift sweep at 14540' on time with 10% increase. Max gas 175 units and ECD @ 12.67 ppg.; Directional drill 6 1/8" hole from 14,642' to 14,784' P/U 280, S/O 115, 150 Rot, 130 RPM, 17K torque on 15k off, 10-20 K WOB, 260 GPM/3200. psi. 23 ROP avg. Pumped Barolift sweep at 14,729' on time with 10% increase. Max gas 141 units and ECD @ 12.67 ppg.; Directional drill 6 1/8" hole from 14,784' to 14,823' P/U 280, S/O 115, 150 Rot, 130 RPM, 17K torque on 15k off, 10-20 K WOB, 260 GPM/3200. psi. 9.8 ROP avg. Max gas 91 units and ECD @ 12.67 ppg.;Circulate hole clean while rotating and reciprocating pipe.;Short trip. POOH on elevators without issue to 13,780'.;Service rig. Clean rig floor.;RIH on elevators without issue to 14,730'. Wash and ream last stand to 14,823' (no fill).; Directional drill 6 1/8" hole from 14,823' to 14,918' P/U 280, S/O 115, 150 Rot, 130 RPM, 17K torque on 15k off, 10-20 K WOB, 260 GPM/3200. psi. 21.1 ROP avg. Max gas 60 units and ECD @ 12.7 ppg.;Daily fluid loss: 22 bbls. Total fluid loss: 804 bbls Magnet collections total: 375# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 14,870' MD/9347' TVD, .1' Below, .94' Right 328 K Revs 9/28/2019 Directional drill 6 1/8" hole from 14,918' to 15031' P/U 280, S/O 115, 150 Rot, 130 RPM, 17K torque on 15k off, 10-20 K WOB, 260 GPM/3200. psi. 18.8 ROP avg. Max gas 60 units and ECD @ 12.7 ppg. Pumped sweep @ 14918' came back on time & 10% increase.; Directional drill 6 1/8" hole from 15031' To 15120' P/U 280, S/O 115, 150 Rot, 130 RPM, 17K torque on 15k off, 10-20 K WOB, 260 GPM/3200. psi. 16.6 ROP avg. Max gas 60 units and ECD @ 12.7 ppg.; Directional drill 6 1/8" hole from 15,120' to 15,198' P/U 280, S/O 115, 150 Rot, 130 RPM, 17K torque on 15k off, 10-20 K WOB, 260 GPM/3200. psi. 13 ROP avg. Max gas 68 units and ECD @ 12.7 ppg.; Directional drill 6 1/8" hole from 15,198' to 15,310'. P/U 280, S/O 115, 150 Rot, 130 RPM, 17K torque on 15k off, 10-20 K WOB, 260 GPM/3200. psi. 18.7 ROP avg. Pumped sweep @ 15,101' came back on time & 5% increase. Max gas 110 units and ECD @ 12.7 ppg.;Daily fluid loss: 6 bbls. Total fluid loss: 810 bbls Magnet collections total: 382# 13 3/8 x conductor annulus: 0 psi Distance to Plan: @ 15,250' MD/9638' TVD, .2' Above, .6' Right 499 K Revs 9/29,12019 Directional drill 6 1/8" hole from 15,310' to 15,423'. P/U 285, S/O 117, 150 Rot, 130 RPM, 17K torque on 15k off, 10-20 K WOB, 260 GPM/3100. psi. 18.8 ROP avg. Pumped sweep @ 15,300' came back on time & 10% increase. Max gas 101 units and ECD @ 12.7 ppg.; Directional drill 6 1/8" hole from 15,423' to 15,475'. P/U 285, S/O 117, 150 Rot, 130 RPM, 17K torque on 15k off, 10-20 K WOB, 260 GPM/3100. psi. 8.7 ROP avg. Max gas 68 units and ECD @ 12.7 ppg.; Directional drill 6 1/8" hole from 15,475' to 15,485'. P/U 285, S/O 117, 150 Rot, 130 RPM, 17K torque on 15k off, 10-20 K WOB, 260 GPM/3100. psi. 6.7 ROP avg. Pumped sweep @ 15,481' came back on time & 10°% increase. Max gas 60 units and ECD @ 12.7 ppg.;Circulate and clean hole while rotating and reciprocating pipe. 260 GPM/3300 psi. 100 RPM/14 K torque.;POOH on elevators without issue from 15,485to 13,059'. Encounter 50K over pull. Back ream from 13,059' to 13,020' at full drilling rate. POOH on elevators without issue into shoe at 11,754'.;Continue POOH to 4" drill pipe. Change out handling equipment and pump dry job. Continue POOH with BHA #14 to 6300'.;Daily fluid loss: 0 bbls. Total fluid loss: 810 bbls Magnet collections total: 388# 13 3/8 x conductor annulus: 90 psi Distance to Plan: @ 15,485' MD/9818' TVD, .2' Below, .25' Left 616 K Revs 9/30/2019 Cont. POOH f/6300' to BHA #14. @612'.;Work BHA, standing back, pulled source, DL MWD tools, L/D BIT Grade- 6,4, WT, A, X,I,BF.;R/U Johnny Wacker, flush stack, drain & blow down surface eq. M/U 4" TJ install test plug, fill surface eq. w/ test water.;Shell test with 4" test joint at 250 U2500 H. Good test. Wait on AOGCC inspector.;Test BOPE at 250 U4000 H. Annular at 250 L12500 H. tested w/4 & 5" tj, AOGCC (Lou Laubenstien) on board to witness test. Lower IBOP failed.;Change out lower IBOP. Retest at 250 U4000 H.;Rig down test equipment. Pull test plug. Drain stack.;Pick up BHA #15.;Daily fluid loss: 0 bbls. Total fluid loss: 810 bbls Magnet collections total: 388# 13 3/8 x conductor annulus: 90 psi Distance to Plan: @ ' MDP TVD, .2' Below, .25' Left 616 K Revs 10/1/2019 Service Rig, Pick up BHA #15 and TIH t/ 2034', shallow test same good.;TIH t/5800', UW 100K, SO 70K.;MAD pass t/6017', pump 260 GPM, 2100psi, Run @ 300 FPH.;MAD pass t/6586', pump 260 GPM, 2100psi, Run @ 300 FPH.;TIH t/ 10,567' UW 160K, SO 85K.;P/U 26 joints of 4"DP to 11,389'.;Change handling equipment to 5", TIH to 11,675', Adjust Hawk jaw.;Warm up mud, circulate a bottoms up. Change dies in Hawk jaw.;RIH on elevators f/ 11,675' to 12,238'.; Daily fluid loss: 0 bbls. Total fluid loss: 810 bbls Magnet collections total: 388# 13 3/8 x conductor annulus: 90 psi Distance to Plan: @ 15,485' MD/9818' TVD, .2' Below, .25' Left 0 K Revs 10/2/2019 Cont. TIH on elevators f/12238', t/15362', filling pipe & servicing NRP's as needed. Wash down last stand w/no fill U15485'.;Directional drill 6 1/8" hole from 15,485' to 15544". P/U 270, S/O 118, 165 Rot, 120 RPM, 17K torque, 10 K WOB, 250 GPM/3530 psi. 29 ROP avg. Max gas 166 units and ECD @ 13 ppg.; Directional drill 6 1/8" hole from 15,544' to 15,662', P/U 285, S/O 115, 172 Rot, 130 RPM, 16K torque, 13 K WOB, 250 GPM/3450 psi.19.6 ROP avg. Max gas 64 units and ECD @ 13 ppg.; Directional drill 6 1/8" hole from 15,662' to 15,800', P/U 290, S/O 115, 173 Rot, 125 RPM, 16K torque, 15 K WOB, 250 GPM/3500 psi.23.0 ROP avg. Max gas 55 units and ECD @ 13 ppg. Pump 25 bbl. sweep @ 15740', comes back on time with 10% increase in cuttings.; Directional drill 6 1/8" hole from 15,800' to 15,930', P/U 285, S/O 117, 165 Rot, 120 RPM, 16K torque, 16 K WOB, 250 GPM/3630 psi, 21.7 ROP avg. Max gas 64 units and ECD @ 13 ppg. Pump 25 bbl sweep, comes back on time with 15% increase in cuttings.;Daily fluid loss: 11 bbls. Total fluid loss: 821 bbls Magnet collections total: 393# 13 318 x conductor annulus: 90 psi Distanceto Plan: @ 15,870' MD/10,113' TVD, .2' Below, 7.0' Right 118 K Revs 10/3/2019 Directional drill 6 1/8" hole from 15,930'. t/16,212' P/U 295, S/O 117, 170 Rot, 120 RPM, 16K torque on, 14k off, 16 K WOB, 250 GPM/3600 psi, 28 ROP avg. Max gas 33 units and ECD @ 13.1 ppg. Pump 25 bbl sweep, Every other stand w/10- 15% increase in cuttings.;Pump Sweep & circulate clean while rot & reciprocating stand, pump 250 GPM, 3750psi Sweep back with 5% increase, take slow pump rates.;POOH on elevators from 16,212' to 12,712'. Work through tight spots at 15,740' / 13,097' / 13,008' Off bottom UW 330K, SO 135K.;POOH on elevators with 5"DP F/ 12,712' - T/ 11,342'. No issues pulling through shoe.;Swap over to 4" handling equipment, finish dry job and blow down Baker BPA and remove. Pump dry job.;POOH with 4"DP F/ 11,342' - T/ 5750'.;Daily fluid loss: 15 bbls. Total fluid loss: 836 bbis Magnet collections total: 403# 13 3/8 x conductor annulus: 90 psi Distance to Plan: @ 16,212' MD(10,375' TVD, 0.07' Below, 2.1' Right �( � 220 K Revs 10/4/2019 Secure service loop cover because of high winds.;POOH w/ 4"DP f/ 5,698' - tl 611' BHA.;R/U vac. to clean BHA, L/D 2 jts. 4"DP. Secure top and bottom of service loop hydraulic hoses.;Lay down BHA #15 as per DID & MWD, cleaning inside and outside of every joint and tool laid down.;Clean and organize rig floor, L/D all handling equipment not needed. Rig down all Baker directional sensors, encoder and wire.;Cut and slip 95' of drill line. Swap over to production power at 2400 hrs.;P/U test tools and make up 2 7/8" test joint. Set test plug and flood stack.;Test Annular, Upper and Lower pipe rams on 2 7/8" test joint.;Test rebuilt IBOP. Rig down all test equipment and drain stack.;Daily fluid loss: 0 bbls. Total fluid loss: 836 bbls Magnet collections total: 403# 13 3/8 x conductor annulus: 90 psi Distance to Plan: @ 16,212 ' MD/10,375' TVD, 0.07' Below, 2.1' Right 0 K Revs 10/5/2019 P/U McCoy tongs & rig up same, service rig.;P/U 2 7/8 Diffuser, & 31 jts 2 7/8" L-80 6.41b IBT tubing xo & disconnect, U1000.71' install centralizer every 6 jts, C/O handling eq. t/ 4".;TIH w/CMT stinger on 4" stands DP t/11.778'.:C/0 handling tools T/5" cont. tih on 5"DP t/16,131' Wash down and tag bottom at 16,212' PUW 270K, SOW 130K.;Circulate mud even, stage up from 2bpm/1000psi to 4 bpm11870psi. Unable to use spacer, circulate and wait on product from beach. Mix spacer and prep to cement.; Pressure test cement lines to rig floor.; Daily fluid loss: 0 bbls. Total fluid loss: 836 bbls Magnet collections total: 403# 13 3/8 x conductor annulus: 90 psi 10/6/2019 Finish PT lines, Rig pump 30 bbls 12ppg spacer, @3bpm 1600psi, pump 181 sxs, 60 bbis ,13ppg, 1.85 yield from Haliburton CMT unit chase 1 bbl water flush lines,;loaded dart in DP & displaced w/rig pump @ 4 bpm @ 1750psi, slowed t/ 3 BPM last 10 bbis. 0 185bbis. olua seated . pressured up t/3100psi observed pressure drop as BHKA disconnected leaving top of cmt stinger assy @ 15,215', CMT in place @ 8:OOAM.;POOH U14186' standing back 5" DP, up wt V VJ 260k.;Drop wiper ball CBU clean @ 4bpm, 1750psi.;Work pipe @ circulate while WOC, clean & clear floor, Housekeeping, work on rig project Iist.;RIH f/ 14,186' to 14,324', tag cement, P/U and tag again to verify, set 25K down. POOH 1 stand and circulate, verify clean and confirm cement numbers.;POOH f/ 14,280' to 10,755'.;Daily fluid loss: 0 bbls. Total fluid loss: 836 bbis Magnet collections total: 403# 13 3/8 x conductor annulus: 90 psi 10/7/2019 POOH f( 10,755' to 10,780'. Swap handling equipment to 4", continue to POOH w/4"DP t/surface.;M/U CIBP, TIH to 11,685'. UW 180K, SO 100K.;Set CIBP at 11,685' per Tri-Point rep, P/U 40k over, set 40K down, confirm set and test to 2500 psi / chart for 30 minutes. Good Test.; Prepare to displace, R/U all hoses and valves needed to reverse circulate, prep pits as needed.; Reverse circulate M08M out of hole with FIW at 5 bpm - 2500 psi, 5718 total strokes.;Clear and �Q clean rig floor of circulating equipment, blow down all lines, clean trip tank and prep pits to start stripping mud from 11.1 ppg to 9.0 ppg. Prepare to L/D $` 4"DP.;Dailyfluid loss: 0 bbls. p� Total fluid loss: 836 bbis 53 ,ffPsL/` Magnet collections total: 403# lr o2 sV 0 10 y ill 13 3/8 x conductor annulus: 90 psi 10/8/2019 Cont. Cleaning TT & housekeeping . and work boat.;POOH Stand back 5" DP f/ 11641' t/10788', up wt 205k, do wt 95k.;C/O handling eq. t/4" POOH clean & I/d 4" DP t(8818', up wt 175k, do wt 80k.;Continue I/dn 4" dp f/ 8818' t/ 4,955' while centrifuging back 11.0 ppg OBM in active system targeting 9.0 ppg and cleaning pits.;Shut do prime mover and swap to production power while Working 2 boats, offload 180 joints 4"DP, 2 Full ISO's of junk fluid from reserve pit, install new line guide, continue to clean mud. strip fittings and sensors off 400 bbl upright water tank and back load mud loggers shack.; Back on rig power. Continue to L/D 4"DP f/ 4,955' to surface - L/D 161 joints for a total of 341 joints. Cont. centrifuging back 11.0ppg MOBM in active, targeting 9.Oppg and cleanin its. 10/912019 M/up wash tool + XO RIH w/ 5" dp removing and cleaning NRP's while RIH t/ 5300' up/dn 150/100k . Cont. centrifuging back 11.0ppg MOBM in active, targeting 9.Oppg and cleaning pits.;Pooh L/D 50 jts. 5" DP cleaning ID and OD, UW 125K, SO 95K, Continue centrifuging back 11.0ppg MOBM in active, targeting 9.Oppg and cleaning pits.;Shut down MTU at 17:30 hrs., use prod. power until 22:00 hrs. Work boat, Offload 161 jts of 4"DP, 400 bbl tank, fill / off load 1 ISO with fluid f/ reserve pit, set 1 ISO on deck, Offload 50 jts. 5"DP, Clean reserve pit. Check pre -load torque of block shaft bearings -good Check IBOP pressure switch;POOH L/D 118 jts. 5" DP cleaning ID and OD while continuing centrifuging back 11.0ppg MOBM in active, targeting 9.0 ppg and cleaning its. 10/10/2019 Back load boat While Kelly up wash out stack and lines w/ water using both MP and function bopes and blow do same. Continue centrifuging back 11.0ppg MOBM in active, targeting 9.0 ppg and cleaning pits.Wash clean and service Hawk jaw and remove from rig floor and secure in transport.; Start removing and cleaning rig floor subs ,XO and equipment and prep for boat. and r1up tongs and handling equipment to run 2-7/8" kill string Continue centrifuging OBM back and pit cleaning.;P/up rabbit and strap 2-7/8" 6.4# L-80 IBT kill string drain stack and landed hanger up/dn 33/35k w/ BPV installed wl Mule shoe @ 549' RILDS.;Clean derrick down to wind walls, Remove McCoy power tongs, snake drains on rig floor, transfer 170 bbls. of 9.7ppg MOBM to reserve pits, transfer 110 bbis 11.0 OBM to pits and centrifuge.; Continue cleaning derrick, draw works, north pipe rack. Continue centrifuging back 11.0ppg MOBM in active, targeting 9.0 pp and cleaning its. Work on demob list. 10/11/2019 Continue power washing and vacuuming and cleaning rig floor wind walls down along with choke house & tools and equipment and store same or prep for boat. Continue centrifuging back 11.0ppg MOBM in active, only being able to get it down to 9.8-10.0 ppg and cleaning pits. Working on demob Iist.;Mech rebuilds koomey unit #2 elect pump, work boat, offload 17 jts 2 7/8" tubing, 1 jt. 5" DP, cuttings boxes, rig equipment not needed. Continue to clean out corners of rig floor, pressure wash wind walls. Start to sort through items found. Inventory buckets of oil for equipment.;Work on centrifuge, reverse, clean and reset o- ring. Continue to centrifuge OBM back from 11.0 ppg. Start to clean and inventory 1502 equipment in pump room. Sort and organize hoses, kill line, choke hose. Remove koomey lines from the stack. Transfer light OBM to premix tank. 10/12/2019 Continue to centrifuge OBM back from 11.0 ppg, t/ 10.Oppg. 426 bbls of 10# OBM ready to move to GPP 335 bbls still processing Work on clean and inventory 1502 equipment, continue sort and organize hoses, strip well head and remove hoses valves from well room continue work 5 gal bucket inventory;Mech work on hawk jaw and rebuild #1 elect pump on koomey unit;Continue centrifuging and processing batch #6 f/ 11.0 t/ 10.0 continue house cleaning all drilling areas remove clean flow lines and store same organize and store and inventory shaker screens clean vacuum flow box Removed derrick cameras and filled choke manifold w/ oil;Clean flow nipple and upper and lower 16" air boot assy., Pull rams and clean, clean & grease ram cavities. N/D Annular& Double gate, prep to put on boat. Transfer 10 ppg mud to Premix tank, start to centrifuge Batch #7of 11.1 ppg OBM in pits. 556 bbls 10ppg ready, 246 bbls 11.1 ppg OBM to process.; Continue centrifuging and processing batch #7 f/ 11.1 ppg. Remove mud cross, single gate & riser, remove valves and prep same for boat. Install dry hole tree and test. Void test: 500 psi/5 min., 5000 psi/ 15 min. Neck Seal test: 500 psi/5 minutes, 5000 psi/ 10 minutes visual. Definitive Survey Report - includin Position Uncertaint - ■ ' • 07/Nov/2019 at 14:43 using WellArchitect 5.1 Hilco Alaska, LLC Cook Inlet, Alaska Offshore Tradin Ba Field MONOPOD Platform slot #31 A-10RD A-10RD Cleanout <5915-60425, 8 1/2" Hole <6074-11746'>, 6 1/8" Hole <11850-16178', 11 /07/2019 SDI G ro <1182-1376>, 12 114" Ontrak Section <1508-6864'> at 5818.00 MD So emick Minimum curvature Ma petit North is 19,46 degrees East of True North td Dev 2.00 S WA ANC Defn ■ • - ■. ■ . ■. ■ • •■ MEN6 NAD27 / TM Alaska SP, Zone 4 (5004), US feet True p,ggggg 1.38 West Slot Actual Datum (RKB) Actual Datum (RKB) mean sea level 101.00 ft 101.00 ft 101.00 ft E 0.00 ft N 0.00 ft 4.98° nclud ed 0.00 ft -3.56 -7.51 218864.52 218872.11 2523116.28 2523119.66 60°53'48.559"N 60°53'48.594"N 151°34'43.636"W 151°34'43.485W 0.00 0.00 0.00 0.00 Start ■ IN 0.00 End MD Iftl 900.00 SDI Kee er Positional Uncertainty roMWD v1.t Standard Model SDI <0-900>- 219397.72 Log Name I Comment 2521500.50 60053'32.779"N Wellbore 151°34'32.077"W 900.00 1106.00 BHI Photomechanical Magnetic (Standard_ _ MSS <0-7073'> A-10 1106.00 1376.00 SDI Keever gyroMWD 0.1 StandaM _ SDI Gyro <1182-1376> A-10RD Stl _ 1376.00 5818.00 BHI OnTrak SAG _ 12 1/4" Ontrak Section <1508-6864'> _ A-10RD St1 5818.00 6042.00 BHI OnTrek((Standard) Cleanout assembly sidetrack <5915-6042'> A-10RD 6042.00 11746.00 BHI AutoTrak G3 (Standard) 8 112" Hole Section AutoTmk/AziTmk <6074-117465 A-10RD 11746.00 16178.00 16178.00 T 16212.00 BHI Unknovtin Tool StandardL Blind Dnllin std 6 1/8" Hole <11850-16178'> Projection to bit A-10RD A-10RD DiameterString I ■ 0.00 _ Inclination 0.00 Azimuth 73.35 TVD 0.00 ■ TVDSSDLS -tOt.00 End MID 0.00 Interval 0.00 Start TVD 215864.52 End TVD 2523116.28 60°53'48.559"N 151°34'43.Wb" rr 0.00 Toolface 73.35 Build Rate rr 0.00 Turn Rate rr 0.00 Vert Sect 0.00 Major Semi 0.00 Minor Semi 0.00 Vert Semi 0.00 Minor Azim comments 0.00 25.00 0.11 73.35 25.00 -76.00 0.01 0.02 218864.54 2523116.29 60°53'48.559"N 151°34'43.636" 0.44 0.00 0.44 293.40 0.02 0.09 0.09 2.30 163.35 50.00 0.21 73.35 50.00 -51.00 0.03 0.09 218864.61 2523116.30 60°53'48.560"N t51°34'43.635' 0.40 -59.00 0.40 0.00 0.09 0.18 0.17 2.30 163.35 75.00 0.27 56.16 75.00 -26.00 0.07 0.18 218864.70 2523116.35 60°53'48.560"N 151°34'43.633' 0.37 -157.98 0.24 -68.76 0.20 0.27 0.26 2.30 340.40 100.00 0.21 49.36 100.00 -1.00 0,14 0.27 218864.79 2523116.41 60°53'48.561"N 151°34'43.631' 0.27 -156.70 -0.24 -27.20 0.30 0.37 0.35 2.30 335.99 125.00 0.17 43.41 125.00 24.00 0.19 0.33 218864.85 2523116.46 60°53'48.561"N 151°34'43.630' 0.18 15.70 -0.16 -23.80 0.38 0.46 0.44 2.30 332.11 150.00 0.42 52.82 150.00 49.00 0.27 0.43 218864.95 2523116.54 60°53'48.562"N 151°34'43.628" 1.02 13.27 1.00 37.64 0.50 0.55 0.52 2.30 329.75 175.00 0.66 57.69 175.00 74.00 0.41 0.62 218865.15 2523116.67 60°53'48.563"N 151°34'43.624' 0.98 -13.14 0.96 19.48 0.73 0.64 0.61 2.30 329.10 200.00 0.80 55.36 200.00 99.00 0.58 0.89 218865.42 2523116.84 60°53'48.565"N 151°34'43.619' 0.57 -165.03 0.56 -9.32 1.05 0.73 0.70 2.31 328.77 225.00 0.72 53.65 224.99 123.99 0.78 1.16 218865.69 2523117.03 60°53'48.567"N 151°34'43.613' 0.33 93.01 -0.32 -6.84 t.37 0.82 0.79 2.31 328.27 250.00 0.73 66.62 249.99 148.99 0.93 1.43 218865.97 2523117.18 60053'48.568"N 151034'43.608" 0.66 127.44 0.04 51.88 t.69 0.92 0.87 2.31 148.53 275.00 0.58 102.03 274.99 173.99 0.97 1.70 218866.24 2523117.21 60°53'48.569"N 151°34'43.602" 1.69 74.66 -0.60 141.64 1.95 1.01 0.96 2.32 150.82 300.00 1.08 145.50 299.99 198.99 0.75 1.96 218866.49 2523116.98 60°53'48.567"N 151*34'43.597' 3.08 48.04 2.00 173.88 2.09 1.09 1.05 2.32 155.00 325.00 1.70 165.35 324.98 223.98 0.19 2.18 218866.71 2523116.42 60°53'48.561"N 151°34'43.592' 3.10 68.44 148 79.40 2.06 1.18 1.14 2.32 159.66 350.00 2.19 187.58 349.97 248.97 -0.64 2.21 218866.72 2523115.59 60°53'48.553"N 151°34'43.592' 3.56 61.31 1.96 88.92 1.74 1.26 1.22 2.33 163.37 375.00 3.20 212.01 1 374.94 273.94 -1.70 1.78 218866.26 2523114.54 60°53'48.543"N 151*34'43.600' 6.03 1 34.35 4.04 97.72 0.89 1.34 1.31 2.33 164.75 400.00 3.92 218.94 399.89 298.89 -2.96 0.87 218865.32 2523113.30 60°53'48.530"N 151°34'43.619" 3.35 40.42 2.86 27.72 -0.46 1.43 1.40 2.34 164.70 425.00 4.71 226.71 424.82 323.82 -4.33 -0.41 218864.00 2523111.96 60°53'48.517"N 151°34'43.645' 3.92 45.16 3.16 31.08 -2.20 1.51 1.49 2.34 164.69 450.00 5.54 234.81 449.72 348.72 -5.73 -2.14 218862.24 2523110.61 60°53'48.503"N 151°34'43.680' 4.40 36.31 3.32 32.40 4.36 1.60 1.58 2.34 164.90 475.00 6.32 239.86 474.59 373.59 -7.11 - -4.32 218860.03 2523109.27 60°53'48.489"N 151'34'43.724'M 3.75 1920. 3.12-2 0.20 E.92 1.69 1.66 2.35 165.67 500.00 7.23 242.36 499.41 398.41 -8.53.......0.00 -9.87 1.78 1.75 2.35 165.80 525.00 8.28 242.57 524.18 423.18 -10.09 -9.90 218854.38 2523106.43 60°53'48.460"N 151°34'43.836' 4.20 -3.54 4.20 0.84 -13.24 1.87 1.84 2.35 164.41 550.00 9.24 242.20 548.89 447.89 -11.86 -13.27 218850.97 2523104.74 60°53'48.443"N 151°34'43.905' 3.85 -4.75 3.84 -1.48 -17.04 1.96 1.93 2.35 162.21 575.00 9.88 241.89 573.54 472.54 -13.81 -16.94 218847.26 2523102.89 60°53'48.423"N 151°34'43.979" 2.57 -0.63 2.56 -1.24 -21.19 2.05 2.03 2.36 160.88 600.00 10.37 241.86 598.15 497.15 -15.88 -20.81 218843.33 2523100.91 2523098.84 60°53'48.403"N 151°34'44.057' 1.96 3.95 1.96 -0.12 -25.57 2.14 2.12 2.36 161.83 625.00 10.89 242.05 622.72 521.72 -18.04 -24.88 218839.21 60°53'48.382"N 151°34'44.139" 2.08 -9.00 2.08 0.76 -30.18 2.22 2.22 2.37 179.95 650.00 11.67 241.44 647.24 546.24 -20.36 -29.19 218834.85 2523096.63 60°53'48.359"N 151°34'44.226" 3.16 5.55 3.12 -2.44 -35.06 2.32 2.32 2.37 238.38 675.00 12.26 241.71 671.70 570.70 -22.83 -33.75 218830.23 2523094.27 60°53'48.335"N 151-34-44.319' 2.37 1 1.92 2.36 1.08 -40.23 2.43 2.41 2.38 242.05 700.00 13.07 241.83 696.09 595.09 -25.42 -38.58 218825.34 2523091.80 60°53'48.309"N 151°34'44.416" 3.24 -0.17 3.24 0.48 -05.71 2.54 2.50 2.38 242.37 725.00 13.86 241.82 720.40 619.40 -28.17 -43.71 218820.15 2523089.17 60°53'48.282"N 151°34'44.520" 3.16 2.10 3.16 -0.04 -51.52 2.66 2.59 2.38 242.49 750.00 14.69 241.94 744.63 643.63 -31.07 -49.15 218814.64 2523086.40 60°53'48.253"N 151°34'44.630" 3.32 0.35 3.32 0.48 -57.68 2.79 2.69 2.39 242.47 775.00 15.58 241.96 768.76 667.76 -34.14 -54.91 218808.81 2523083.47 60053'48.223"N 151034'44.746" 3.56 1.03 3.56 0.08 -64.19 2.92 2.78 2.39 242.40 800.00 16.36 242.01 792.80 691.80 -37.37 -6698 218802.66 2523080.39 60°53'48.191"N 151°34'44.869' 3.12 1.87 3.12 0.20 -71.06 3.07 1 2.88 2.40 242.34 825.00 1,7 242.09 1116.74 715.74 46.74 -67.33 218796.23 2523077.17 60°58.158"N 3'4 151°34'44.9' 97 2.88 3.59 2.88 0.32 -78.24 3.23 2.97 2.40 242.27 850.00 18.07 242.29 840.57 739.57 -44.27 -74.01 218789.47 2523073.81 60°53'48.123"N 151°34'45.132" 3.97 4.75 3.96 0.80 -85.78 3.40 3.07 2.41 242.22 875.00 1 18.93 242.51 864.28 763.28 -47.94 -81.04 218782.35 2523070.30 60°53'48.087"N 151°34'45.274" 3.45 2.87 3.44 0.88 -93.71 3.59 3.17 2.42 242.20 900.00 19.81 242.64 887.87 786.87 -51.76 -88.40 218774.90 2523066.66 1 60°53'48.050"N 151°34'45.423" 3.52 16.49 3.52 0.52 -101.99 3.80 3.26 2.42 242.21 957.00 21.50 244.00 941.20 840.20 -60.78 -106.37 218756.72 2523058.08 60°53'47.961"N 151034'45.786' 3.08 5.57 2.96 2.39 -122.09 4.07 3.42 2.42 241.81 1106.00 26.00 245.00 1077.55 976.55 -86.56 -160.53 218701.95 2523033.6t 60°53'47.707"N 151°34'46.881' 3.03 -156.50 3.02 0.67 -182.08 4.60 4.26 2.71 227.58 1182.00 20.83 238.53 1147.28 1046.28 -100.67 -187.18 218674.97 2523020.15 1 60°53'47.568"N 151°34'47.420' 7.59 -172.80 -6.80 -8.51 -2 22.19 4.98 4.71 2.97 202.00 1278.00 15.83 236.21 1238.38 1137.38 -116.87 -212.64 218649.13 2523104.16 60°53'47.408"N 151°34'47.934' 5.26 -170.63 -5.21 -2.42 -242.11 5.13 4.76 3.07 217.93 1376.00 11.66 232.79 1333.55 1232.55 -130.30 -231.64 218629.81 2522991.59 1 60°5347.276"N 151034'48.319' 4.33 176.15 -4.26 -3.49 -265.01 5.33 4.81 3.17 223.92 Page 1 of 3 4531.00 57.29 63.96 3617.72 3516.72 672.47 1316.69 1 220197.01 2523756.85 60-53-55.181 "N 151 °34'17.020' 0.50 20.98 -0.32 1477.54 44.04 12.50 10.17 62.68 4626.00 57.82 64.20 3668.69 3567.69 707.51 0 220269.93 2523790.15 60°53'55.526"N 151°34'15.562" 0.60 15.70 0.56 1557.70 46.07 12.65 10.46 62.77 4719.00 58.61 64.46 3717.67 3616.67 741.76 220341.99 2523822.66 60°53'55.863"N 151°34'14.122" 0.88 10.69 0.85 1636.75 48.08 12.79 10.74 6255 4814.00 59.11 64.57 3766.80 3665.80 776.745 220416.21 2523855.87 60°53'56.207"N 151°34'12.638' 0.54 31.49 0.53 171806 50.16 12.95 11.04 62.94 4903.00 59.49 64.84 3812.24 3711.24 809.444 220486.16 2523886.89 60°53'56.529"N 151*34-11.240" 0.50 85.30 0.43 dO.25 1794.58 52.11 13.09 11.32 63.02 5002.00 59.50 64.98 3862.49 3761.49 845.61 F1460.05 9 220564.26 2523921.19 60°53'56.885"N 151°34'09.678' 0.12 68.01 0.01 1879.88 54.30 13.25 11.64 33.125098.00 59.70 65.55 3911.07 3810.07 880.269 220640.27 252395402 60-53-57.226"N 151°34'08.158' 0.55 -11.10 0.21 1962.68 56.42 13.40 11.95 63.21 5192.00 60.32 65.41 3958.06 3857.06 914.046 220715.14 2523986.01 60°53'57.559"N 151°34'06.660' 0.67 -14.55 0.66 2044.09 58.52 13.56 12.26 63.31 5288.00 60.96 65.22 4005.13 3904.13 948.999 220791.98 2524019.11 60°53'57.903"N 151°34'05.123' 0.69 -3.28 0.67 2127.76 60.67 13.72 12.58 63.39 5374.00 61.42 65.19 4046.57 3945.57 980.59 9 220861.13 2524049.06 60°53'58.214"N 151°34'03.740' 0.54 19.09 0.53 -0.03 2203.11 62.62 13.86 12.88 63.46 5469.00 62.29 65.53 4091.38 3990.38 1015.51 2049.73 220938.08 2524082.14 60°5358.558"N 151°34'02.201' 0.97 -160.58 0.92 0.36 2286:88 64.78 14.02 13.20 63.54 5563.00 60.83 64.94 4136.15 4035.15 1050.13 2124.79 221013.95 2524114.94 60°53'58.898"N 151°34'00.684' 1.65 -171.35 -1.55 -0.63 2369.53 66.92 14.18 13.54 63.60 5657.00 58.86 64.59 4183.36 4082.36 1084.78 2198.31 221088.28 2524147.81 60°53'59.239"N 151°33'S9.197' 2.12 28.19 -2.10 _ -0.37 2450.80 69.01 14.34 13.88 63.64 5752.00 59.02 64.69 4232.38 4131.38 1119.64 2271.84 221162.63 2524180.88 60°53'59.583"N 151°33'57.71 I'M 0.19 151.47 0.17 1 0.11 2532.18 71.10 14.52 14.23 63.68 5818.00 58.24 65.19 4266.74 4165.74 1143.51 2322.89 221214.24 2524203.52 60153'59.817"N 151°33'56.679' 1.34 -16.30 -1.18 0.76 2588.53 72.55 14.65 14.46 63.71 5916.00 60.38 64.47 4316.24 4215.24 1178.99 2398.38 221290.56 2524237.17 60°54'00.167"N 151 *33'55.152'M 2.29 51.22 2.20 -0.74 2671.94 74.36 15.76 14.31 63.73 6042.00 61.13 65.53 4378.29 4277.29 1225.81 2498_80 221392.08 2524281.56 60°54'00.628"N 151°33'53.122' 0.94 -6.65 0.59 0.83 2782.75 76.36 15.85 14.41 63.76 6074.00 62.50 65.35 4393.40 4292.40 1237.54 2524.46 221418.01 2524292.67 60°54'00.743"N 151°3X52.603' 4.31 168.73 4.28 -0.56 2810. 66 7687 15.93 14.37 6-377 6167.00 60.62 65.78 4437.69 4336.69 1271.37 2598.90 221493.25 2524324.69 60°54'01.076"N 151°33'51.098' 2.06 169.45 -2.02 0.46 2892.72 78.36 1 15.98 14.42 63.80 6262.00 59.01 66.13 4485.45 4384.45 1304.83 2673.89 221569.02 2524356.34 60°54'01.405"N 151 °33'49.582' 1.72 160.91 -1.69 0.37 2974.83 79.87 16.05 14.51 63.84 6357.00 58.20 6646 4534.94 4433.94 1337.43 2748.14 221644.03 1 2524387.14 60°54'01.726"N 151°33'48.081' 0.90 90.15 -0.85 0.35 3055.90 61.40 16.12 14.62 63.88 6454.00 58.20 67.03 4586.06 4485.06 1369.98 2823.88 221720.53 2524417.86 60°54'02047"N 151°33'46.550' 0.50 86.91 0.00 0.59 3138.30 82.97 16.20 14.73 63.94 6547.00 58.23 67.65 4635.04 4534.04 1400.43 2896.83 221794.19 2524446.55 60°54'02.346"N 151°33'45.075' 0.57 -82.03 0.03 0.67 3217.28 84.50 16.29 14.85 64.00 6644.00 58.26 67.40 4686.09 4585.09 1431.96 2973.05 221871.15 2524476.23 60°54'02.657"N 151°33'43.534' 0.22 -95.40 0.03 -0.26 3299.68 86.11 16.39 15.00 64.07 6738.00 58.23 67.02 4735.56 4634.56 1462.92 3046.74 221945.56 2524505.41 1 60-54-02.961 "N 151 °33'42.044' 0.35 -90.13 -0.03 -0.40 3379.55 87.70 16.49 15.17 64.13 6833.00 58.23 66.52 4785.58 4684.58 1494.78 3120.96 222020.52 2524535.47 60°54'03.275"N 151°33'40.543 0.45 -70.37 0.00 -0.53 3460.28 89.32 16.60 15.35 64.18 6928.00 58.30 66.29 4836.55 4734.55 1527.12 3195.00 222095.32 2524566.02 60°54'03.593"N 151'33'39.046' 0.22 -108.19 0.07 -0.24 3541.05 90.96 16.72 15.56 64.22 Page 2 of 3 12987.00 58.68 67.15 7991.91 7890.91 3695.77 7888.12 226839.24 2526621.03 60°54'24.926"N 151'32'04.141' 1.12 -149.02 0.07 -1.31 8710.97 214.73 37.83 52.51 64.88 13065.00 57.31 66.17 8033.25 793225 . 3721.97 7948.85 226900.58 2526645.76 60°54'25.184"N 151*32'02.912' 2.05 -147.84 -1.76 -1.26 18.24 38.76 54.13 64.91 13081.00 57.03 65.96 8041.92 7940.92 3727.42 7961.14 22691 MO 2526650.91 60°54'25.238"N 151-32'02.664' 2.07 -17224 . -1.75 -1.31 8790.53 218.97 38.96 54.47 64.91 54.29 65.50 8095.51 7994.51 3759.66 8032.65 226985.26 2526681.42 60°54'25.555"N 151°32'01.217 2 -164.87 8 -0.48 6 223.38 40.20 .47 64.9313176.00 13271.00 51.57 64.56 8152.77 54.72 2526711.74 6054'25.869"N 151°3159.828" 2.97 170.76 -2.86 -0.99 89 41.59 58.48 64.94 48.75 65.17 8212.98 8111.98 3822.30 8166.69 227120.77 2526740.82 60°54'26.171"N 151°31'58.506" 3.04 -173.96 -3.00 0.91 2 43.10 60.45 64.9413365.00 13459.00 46.49 64.84 8276.34 8175.34 3861.64 8229.62 227184.39 2526768.63 60°54'26.459"N 151°31'57.233" 2.42 -154.35 -2.40 -0.35 9086.35 236.68 44.73 6 13553.00 44.47 63.45 8342.25 8241.25 3880.85 8289.94 227245.38 2526796.38 60°5426.746"N 151°31'56.013' 2.39 143.70 -2.15 -1.48 9153.35 241.06 4648 6 13648.00 41.29 67.05 8411.86 8310.86 3907.96 8348.59 227304.67 2526822.06 60°54'27.013"N 151'31'54.827' 4.22 164.72 -3.35 3.79 9217.97 245.41 487 6 13750.00 39.86 67.66 8489.34 8388.34 3933.50 8409.82 227366.50 2526846.13 60°54'27.264"N 151°31'53.589' 1.45 -82.94 -1.40 0.60 9284.25 249.98 50.53 68.08 64.99 13843.00 39.99 66.16 8560.66 8459.66 3956.92 8464.71 227421.94 2526868.21 60`54'27.494"N 151°31'52.478' 1.05 -90.30 0.14 -1.62 9343.90 254.18 52.56 69.85 65.02 13938.00 40.01 63.57 8633.44 8532.44 3982.85 8519.98 227477.82 2526892.81 60°54'27.749"N 151°31'51.360' 1.75 89.67 0.02 -2.72 9404.96 258.57 54.67 71.67 65.02 14034.00 40.02 64.72 8706.96 8605.96 4009.77 8575.53 227534.00 2526918.39 60°54'28.014"N 151'31'50.237' 0.77 87.47 0.01 1.20 9466.67 263.10 56.83 73.53 65.01 14128.00 40.08 66.40 8778.92 8677.92 4034.79 8630.59 227589.64 2526942.07 60G54'26260"N 151°31'49.123' 1.15 102.57 0.06 1.79 9527.15 267.66 58.99 75.37 65.02 14223.00 40.06 66.54 8851.62 8750.82 4059.21 8686.66 227646.28 2526965.13 60°54'28.500"N 151°31'47.989' 0.10 -93.70 -0.02 0.15 9588.28 272.24 61.20 77.25 65.05 14317.00 40.01 65.13 8923.59M88224083.96 8741.82 227702.03 2526988.55 60°54'28.743"N 151°31'46.873' 0.97 80.78 -0.05 -1.50 964874 27689 63.41 79.12 65.06 14411.00 40.03 65.32 8995.584109.29 8796.71 227757.50 2527012.55 60°54'28.992"N 151*31'45.763' 0.13 -94.50 0.02 0.20 9709.19 28160 65.64 81.00 65.07 14505.00 39.97 63.98 9067.594135.16 8851.31 227812.71 2527037.09 60°54'29.247"N 151°31'44.658' 0.92 79.91FO.31 -1.43 9769.61 286.38 67.90 8289 6506 14600.00 40.02 64.41 9140.374161.74 890628 227868.30 2527062.34 60°5429.508"N 151°31'43.547" 0.30 91.20 0.45 9830.66 291.26 70.20 84.82 65.05 14695.00 40.01 66.35 9213.13 . 4187.18 8961.80 227924.42 2527086.44 60°54'29.758"N 151°31'42.423' 1.31 -85.65 2.04 9891.73 296.21 72.52 86.75 65.06 14790.00 40.10 64.74 9285.85 9184.85 4212.49 9017.45 227980.66 2527110.40 60°54'30.007"N 151°31'41.298' 1.09 -94.82 -1.69 9952.86 301.22 74.85 88.70 65.07 14882.00 40.05 63.74 9356.25 9255.25 4238.23 9070.79 228034.61 2527134.86 60°54'30.260"N 151°31'40.219' 0.70 90.42 -1.09 10012.08 306.12 77.12 90.60 65.06 14977.00 40.05 64.84 9428.97 9327.97 4264.75 9125.87 228090.30 2527160.03 60°54'30.521"N 151°31'39.105' 0.75 99.84 1.16 10073.21 311.22 79.48 92.57 65.05 15073.00 39.99 65.39 9502.49 9401.49 4290.72 9181.87 228146.91 2527184.66 60°54'30.776"N 151°31'37.972' 0.37 72.90 0.57 10134.94 316.43 81.88 94.56 65.05 15168.00 40.08 65.84 9575.22 9474.22 4315.95 9237.52 228203.16 2527208.54 60°54'31.024"N 151°31'36.846' 0.32 -143.23 0.47 10196.04 321.62 84.26 96.55 65.06 15263.00 39.73 65.43 9648.10 9547.10 4341.09 9293.04 228259.27 2527232.33 60°54'31.271"N 151031'35.723' 0.46 -36.24 -0.43 10256.98 326.85 86.66 98.53 65.07 15356.00 40.02 65.10 9719.47 9618.47 4366.04 9347.19 228314.00 2527255.97 60°54'31.516"N 151°31'34.628" 0.39 -98.79-0.35 10316.61 332.00 89.02 100.48 65.08 2527297.30 60°54'32.632"N -U.U4 Page 3 of 3 Actual Wellpath Geographic Report - including Position Uncertainty • • • • • • , • 07/Nov/2019 at 14:29 using WellArchitect 5.1 Hilco Alaska, LLC Cook Inlet, Alaska (Offshore) Tradin Ba Field MONOPOD Platform slot #31 A-1 ORD Stl A-10RD St1 SDI Gyro <1182-1376>, 12 1/4" Ontrak Section <1508-68645 11/07/2019 SDI <0-900>, MSS <957-7073> at 1106.00 MD So emick Minimum curvature Magnetic North is 19,46 degrees East of True North 2.00 Std Dev WA ANC Defn • - • • •. •. •. • • •• NAD27 / TM Alaska SP, Zone 4 5004 , US feet True p_ggggg 1.3E West Slol Actual Datum (RKB Actual Datum (RKB) mean sea level 101.00 ft 101.00 fl 101.0011 E 0.00 It N 0.00 It 64970 included 0.00 ft -3.56 -7.51 218864.53 218872.11 219397.72 2523116.2E 2523119.66 2521500.50 60°53'48.559"N 60°53'48.594"N 1 60°53'32.779"N 151 °34'43.636"W 151°34'43.485"W 151°34'32.077"W 0.00 0.00 0.00 0.00 Start MD 0.00 900.00 110600 End MD 900.00 1106.00 1376.00 Positional Uncertainty Model SDI Keeper ymMWD v1.1 (Standard) BHI Photomechanical Ma netic Standard SDI Keeper gyroMWD vi.i StandaM Log SDI <0-900> MSS <0-7073'> SDI G ro <1182-1376> Name I Comment A-10 St1137600 �AlORD Wellbore _ 12 1/4" Ontrak Section <1508�864'> Stt6864.00 6950.00 Blind Drillin std Proection to bit Stt DiameterString I Target A-A0Rw 11 Name TO1 Pol on _8423.30 TVD 10200.00 North 3909.47 4565.33 East 10144.63 Grid East 227316.44 22911600 Grid North 2525823.30 2527436.00604 Latitude °5 60''27.402N N1MD Longitude 311559W °3'18499 111 Shape oint n0RD of o Comment [ft] 0.00 Inclination 0.00 Azimuth 73.35 TVD 0.00 TVDSS -101.00 North 0.00 East 0.00 Grid East 52 218864w Grid North 2523116.2E Latitude 60°53'48.559"N Longitude 151°34'43.636" DLS rr 0.00 Toolface 73.35 Build Rate Turn 0.00 Rate r 0.00 Vert Sect 0.00 Major Semi 0.00 Minor Semi 0.00 Vert Semi 0.00 Minor Azim Comments 0.00 25.00 0.11 73.35 25.00 -76.00 0.01 0.02 218864116.29 60°53'48.559"N 151°3443.636" 0.44 0.00 0.44 293.40 0.02 0.09 0.09 2.30 163.35 _ 50.00 0.21 73.35 50.00 -51.00 0.03 0.09 218864116.30 60053'48.560"N 151034'43.635' 0.40 -59.00 0.40 0.00 0.09 0.18 0.17 2.30 163.35 75.00 0.27 56.16 75.00 -26.00 0.07 0.18 218864116.35 60°53'48.560"N 151°34'43.633' 0.37 -157.9E 0.24 -68.76 0.20 0.27 0.26 2.30 340.40 100.00 0.21 49.36 100.00 -1.00 0.14 0.27 218864116.41 60°53'48.561"N 151°3443.631" 0.27 -156.70 -0.24 -27.20 0.30 0.37 0.35 2.30 335.99 125.00 0.17 43.41 125.00 24.00 0.19 0.33 218864116.46 60°53'48.561"N 151°3443.630" 0.1E 15.70 -0.16 -23.80 0.38 0.46 0.44 2.30 332.11 _ 150.00 0.42 52.82 150.00 49.00 0.27 0.43 218864116.54 60°53'48.562"N 151°34'43.628" 1.02 13.27 1.00 37.64 0.50 0.55 0.52 2.30 329.75 _ 175.00 0.66 57.69 175.00 74.00 0.41 0.62 218865116.67 60°53'48.563"N 151°34'43.624" 0.9E -13.14 0.96 19.4E 0.73 0.64 0.61 2.30 329.10 _ 200.00 0.80 55.36 200.00 99.00 0.58 0.89 2188653116.84 60°53'48.565"N 151°34'43.619" 0.57 -165.03 0.56 -9.32 1.05 0.73 0.70 2.31 328.77 _225.00 0.72 53.65 224.99 123.99 0.78 1.16 218865.69 2523117.03 60°53'48.567"N 151°34'43.613' 0.33 93.01 -0.32 -6.84 1.37 0.82 0.79 2.31 328.27 _ 250.00 0.73 66.62 249.99 148.99 0.93 1.43 218865.97 2523117.18 60°53'48.568"N 151°34'43.608' 0.66 127.44 0.04 51.88 1.69 0.92 0.87 2.31 148.53 275.00 0.58 102.03 274.99 _ 173.99 0.97 1.70 218866.24 2523117.21 60°53'48.569"N 151°34'43.602' 1.69 74.66 -0.60 141.64 1.95 1.01 0.96 2.32 150.82 _ 300.00 1.08 145.50 299.99 198.99 0.75 1.96 218866.49 2523116.98 60°53'48.567"N 151°34'43.597" 3.08 48.04 2.00 173.88 2.09 1.09 1.05 2.32 155.00 325.00 1.70 165.35 324.98 223.98 0.19 2.18 218866.71 2523116.42 60°53'48.561"N 151°34'43.592" 3.10 68.44 2.48 79.40 2.06 1.18 1.14 2.32 159.66 _ 350.00 2.19 187.58 349.97 248.97 -0.64 2.21 218866.72 2523115.59 60°53'48.553"N 151°34'43.592" 3.56 61.31 1.96 88.92 1.74 1.26 1.22 2.33 163.37 375.00 3.20 212.01 374.94 273.94 -1.70 1.78 218866.26 2523114.54 60°53'48.543"N 151°34'43.600" 6.03 34.35 4.04 97.72 0.89 1.34 1.31 2.33 164.75 _ 400.00 3.92 218.94 399.89 298.89 -2.96 0.87 218865.32 2523113.30 60°53'48.530"N 151 °34'43.619' 3.35 40.42 2.88 27.72 -0.46 1.43 1.40 2.34 164.70 425.00 4.71 226.71 424.82 323.82 -4.33 -0.41 218864.06 2523111.96 60°53'48.517"N 151°34'43.645' 3.92 45.16 3.16 31.08 -2.20 1.51 1.49 2.34 164.69 450.00 5.54 234.81 449.72 348.72 -5.73 -2.14 218862.24 2523110.61 60°53'48.503"N 151°34'43.680' 4.40 36.31 3.32 32.40 -4.37 1.60 1.58 2.34 164.90 475.00 6.32 239.86 474.59 373.59 -7.11 -4.32 218860.03 2523169. 77 60°5348.489"N 151°34'43.724' 3.75 19.20 3.12 20.20 -6.92 1.69 1.66 2.35 165.67 500.00 7.23 242.36 499.41 398.41 -8.53 -6.90 218857.41 2523107.91 60°53'48.475"N 151'34'43.776' 3.83 1.65 3.64 10.00 -9.87 1.78 1.75 2.35 165.80 525.00 8.28 242.57 524.18 423.18 -10.09 -9.90 218854.38 2523106.43 60°53'48.460"N 151°34'43.836' 4.20 -3.54 4.20 0.84 -13.24 1.87 1.84 2.35 164.41 550.00 9.24 242.20 548.89 447.89 -11.86 -13.27 218850.97 2523104.74 60°53'48.443"N 151°34'43.905" 3.85 -4.75 3.84 .48 -17.04 1.96 1.93 2.35 162.21 575.00 9.8E 241.89 573.54 472.54 -13.81 -16.94 218847.26 _2523102.89 60°53'48.423"N 151'34'43.979' 2.57 -0.63 2.56 .24 -21.19 2.05 2.03 2.36 160.88 600.00 10.37 241.86 598.15 497.15 -15.88 -20.81 218843.33 2523100.91 60°53'48.403"N 151°34'44.05T 1.96 3.95 1_96 .12 -25.58 2.14 2.12 2.36 161.83 625.00 10.89 242.05 622.72 521.72 -18.04 -24.88 218839.21 2523098.84 60°53'48.382"N 151°34'44.139' 2.0E -9.00 2.08 .76 -30.18 2.22 2.22 2.37 179.95 _ 650.00 11.67 241.44 647.24 546.24 -20.36 -29.19 218834.85 2523096.63 60°53'48.359"N 151°34'44.226' 3.16 5.55 3.12 .44 !-2 -35.06 2.32 2.32 2.37 236.3E 675.00 12.26 241.71 671.70 570.70 -22.83 -33.75 218830.23 2523094.27 60°53'48.335"N 151°34'44.319' 2.37 1.92 2.36.0E A0.24 2.43 2.41 2.3E 242.05 700.00 13.07 241.83 696.09 595.09 -25.42 -38.58 218825.34 2523091.80 60*53, 8.309"N 151°34'44.416' 3.24 -0.17 3.24 .4E -45.71 2.54 2.50 2.38 242.37 725.00 13.86 241.82 720.40 619.40 -28.17 -43.71 218820.15 2523089.17 60°53'48.282"N 151°34'44.520' 3.16 2.10 3.16 .04 -51.52 2.66 2.59 2.3E 242.49 75000 14.69 241.94 744.63 643.63 -31.07 -49.15 218814.64 2523086.40 60°53'48.253"N 151°34'44.630' 3.32 0.35 3.32 .4E -57.68 2.79 2.69 2.39 242.47 775.00 15.5E 241.96 768.76 667.76 -34.14 -54.91 218808.81 2523083.47 60°53'4E.223"N 151°34'44.746" 3.56 1.03 3.56 0.0E -64.20 2.92 2.78 2.39 242.40 800.00 16.36 242.01 792.80 691.80 -37.37 -60.98 218802.66 2623080.39 60°53'48.191"N 151°34'44.869" 3.12 1.87 3.12 0.20 -71.06 3.07 2.88 2.40 242.34 825.00 17.08 242.09 816.74 715.74 -40.74 -67.33 218796.23 2523077.17 60°53'48.158"N 151°34'44.997" 2.8E 3.59 2.8E 0.32 -78.25 3.23 2.97 2.40 242.27 850.00 18.07 242.29 840.57 739.57 -44.27 -74.01 218789.47 2523073.81 60°53'48.123"N 151°34'45.132" 3.97 4.75 3.96 0.80 -85.79 3.40 3.07 2.41 242.22 _ 875.00 18.93 242.51 864.2E 763.2E 47.94 -81.04 218782.35 2523070.30 60°5348.087"N 151°34'45.274" 3.45 2.87 3.44 0.8E -93.71 3.59 3.17 2.42 242.20 900.00 19.81 242.64 887.87 786.87 -51.76 -88.40 218774.90 2523066.66 60°53'48.050"N 151°34'45.423" 3.52 16.49 3.52 0.52 -102.00 3.80 3.26 2.42 242.21 957.00 21.50 244.00 941.20 840.20 b0.78 -106.37 218756.72 2523056.OB 60°53'47.961"N 151°34'45.786" 3.0E 5.57 2.96 2.39 -122.09 4.07 3.42 2.42 241.81 1106.00 26.00 245.00 1077.55 976.55 -86.56 -160.53 218701.95 2523033.61 60°53'47.707"N 151°34'46.881" 3.03 -156.50 3.02 0.67 -182.08 4.60 4.26 1 2.71 227.58 _ Page 1 of 2 4249.00 58.97 65.08 3470.10 3369.10 569.80 1099.51 219977.41 2523659.44 60053'54.170"N 151034'21.411" 0.90 7.14 0.87 0.24 1237.33 37.95 12.08 9.29 62.25 4342.00 59.59 65.17 3517.61 3416.61 603.43 1172.04 220050.73 2523691.31 60°5354.501"N 151°34'19.944' 0.67 -162.01 0.67 0.10 1317.27 39.97 12.21 9.56 62.44 4436.00 57.59 64.40 3566.59 3465.59 637.60 1244.62 220124.11 2523723.72 60°53'54.837"N 151°34'18.477' 2.24 -129.09 -2.13 -0.82 1397.49 42.01 12.35 9M 62.59 4531.00 57.29 63.96 3617.72 3516.72 672.47 1316.69 220197.01 2523756.85 60053'55.181"N 151°34'17.020' 0.50 20.98 -0.32 -0.46 1477.56 44.04 12.50 10.17 62.68 4626.00 57.82 64.20 3668.69 3567.69 707.51 1388.80 220269.93 2523790.15 60°53'55.526"N 151034'15.562' 0.60 15.70 0.56 0.25 1557.72 46.07 12.65 10.46 62.77 4719.00 58.61 64.46 3717.67 3616.67 741.76 1460.05 220341.99 2523822.66 60°53'55.863"N 151034'14.122' 0.88 10.69 0.85 0.28 1636.76 46M 12.79 10.74 62.85 4614.00 59.11 64.57 3766.80 3665.80 776.74 1533.45 220416.21 2523855.87 60°53'56.207"N 151°34'12.638' 0.54 31.49 0.53 0.12 1718.07 50.16 12.95 11.04 62.94 4903.00 59.49 64.84 3812.24 3711.24 809.44 1602.64 220486.16 2523886.89 60°53'56.529"N 151'34'1 1.240'M 0.50 85.30 0.43 0.30 1794.60 52.11 13.09 11.32 63.02 5002.00 59.50 64.98 3862.49 3761.49 845.61 1679.89 220564.26 2523921.19 60°53'56.885"N 151°34'09.678' 0.12 68.01 0.01 0.14 1879.89 54.30 13.25 11.64 63.12 5098.00 59.70 65.55 3911.07 3810.07 880.26 1755.09 220640.27 2523954.02 60°53'57.226"N 151°34'08.158' 0.55 -11.10 0.21 0.59 1962.69 56.42 13.40 11.95 63.21 5192.00 60.32 65.41 3958.06 3857.06 1 914.04 1829.16 220715.14 2523986.01 60°53'57.559"N 151034'06.660' 0.67 -14.55 0.66 -0.15 2044.10 58.52 13.56 12.26 63.31 5288.00 60.96 65.22 4005.13 3904.13 1 948.99 1905.19 220791.98 2524019.11 60°53'57.903"N 151°34'05.123' 0.69 -3.28 0.67 -0.20 2127.77 60.67 13.72 12.58 63.39 5374.00 61.42 65.19 4046.57 3945.57 980.59 1973.59 220861.13 2524049.06 60-53-58.214"N 151:34'03:740'M 0.54 T 19.09 0.53 -0.03 2203.13 62.62 13.86 12.88 63.46 5469.00 62.29 65.53 4091.38 3990.38 1015.51 2049.73 220938.08 2524082.14 60°5358.558"N 151°34'02.201' 0.97 -160.58 0.92 0.36 2286.89 64.78 14.02 13.20 63.54 5563.00 60.83 64.94 4136.15 4035.151 1050.13 2124.79 221013.95 2524114.94 60°5358.898"N 151°34'00.684' 1.65 -171.35 -1.55 -0.63 2369.54 66.92 14.18 13.54 63.60 5657.00 58.86 64.59 4183.36 4082.36 1084.78 2198.31 221088.28 2524147.81 60°53'S9.239"N 151°33'S9.197' 2.12 28.19 -2.10 -0.37 2450.82 69.01 14.34 13.88 63.64 5752.00 59.02 64.69 4232.38V4487.08 38 1119.64 2271.84 221162.63 2524180.88 60°53'59.583"N 151°33'57.711' 0.19 151.47 0.17 0.11 2532.20 71.10 14.52 14.23 63.68 5847.00 57.90 65.41 4282.0707 1153.79 2345.25 221236.84 2524213.26 60°53'59.919"N 151°33'56.226' 1.34 171.33 -1.18 0.76 2613.16 73.19 14.70 14.56 63.73 5942.00 57.02 65.57 4333.1717 1187.02 2418.12 221310.49 2524244.72 60°54'00.246"N 151°33'S4.753' 0.94 175.84 -0.93 0.17 2693.24 75.25 14.89 14.89 63.78 6035.00 56.79 65.59 4383.9595 1219.23 2489.06 221382.18 2524275.21 60°54'00.563"N 151°33'53.319' 0.25 -36.82 -0.25 0.02 2771.15 77.25 15.07 15.21 63.84 6135.00 57.88 64.63 4437.9292 1254.66 2565.42 221459.37 2524308.80 60°54'00.912"N 151°33'51.775' 1.36 167.76 1.09 -0.96 2855.33 79.42 15.27 15.56 63.88 6224.00 57.53 64.72 4485.4848 1286.84 2633.42 221628.13 2524339.33 60°54'01.228"N 151°33'50.400' 0.40 -151.57 -0.39 0.10 2930.56 81.36 15.46 15.87 6-391 6315.00 57.39 64.63 4534.4242 1319.66 2702.77 221598.24 2524370.47 60°54'01.551"N 151°33'48.998' 0.17 120.68 -0.15 -0.10 3007.27 83.33 15.64 16.19 63.93 6414.00 56.97 65.48 4588.0808 1354.74 2778.20 221674.50 2524403.73 60°54'01.897"N 151°33'47.473" 0.84 0.60 -0.42 0.86 3090.47 85.47 15.84 16.53 63.96 6507.00 57.78 65.49 4638.2222 1387.24 2849.46 221746.52 2524434.50 60°54'02.216"N 151°33'46.032' 0.87 -164.61 0.87 0.01 316879 8749 16.04 16.85 64.00 6604.00 56.30 65.00 4690.99.99 1421.32 2923.37 221821.23 2524466.79 60*54'02.552"N 151°33'44.538' 1.58 11.83 -1.53 -0.51 3250.18 89.58 16.25 17.20 64.04 6697.00 56.90 65.15 4742.19.19 1454.04 2993.78 221892.40 2524497.81 60°54'02.874"N 151-33-43.115" 0.66 26.53 0.65 0.16 3327.82 91.58 1 16.45 17.53 64.07 _ i.o39 vv a.oy m.zn 3.3L 1.8U 34V U 83.ti6 16.66 17.86 64.11 ""'� 6864.00 61,11 67.40 4827.23 4726.23 1511.21 3125.58 222025.54 2524551.78 60°54'03.437N 151°33'40.450' 1.59 0.00 1.49 0.63 3471.43 95.31 16.82 18.17 64.17 6950.00 61.11 67.40 4868.78 4767.78 1540.15 3195.10 222095.73 2524579.04 1 60°54'03 721"N 151 °3339 .44"W 0.00 1 0.00 1 0.00 1 0.00 1 3546.66 1 97.28 1 18 08 1 18.15 1 64.22 Page 2 of 2 Lease & Well No. County TD 6 950 00 Hilcorp Energy Company CASING & CEMENTING REPORT TBN A-1ORD State Alaska CASING RECORD Intermediate w Shoe Denth 5.818.on Date Run 17-Aug-19 Supv. Shane Hauck PBTD Casing (Or Liner) Detail Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top 1 Shoe 3.22 5,818.00 5,814.78 1 Casing 9 5/8 47.0 L-80 DWC/C 39.58 5,814.78 5,775.20 1 Float Collar L-80 1.39 5,775.20 5,773.81 1 Casing 9 5/8 47.0 L-80 DWC/C 40.15 5,773.81 5,733.66 1 Baffle 1.51 5,733.66 5,732.15 61 Casing + pup 9 5/8 47.0 L-80 DWC/C 2,411.16 5,732.15 3,320.99 1 ES Cmntr 2.95 3,320.99 3,318.04 84 1 Pup/Csg/Cut Jt 1 9 5/8 1 47.0 1 L-80 DWC/C 3,279.75 3,318.04 38.29 Centralizer Placement: 2 on it 1 &3. 1 on 2. 1 on 4-30. 1 on every other from 32 - 60. 1 on 61-66. 1 on every other 68 - 112. CEMENTING REPORT Shoe @ 5818 FC @ 5,775.20 Top of Liner Preflush (Spacer) Type: Clean Density (ppg) 10.5 Volume pumped (BBLs) Lead Slurry Type: 1/11 Sacks: 300 Yield: Density (ppg) 12 Volume pumped (BBLs) 125.3 Mixing / Pumping Rate (bpm): Tail Slurry w Type: Premium G Sacks: 450 Yield: rDensity (ppg) 15.8 Volume pumped (BBLs) 92.5 Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: LL Displacement: Type: OBM Density (ppg) 9.8 Rate (bpm): 400 Volume (actual / calculated): 22 FCP (psi): 700 Pump used for disp: Rig Bump Plug? X Yes No Bump press Casing Rotated? Yes X No Reciprocated? _Yes X No % Returns during job 34 Cement returns to surface? Yes X No Spacer returns?_ Yes X No Vol to Surf: 0 Cement In Place At: 20:27 Date: 8/18/2019 Estimated TOC: 0 Method Used To Determine TOC 41.2 2.35 4.5 1.15 3.5 2900 Stage Collar @ 3320.99 Type ES cementer Closure OK Preflush (Spacer) Type: Clean Density (ppg) 10.5 Volume pumped (BBLs) 36 Lead Slurry Type: 1/II Sacks: 630 Yield: 2.4 Density (ppg) 12 Volume pumped (BBLs) 267.8 Mixing / Pumping Rate (bpm): 5.5 Tail Slurry Type: Sacks: Yield: w Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): o Post Flush (Spacer) z o Type: Density (ppg) Rate (bpm): Volume: w N Displacement: Type: OBM Density (ppg) 9.8 Rate (bpm): 6.1 Volume (actual / calculated): 280/245 FCP (psi): 480 Pump used for disp: Rig #2 MP Bump Plug? Yes X No Bump press 0 Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job 36 Cement returns to surface? X Yes No Spacer returns? X Yes No Vol to Surf: 185 Cement In Place At: 23:20 Date: 8/19/2019 Estimated TOC: 0 Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: 185 Total Volume cmt Pumped: _ Cmt returned to surface: 60 Calculated cement left in wellbore: 210 OH volume Calculated: OH volume actual: Actual % Washout: www.wellez.net WellEz Information Management LLC 270 ver 04818br Lease & Well No. County TD 11, 782.00 Hilcorp Energy Company CASING & CEMENTING REPORT TBN A-1 ORD State Alaska CASING RECORD Liner IV Shoe Deoth: 11.754.00 Supv PBTD: Date Run 9-Sep-19 Harold Soule Casing (Or Liner) Detail Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top 1 Shoe 8 5/8 29.0 CDC 1.43 11,754.00 11,752.57 1 Pup 7 29.0 L-80 CDC 20.15 11,752.57 11,732.42 152 Liner 7 29.0 L-80 CDC HTQ 6,136.54 11,732.42 5,595.88 1 Pup 7 29.0 L-80 CDC HTQ 19.02 5,595.88 5,576.86 1 HPQC 7 3/4 5.45 5,576.86 5,571.41 1 LSS 7 8.69 5,571.41 5,562.72 1 Seals 2.75 5,562.72 5,559.97 1 SLZXP 32.36 5,559.97 5,527.61 Csg Wt. On Hook: 300 Type Float Collar: None Csg Wt. On Slips: Type of Shoe: Reamer Rotate Csg X Yes No Recip Csg Yes X No Fluid Description: OBM Liner hanger Info (Make/Model): BOT/SLZXP Liner hanger test pressure: 4100 Centralizer Placement: There is a floatina centralizer on every ioint 1 to 143 No. Hrs to Run: 84 Casing Crew: Weatherford Ft. Min. 10.8 PPG Liner top Packer?: X Yes No Floats Held Yes No CEMENTING REPORT Shoe @ 11754 FC @ Top of Liner 5528 Preflush (Spacer) Type: Mud push Density (ppg) 12 Volume pumped (BBLs) 10 Lead Slurry Type: cement Sacks: 63 Yield: 1.53 Density (ppg) 14 Volume pumped (BBLs) 17 Mixing / Pumping Rate (bpm): 2 Tail Slurry w Type: Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type. cement wiper Density (ppg) 12 Rate (bpm): 3 Volume: 10 LL Displacement: Type: OBM Density (ppg) 10.8 Rate (bpm): 4 Volume (actual / calculated): 126/126 FCP (psi): 1660 Pump used for disp: Rig Bump Plug? Yes X No Bump press _ Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: 0 Cement In Place At: 3:18 Date: 9/16/2019 Estimated TOC: 11,650 Method Used To Determine TOC: Strokes pumped Post Job Calculations: Calculated Cmt Vol @ 0% excess: 17 Total Volume cmt Pumped: _ Cmt returned to surface: 0 Calculated cement left in wellbore: 2.9 OH volume Calculated: 13.6 OH volume actual: 14.1 Actual % Washout: www.wellez.net WellEz Information Management LLC 17 ver 04818br ara—o�� Ifilmirp Ala4m. Lid. DATE 10/17/2019 To: AOGCC D e b r a O u d e a n Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com Meredith Guhl 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 to] �. ; EE WASHFD AND DRTFD V."J.t RECEIVED OCT 10 2019 A®GCC WELL TYPE BOX SAMPLE INTERVAL A -LORD WASHED AND DRIED BOX 1 OF 7 6060' - 7500' A -LORD WASHED AND DRIED BOX 2 OF 7 7500' - 9000' A -LORD WASHED AND DRIED BOX 3 OF 7 9000' - 10200' A -LORD WASHED AND DRIED BOX 4 OF 7 10200' - 11400' A -LORD WASHED AND DRIED BOX 5 OF 7 11400' - 13200' A -LORD WASHED AND DRIED BOX 6 OF 7 13200' - 14820 A -LORD WASHED AND DRIED BOX 7 OF 7 14820' - 16212' A-10RD PB1 WASHED AND DRIED BOX 1 OF 4 990, - 2400' A -LORD PB1 WASHED AND DRIED BOX 2 OF 4 2400' - 4200' A -LORD PB1 WASHED AND DRIED BOX 3 OF 4 4200' - 6000' A -LORD PB1 WASHED AND DRIED BOX 4 OF 4 6000' - 6950' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: ( 0 l ( -7 /l I THE STATE 'ALASKA GOVERNOR MIKE DUNLEAVY 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 Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 VkI r� Re: Trading Bay Field, Tyonek G and Hemlock Prospect Pool, A-IORD Permit to Drill Number: 219-076 Sundry Number: 319-456 Dear Mr. Myers: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Jer y ice Chair DATED this U day of October, 2019. ABDMS I� OCT 14 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑J 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: Hilcorp Alaska, LLC Exploratory Q Development ❑ Stratigraphic ❑ Service ❑ 219-076 ' 3. Address: 6. API Number: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20064-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑✓ A-10RD 9. Property Designation (Lease Number): 10. Field/Pool(s): 5 (v ` Al 1� 6>w 751 Tyonek G / Hemlock Prospect ADLO18731 !f�LC� . 11. w . •% y PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 16,212' 10,375' 14,324' (TOC on 10/6) 8,927' 3768 14,324' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 264' 20" 264' 264' Surface 1,095' 13-3/8" 1,095' 1,068' 3090 psi 1540 psi Intermediate 5,818' 9-5/8" 5,818' 4,267' 6870 psi 4750 psi Production 6,226' 7" 11,754' 11,750' 8160 psi 7020 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 2-7/8" L-80 15,215' Packers and SSSV Type: N/A Packers and SSSV MD (ft) and TVD (ft): N/A 12. Attachments: Proposal Summary Q Wellbore schematic Q 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: 10/4/2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑� ' GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Yes Date: 10/4/2019 Commission Representative: Guy Schwartz GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Monty Myers Contact Name: Monty Myers Authorized Title: Drilling Manager Contact Email: I7 m erS hilcor .corn Contact Phone: 777-8431 Authorized Signat Date: d —7, 9 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representa ive may witness Sundry Number: l0 Plug Integrity E;�/ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other. /► 1BDMS _4P`^'OCT 14 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: �2APPROVED BY Approved by: + COMMISSIONER THE COMMISSION Date: 1 "' U v l 1 ® L �L/ S> Jf✓ Submit Form and Form 10-403 Revised 4/20 Approved ap li aRIGLNALomthe� 5Ateof approval. Attachments in Duplicate 0 Ililcorp Alaska, ILL, Well Prognosis Well: A-10RD Date: 10/7/19 Well Name: A-10RD API Number: 50-733-20064-01-00 Current Status: Running CIBP Leg: N/A Estimated Start Date: October 4th, 2019 Rig: Monopod Rig 56 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Cody Dinger 777-8389 Permit to Drill Number: 219-076 First Call Engineer: Monty Myers (907) 777-8431 (0) (907) 538-1168 (M) AFE Number: Brief Well Summary —We have successfully drilled the A-10RD exploration well to a TD of 16,212' TMD. Unfortunately, we encountered wet sand in the Hemlock and the production hole needs to be abandoned. We do have future utility for the well out of the 7" liner set at 11,754' TMD, so I would like to propose the following temporary abandonment procedure. Notes Regarding Wellbore Condition — • Top of Tyonek G—15,857' TMD • Top of Hemlock— 16,060'TMD • TD of well with 6-1/8" hole—16,212' Rig 56 Procedure — Work performed: • Pick up 30 joints (-1000') of 2-7/8" sacrificial tubing with 5 centralizers spaced out every 6 joints, crossed over to a BHK disconnect. • Run in the hole to TD of 16,212' and circulate bottoms up • Mix and pump 30 bbls of 12ppg spacer, followed by 44.5 bbls of 13ppg cement, drop BHK dart chased by 5 bbls of fresh water. • Release from BHK disconnect. Top at 15,215' TMD. Pull up hole to the shoe and wait on cement. Circulate hole clean. • RIH and tag TOC (notice must be made to AOGCC for opportunity to witness) • Cement was tagged a 14,324' TMD on 10.5.2019 _ Work to be performed: • PU 7" CIBP and RIH to—11,735' and set CIBP. • After setting CIBP, set down 10 klbs to confirm CIBP is set. • Pressure test casing to 2500psi on chart for 30 mins • Displace well to FIW with corrosion inhibitor and POOH. • PU 500' of 2-7/8" tubing as a kill string • Land hanger in wellhead. • ND BOPE and NU tree and test. Attachments 1. Actual Schematic Hilcoro Alaska. UC KB to MSL =101' MSL to Mudline = 66' t 20" j 13-3/6- 9-s/8" r 2 CA 3P T. 4 G Zone "4 1 Heliack Yt' eft , d! 61JS" hole PBTD:14,324' TD:16,212' =• 0 • CASING DETAIL Trading Bay Unit Well: A -LORD Last Completed: Future PTD:219-076 API: 50-733-20064-01 Size Wt Grade Conn ID Top Btm 20" Conductor Pile Surface —264' 13-3/8" 61 K-55 BTC 12.515" Surface 1,095' 9-5/8" 47 L-80 DWC/C 8.681" Surface 5,818' 7" 29 L-80 CDC HTQ 6.184" 5,528' 11,754' TUBING DETAIL 2-7/8" 6.5 P-110 8 round EUE 2.441" Surface ±500' 2-7/8" 6.5 P-110 8 round EUE 2.441" 15,215' 16,212' Cti'-aw� JEWELRY DETAIL No Depth (MD) Depth (TVD) Item 1 ±37' ±37' Hanger 2 ±11,735' 7,338 7" CIBP 3 15,215' 9,601' 3-1/2" BHK Disconnect sub 4 15,218' 9,603' 2-7/8" 6.4# L-80 tubing string 5 14,324' 9,563' TOC plug Depth (MD) Depth (TVD) ID OD Item 15,857' ±9,563' Top Tyonek G 16,060' ±10,212' Top of Hemlock Updated By: OD 10/07/19 Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Friday, October 4, 2019 1:42 PM To: Mack Myers; Rixse, Melvin G (CED); Davies, Stephen F (CED) Cc: Cody Dinger; Dan Marlowe Subject: RE: [EXTERNAL] RE: PTD# 219-076 (A-1 ORD Abandonment plan) Monty, You have verbal approval to P & A well as proposed with the following stipulations: 1) Reservoir isolation cement top must be tagged with drillpipe after leaving sacrificial string in wellbore. TOC must beat least 50'above release tool. Notify AOGCC inspectors to witness tag. 2) Standoff centralizers to be used on sacrificial cement string to ensure adequate zonal isolation. 3) After setting CIBP in 7" casing the wellbore casing must be tested to 2500 psi and charted for 30 min. (cement cap on CIBP is waived in order to facilitate whipstock for future sidetrack) Submit 10-403 sundry as soon as possible with the details (request to suspend well). Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.aov). From: Mack Myers <mmyers@hilcorp.com> Sent: Friday, October 4, 2019 11:54 AM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: Cody Dinger <cdinger@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: RE: [EXTERNAL] RE: PTD# 219-076 (A-10RD Abandonment plan) Thanks for the information Guy. Please see the attached log and the updated schematic of what the well will look like. We will submit a 10-407 for the work next week. Please let me know if this is sufficient or if you need anything else. If I can impose confidentiality on this email and the log it would be appreciated. Thank you! Monty M Myers Drilling Manager 907.538.1168 (c) 907.777.8431 (o) From: Schwartz, Guy L (CED)[mailto:guy.schwartz@alaska.gov] Sent: Friday, October 4, 2019 10:10 AM To: Mack Myers <mmyers@hilcorp.com>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: Cody Dinger <cdinger@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: [EXTERNAL] RE: PTD# 219-076 (A-10RD Abandonment plan) Monty, Can you send us the LWD logs? I'll get back to you on the below request as soon as we review.... The well would also be considered suspended after P &A' ing the lower section. A Sundry will be required for the proposed plugging work but we can give you verbal approval pending review of the logs. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Mack Myers <mmyers@hilcorp.com> Sent: Friday, October 4, 2019 9:22 AM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Cc: Cody Dinger <cdinger@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: PTD# 219-076 (A-10RD Abandonment plan) Guy, We have successfully drilled the A-10RD exploration well to a TD of 16,212' TMD. Unfortunately, we encountered wet sand in the Hemlock and the production hole needs to be abandoned. We do have future utility for the well out of the 7" liner set at 11,754' TMD, so I would like to propose the following temporary abandonment procedure. Top of Tyonek G — 15,857'TMD Top of Hemlock—16,060' TMD TD of well with 6-1/8" hole—16,212' • Pick up 1000' of 2-7/8" sacrificial tubing, crossed over to a BHK disconnect. • Run in the hole to TD of 16,212' and circulate bottoms up • Mix and pump 30 bbls of 12ppg spacer, followed by 44.5 bbls of 13ppg cement, drop BHK dart chased by 5 bbls of fresh water. • Release from BHK disconnect. Pull up hole to the shoe at 11,754'. Circulate hole clean. • PU 7" CIBP and RIH to 11,735' and set CIBP. • After setting CIBP, set down 10 Ibs to confirm CIBP is set. • Displace well to FIW with corrosion inhibitor and POOH. • PU 500' of 2-7/8" tubing as a kill string • Land hanger in wellhead. • ND BOPE and NU tree and test. This gives us enough cement to cover the uppermost hydrocarbon bearing zone by 645' and is in accordance with 20AAC 25.112(a)(1)(B). Please let me know if you have any questions or concerns with this plan, as we would like to move this direction beginning later this afternoon on 10.04.2019. Thank you! Monty M Myers Drilling Manager 907.538.1168 (c) 907.777.8431 (o) The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. /C 4 I H Hilcorp Alaska. LLC KBtoMSL=101' MSLtoMudline=66 PBTD: ±] 5,162' 1D: 16, 2 1.2' Trading Bay Unit 'ell: A -LORD PROPOSED Last Completed: Future PTD: 219-076 API: 50-733-20064-01 CASING DETAIL Size Wt Grade Conn ID Top Btm 20" Conductor Pile Surface —264' 13-3/8" 61 K-55 BTC 12.515" Surface 1,095' 9-5/8" 47 L-80 DWC/C 8.681" Surface 5,818' 7" 29 L-80 CDC HTQ 6.184" 5,527' ±11,754' TUBING DETAIL 65 P-110 8round EUE 2.441" S,Orfa,-e S00' 6S P-110 8 round EUE 2.441" 1.5,2' ±' ei.212' JEWELRY DETAIL Depth (MD) Depth (TVD) ID OD Item ±37' ±37' Hanger ±11,735' 7,338 7" CIBP ±15,210' 9,601' 3-1/2" BHK Disconnect sub ±15,212' 9,603' 2-7/8" 6.5# P-110 Sacrificial tubing string ±15,160' 9,563' TOC plug C 4 4, Z S0J es /-:�i) i-" ti )epth (MD) Depth (TVD) ID OD Item 5,857' ±9,563' 6,060 10,212' op oI He��loc'r: Updated By:1LL09/11/19 Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Wednesday, September 18, 2019 1:35 PM To: Mack Myers; Rixse, Melvin G (CED) Cc: Cody Dinger Subject: RE: [EXTERNAL] RE: PTD #219-076 (7" liner primary cement squeeze) Thanks Monty, FIT data looks good. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guv.schwartz@alaska.gov). From: Mack Myers <mmyers@hilcorp.com> Sent: Wednesday, September 18, 201910:04 AM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Cc: Cody Dinger <cdinger@hilcorp.com> Subject: RE: [EXTERNAL] RE: PTD #219-076 (7" liner primary cement squeeze) Guy, Please see the attached FIT data for the A-10RD. We drilled the shoe out this morning and found some hard cement. The FIT was good to 13.Oppg. Monty M Myers Drilling Manager 907.538.1168 (c) 907.777.8431 (o) From: Schwartz, Guy L (CED) fmailto:guy.schwartz@alaska.gov] Sent: Tuesday, September 17, 2019 2:35 PM To: Mack Myers <mmyers@hilcorp.com>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Cc: Cody Dinger <cdinger@hilcorp.com> Subject: [EXTERNAL] RE: PTD #219-076 (7" liner primary cement squeeze) Monty, Thanks for update... glad you got the fish out. Please send me the FIT info when you get it. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv.schwartz@alaska.aov). From: Mack Myers <mmyers@hilcorp.com> Sent: Monday, September 16, 2019 2:02 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Cc: Cody Dinger <cdinger@hilcorp.com> Subject: PTD #219-076 (7" liner primary cement squeeze) Guy, In reference to our phone discussion last week talking about the inability to circulate on the 7" liner. We successfully reamed the liner all the way to TD then had to secondary release off of the liner because we were unable to drill down the 30' required to perform the primary release mechanism from the Two Trip Drilling Liner system (TTDL). When we performed the secondary release we, also backed off our drill string 7 joints below the 7" liner top, leaving 6000+ feet of drill pipe inside the liner and a motor and bit sticking out the bottom of the liner. Since we were packed off somewhere in the liner there was concern that we could pull the liner up the hole if it wasn't anchored. We made the decision to go ahead and run the ZXP liner hanger/packer to anchor the liner prior to attempting to fish the drill string. After the hanger/packer was set and tested we were able to screw back into the fish and pull it to surface with 100% recovery. The cause off the back off was an under torqued connection we found. After the fish was recovered we ran in with our cement retainer as per normal operations. We set the retainer at 11,700'-11,702' TMD and squeezed 17 bbls of 14ppg class G cement. The shoe is at 11,782'. This would leave 3 bbls of cement inside the shoe, and 697' of cement in the annulus between the 7" liner and the 8-1/2" hole if it all went up the hole. The job went as planned. We increased our density to 14 ppg because this density is compatible with the additive and the tests we had run on the slurry. The original planned density for this liner was 13 ppg. We will now, go into drilling our 6-1/8" contingency hole size for our production section and run a 5" flush joint liner and cement it, when we find the pay zone. Please let me know if you have any questions about our operations. Thank you! Monty M Myers Drilling Manager 907.538.1168 (c) 907.777.8431 (o) The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. THE STATE GOVERNOR MIKE DUNLEAVY Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 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 Re: Trading Bay Field, Tyonek G/ Hemlock Prospect Pool, Trading Bay St. A-1 ORD Permit to Drill Number: 219-076 Sundry Number: 319-396 Dear Mr. Myers: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 5- day of September, 2019. RBDMSEP 0 51pig STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 I 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑J 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: Hilcorp Alaska, LLC Exploratory P1, Development ❑ Stratigraphic ❑ Service ❑ 219-076 3. Address: 6. API Number: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20064-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A --�'�j' yr. Will planned perforations require a spacing exception? Yes ❑ No ❑J A-10RD 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL018731 /f /?(�_ i� j Tyonek G / Hemlock Prospect 11. /I� -, , j PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7,715' 5,251' 7.715' 5,251' 3768 Casing Length Size MD TVD Burst Collapse Structural Conductor 264' 20" 264' 264' Surface 1,095, 13-3/8" 1,095' 1,068' 3090 psi 1540 psi Intermediate 5,818' 9-5/81, 5,818' 4.267' 6870 psi 4750 psi Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: N/A Packers and SSSV MD (ft) and TVD (ft): N/A 12. Attachments: Proposal Summary Q Wellbore schematic Q 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: 8/9/2019 OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Yes Date: 8/9/2019 Commission Representative: Guy Schwartz GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Monty Myers Contact Name: Monty Myers Authorized Title: Drilling Manager Contact Email: rmm erS hIIcor .com Contact Phone: 777-8431 Authorized Signature: — Date: 2g COMMISSION USE ONLY Conditions of approval: Notify Commission so that a represe ay witness Sundry Number: !"/1► Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other. yJf �aC "L'A'- 5 "flo t"J, l /� e k- �t Y c� ° : °Z �� '----�BDIMS 0 .(��'SF.P j / 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ e , Spacing Exception Required? Yes ❑ No d Subsequent Form Required: V `DD APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: y F� rn Tti 403 Re ised�4 2 17 Appro d appli at s�ii fa2��j�sk the date of approval I ' Submit Form and Attachments in Duplicate /a lh 3D . K Hileorp Alaska, LL, Well Prognosis Well: A-10RD Date: 8/23/19 Well Name: A-10RD API Number: 50-733-20064-01-00 Current Status: Cased/Cemented Leg: N/A Estimated Start Date: August 9th, 2019 Rig: Monopod Rig 56 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Cody Dinger 777-8389 Permit to Drill Number: 219-076 First Call Engineer: Monty Myers (907) 777-8431 (0) (907) 538-1168 (M) AFE Number: Brief Well Summary — While drilling 12-1/4" hole we encountered some difficulty keeping the hole clean due to coals sloughing. Decision was made to call TD short at 6,950'. We rigged up and ran 9-5/8" in the well and ended up hanging up 9-5/8" casing at 5,833'. We went ahead and pumped our 2-stage cement job as per plan and lost circulation on the Vt stage. We opened the ES cementer and pumped the 2"d stage with full returns, and good cement to surface, but was unable to bump the plug after pumping 40 bbls over calculated displacement. We closed the valves on the cement head and waited for cement to set. Upon investigation of the cement head, we found that the plug launched but cocked sideways and then hung up in a profile in the head. After cutting casing off and setting slips we established injectivity through the ES cementer at % bbl per min and 520 psi to confirm it was clear of cement. We then ran in hole to the ES cementer and shifted it closed with the bit. After shifting the tool we pressure tested the casing above the ES cementer to 1100 psi. The casing tested good so we drilled out the ES cementer. After drilling out the ES cementer, we ran to bottom and tested the casing again to 3300 psi for 30 mins. Notes Regarding Wellbore Condition —The wellbore inclination is a 60 degree slant well through several coal packages. With the sloughing coals we have seen that increased MW at this inclination is very helpful. We had planned to use a 9.5 ppg OBM but are currently running a 10.6 ppg OBM with improved hole conditions. The directional plan will not deviate from what was permitted. Rig 56 Procedure —With the reduction in the length of the cased hole we have on surface, we will have to set our 7" liner short of our planned TD as well and revert to running a 5" flush joint liner for our final production string. We will drill our 8-1/2" hole to 12,000' TMD to isolate some additional coals and the fault that we will cross. Planned TD was 16,002'. The footage will not change for the 7" liner so the cement volumes will not change. However, an additional FIT test to 13.5 ppg equivalent will be performed at 12,000'. A 6-1/8" hole will be drilled from 12,000' to 16,000' and a 5" 18# P-110 liner will be run and cemented with 49 bbls of 15.8 ppg class G cement. Attachments 1. Actual Schematic 2. Proposed Schematic Ililcorp Alaska, LLC KBtoMSL=101' MSLtoMudline=66' 20" ES Cmntr @ 3,318' MD Current TD: 7,715' MD Current Schematic CASING DETAIL Trading Bay Unit Well: A-10RD Last Completed: Future PTD:219-076 API: 50-733-20064-01 Size Wt made I Conn ID Top Btrn 2U" Conductor Pile Surface -264' 13-3/8" 61 K-55 BTC 12.515" Surface 11095, 9-5/8" 47 L-80 DWC/C 8.681" Surface 5,818' Updated By: CJD 08/22/19 Hilcorp Alaska, LLC KB to MSL =101' MSL to Mudline = 66' PBTD: ±15,906' TD: ±16,002' PROPOSED CASING DETAIL Trading Bay Unit Well: A-10RD Last Completed: Future PTD: 219-076 API: 50-733-20064-01 Size Wt Grade Conn ID Top Btm 20" Conductor Pile Surface -264' 13-3/8" 61 K-55 BTC 12.515" Surface 1,095' 9-5/8" 47 L-80 DWC/C 8.681" Surface 5,818' 7" 29 L-80 CDC HTQ 6.059" ±5,618' +12,000 5" 18 P-110 Hydril511 4.276" ±11,800 ±16,000' TUBING DETAIL 2-7/8" 6.5 P-110 8 round EUE 2.441" Surface ±13,050' 2-3/8" 4.6 L-80 8 round EUE 1.995" ±13,050' ±15,450' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item ±37' ±37' Hanger 1 ±350' ±350' 2.313" SSSV ±2,057' ±2,000' 2.441 3.500 GLM #1 ±3,368' ±3,000' 2.441 3.500 GLM #2 ±4,303' ±3,500' 2.441 3.500 GLM #3 ±5,238' ±4,000' 2.441 3.500 GLM #4 ±6,173' ±4,500' 2.441 3.500 GLM #5 ±7,108' ±5,000' 2.441 3.500 GLM #6 2 ±8,043' ±5,500' 2.441 3.500 GLM #7 ±8,978' ±6,000' 2.441 3.500 GLM #8 ±9,913' ±6,500' 2.441 3.500 GLM #9 ±10,848' ±7,000' 2.441 3.500 GLM #10 ±11,783' ±7,500' 2.441 3.500 GLM #11 ±12,717' ±8,000' 2.441 3.500 GLM #12 3 ±13,050' ±8,178' 2.441 3.500 X-Over ±13,652' ±8,500' 2.441 3.500 GLM #13 4 ±14,417' ±9,000' 2.441 3.500 GLM #14 ±14,996' ±9,443' 2.441 3.500 GLM #15 5 ±15,024' ±9,465' 1.975" 3.669" Halliburton ROC Gauge Mandrel w/ 0.25" TEC wire 6 ±15,075' ±9,504' Packer 7 ±15,100' ±9,523' 1.875" X-Nipple 8 ±15,425' ±9,772' Sliding Sleeve 9 ±15,435' ±9,780' Packer 10 ±15,445' ±9,787' 1.791" XN-Nipple 11 ±15,450' ±9,791' WLEG PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) (TVD)Btm FT Date Status G ±15,258' ±15,430' ±9,644' ±9,776' ±172' Future Proposed H ±15,440' ±16,000' ±9,783' ±10,212' ±560' Future Proposed - e7' '�� Updated By:CJD 08/28/19 Schwartz, Guy L (CED) From: Paul Mazzolini <pmazzolini@hilcorp.com> Sent: Friday, August 9, 2019 2:51 PM To: Schwartz, Guy L (CED) Cc: Mack Myers; Cody Dinger Subject: Monopod A 10rd, PTD 219-076 Guy, As discussed with you this morning Hilcorp Alaska notified the AOGCC that the 9 5/8" intermediate casing would be set at a s.�er depth 6929'MD/4858'TVD vs permitted setting depth of 9805'MD/ 6326'TVD due to deteriorating hole conditions based upon the casing shoe being in a competent formation and that adequate FIT (13.5 ppg EMW) can be obtained to meet permit requirements. At this time BOPE are being tested and then a dumb iron clean out BHA will be picked up and hole cleaned out to TD to make sure no junk from the last bit run (3 cones) will hamper the running of 9 5/8" casing to TD. The intermediate hole section present TD at 6929' MD is in the Middle Kenai C Zone and made up of tuffaceous claystone and siltstone which will be a very competent shoe. It is still anticipated that the production hole section will be drilled with a 9.5 ppg OBM mud. Calculations for the FIT and Kick Tolerance are as follows: - FIT to 13.5 ppg EMW: (13.5 — 9.5)*0.052*4858' TVD = 1010 psi - Kick Tolerance : (13.5 — 9.5)*(4858' / 10,187') = 1.9 ppg Additional engineering will be needed for the cement job but with the reduced column of cement required for the shorter intermediate casing a single stage cement job would be utilized. Let me know if you would like to discuss, 777-8369. Regards Paul The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number FWell Permit Number Start Date End Date A-10RD Rig 56 50-733-20064-01-00 219-076 7/17/2019 Future Daily Operations: 8/21/19 - Wednesday Continue open ram doors and clean out cavities. finish change top pipe rams to variables found mud seal on DS door of single gate sticking out mech. re -seated same and functioned piston (ok) Reinstall koomey lines r/dn bail extension and cleaning of pill pits assist welder in cutting csg stub and retrieval of closing plug build 5" test jt. R/up test equipment. Sparrow Crane inspector Inspected both cranes. Re move fittings from csg spool and dress tbg spool. Fill stack w/ water purge air and shell test ok chg chart. work boat bring on 100 jts 5" dp Repair CMV #5. Test BOPE on 5" witness by AOGCC inspector Mr. Guy Cook. w/ no test failures but Test #6 had connection leak on XO to TDS had to chg out and retest ok Pull test joint to rig floor. Perform injectivity test. Pumped a total of 7 bbls at .5 BPM and able to inject at 520 psi. Bled back 2.5 bbls. Consulted with engineer and decision made to proceed with picking up drilling assembly. Break down test joint. Set empty spool on rotary table. Remove line guide rubbers. Hang blocks. Rig up to slip on new drill line. Hold PJSM. Install drill line snakes. Spool new line through derrick without issue. Unspool drill line off of drawworks onto spool in rotary table. String new drill line into drum. Unhang blocks. Clear rig floor. 8/22/19 - Thursday Remove hanging line and set and test crown -o- madic remove drill line spool of old line from rotary off rig floor. Service rig. Adjust torque tube to center TDS over hole. mech and mtr man work on CMV #5 (pressure locked) clean out DS pipe rack drain start strap dp P/up rabbit same. Continue p/up rabbit and strap 5" 5-135 19.50# XT50 dp and rih 30 jts while derrick man Dress out DS board continue house keeping and rig organization work boat Pooh and test rack dp on DS east pipe rack Strap pipe on deck and prep p/up BHA # 5. Pick up BHA #5 as per DD's and 1�" t. stand of drill pipe. Removed joint of bent HWDP and replaced. Laid down jars and replaced with new 61/2" jars. Clean up and reorganize vac hoses. Clean and organize choke manifold area. Change out regulator on rig air multiplier. RIH with BHA #5 picking up 5" S-135 19.50# XT50 drill pipe to 1755'. Shallow hole test MWD at 1500' (good). Continue RIH picking up DP from 1755' to 3270'. Tag ESC at 3319'. P/U 120, S/0 90. Set down 22K to 3324'. Shut in and pressure up to 750 psi with bleed off. Open bag. Set down 60 K and repeat with bleed off. Set down while circulating at 2 BPM and slight rotation. Saw indication of tool shift. Pressure uo to 1000 psi with annular shut and hold for 5 minutes. Bleed off/open annular. P/U 3' and repeat pressure test to 1100 psi for 10 minutes (good test). Bleed off pressure/open annular. Establish parameters: P/U 120, S/0 90, Rot 105. 335 GPM/950 psi. Drill ESC from 3323' to 3329' with 6 K WOB/9 K torque. 8/23/19 - Friday Wash and ream from 3329' to 3470' to get past cmt stringers. Rih on elevators f/ 3470' t/ 4429' up/dn 130/90k. Circ and warm mud and stage up pump rate and rpm f/ 575 gpm @ 2700 psi and 120 rpm w/ 7k torque & circ clean (getting back a lot cmt ) 3X btm/up and work full std f/ 4429' t/ 4515'. Rih on elevators f/ 4515' S640' Kelly up. wash and ream f/ 5640' t/ 5744' @ 525 gpm @ 2500 psi @ 120 rpm w/ 10k tq (work crew over c w chg late do to weather). Lost tds HPU trouble shoot same. Continue wash and ream f/5744' t/ 5755'. Rack back 2 std and r/up to test csg geand Test t/ 3299 psi >3166 psi in 30 min on chart r/dn test equipment wash in hole f/ 5658' t/ tag @ 5755'. drill cmt and plugs f/ 5755' t/ top of float collar @ 5773' (lost MP #2 chg out bleeder valve?) continue w/ #1 mp @ 442 gpm @ 1800 psi @ 122 rpm @ 13-22k drill float collar and solid cmt t/ top shoe @ 5814' #2 MP back on line 579 gpm @ 2855b psi @ 100-125 @ 15-21k. Work full stand and circulate clean f/ 5814' while changing out CMV #5. Test same 250 L/4000 H. Drill float shoe from 5814' to 5818'. P/U 160, S/O 100, Rot 120/17 torque. 550 GPM/2650 psi. Wash and ream with above parameters from 5818' to 5856'. +-10' of hard cement below shoe. Work stuck pipe at 5856'. Had total pack -off and no rotation. Work pipe utilizing jars and pump with slack off to 90 K and staging jars up from 225 K to 300 K before working string free. Regain rotation and circulation. Pull up to 5850'. Set stand back and pick up working single. Circulate and work pipe from 5800' to 5845' at full drilling rate. Hole continuing to unload quarter size pieces of coal. Wash and ream area from 5840' to 5877' experiencing pack -offs but able to pull up out of it. Hole continuing to unload cuttings while working pipe (>40 bbls). 550 GPM/2560 psi. Continue working pipe from 5800' to 5877' cleaning hole and weighting up to 10.2 ppg. i� Hilcorp Alaska, LLC Hilt m-11,ln.ka_LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-10RD Rig 56 50-733-20064-01-00 219-076 7/17/2019 Future 8/24/19 - Saturday Continue working pipe from 5800' to 5878' cleaning hole and weighting up to 10.2 ppg. (Coal cutting load has diminished and slight pack -off has disappeared ). Rack back std w/ working single w/ bit in casing @ 5780'. Perform post jarring inspection of derrick and TDS. Service rig while continuing t/ circulate and weight up to 10.4+ ppg. Circulate at 550 GPM/2500 psi while bringing mud weight up to 10.4 ppg. Wash and ream in hole f/ 5780' to 5973' @ 550 GPM/2500 psi. 125 RPM w/ torque swings f10 t/20 K. Wash and ream in hole 5973' to 6067' @ 550 GPM/2500 psi. 150 RPM/ 12 K. Surveys show us to be 4 degrees above old hole with azimuth unchanged. Drill from 6067' to 6103' (72' FPH/ ROP). Consult with engineer and decision made to stop here as this is'new' hole. Circulate clean up cycle and pump Barolift sweep while working stand. Sweep came back on time with 25% increase in cuttings. Continue circulating until shakers cleaned up. 10.4 ppg in/out. BROOH at full drilling rate from 6103' to 5814' without issue. Hole began unloading quarter size chunks of coal. Worked back through 5850' to 5860' area at 150 RPM/12 K torque, 500 GPM/ 2560 psi until shakers cleaned up. High gas of 460 units. RIH in elevators to 6103'. Had 40 K set down at 5890' and washed and reamed through area until clean. POOH on elevators into shoe at 5816'. Circulate and condition until mud was 10.4 ppg in and out. Perform FIT to 13.7 ppg EMW. Pump dry job. POOH with BHA#5. 8/25/19 - Sunday POOH with BHA #5. f/ 5800' t/ 4906'. Notice leak on flow nipple. Continue pulling 5 std t/ lower fluid level in flow nipple for air boot change out. Change out air boot. Attempt POOH. Having air issues on clutch. Install oiler on air booster. Resume POOH to BHA. Had mech look at brakes due to vibration. Adjust spring tension on brake band. Lay down BHA #5. Bit grade: 1,1,WT,AII, 1/16",BHA. Top stab had some chunking out damage and 1/16" out w/ heat checking. Bottom stab good. Calculated 58.1 bbls, actual = 62.6 bbls diff = 4.5 bbls. Clear clean rig floor. Pull flow nipple. Check and install back up air boot rubbers. Clear rig floor of BHA #5 components and prep to pick up BHA #6. Pick up BHA #6 drilling assembly as per DD/MWD's. RIH with BHA #6 to 630'. Stage NPR's on rig floor. RIH to 2142' and shallow hole test. POOH with 15 stands installing NRP's and standing back. Service rig. Change dies in ST-80. RIH with BHA #6 to 5750' filling pipe and warming mud at 2650' and 5750'. Warm mud and obtain SPR's before going into open hole. Wash and ream at full drilling rate from 5818' to 5895'. P/U 123, S/01205, 122 Rot, 125 RPM, 16 K torque, 8/26/19 - Monday Wash and ream at full drilling rate from 5895' to 6103'. P/U 123, S/01205, 122 Rot, 125 RPM, 16 K torque, 500 GPM/2200 psi. tag btm and down link w/ trip gas of 201 units. Drill 8-1/2" dir. hole w/ auto trak f/ 6103' t/ 6328' P/U 185, S/0 95k , 125 Rot, 195 RPM, 11-12K torque, 550 GPM/2500 psi, WOB 15-20k, MW in out @10.5 ppg, ECD @ 12.1 ppg, pump 35 bbl Barolift sweep every other std while drilling #1 @ 6240' Back on time w/ 50% w/ BBG 35 units. Continue drilling 8-1/2" dir hole w/ auto trak F/ 6328' t/6538" P/U 190, S/0 98k , 130 Rot, 180 RPM, 12K torque, 550 GPM/2500 psi, WOB 15-20k, MW in out @10.5 ppg, ECD @ 12.1 ppg, pump 35 bbl Barolift sweep every other std while drilling #2 @ 6428' Back on time w/ 25% max gas 472 units. Mud loggers seeing log from old hole not lining up w/ new hole count pipe chk pipe tally (found tally to be off a single) Circulate and rotate and reciprocate for clean up cycle while MWD Recalibrate tools. Directional drill 8 %" hole from 6506' t/6627'. P/U 195, S/0 98, 133 Rot, 190 RPM, 11-13 K torque, 10-15 K WOB, 550 GPM/2400 psi. 80.7 ROP avg. Pumped sweep at 6580' coming back on time with 20% increase. Max gas 75 units. Directional drill 8 %" hole from 6627' t/6875'. P/U 200, S/0 98, 133 Rot, 200 RPM, 11-13 K torque, 15 20 K WOB, 550 GPM/2450 psi. 41.3 ROP avg. Pumped sweep at 6772' coming back on time with 15% increase. Max gas 295 units. Directional drill 8 %" hole from 6875' t/7150'. P/U 200, S/0 98, 133 Rot, 200 RPM, 11-13 K torque, 15-20 K WOB, 550 GPM/2450 psi. 68.8 ROP avg. Pumped sweep at 7100'. Max gas 295 units. Sweep came back on time with 25% increase in cuttings. Continue to work full stand at full drilling rate to clean hole. BROOH at full drilling rate from 7150' to 6960'. 8/27/19-Tuesday BROOH at full drilling rate from 6960' to shoe shakers loaded the whole way. Rotate and reciprocate work full stand unload csg. Service rig and chg/out 1500 amp brk for SCR#3, production change out back pressure valve for source water. POOH f/5827', t/4599', installing NRP's, up wt 157k, do wt 103k. TIH on elevators f/4599', t/7056', up wt 190k, do wt 95k, wash & ream last stand down t/7150', no fill pump 550 gpm, 2450psi. Directional drill 8 %" hole from 7150' t/7400'. P/U 220, S/0 98, 136 Rot, 200 RPM, 11-13 K torque, 15-20 K WOB, 550 GPM/2500 psi. 50.0 ROP avg. Pumped sweep at 7340' coming back on time with 30% increase. Max gas 350 units. Directional drill 8 %" hole from 7400' t/7715'. RJU 22f)_ S/0 98, 136 Rot, 200 RPM, 11-13 K torque, 15-20 K WOB, 550 GPM/2500 psi. 63.0 ROP avg. Pumped sweep at 7523' coming back on time with 30% increase. Max gas 215 units. Noticed loose NRP on stand #75 while back reaming. Investigated that it had come loose from previous stand due to keeper pin not being installed properly. Replace both NRP's on top joint of stand #74. Wash pipe packing failed concurrently. Change out same. Hilcorp Alaska, LLC Ifilc,,rpAla-ka.LIA: Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-10RD Rig 56 50-733-20064-01-00 219-076 7/17/2019 Future Daily Operations: 8/28/19 - Wednesday Change out wash pipe packing. Directional drill 8 Y2" hole from 7716' t/7905'. P/U 220, S/0 98, 136 Rot, 200 RPM, 11- 13 K torque, 15-20 K WOB, 550 GPM/2500 psi. 54 ROP avg. Pumped sweep at 7716' coming back on time with 20% increase. Max gas 336 units. Pump sweep, @ 550 gpm, 2600psi, back on time with 10% increase, cont CBU x2. BROOH f/7905' t/6390', 600gpm, 2600psi, rot wt 133k, 150rpm, tq. 11-13k, up wt 200k, do wt 95k. Increase of cuttings coming back, CBU @ 600 GPM, 2500psi, rot & reciprocate until cleaned up. BROOH from 6390' into shoe at 5814'. 600 GPM/ 2400 psi, 150RPM/13 K torque, P/U 200 K, S/0 95 K, Hole unloading on each stand pulled. Pack -off and torque issues pulling into shoe. Work through several times until cleaned up. 195 units gas at bottoms up. Circulate and work pipe inside shoe until shakers cleaned up. 600 GPM/2380 psi. 150 RPM/13 K torque. Blow down top drive. Drain stack. Make up test joint. Change out choke manifold valve #3. Had difficulty draining stack due to annulus valve plugging off. Hang off string. Fill stack with water and fluid pack choke. Rig up test manifold. 8/29/19 - Thursday Finish flushing & filling surface equipment w/test fluid, & setup test manifold. Test BOPE as per Hilcorp & AOGCC expectations, Witness was waived by AOGCC inspector Jim Regg 8-28-19. Tested with 5" tubular 250/4000 as per sundry (annular 250/2500) good, Tested gas alarms & PVT good. R/D test equipment. Pull test plug and lay down same. Adjust torque. tube to center over hole, Change out saver sub. Service rig. Pull 9 stands and install NPR's. TIH from 4690' to 5733'. RIOH on elevators from 5733' to 6865' without issue. Fill pipe. Noticed that IBOP actuator yoke was bent and one guide roller was out of track. (Photos in o-drive). Weighting up to 10.7 ppg. Repair IBOP actuator yoke and function test same. RIOH on elevators from 6865' to 7810' without issue. Safety ream last stand from 7810' to 7905' at 150 RPM/13 K torque. 550 GPM/2650 psi. Had 30' of fill. Directional drill 8 %" hole from 7905' to 8000'. P/U 220, 5/0 98, 136 Rot, 200 RPM, 11- 13 K torque, 15-20 K WOB, 550 GPM/2650 psi. 47.5 ROP avg. Max gas 179 units. 8/30/19 - Friday Directional drill 8 %:" hole from 8000' to 8375'. P/U 220, 5/0 98, 136 Rot, 200 RPM, 11-13 K torque, 15-20 K WOB, 550 GPM/2650 psi. 62 ROP avg. Max gas 420 units. pump sweep @ 8188', had 50% increase in cuttings. Directional drill 8 %" hole from 8375' to 8511', P/U 220, S/0 98, 136 Rot, 200 RPM, 11-13 K torque, 15-20 K WOB, 550 GPM/2650 psi. 54 ROP avg. Max gas 332 units. SCR room heated up power limit light came on, pick up & circulate while cooling room down. Directional drill 8 %" hole from 8511', to 8634'. P/U 225, S/0 105, 142 Rot, 200 RPM, 11-13 K torque, 15-20 K WOB, 550 GPM/2650 psi. 49.2 ROP avg. Pumped sweep at 8567' coming back on time with 30% increase. Max gas 250 units. Directional drill 8 %" hole from 8634' to 8848'. P/U 230, S/0 105, 145 Rot, 200 RPM, 11- 13 K torque, 15-20 K WOB, 550 GPM/2650 psi. 35.6 ROP avg. ROP slowed down to +-7 FPH and torque dropped off to 12 K. Pumped sweep at 8760' coming back on time with 30% increase. Max gas 238 units. Pump sweep and clean up cycle while working string from 8848' to 8755'. Sweep came back on time with 30% increase. 600 GPM/3150 psi, 200 RPM/12 K torque. BROOH from 8848' to 8000'. 600 GPM/3000 psi, 180 RPM/12 K torque. Cuttings increased substantially. Pump sweep and perform clean up cycle while working stand at full drilling rate from 8000' to 7920'. 8/31/19 - Saturday Pump sweep and perform clean up cycle while working stand at full drilling rate from 8000' to 7920'. Sweep came back on time with 30% increase. Cont. BROOH @ drilling rate, f/7920 t/7339'working through packoff issues as needed, pump sweep @ 7653' Sweep came back on time with 25% increase. Cont. BROOH @ drilling rate, f/7339' t/6385' working through packoff issues as needed. Rack back stand. P/U single and work stuck pipe until free. CBU clean and L/D single. Cont. BROOH @ drilling rate from 6385' to 5816' working through pack -off issues as needed. 550 GPM/2300 psi, 180 RPM/12 K torque. Circulate sweep at 5916' bringing back 35% increase and on time. Each stand back reamed from 6385' to shoe unloaded with quarter size pieces of coal. Recovered 45 bbls of cuttings from 6385' to shoe. High gas 421 units. Circulate bottoms up inside shoe while working string at full drill rate. Pump dry job. POOH with BHA #6. Hilcorp Alaska, LLC llilcorp ja—ka.LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-10RD Rig 56 50-733-20064-01-00 219-076 7/17/2019 1 Future 9/1/19 - Sunday Cont. stand back BHA in derrick, plug in & D/L MWD , bit was 1/16" under gauge, had a wash out on onejet. Service rig, D/W, Blocks Crown, TDS. Remove absorbent that was blocking trip tank flow line. M/U BHA #7. TIH w/ BHA #7 to 1386'. RIH from 1386' to 5724'. Shallow hole test tools at 1850' (good). Service Rig, Cut & slip drill line (75'). RIOH on elevators from 5818' to 8270'. Set down 40 K. Wash and ream 8250' to 8280' and clean up area. RICH on elevators to 8757'. Wash and ream last stand from 8757' to 8848'. No fill. 550 GPM/3150 psi, 180 RPM/13 K torque. Obtain SPR's. Max gas at bottoms up 197 units. Directional drill 8 Y2" hole from 8848' to 9229'. P/U 225, S/O 110, 140 Rot, 200 RPM, 15 K torque, 15- 20 K WOB, 550 GPM/3150 psi. 63.5 ROP avg. Pumped sweep at 8858' coming back on time with 15% increase. Max gas 257 units. Pumped sweeD at 9037'coming back with 30% increase. 9/2/19 - Monday Directional drill 8 %" hole from 9229' to 9576'. P/U 255, S/O 110, 159 Rot, 200 RPM, 17 K torque, 15-20 K WOB, 550 GPM/3050 psi. 58 ROP avg. Pumped sweep at 9418' coming back on time with 20% increase. Max gas 421 units. Directional drill 8 %" hole from 9576'.to 9736 P/U 255, S/O 110, 159 Rot, 200 RPM, 17 K torque, 15-20 K WOB, 550 GPM/3050 psi. 53 ROP avg. Pumped sweep every other stand. CBU @ 550 psi, work pipe, while swapping Generators, ( had source water issue). Directional drill 8 %" hole from 9736', to 9893' P/U 255, S/O 110, 159 Rot, 200 RPM, 17 K torque, 15-20 K WOB, 550 GPM/3050 psi. 63 ROP avg. Pumped sweep every other stand. Directional drill 8 %" hole from 9893' to 10,272'. P/U 255, S/O 110, 159 Rot, 200 RPM, 17 K torque, 15-20 K WOB, 550 GPM/3050 psi. 63.2 ROP avg. Pumped sweep every other stand. Max gas 414 units. Pump sweep and perform clean up cycle working pipe from 10,272' to 10,190' at 600 GPM/3500 psi, 200 RPM/17 K torque. Directional drill 8 %" hole from 10,272' to 10,457'. P/U 255, S/O 110, 159 Rot, 200 RPM, 17 K torque, 15-20 K WOB, 550 GPM/3050 psi. 41 ROP avg. Pumped sweep every other stand. Max gas 250 units. 9/3/19 - Tuesday Directional drill 8 Y2" hole from 10,457' to 10,647'. P/U 287, S/O 117, Rot 167, 200 RPM, 17 K torque, 15-20 K WOB, 550 GPM/3000 psi. 32.5 ROP avg. Pumped sweep every other stand. Max gas 301 units. Directional drill 8 %" hole from 10,647' to 11,064'. P/U 285, S/O 117, Rot 162, 200 RPM, 16 K torque, 15-20 K WOB, 550 GPM/3000 psi. 69.5 ROP avg. Pumped sweep every other stand. Max gas 520 units. Directional drill 8 %" hole from 11,064' to 11,451'. P/U 294, S/O 120, Rot 164, 200 RPM, 16 K torque, 15-20 K WOB, 550 GPM/3160 psi. 64.5 ROP avg. Pumped sweep every other stand. Max gas 486 units. Directional drill 8 %" hole from 11,451' to 11,760'. P/U 287, S/O 110, Rot 165, 200 RPM, 15-17K torque, 15-20 K WOB, 550 GPM/3100 psi. 51.5 ROP avg. Pumped sweep every other stand. Max gas 413 units. q A- Iozj� 2-007 c Regg, James B (CED) From: Sent: To: Regg, James B (CED) �1 Friday, August 16, 2019 11:24 AM Shane Hauck 1 Cc: Mack Myers Subject: RE: [EXTERNAL] RE: Monopod platform AOGCC Test Witness Notification Request: Other, 56 A-10rd Thank you for the explanation. Approval granted to delay the BOPE test until the 9 5/8" casing is set and cemented. You must test BOPE if unable to get casing to bottom and trip to surface. I'd appreciate an email update when casing is on bottom so we have time to line up a Inspector for witness. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or lim.regg@alaska.gov. From: Shane Hauck <shauck@hilcorp.com> Sent: Friday, August 16, 2019 11:04 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Mack Myers <mmyers@hilcorp.com> Subject: RE: [EXTERNAL] RE: AOGCC Test Witness Notification Request: Other, 56 A-10rd Monopod platform Sorry Mr. Regg I took it from your E-mail that you wanted me to resubmit request (I took that to be on the web based notice system and it only gives you 30 words I should have sent an E-mail ) Yes we did change top rams to 9-5/8 " and was tested good (see attached chart) Our justification is hole issues coal are giving us issues and are time sensitive and had tuff clean out run and would like to them behind casing as soon as we can also this is the same for why we did not test early we did test 9-5/8" rams chart is attached we have had (3) bope test since drilling well has been started first one we did half to flush super choke & change CMV #16 and was witnessed by Mr. Adam Earl but other two test have been good w/ no issues super choke was functioned and have no issues w/ safety valve that is XO to our casing if you would like I could, before exiting 13- 3/8" shoe test our choke manifold? Thanks Shane R Hauck Hilcorp DSM Rig 907-776-6675 From: Regg, James B (CED) [mailto:iim.regg@alaska.gov] Sent: Friday, August 16, 2019 9:33 AM To: Shane Hauck <shauck@hilcorp.com> Subject: [EXTERNAL] RE: AOGCC Test Witness Notification Request: Other, 56 A-10rd Monopod platform Last BOPE test report I saw showed the stack configured with 2 sets of 2 7/8 x 5 % VBRs. Did you install and test casing rams? Sent the test chart. Where is the justification for delaying the test that I requested? What prevented testing BOPE before running casing? Was a partial test of components that could be used in the event of a well control feasible or event considered? Brief summary of BOPE performance based on tests since commenced the well? Jim Regg Supervisor, Inspections AOGCC 333 W.71h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or lim.regg@alaska.gov. From: Shane Hauck <noreply@formresponse.com> Sent: Friday, August 16, 2019 7:10 AM To: DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe. bay@alaska.gov> Subject: AOGCC Test Witness Notification Request: Other, 56 A-10rd Monopod platform Question Answer Type of Test Requested: Other Requested Time for 08-19-2019 11:00 AM Inspection Location 56 A-10rd Monopod platform Name Shane Hauck E-mail shauck@hilcorp.com Phone Number (907) 776-6675 Company Hilcorp Mr. Regg Could we delay our bope test tell we get our csg run and Other Information: cemented? We are currently running csg Thanks Shane Submission ID: 4417774161318680487 ' Q �� t� cis►� �� reso-- sd 4500 CHAqT 45 i / �.. tom_ -----1.-1� ..� �., , '"\,� \ `,' �+- --4• \ , � \ \ :. �.,,:. � •--+,-_.' � � to 41 .., t\ \ ' +� � _.�.`_ _._..-�.�.. � _. � '` � / o � !; �` I .•! • r / I � � CAS i —oo' 0002 y RECENEDo JUL 2 2 2019 _�. STATE OFALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 CONNOINIIAL 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown[] Suspend ❑ Perforate 11 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: G/L Qipmoletion El- 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Num e : Hilcorp Alaska, LLC Exploratory Q Development ❑ Stratigraphic ❑ Service ❑ 219-076 - 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-200 4-01-00 7. If perforating: �S� S� 8. Well Na/me qn N ber: What Regulation or Conservation Order governs well spacing in this pool?, 7 CO 69 /��k �C j��✓�a� ��- 7 l �f —1&gb Will planned perforations require a spacing exception? l Yes ❑ No ❑ (/ '�- Z'L % 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL018731 / ADL393693 / ADL018776 Tyonek G /Hemlock Prospect 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): (/ Plugs (MD): Junk (MD): ±16,002 (proposed) ±10,086 (proposed) ±15,906 (proposed) ±10,140 (proposed) psi N/A N/A Casing Length Size MD / TVD Burst Collapse Structural Conductor -264' 20" -264' ±264' Surface 1,095' 13-3/8" 1,095' ±1,068' 3,090 psi 1,540 psi Intermediate Production ±9,805 (proposed) 9-5/8" ±9,805 (propose' ±6,442' (proposed) 6,870 psi 4,760 psi Liner ±6,397 (proposed) 7" ±16,OAbqrg s0 +10,214' (proposed) 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Si z Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A N/A 12. Attachments: Proposal Summary Q Wellbore s atic J3. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketc Exploratory Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9 OIL WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is tr hd the procedure approved herein will not be deviated from without prior written appr val. Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations M ager Contact Email: dmarlowe hIICOr .CO Contact Phone: (907) 283-1329 Authorized Signature: tL/1z' Date: �' Z �� COMMISSION U E ONLY mission sot t a representative may witness Sundry Number: /� r ✓ _ 1 /l,J (✓•1 Conditions of apZRequired? Plug Integrity OP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4BDM�+]9�lJr 0 2019 Post Initial InjectYes ❑ No ❑ I / Spacing ExceptiYes ❑ No ❑ Subsequent Form Required: -- - APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: �'[ I NAM Submit Form and Form 10-403 Revised 4/2017 Approved applicationi I 111000 1 othi _date of approval. Attachments in Duplicate CONFIDENTIAL 11 Hilcorp Alaska, LLC Well Work Prognosis Well Name: A-10rd API Number: 50-733-20064-01 Current Status: New Sidetrack of SI Producer Leg: N/A Estimated Start Date: September 01, 2019 Rig: Monopod Rig #56 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 219-076 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Monty Myers (907) 777-8431 (0) (907) 538-1168 (M) Current Bottom Hole Pressure: 4,400 psi @ 9,518' TVD 0.462 Ibs/ ft (8.89 ppg) estimated Maximum Expected BHP: 4,400 psi @ 9,518' TVD 0.462 Ibs/ ft (8.89 ppg) estimated Maximum Potential Surface Pressure: 3,448 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) Brief Well Summary A-10rd is a commingled Tyonek G / Hemlock producer that will be completed with Gas Lift. This new well was side tracked from the current A-10 mother bore, a shut-in gas lifted producer. This workover will run completion and perforate the new well. The completion will allow the Tyonek G and Hemlock to be produced independently. Last Casine Test: Casing and liner tested to 3,500 psi under PTD 219-076 Procedure: 1. ***Take over operations from the Drilling Sidetrack Program *** 2. Test BOP's every 7 days continued from last test date from PTD 219-076. Test to 250psi low/4,000psi high / 2,500 psi annular. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 3. Completion fluid will be brine. BOP's will be closed as needed to circulate the well. 4. ** If not already completed under PTD 219-079, Rig up E-Line and run gamma/ccl/cbl. 5. PU and RIH with TCP guns, Correlate on depth and perforate. 6. Circulate bottoms up and assure well is static, release underbalance packer, circulate again and ensure well is static. POOH 7. PU and RIH with Gas Lift completion. 8. Set Packer / Pressure test completion: a. Pressure up and set packer b. Test tubing against plug in XN nipple to 2,500# and chart for 30 minutes. c. Test IA to 2,000 psi and chart for 30 minutes (This will pressure up tubing also). d. Pull prong and plug in XN-Nipple. 9. Set BPV. NU tree, test same. 10. Turn over to production. 11. Schedule SVS testing with AOGCC as per regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Proposed 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form 20" 13- D% 9 ng Plu Back for C0NFj1"NjjA[ `ell#A10 Unit PTD: 167-076 IIileorp Alaska, LLC Sidetrack Schematic API: 50-733- Plug Back: 05/18/200 /18/2019 KB 37'. KB to MSL: 101'. MSL to Mudline 66' ie CASING DETAII. SIZE WT GRADE CONN ID TOP BTM. 20" Conductor Pile Surface "264' 13-3/8" 61 K-55 BTC 12.515 Surface 1,095' 9-5/8" 40 J-55 BTC 8.835 1,393' 4,111' 40 N-80 BTC 8.835 4,111' 5,600' 43.5 N-80 BTC 1 8.755 1 5,600' 7,053' Tubing Detail: LS 3-1/2" 9.2 N-80 Butt 2.992 4,123' 4434' 2-7/8" 6.4 N-80 Butt 2.441 4435' 5718' SS3-1/2" 9.2 N-80 Butt 2.992 4,013' 4145' 2-7/8" 6.4 N-80 Butt 2.441 4146' 4191' Dip Tube 2-3/8" x 1-1/2" 6.2 N-80 Butt 1.853 4084' 5537' JEWELRY DETAIL NO Depth MD Depth TVD ID OD Item 1,540' 1,470' CIBP w/ 527' cement 4,008' 3,716' Cl BP w/ 373' cement SHORT STRING E 4,044' 3,749' 2.875 5.62 GLM #54- Otis RW4 (4.37" Minor OD) F 4,080' 3,781' 2.75 Otis "XA" Sliding Sleeve G 4,145' 3,841' 2.441 Cross over, 3-1/2" X 2-7/8" H 1 4,146' 3,842' 1 2.380 1 8.435 1 Otis "RTH" Triple Hydraulic Packer(3-1/2"x2-7/8"x2-3/8") I 4,189' 3,882' 2.205 Otis "XN" Nipple J 4,191' 3,884' EOT LONG STRING 6 4,147' 3,843' 3.000 8.435 Otis "RTH" Triple Hydraulic Packer(3-1/2"x2-7/8"x2-3/8") 7 4,249' 3,937' 2.75 Otis "XA" Sliding Sleeve 8 4,434' 4,109' Cross over, 3-1/2" X 2-7/8" 9 4,497' 4,168' GLM #L4- Camco KBMG-LT 10 4,754' 4,874' 4,409' 4,522' Blast Joints 11 5,030' 4,668' GLM #L5- Camco KBMG-LT 12 5,442' 5,053' GLM #L6-Camco KBMG-LT 13 1 5,604' 5,205' 2.313 Otis "XA" Sliding Sleeve 14 5,640' 51239' Locator Seal Assy. 15 5,641' 5,240' Otis 9-5/8" x 4" "BD" Perm Packer 16 5,685' 5,281' 2.313 Otis "X" Nipple 17 5,718' 5,312' Mule Shoe. Dip Tubing a. 4,084' 3,785' Top of Dip Tube (1 perforated joint) 4,147' 3,843' 1.940 8.435 b. 4,159' 3,854' 1-1/2" Telescoping Joint C. 4,496' 4,167' GLM #L4 - Camco KBMG-LT d. 4,513' 4,183' 1-1/2" Telescoping Joint e. 5,030' 4,668' GLM #L5 - Camco KBMG-LT f. 5,052' 4,689' 1-1/2"TelescopingJoint g. 5,442' S,053' GLM #1_6 - Camco KBMG-LT h. 5,537' 5,142' Bull Plug FISH Date Depth Description 10/05/1978 6,500' Junked Perm Packer 07/16/1973 6,494' 2 Junked Retainers 07/14/1973 6,496' 1/2 of ring from hydraulic packer 08/09/1970 6,503' Guiberson Packer Model A 08/08/1970 6,503' Junked Retainer 07/30/1970 6,515' Junked BP 03/25/1968 6,525' Junked BP 03/21/1968 6525' Junked BP KB ELEV = 101' PBTD = 6,750' TD = 7,073' ANGLE thru INTERVAL = 12.7° Perforation Details on Next Page Updated by: JLL 05/29/19 Plug Unit Back foX O FI NTIA[ Well#A-ing 10 PTD: 167-076 IIilcnrp Alaska, LLC Sidetrack Schematic API: 50-733-20064-00 Plug Back: 05/18/2019 Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt. Accum. SPF Date Last Opr. Present Condition 3,840' 3,860' 3,563' 3,582' 20' 4 3/22/1968 Isolated 4,148' 4,168' 3,844' 3,863' 20' 4 3/20/1968 Isolated 4,240' 4,241' 3,929' 3,930' 1' 4 3/24/1968 Isolated C 4,262' 4,288' 3,949' 3,973' 26' 4&8 7/30/1970 Isolated C 4,316' 4,354' 3,999' 4,035' 1 38' 4&8 1 7/30/1970 Isolated C 4,398' 4,430' 4,076 41106' 32' 4&8 7/30/1970 Isolated C 4,498' 4,514' 4,169' 4,184' 16' 4&8 7/30/1970 Isolated C 4,572' 4,592' 4,238' 4,257' 20' 4&8 7/30/1970 Isolated C 4,668' 4,694' 4,328' 4,353' 26' 4&8 7/30/1970 Isolated C-7 4,766' 4,864' 4,420' 4,512' 98' 4, 8 & 12 7/30/1970 Isolated C 5,012' 5,050' 4,651' 4,687' 38' 4 3/26/1968 Isolated C 5,096' 5,100' 4,730' 4,734' 4' 4 7/30/1970 Isolated C 5,124' 5,132' 4,756' 4,764' 8' 4 7/30/1970 Isolated C 5,244' 5,249' 4,868' 4,873' 5' 4 7/30/1970 Isolated C 5,325' 5,358' 4,944' 4,975' 33' 1 4, 8 & 12 7/30/1970 Isolated C 5,532' 1 5,534' 5,137' 5,139' 2' 3/5/1970 Isolated C 5,534' 5,590' 5,139' 5,191' 56' 4&8 7/30/1970 Isolated C 5,590' 5,592' 5,191' 5,193' 2' 3/5/1970 Isolated D 5,684' 5,712' 5,280' 1 5,307' 28' 8 7/30/1970 Isolated 53-8 5,787' 5,838' 5,379' 5,429' 51' 4, 8 & 12 3/8/1974 Isolated 54-5 5,870' 5,880' 5,460' 5,469' 1 10' 8 7/16/1973 Isolated 54-9 5,900' 5,954' 5,489' 5,541' 54' 12 7/16/1973 Isolated D 5,985' 6,020' 5,571' 5,60T 35' 4&8 7/30/1970 Isolated D 6,030' 6,134' 5,615' 5,716' 104' 4,8,12&16 3/8/1974 Isolated 57-2 6,160' 6,245' 5,742' 5,826' 85, 4,8,12&16 3/8/1974 Isolated E 6,274' 6,296' 5,854' 5,876' 22' 8 8/8/1970 Isolated E 6,274' 6,296 5,854' 5,876' 22' 4, 8 & 12 7/16/1973 Isolated E 6,320' 6,352' 5,900' 5,932' 32' 12 7/16/1973 Isolated 6,600' 6,740' 6,179' 6,319' 140' 4 1/6/1968 Isolated 6,760' 6,840' 6,339' 6,419' 80' 4 1/4/1968 Isolated 6,904' 6,919' 6,483' 6,498' 1 15' 4 1/3/1968 Isolated Updated by: JLL 05/29/19 Hilcurp Alaska, LLC KB to MSL =101' MSL to Mudline = 66' PBTD: ±15,9: 6" TD: ±16,002 �o�dFmE�ui a� PROPOSED CASING DETAIL Trading Bay Unit 'ell: A -LORD Last Completed: Future PTD: 219-076 API: 50-733-20064-01 Size Wt Grade Conn ID Top Btm 20" Conductor Pile Surface -264' 13-3/8" 61 K-55 BTC 12.515" Surface 1,095' 9-5/8" 47 L-80 Hyd 563 8.681" Surface ±1,000' 9-5/8" 47 L-80 DWC/C 8.681" ±1,000' ±9,805' 7" 29 L-80 CDC HTQ 6.059" 1 ±9,605' , ±16,002 TUBING DETAIL 2-7/8" 6.5 P-110 8 round EUE 1 2.441" 1 Surfa 1 ±15,450' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item ±37' ±37' Hanger 1 ±350' ±350' 2.313" Sssv ±2,057' ±2,000' 2.441 3.5 GLM 1 ±3,368' ±3,000' 2.441 410V GL #2 ±4,303' ±3,500' 2.441 M #3 ±5,238' ±4,000' 2.441 j 500 GLM #4 ±6,173' ±4,500' 2.441 3.500 GLM #5 ±7,108' ±5,000' 3.5 GLM #6 ±8,043' ±5,500' .441 3. 00 GLM #7 2 ±8,978' ±6,000' 2.441 .500 G 8' ±9,913' 6,5 .441 3. 6L 9 v. ±10,848' _7, 0' 2.441 3.500 GLM #1 ±11,783' ±7,500' 2.44 3.500 GLM #1 ±12,717' ±8,000' 2. 1 3.500 GLKV ±13,652' ±8,500' .441 3.500 GL 13 ±14,417' ±9,000' 2.441 3.500 GLNI#14 ±14,996' ±9,443' 2.441 3.500 GLM #15 - Orifice 3 ±15,024' ±9,46 1.975" 3.669" Halliburton ROC Gauge Mandrel w/ 0.25" TEC wire 4 ±15,075' ±9,5 4' Packer 5 ±15,100' ±9 23' 1.875" X-Nipple 6 ±15,425, 1772' Sliding Sleeve 7 ±15,435' ±9,780' Packer 8 ±15,445' ±9,787' 1.791" XN-Nipple 9 ±15,45 ±9,791' WLEG PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) (trn FT Date Status ±15,258' ±15,430' ±9,644' ±9,776' ±172' Future Proposed H ±15,440' ±16,000' ±9,783' ±10,212' ±560' Future Proposed Updated By: AL 07/12/19 CONFIDEVIAL Monopod Platform 2018 BOP Stack Hilnirp Alap ka, LIA'. CONFIDENTIAL . . . . . . . . . . . . . --- ....... . . . . . . . CONFIBEVIAL 14 Hilcorp Alaska, LLC Attachment #1 Monopod Rig # 56 BOP Test Procedure Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Monopod Rig # 56 WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Circulate down tubing taking returns to production off of the annulus and sweep gas and oil to production until returns are clean. 4) Confirm that well is static shooting fluid levels if necessary right before ND/NU. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test per standard Monopod Rig #56 BOPE test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, establish static fluid level, shoot fluid level with an echometer gun or tag with slick line to establish static fluid level if necessary. 2) Once the fluid level is established to be static, notify Hilcorp Anchorage Operations Engineer. 3) Proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift -threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test) joint to lift -threads d) Plug penetrations in hanger. For ESP wells - Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 4) If both set of threads appear to be bad and unable to hold a pressure test and / or a penetrator leaks, notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC - guy.schwartz@alaska.gov ) and Mr. Jim Regg (AOGCC-jim.regg@alaska.gov ) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE Hileorp Alaska, LLC Monopod Rig # 56 BOP Test Procedure Attachment #1 b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 5) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 6) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Note: BOPE high test pressures will be determined upon Approved Sundry. Test joint sizes will be determined upon well work. Subsequent Tests (i.e. Test Plug can be set in the Tubing -head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-2 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position CONFIDEVIAL Monopod Rig # 56 14 BOP Test Procedure Hileurp Alaska, LLC Attachment #1 them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. d) Open C-2. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves, to 250 psi low and 3,000 psi high, for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. ii) Valves, 3, 4, 9. After test, open valves 3 & 4. Leave 9 closed. iii) Valves 5, 6, 9. After test, open valves 5 & 6, leave 9 closed. iv) Valves, 7, 8, 9. After test, open all valves. e) Close C-3. This is the HCR (the hydraulic controlled remote) valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test, open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test C-1, C-2, and C-4 on the kill (pump -in) side by pressuring up on tubing. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2"d set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre -charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position Hilcorp Alaska, LLC Monopod Rig # 56 BOP Test Procedure Attachment #1 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. U Ct ct O W. So (D 0 -0 0) 22 C: tB � U U C a) Et E 0) O •� U � O a) Q- a E L �- () L O N O a) > L m a) L C In o a� 0) aa)i m CY) _r_ C U (B N U 0 0 �0 _� (� o� L t� C:U mU -00 O ca' Q a) E a`) = a, U O O 0) m c = mw r Lo m U 0 > 0 U o y L L Q as a) N Q O >+ 2 CLCL = Q CD (W = ym L = a M n 'a m a >- Z d t U a� a� 0 aL d R ai R a L) a) cn cu 0 Q Q El 0 co 0- a) lei Carlisle, Samantha J (CED) From: Schwartz, Guy L (CED) Sent: Friday, October 4, 2019 10:12 AM To: Dan Marlowe Cc: Carlisle, Samantha J (CED) Subject: RE: PTD# 219-076 (A-10RD completion Sundry) Dan, We have assigned sundry 319-345 for the completion of A-10RD. AOGCC will withdrawn this sundry as requested. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains inforration from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartzC@alaska.govov). From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Friday, October 4, 2019 10:03 AM To: Mack Myers <mmyers@hilcorp.com>; Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Cc: Cody Dinger <cdinger@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: PTD# 219-076 (A-10RD completion Sundry) Guy Have you assigned a Sundry number to our submitted completions permit? We also request withdrawing that sundry at this time. Thanks Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Email DMarlowe(o).hilcorp.com Hilcorp A Company Built on Energy From: Mack Myers Sent: Friday, October 4, 2019 9:22 AM To:'guy.schwartz@alaska.gov' <Ruy•schwartz alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaslca.gov> Cc: Cody Dinger <cdinger@hilcorp.com>; uan Marlowe <dmarlowe@hilcorp.com> Subject: PTD# 219-076 (A-10RD Abandonment plan) Guy, We have successfully drilled the A-10RD exploration well to a TD of 16,212' TMD. Unfortunately, we encountered wet sand in the Hemlock and the production hole needs to be abandoned. We do have future utility for the well out of the 7" liner set at 11,754' TMD, so I would like to propose the following temporary abandonment procedure. Top of Tyonek G — 15, 857' TMD Top of Hemlock— 16,060' TMD TD of well with 6-1/8" hole — 16,212' • Pick up 1000' of 2-7/8" sacrificial tubing , crossed over to a BHK disconnect. • Run in the hole to TD of 16,212' and circulate bottoms up • Mix and pump 30 bbls of 12ppg spacer, followed by 44.5 bbls of 13ppg cement, drop BHK dart chased by 5 bbls of fresh water. • Release from BHK disconnect. Pull up hole to the shoe at 11,754'. Circulate hole clean. • PU 7" CIBP and RIH to 11,735' and set CIBP. • After setting CIBP, set down 10 Ibs to confirm CIBP is set. • Displace well to FIW with corrosion inhibitor and POOH. • PU 500' of 2-7/8" tubing as a kill string • Land hanger in wellhead. • ND BOPE and NU tree and test. This gives us enough cement to cover the uppermost hydrocarbon bearing zone by 645' and is in accordance with 20AAC 25.112(a)(1)(B). Please let me know if you have any questions or concerns with this plan, as we would like to move this direction beginning later this afternoon on 10.04.2019. Thank you! Monty M Myers Drilling Manager 907.538.1168 (c) 907.777.8431 (o) The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. THE STATE 0 4511011 =I W "al GOVERNOR MIKE DUNLEAVY Monty Myers Drilling Manager Hilcorp Alaska, LLC. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: North Trading Bay Field, Exploratory Oil Pool, Hilcorp Alaska, LLC. Permit to Drill Number: 219-076 Surface Location: 1602' FSL, 570' FEL, Sec. 4, Bottomhole Location: 849' FSL, 1420' FEL, Sec 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 Trading Bay State A -LORD T9N, R13W, SM, AK 35, T10N, R13W, SM, AK Enclosed is the approved application for the permit to drill the above referenced exploration well. 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. 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 Hilcorp Alaska, LLC. in the attached application, the following well logs are also required for this well. Mud log, open -hole gamma ray and resistivity required from surface casing shoe to total depth of the well. Mud log, open -hole gamma ray, resistivity, and porosity required from 9-5/8' casing shoe to the total depth of the 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 approvals 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. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the AOGCC's internal use. 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, Jessie L. Chmielowski Commissioner DATED this A day of June, 2019. STATE OF ALASKA A ,KA OIL AND GAS CONSERVATION COM .-.ION PERMIT TO DRILL MAY 14 20919 20 AAC 25.005 1 a. TyDP of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill I ' Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑ Single Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill E�2eentry❑ Exploratory - Oil El Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑✓ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q - Single Well ❑ 11. Well Name and Number: Hilcorp Alaska, LLC Bond No. 022035244 • A-1 ORD 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 16,002' • TVD: 10,086' Tyonek G / Hemlock Prospect 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1602' FSL, 570' FEL, Sec 4, T9N, R13W, SM, AK ADL018731, ADL393693, ADLO18776 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 607' FSL, 1945' FEL, Sec 35, T1 ON, R13W, SM, AK N/A 7/7/2019 ' 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 849' FSL, 1420' FEL, Sec 35, T1 ON, R13W, SM, AK 7360 2,100' to nearest lease boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 101' 15. Distance to Nearest Well Open Surface: x-218864 • y- 2523116 • Zone-4 GL / BF Elevation above MSL (ft): N/A to Same Pool: N/A 16. Deviated wells: Kickoff depth: 1,095 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 58.8 degrees Downhole: 4768 Surface: —x:w- 3%�pe a 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 12 1/4 9-5/8" 47# L-80 Hyd 563 1,000, Surface Surface 1,000' 980' Stg 1 - L - 1999 ft3 T - 245 ft3 9-5/8" 47# L-80 DWC/C 8,805' - 9,805' 6,326' Stg 2 - L - 1516 ft3 8-1/2" 7" 29# L-80 CDC HTQ 6,397' 9,605' 6,223' 16,002' 10,086, L - 1308 ft3 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 7,073' 6,652' 3,636' TOC Tag 1,275' 1,240' 1,275' - 1,500' Casing Length Size Cement Volume MD TVD Conductor/Structural 264' 20" N/A 264' 264' Surface 1,095' 13-3/8" 1200 sx 1,095' 1,068' Intermediate Production 5,553' (Recovering Cut Csg Currently 9-5/8" 1500 sx 7,053' 6,632' Liner Perforation Depth MD (ft): N/A Perforation Depth TVD (ft): N/A Hydraulic Fracture planned? Yes ❑ No ❑� - 20. Attachments: Property Plat Q BOP Sketch Drilling Program Time v. Depth Plot e B Shallow Hazard Analysis B✓ 8 Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Monty Myers Authorized Name: Monty Myers Contact Email: mmi erS hllCor .cord Authorized Title: Drilling Manager Contact Phone: 777-8431 Authorized Signature: Date: Commission Use Only Permit to Drill 2l C1 � 74 API Number: l Z '"Z=C Permit Approv I See cover letter for other requirements. Number: 50-— —) Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbedFrneihaAe, gas hydrates, or gas contained in shales: Other: 0 — t �� / ` I ` Samples req'd: Yes Rr No ❑ Mud log req'd: Yes [�No El/ ❑ YNo QQ HZS measures: Yes No ❑ Directional svy req'd: Yes Spacing exception req'd: Yes [:1 Nov Inclination -only svy req'd: Yes ❑ No - d Post initial injection MIT req'd: Yes ❑ No ❑ Approved by: APPROVED BY COMMISSIONER THE COMMISSION Date: n nMFG SubmitForand Form 10- 1 Revised 5/2017 This permit is vali r t IoNAL approval per 20 AAC 25.005(g) ttachments in Dug'cate Hilcorp Alaska, LLC Monopod Platform A-1 ORD Drilling Program Exploration Well Revision 0 May 10", 2019 A -LORD Drilling Procedure Hilcorp Energy Company Contents 1.0 Well Summary.................................................................................................................................2 2.0 Management of Change Information............................................................................................3 3.0 Tubular Program: ........................................................................................................................... 4 4.0 Drill Pipe Information: ................................................................................................................... 4 5.0 Internal Reporting Requirements..................................................................................................5 6.0 Planned Wellbore Schematic..........................................................................................................6 7.0 Drilling / Completion Summary.....................................................................................................7 8.0 Mandatory Regulatory Compliance / Notifications.....................................................................8 9.0 R/U and Preparatory Work..........................................................................................................10 10.0 BOP N/U and Test.........................................................................................................................13 11.0 Drilling 12-1/4" Hole Section........................................................................................................14 12.0 Run 9-5/8" Intermediate Casing..................................................................................................17 13.0 Cement 9-5/8" Casing (2-Stages)..................................................................................................22 14.0 Drilling 8-1/2" Hole Section..........................................................................................................27 15.0 Running 7" Production Liner.......................................................................................................32 16.0 Cementing 7" Production Liner...................................................................................................35 17.0 Wellbore Clean Up & Displacement............................................................................................38 18.0 BOP Schematic (12-1/4" and 8-1/2" Hole Sections)...................................................................39 19.0 Wellhead Schematic......................................................................................................................40 20.0 Days Vs Depth................................................................................................................................41 21.0 Estimated Formation Tops and Pressures..................................................................................42 22.0 Anticipated Drilling Hazards.......................................................................................................43 23.0 FIT Procedure................................................................................................................................45 24.0 Choke Manifold Schematic...........................................................................................................46 25.0 Casing Design Information...........................................................................................................47 26.0 12-1/4" Hole Section MASP..........................................................................................................48 27.0 8-1/2" Hole Section MASP............................................................................................................49 28.0 Spider Plot (NAD 27)....................................................................................................................50 29.0 As Built (NAD 27)..........................................................................................................................51 30.0 Offset MW vs TVD Chart.............................................................................................................53 31.0 Directional Plan (wp04)................................................................................................................54 HilmT Energy Company Ene 1.0 Well Summary A-IORD Drilling Procedure .) �;- (' C rwlowo✓j Well A-1 ORD Leg & Slot Designation Slot 31 Planned Completion Type Gas Lift on 2-7/8" X 2-3/8" Tubing Target Reservoir(s) Hemlock and West Foreland Planned Well TD, MD / TVD 16,002' MD / 10,187' TVD PBTD, MD / TVD 15,906' MD / 10,114' TVD Surface Location (Governmental) 1602' FSL, 570' FEL, Sec 4, T9N, R13W, SM, AK Surface Location (NAD 27) X=218864.5, Y=2523116.3 Surface Location (NAD 83) Top of Productive Horizon (Governmental) 607' FSL, 1945' FEL, Sec 35, T10N, R13W, SM, AK TPH Location (NAD 27) X=228143.3, Y=2527182.0 TPH Location (NAD 83) BHL (Governmental) 849' FSL, 1420' FEL, Sec 35, T10N, R13W, SM, AK BHL (NAD 27) X=228674.07, Y=2527412.27 BHL (NAD 83 ) AFE Number 1910558 (D,C,F) AFE Drilling Days 46 AFE Completion Days 10 AFE Drilling Amount $10.8 MM AFE Completion Amount $2.8 MM Work String 5" 19.5# 5-135 NC-50 (Rental String from Weatherford) KB Elevation above MSL 101 ft MSL to ML 66 ft BOP Equipment 13-5/8" 5M Hydril "GK" Annular BOP 13-5/8" 5M Cameron Type U Double Ram 13-5/8" 5M Cameron Type U Single Ram Page 2 Revision 0 May, 2019 A -LORD Drilling Procedure 2.0 Management of Change Information Hilcoip Alaska, LLC Changes to Approved Permit to Drill Date: May 13, 2019 Subject: Changes to Approved Permit to Drill for A-1 ORD File #: A-1ORD Drilling Program Any modifications to A-1 ORD Drilling Program will be documented and approved below. Changes to an approved APD will be communicated and approved by the AOGCC prior to continuing forward with work. Hi1mTF- C�PanY Sec Page Date Procedure Change Approved Approved By By Approval: Monty M Myers Prepared: Drilling Manager Drilling Engineer Date pate Page 3 Revision 0 May, 2019 A-IORD Drilling Procedure 1 1" rNl 7 a T .5.0 I uDular Frogram: Hole Section 011 in ID (in) Drift (in) Conn OD (in) Wt (#/ft) L-80 I YD563 Burst si, _ 6870 Collapse (psi) Tensio (Wbs 12-1/4" 9-5/8" 8.681" 8.525" 10.625" 47 4750 1086 12-1/4" 9-5/8" 8.681" 8.525" 10.625" 47 L-80 DWC/C 6870 4760 1086 8-1/2" 7" 6.184" 6.059 7.656" 1 29 L-80 CDC-HTQ 8160 7020 676 4.0 Drill Pipe Information: Hole Section: OD (in) ID (in) TJ ID TJ OD ) Wt #/ft Grade Conn Burst si) Collapse si Tension k-lbs All 5" 4.276 3-1/8 6-5/8 19.5 S-135 NC-50 17,100 15,110 560 All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Revision 0 May, 2019 A -LORD Drilling Procedure Hilcorp Encrgy Company 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • 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. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini cghilcorp.com, mmyers@hilcorp.com and cdinger@hilcoKp.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by lam on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. Each rig will be assigned a usemame to login with. 5.4 EHS Incident Reporting • Notify EHS field coordinator. 1. This could be one of (3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don't wait until an emergency to have to call around and figure it out!!!! a. John Coston: 0: (907) 777-6726 C: (907) 227-3189 b. Matt Hogge: 0: (907) 777-8418 C: (907) 227-9829 2. Spills: Keegan Fleming: 0:907-777-8477 C:907-350-9439 Notify Drlg Manager 1. Monty M Myers: 0: 907-777-8431 C: 907-538-1168 Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final "As -Run" Casing tally to mmyers@hilcoip.com and cdinger _cr,hilcorp.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to mmyers@hilcorp.com and cdinger@hilcorp.com Page 5 Revision 0 May, 2019 Hilcorp Energy Company 6.0 Planned Wellbore Schematic 11 PROPOSED I lilr�un U:nl.a. LL1 KB to MSL =101' MSL to Mudline = 65 A PBTD:15,906' MD / 10,114' TVD TD: 16,002'MD/ 10,187 TW A -LORD Drilling Procedure Trading Bay Unit Well: A -LORD Last Completed: Future PTD:XXX-XXX API: 50-733-20064-XX Page 6 Revision 0 May, 2019 A -LORD Drilling Procedure Hilcorp Energy Company 7.0 Drilling / Completion Summary A-1 ORD is a sidetrack well targeting additional reservoirs in the Lower Tyonek and Hemlock formations in the North Trading Bay Field. The base plan is an "S" shaped wellbore which builds up to 59 degrees with a 10,700' vertical section. TD is planned at 16,002' MD / 10,187' TVD. Drilling operations are expected to commence approximately July 7th, 2019. A separate completion sundry will be submitted outlining the details of the perforations and gas lift completion that will be run. The general sequence of operations covered in this APD are summarized below: 1. Prep rig 56 for drilling operations. Previous operations were P&A and slot recovery of A-10. 2. N/U BOPE and test. / .3 `ae '-(,dA ,i' t 3`1/" e%/v'i S 3. Drill 12-1/4" hole from 1,095' to 9,805' MD. Run and cmt 9-5/8" casing in 2 stages. 4. Clean out well and prep for production hole. 5. Test BOPE 6. Drill 8-1/2" hole section to 16,001' MD. Run and cmt 7" production liner. 7. Clean out 7" production liner, displace to completion fluid. Prepare wellbore for mechanical completion assy. Cii-=l Ci �-(C: /t,-?� t'�A Page 7 Revision 0 May, 2019 A -LORD Drilling Procedure Hilcorp Energy Company 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. • BOPs shall be tested at (1) week intervals during the drilling of A-1 ORD. Ensure to provide AOGCC 48 hrs notice prior to testing BOPs. • The initial test of (,equipment will be to 250/- .psi & subsequent tests of the BOP equipment will be to 250 psi for 515 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. • If the BOP is used to shut in on the well in a well control situation, we must testALL BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 7 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system" • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: <_ • Variance requested from AOGCC reg 20.AAC.25.035(C). Only (1) 16" diverter line can be R/U that will have a straight shot off the platform (East). To rig a diverter line up 180 degrees from that would have too many bends to be effective. 40 Page 8 Revision 0 May, 2019 Hilcorp Energy Company A -LORD Drilling Procedure 1 I Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) • 13-5/8" Hydril GK 5M annular • 13-5/8" 5M Cameron U Double gate • Blind ram in btm cavity Initial Test: 250/� (Annular 2500 psi) 12-1/4" 0 Mud cross 8-1/2" • 13-5/8" 5M Cameron U single gate Subsequent Tests: • 3-1/16" 5M Choke Manifold 250/3-M7 Yo_ • Standpipe, floor valves, etc (Annular 2500 psi) • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Secondary back-up is an air pump, and tertiary emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event (BOPs utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPS. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: j im.regggalaska. gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz2alaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: victoria.loeppgalaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectorsgalaska.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 9 Revision 0 May, 2019 A -LORD Drilling Procedure Hilcorp Energy Company 9.0 RX and Preparatory Work R-3 " S w. 9.1 Mix mud for 12-1/4" hole section. 12-1/4" hole mud program summary: C i JA1 n A)�; o 0-s Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. Canrig PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. , System Type: 9.0 ppg 80/20 Enviromul MOBM Properties: MD Mud Weight Viscosity Pv YP HTHP WPS ES (PPg) 1,095 — 9,805' 9.0- 9.5 50-80 25-35 15-22 <5 250-270K >580 System Formulation: 80/20 Enviromul MOBM Product Concentration LVT 0.662 bbl Water .172 bbl INVERMUL NT 4 ppb EZ MUL NT 4 ppb GELTONE V 6-10 ppb Lime 7 ppb DURATONE HT 2 ppb Calcium Chloride 21 ppb BAROID 41 9.0 ppg (as needed) BARACARB 5 3-5 ppb BARABLOK 2 ppb BAROTROL PLUS 4 ppb 1. Mud weight: Maintain the density at 9.0 — 9.5 ppg or as directed; use solids control and whole mud dilution. Increase the density as required for hole stability/coal sloughing. Maximize solids control usage. 2. Rheology: Maintain a YP between 15 - 22 or as needed to achieve adequate hole cleaning. Pump high viscosity sweeps throughout the interval as needed, particularly prior to POH for casing. Optimized mud theology and flow rate will be the primary mechanisms for achieving hole cleaning in this wellbore. Maximize pipe rotation (ideally > 100 RPM). 3. Lubricity: No cuttings will be allowed to be overboarded. Use lubes as required. Page 10 Revision 0 May, 2019 A -LORD Drilling Procedure HilmiT Energy Company 4. Other issues: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to reduce the chances for losses and differential sticking. LCM (BARACARBs 5/25/50, STEELSEAL 50/100/400) and shale stabilizers (BAROTROL PLUS, SOLTEX) should be maintained at elevated concentrations while drilling coals to help strengthen the wellbore. Operations Summary Soda ash and citric acid should be used to pretreat for any negative effects of the cement. BARAZAN D+ should be used to maintain rheological parameters. BARACARB 5/25/50 should be maintained at 5 ppb and BAROFIBRE\STEELSEAL 50/100/400 should be maintained at 5 ppb for a total of 10 ppb LCM. BAROTROL PLUS and SOLTEX should be added to help control coal seams. Maintain the mud as clean as possible while drilling. Should sweeps be required, a high viscosity sweep is recommended. Daily additions of X-CIDE 207/ALDACIDE G MUST be made to control bacterial action. PAC L/DEXTRID LT should be used for filtrate control. While drilling, monitor the torque and drag to determine if liquid lubricant is required. If so, approval from town will be required prior to additions of lubricants. When penetrating high -clay content sections, the addition of CON DET PREMIX is recommended to reduce the incidence of bit balling and shaker blinding. Maintain the pH in the 8.5 — 9.5 range with caustic soda or KOH. The system rheology may be relaxed as hole conditions allow. This will also lower the ECD for any possible loss zones which might be found and reduce swab tendencies. However, be prepared to increase the YP if hole cleaning becomes an issue. Stress slow pipe movement to the drillers to reduce surge/swab. Stage pumps up slowly after connections and begin rotation prior to pumping (this will break the gels and reduce the pressure required to break the gels). If any trips are required, consider spotting a 20 bbl, 20 ppb LCM pill across the loss zone. The pill should consist of base mud with 10 ppb BARACARB 50 and 10 ppb STEELSEAL added. This pill would reduce the effects of tripping back in and allow time for the LCM to "soak" into the zone. STEELSEAL's and BARACARB's will not dehydrate the mud which will allow for lower ECD on the first bottoms up after TIH. Reduce system YP as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what YP value they have targeted). Consider spotting a STEELSEAL/BAROTROL PLUS/SOLTEX pill (20 ppb of the different sizes of STEELSEAL, 4 ppb BAROTROL PLUS, 4 ppb SOLTEX) prior to running the casing if losses or sloughing have been seen in this interval. Sweeps Utilize high viscosity sweeps or weighted sweeps as needed to clean the hole. Monitor all sweeps pumped and report their effectiveness. The objective of the sweep is to change the flow characteristics/carrying capacity that are inherent with the mud system. Select sweep type accordingly. Page 11 Revision 0 May, 2019 A -LORD Drilling Procedure Hilcorp Energy Company 9.2 Install 6" liners in mud pumps. We will want to pump at 900 — 1000 gpm to clean the 12-1/4" hole. 6" liners will deliver 502 gpm @ 120 spm @ 95% eff @ 4665 psi. Performance of FD-1600 Triplex Mud Pump Liner Size and Pressure Rating 7" 178 mm W 171 mm 6 "", 165 mm 6" 152 mm 51/" 140 mm 5" 127 mm 3423 241 3688 259 3981 280 4665 328 5000 352 6000 352 psi kg/rM2 psi kg/em2 psi kgiW psi kg/tan2 psi kg/om2 psi kg/cm' Strokes Horsepower Per Minute Rating Volume - Gallons (Liters) per Minute 120 1600 1622 719 (2721) 669 (2532) 620 (2347) 529 (2002) 444 (1680) 367 (1389) 110 1467 1488 659 (2494) 613 (2320) 568 (2150) 465 (1836) 407 (1540) 337 (1275) 100 1333 1352 599 (2267) 557 (2108) 517 (1958) 441 (Mg) 370 (1400) 306 (1158) 90 1200 1217 539 (2040) 502 (1900) 465 (1760) 997 (1503) an (1260) 275 (1041) 80 1067 1082 479 (1819) 446 (1688) 413 (1569) 353 (1336) 296 (1120) 245 (927) 70 933 946 419 (1586) 390 (1476) 362 (1370) 309 (1170) 258 (976) 214 (810) 60 800 811 359 (1359) 334 (1264) 310 (1173) 264 (m) 222 (840) 183 (693) Gallons (Liters) per Revolution 5.99 (22.67) 5.57 (21.08) 5.16 (19.53) 4.41 (16.69) 370 (14.00) 306 (11.58) Based on 10096 wkrmetric a`f mrxyand 90% mecharrcal effbey. Typical6ners are shown. Other data is available upon request. Page 12 Revision 0 May, 2019 0 Hi1COIp Energy Company 10.0 BOP N/U and Test A -LORD Drilling Procedure 10.1 * BOPE was NU and tested on prior decompletion sundry. Continue on to step 11. BE sure test is current for a 14 day drilling cycle. 10.2 N/U 13-5/8" x 5M BOP as follows (top down): • 13-5/8" x 5M Hydril "GK" annular BOP. • 13-5/8" Cameron Type "U" Double ram. (5" pipe ram in top cavity, blind ram in btm cavity) • 13-5/8" mud cross • 13-5/8" Cameron Type "U" single ram. (5" pipe ram) • N/U pitcher nipple, install flowline. • Install (1) manual valves & (1) HCR on kill side of mud cross. Manual valve used as inside or "master valve". • Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 10.3 Run 5" BOP test assy, land out test plug (if not installed previously). • Test BOP to 250� si for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Ensure to leave casead side outlet open so pressure does not build up beneath test plug. 10.4 R/D BOP test assy. 10.5 Continue mixing 9.0 ppg 80/20 Enviromul MOBM drilling fluid for 12-1/4" hole section. 10.6 Set wearbushing in wellhead. 10.7 Rack back as much 5" DP in derrick as possible to be used while drilling the hole section. 10.8 Leave 6" liners in mud pumps. Page 13 Revision 0 May, 2019 A -LORD Drilling Procedure Hilcorp Energy Company 11.0 Drilling 12-1/4" Hole Section 11.1 Ensure to have an RTTS available on the rig for 13-3/8" casing in the event we need to hunt for a casing leak. 11.2 Ensure BHA components have been inspected previously. 11.3 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 11.4 Bit nozzles should be (5) x 16's. Have the DD run independent hydraulic calculations to ensure optimum TFA. 11.5 Pick up the 12-1/4" BHA as follows: Monopod A-10RD RIG: ER Bottom Hole Assembly 01 12.254n Hole Rev 1 WPDra`t DEPTH IN 1,106' W P Dra? DEPTH OUT 10,000' BHA OBJECTIVE: Drop to vertical and build back up to 57 avoiding offset wells AC vary tight Gyro Single Shots required ITEM EQUIP. GAUGE BODY BODY DOWN UP UNIT ACCUM. ppf NO. I DESCRIPTION PROVIDER 00 OD 10 CONN CONN LENGTH LENGTH 1 121A•Bd-PDC BHGE 12.-*•'9 105,15 Reg P.n 1.23 12) 2 8' X-treme 15 ako n' 12 1:8' UBHS wrAoal lnsW led BHGE 12.125 8.00 6 YS s SAS a 28.90 3D.10 138.00 3 8- NM StringStab wl 12 V8- Slrht Blades BHGE 12.125 8.00 2.88 a y3 Reg P o sa Reg 8 5.00 35.10 175.54 4 8' NhICSDP BHGE 8.00 2.75 c 5.3 Rep P o 5'6• Reg a 10.00 45.10 101.00 5 Stop Sub BHGE 825 2.81 s 5.3 P 3 1,,a• r_ a 2.00 47.10 200.00 8 __ Ontrak (GFtRes'PWDrrVS&'Surve) --7- BHGE 3 39 2.70 3 tri• T2 P 31N• T2 8 13.90 a 06.06 1r9. 00 7 $' Modular Stabalizef BHGE +2 +23 3 2T 793 I. i ri' T2 P 3 1.- T2 8 3 7a 71.30 163.cc 8 18CPM(Fvl BHGE 3 20 2.76 3 i:i• T2 P a t:i• T2 a 11?3 03.35 153 s6 9 BHGE 325 2.01 5 1,Y T2 P 6 ZM Reg 6 2.00 33.55 .=o.o0 10 Sub BHGE 325 3.00 6 3r3 Reg P 6 5V Rep 8 3.45 91,00 137.cc 11 E8'NMCSDP BHGE _ _ a a3 2.13 o sm Rep P 6 59• Rep a 4.00 90.00 1".a8 12 P BHGE 500 2.75 a so Rep P a S3 Rev a 6200. 157.00 is! 13 BHGE 300 2.75 63,13 Fto P NC306 3.00 100.00 100.00 14 9 Joins 5' HW DP 09.77kt8 Adjusted weight) RIG o c25 TJ 5W 3.so t3C3o P NC30 8 279.00 239.00 29 n 15 Drilling Jar ? coo 1 3.Qo K'=P NC50a 32.50 271.50 18 5 Joins 5' HW DP 149 770+1t A&,usted weight) RIG a e25 T2 500 3.00 Nc3o P Nc36 a 153.00 626 50 29.77 17 5'S-135 Drill Pi 22.86"Adjusted weight) RIG 6.02s TJ 500 2,22 rxsoP NC30a 1 9373.50 10o0a on 22.M 18 need to confirm HW DP and DP Specs and Weights) 19 Notes and Comments Ttxro's, Dogep Oe- Lt-Ptin-d DOWCO < z Su- RPM.A oS tno-71 mu an`-�LschanicafSpecifications FLOW RATES: a- Xa Yotw (393-WY-a.23- BCPY Normal Flow (33WO33•i23) MUD TYPE: Yoe DL Rot I Sn00 RPY: wmB Sensor Distance Information s-ev we EGO: 49.2 V33(vuWa0a"31: so 6' Gamma Rir. 43.4' NonYag bes- 30.z RnROvnY. 53.G N-IM0 At : 53.2- Page 14 Revision 0 May, 2019 HilmTEnergy Company 11.6 Primary Bit for 12-1/4 hole is the Baker Hughes Kymera Hughes Christensen Kymera""*' Hybrid Bits Best of Both Worlds Designed to take advantage of the best attributes of both, Kymera combines roller cone and fixed cutter elements. Improved Directional Control Relative to PDC bits, Kymera generates lower overall torque and minimized torque fluctuations to improve tool face control and reduce vibrations. I. Lower vibration The unique design of Kymcm bits proN ides an extreme(} h stable drilling platform that mitigates vibration present in roller con, a PDC environments.:. Better toolface control Superior directional bit for motor or rotary applications with better toolface control and steerability than a PE Faster and More Durable When drilling interbedded and harder formations, relative to PDC bits, this unique design provides increased durability in transition zones and smoother, faster drilling in hard rock. Bit Specifications A -LORD Drilling Procedure PRODUCT OVERVIEW !Number of Blades, Cones 3.3 Gauge / Makeup Length 5 in (127 mm) / 16.145 in (410.1 mm) Primary Cutter Size 0.75 in (19.1 min). Bit Breaker F Cutter Quantity (Total, Face) (37,19) Connexion 6 Si8 Reg Pin Cutting Structure (Inner, Heel, Gauge)Conic/Conic(Carbide 37.1 - 40.90-ib 450.3 - ? I ?' Bit Sub 55.41,Nm) Makeup Torque 7 : 4. and larger Bit 42.7 - 46.9kft-lb (57.9 - Number of Nozzles 3 SP, 3 PORT Sub 63.6kNm) Fixed TFA 0.451 sq.in (290.32 sq.mm) Approx. Shipping Wcight280 lbs (127 kg) Bearing / Seal Package Journal w/Inscrt / Ref. Part Number S11933 Single Energizer MFS Operating Recommendations* HN,draulie flow rate: 550-1200g in (2100-45501pm). Rotation Soo:& For Rotary and Motor Applications. Max. Weight On Bit: 67 kib (A9 to or WaN) Page 15 Revision 0 May, 2019 A -LORD Drilling Procedure Hilcorp Energy Company 11.7 TIH to TOC (Est at 900'). CBU and test casing to.500 psi / 30 min. 11 11.8 Drill out cement and drill 20' new formation from 1095' to 1115'. 11.9 CBU and condition mud to 9.5 ppg in/out. iS -- 11.10 Conduct FIT t�pg EMW. o e D 2'0 — lots 9.5) * 0.052 * 1080' tvd :'ktI-p si 11.11 Drill 12-1/4" hole section along approved directional wellpath to section TD. Section TD is planned to set the 9-5/8" at 9805' MD past the Bruin Bay Fault and above the Tyonek E. ✓ • Begin drilling with light WOB to initiate a new PDC bottom hole pattern. • Work pipe through coal seams as req'd. Avoid excessive backreaming. Backreaming & surging the coals has an adverse effect on the quality of the wellbore. • Utilize formation type log to identify coal seams and plan directional work accordingly. • Pump sweeps as required for additional hole cleaning. • Ensure solids control equipment functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Adjust MW as necessary to maintain hole stability. Keep API fluid loss < 11 • Pull wiper trips as hole conditions dictate. A good rule of thumb is to start with wiper trips every 500' �� ,� G�itLi► �i�.� L / J r 04 �� IZ"!y l0� i �4u-trt 1-" a 1 11.12 At section TD, sweep hole & C-U. Pull a wiper trip back to the 13-3/8" shoe. OH & -handle BHA as appropriate. • Note any tight spots or hole problems on AM report. • Utilize LWD to aid in casing point selection. 11.13 No open hole logs are planned for the 12-1/4" hole section on A -LORD. Page 16 Revision 0 May, 2019 A -LORD Drilling Procedure Hilcolp Energy Company 12.0 Run 9-5/8" Intermediate Casing 12.1 Pull wear bushing. Install and test 9-5/8" casing rams in upper ram cavity (250/3Wpsi). 12.2 R/U Weatherford 9-5/8" casing running equipment. • 14-50 Weatherford High Torque tongs. • Flush mounted spider & adapter bushing. • Back up tongs (rig provided) for 9-5/8" casing. • Ensure all casing has been drifted on the pipe rack prior to running. • Be sure to count the total # of joints on the rig before running. • Keep hole covered as much as possible while R/U casing tools. Monitor wellbore on trip tank. Record OD's, ID's, lengths, S/N's of all shoe track components & the stage collar. Ensure 9-5/8" DWC/C x 5" NC-50 crossover on rig floor and M/U to FOSV. 12.3 P/U the reamer shoe joint. Visually verify there is no debris inside joint. 12.4 M/U and thread lock shoe track assy consisting of: • (1) Shoe joint with reamer shoe bucked on (thread locked). Install centralizers at 10' from each end btwn stop collars. • (1) Joint with float collar bucked on pin end & thread locked. Install (1) centralizer mid tube over a stop collar. • Ensure bypass baffle is correctly installed on top of float collar. Bypass Baffle This end up. • (1) Joint with Halliburton bypass baffle adapter bucked on pin & threadlocked. Install (1) centralizer mid tube over a stop collar. • Ensure proper operation of float equipment. • Ensure to record S/N's of all float equipment and stage tool components. Page 17 Revision 0 May, 2019 A-IORD Drilling Procedure Hilcorp Energy Company 12.5 Float equipment and Stage tool equipment drawings: A �T Overall Length Type H ES Cementer B Part No. SO No_ Closing Sleeve No. Shear Pans Opening Sleeve No. Shear Pins ES Cementer Depth Ba-e Adapter (if used) ID Depth Bypass or Shut-off Baffle ID Depth Float Collar Depth Float Shoe Depth Hole TD *'Reference Casmg Sales Manual Section 5 C Max- Tool OD D Openin Seat ID E Closing Seat ID Plug Set Part No. SO No. WE Closing Plu-S •D Opening Plug OD OD Shut-off Plug OD Bypass Plug (if used) OD Itikorp ES-B Running Order i ES4I Cerra~ Slest OM PMy Baffle Adapter Sn By4bass Plug By Pass Baffle Float Collar Float shoe Page 18 Revision 0 May, 2019 Hi1mTEnergy Company 12.6 12.7 12.8 12.9 A -LORD Drilling Procedure Continue running 9-5/8" intermediate casing. Use "Best O Life 2000" thread compound. Dope pin end only using a paint brush. Install centralizers every joint for the first 30 joints. Then every other joint up to 2500' TMD. Leave centralizers free floating so they are free to slide up and down the joint unrestricted. 9-5/8" 47# L-80 DWC Make Up Torques: Casing OD Min M/U Torque Max M/U Torque 9-5/8" 40,000 ft-lbs 50,000 ft-lbs 9-5/8" 479 L-80 HYD 563 Make Up Torques: Casing OD Min M/U Torque Max M/U Torque 9-5/8" 13,200 ft-lbs 23,000 ft-lbs Install the Halliburton Type H ES -II Stage tool so that it is positioned at 4400' MD / 3532' TVD. Install centralizers over couplings on 3 joints below and above stage tool. Do not place tongs on ES cementer, this can cause damage to the tool. Ensure tool is pinned with 6 opening shear pins. There are 6 holes, the tool is normally sent with only 4 pins installed. This will allow the tool to open at 3300 psi. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. Slow in and out of slips. 12.10 The last 25 joints of 9-5/8" 47# casing will be HYD 563. Ensure 9-5/8" HYD 563 x 5" NC-50 crossover on rig floor and M/U to FOSV. 12.11 P1i 1 casing hanger joint and M/LT to stringy. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe +/- 20' from TD when landed. Strap the landing joints while on the pipe deck and mark the joints to use as a reference when landing the hanger. 12.12 Lower string and land out in wellhead. Confirm measurements indicate hanger has correctly landed out in the wellhead profile. 12.13 R/U circulating equipment and circulate B/U. Condition mud for cement job. Page 19 Revision 0 May, 2019 12.14 Reciprocate casing if possible while conditioning mud. 12.15 Estimated string weight at TD will be close to 500k. Technical Specifications Connection Type: Size(O.D.): Weight (Wall): DWC/C Casing 9-5/8 in 47.00 Ib/ft (0.472 in) standard Material L-80 Grade 80,000 Minimum Yield Strength (psi) 95,000 Minimum Ultimate Strength (psi) Pipe Dimensions 9.625 Nominal Pipe Body O.D. (in) 8.681 Nominal Pipe Body I.D.(tn) 0.472 Nominal Wall Thickness (in) 47.00 Nominal Weight (lbs/ft) 46.18 Plain End Weight (lbs/ft) 13.572 Nominal Pipe Body Area (sq in) Pipe Body Performance Properties 1,086,000 Minimum Pipe Body Yield Strength (Ibs) 4,750 Minimum Collapse Pressure (psi) 6,870 Minimum Internal Yield Pressure (psi) 6,300 Hydrostatic Test Pressure (psi) Connection Dimensions 10,625 Connection O.D. (in) 8,681 Connection I.D. (in) 8.525 Connection Drift Diameter (in) 4.81 Make-up Loss (in) 13.572 Critical Area (sq in) 100.0 Joint Efficiency (%) Connection Performance Properties 1,086,000 Joint Strength (Ibs) 16,500 Reference String Length (ft) 1.4 Design Factor 1,122,000 API Joint Strength (Ibs) 543,000 Compression Rating (Ibs) 4,750 API Collapse Pressure Rating (psi) 6,870 API Internal Pressure Resistance (psi) 19.0 Maximum Uniaxial Bend Rating Idegrees/100 ft] Appoximated Field End Torque Values 40,000 Minimum Final Torque (ft-Ibs) 50,000 Maximum Final Torque (ft-lbs) 59,400 Connection Yield Torque (ft-lbs) A -LORD Drilling Procedure Grade: L-80 "llp" ttnrtt�Irltitlillr u s A VAM-USA 4424 W. Sam Houston Pkwy. Suits 150 Houston, TX 770411 Phone: 713-479.3200 Fax: 713479-3234 E-mail: VAMUSAsslesfd r.a.va'aour�c.tprr Page 20 Revision 0 May, 2019 A -LORD Drilling Procedure Hilcorp Energy Company An Outside Diameter 9.6250 in. Min. Wall 87.54E go Thickness (1) Grade L80 Type 1 Wall Thickness 0.472 in. Connection OD REGULAR COUPLING PIPE BODY Option Body: Red 1st Band: Red Grade L80Type 1' Drift API Standard 1st Band Brown 2nd Band: 2nd Band. - Brown Type Casing 3rd Band: - 3rd Band. - 4th Band - PIPE BODY DATA GEOMETRY Nominal OD 9.625 in Nominal Weight 47.00lbsttt Drift 8.525 in Nominal to 8.681 in Mall Thickness 0.472 in. Plain End Weight 46.18 ibstft OD Tolerance API PERFORMANCE i Body Yield Strength 1086 x1000 Ibs internal Yield 6870 psi SMYS 80000 psi q'+ Collapse 4750 psi f. CONNECTION DATA GEOMETRY Connection OD 10.625 in. Coupling Length 9.25 in. Connection 10 8.681 in. '+ Make-up Loss 4.050 in Threads per in 3.29 Connection OD Opt:on REGULAR PERFORMANCE ,r tC `., Tension Efficiency 100.0 % Joint Yield Strength 1086.000 x1000 internal Pressure Capacity 6870.000 psi His Compression Efficiency 100.0 % Compression Strength 1086.000 x1000 Max Allowable Bending 38 `t100 It lbs External Pressure Capacity 4750.000 psi Coupling Face Load 640000 Ibs MAKE-UP TORQUES Minimum 13200 ft-ibs Optimum 15800 ft-ibs Maximum 23000 ft-Ibs OPERATION LIMIT TORQUES Operating Torque 50000 ft-ibs Yield Torque 75000 fl-Ibs BUCK -ON Minimum 22000 ft-lbs Maximum 25000 ft-Ibs Notes This connection is fully interchangeable with: Wedge 563e - 9.625 in. - 36 ! 40143.5 / 53 5 Ibstft Connections With DopelessS Technology are fully compatible with the same connection in its Standard version Page 21 Revision 0 May, 2019 A-IORD Drilling Procedure Hilcorp Energy Company 13.0 Cement 9-5/8" Casing (2-Stages) 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. • Discuss how to handle cmt returns at surface. Ensure vac trucks are on standby and ready to assist • Pre determine which pump will be utilized for displacement, and how fluid will be fed to displacement pump • Ensure adequate amounts of water for mix fluid is heated and available in the water tanks • Positions and expectations of personnel involved with the cement operation i. Extra hands in the pits to strap during the cement job to identify any losses • Review test reports and ensure pump times are acceptable • Conduct visual inspection of all iron used to route slurry to rig floor 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cmt pump or treating iron will not be pumped downhole. 13.4 RAJ cementing head (if not already done so). Company rep to witness top and bottom plugs have been loaded correctly. 13.5 Fill surface lines with water and pressure test. 13.6 Pump 60 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug (flexible bypass plug) — HEC rep to witness. Mix and pump cement per below calculations for the 1 st stage, confirm actual cement volumes with cementer after TD is reached. 13.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead & tail slurry, and TOC will be brought to the stage tool. Page 22 Revision 0 May, 2019 0 Hilcorp Energy Company A -LORD Drilling Procedure Estimated 11t Stage Total Cement Volume: Section Calculation Vol (bbl) Vol (ft3) 12-1/4" OH X 9-5/8" Casing (9305' - 4400') X .0558 X 1.3 = 356 1999 v J Total Lead 356 1999 12-1/4" OH X 9-5/8" Casing (500') X .0558 X 1.3 = 37 208 9-5/8" Shoe Track 90' X .0732 bpf = 6.6 37 Total Tail 43.6 245 Cement Slurry Design (Ft stage cement jobs): 9z""l S,z l2-5, 5 f System VariCem ExpandaCem Density 12.0 lb/gal 13.0 lb/gal Yield 2.41 ft3/sk 1.89 ft3/sk Mix Water 13.9 gal/sk 10.1 gal/sk 13.9 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the casing collar depths in mind. If the hole gets "sticky", position casing string at desired depth and continue with cement job. 13.10 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits. HEC Rep to witness. 13.11 Ensure rig pump is used to displace cmt. 13.12 Displacement calculation: (9,805' — 90') x .0732 bpf = 712 bbl total 13.13 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. . 13.14 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of the shoe track volume, —3.3 bbls before consulting with drilling engineer. 13.15 If the plug is not bumped, consult the drilling engineer. Ensure the free fall stage tool opening plug is available if needed. This is the backup option to open the stage tool if the plugs are not bumped. Page 23 Revision 0 May, 2019 A -LORD Drilling Procedure Hilcorp Energy Company 13.16 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.17 Increase pressure to 3300 psi to open circulating ports in stage collar. Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface and volume pumped to see the returns. Circulate until YP < 20 again in preparation for the 2nd stage of the cement job. 13.18 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker bypass line to the cuttings tank. Have sacks of sugar available and vac trucks ready to assist. Ensure to flush out any rig components used to route cement. Second Stage Cement Job: 13.19 Prepare for the 2nd stage as necessary. Circulate until 1 stage reaches sufficient compressive strength. Hold pre job safety meeting. 13.20 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 13.21 Fill surface lines with water and pressure test. 13.22 Pump 60 bbls 10.5 ppg tuned spacer. 13.23 Mix and pump cement per below recipe for the 2nd stage. 13.24 Cement volume based on annular volume + open hole excess (30% for lead). Job will consist of lead cement only, TOC brought to. 500' inside 13-3/8" surface casing. V Page 24 Revision 0 May, 2019 A -LORD Drilling Procedure Estimated 2nd Stage Total Cement Volume: Section Calculation Vol (bbl) Vol (ft3) 13-3/8" Surface X 9-5/8" Casing (500') X .05973 bpf = 30 168 12-1/4" OH X 9-5/8" Casing (4400' - 1095') X .0558 X 1.3 = 240 1347 Total Lead 270 1516 Cement Slurry Design (2nd stage cement job): System VariCem Density 12.0 lb/gal Yield 2.41 ft3/sk Mix Water 13.9 gal/sk 13.25 After pumping cement, drop ES Cementer closing plug and displace cement with drilling mud out of mud pits. 13.26 Displacement Calculation: 4400' x .0732 bpf = 323 bbls mud 13.27 Monitor returns closely while displacing cement. Adjust pump rate if necessary. Wellhead side outlet valve in cellar can be opened to take returns to cellar if required. Be prepared to pump out fluid from cellar. Have some sacks of sugar available to retard setting of cement. 13.28 Decide ahead of time what will be done with cement returns if any come to surface. 13.29 Land closing plug on stage collar and pressure up to 1000 — 1500 psi to ensure stage tool closes. Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool has closed. Set slips and back out and cut joint. 13.30 Flush out wellhead with FW and BOP stack thoroughly to ensure cement, mud and cuttings are removed. 13.31 M/U pack -off running tool and pack -off to bottom of Landing joint. Set casing slips packoff. Run in lock downs and inject plastic packing element. Pressure test t/ 2450 psi. 13.32 Lay down landing joint and pack -off running tool. Page 25 Revision 0 May, 2019 Hilcorp Energy Company A -LORD Drilling Procedure Ensure to report the following on WellEz: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration • Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid • If losses are seen during cement job, note at operation during the cement job they were observed and where the cement was • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface & volume • Note time cement in place • Note calculated top of cement 13.33 Add any comments which would describe the successor problems during the cement job Page 26 Revision 0 May, 2019 A -LORD Drilling Procedure Hilcorp Energy Company 14.0 Drilling 8-1/2" Hole Section 14.1 Remove 9-5/8" casing rams from upper ram cavity. Install and test 3-1/2" x 7" VBR. Test on 5" DP to 250/;'I I<psi. qe�" 14.2 Run and set wear bushing in wellhead. 14. 3 P/U 8-1/2" directional drilling assy consisting of. Rev 1 A•10RD RIG:t Bottom Hole Assembly 02 8.54n Hole Rev 1 WP Draft UGFffS DEPTH IN 10,000' Page 27 Revision 0 May, 2019 Hilco p Energy Company 14.4 TIH w/ directional assy to TOC (estimated at 4400' MD) 14.5 Primary bit is the Baker Hughes Kymera Hughes Christensen KymeraTm Hybrid Bits Best of Both Worlds Designed to take advantage of the best a both, Kymera combines roller cone and fixed cutter elements. improved Directional Control Relative to PDC bits, Kymera ger overall torque and minimized torque fluctuations to improve to control and reduce vibrations. Lower vibration The unique design of Kymera bits provides an stable drilling platform that mitigates vibration present in roller PDC environments. Better toolface control Superior directional bit for motor or rota applications with better toolface control and steerability than a Faster and More Durable When drilling interbedded and harde relative to PDC bits, this unique design provides increased dur transition zones and smoother, faster drilling in hard rock. Bit Specifications Number of Blades, Cones 4, 2 Primary Cutter Size 0.625 in (15.9 mm) Cutter Quantity (Total, Face) (18, 14) Cutting Structure (inner, Heel, Gauge) Conic/Conic/Carbide Number of Nozzles Fixed TFA Bearing 1 Seal Package 4 CSP 0 sq.in (0 sq.mm) A-IORD Drilling Procedure PRODUCT OVERVIEW Gauge/ Makeup Length 5.5 in (139.7 mm)19.792 in (148.7 mm) Bit Breaker U Connection 4-1/2 Reg Pin 5 It2' On Sub 12.5 - 13.7kft-lb 06.9 . 18.6kNm) Makeup Torque 5 311' Bit Sub 16.5 - 18.tkft-lb (22.1. 24.01 m) 6' and larger Bit Sub 20.3. 221k't-lb (27.6. 3J.At m) Approx. Shipping Weight 105 lbs (47.6 kg) Journal wnnsert / Ref. Part Number X23762 Single Energizer MFS Operating Recommendations' Hydraulic flog; rate: 300-750 gpm (1150-2850 1pm). Ro?anon Speed: For Rotary and Motor Applications. Max. Weight On Bit: 42 k1b (18 to or kdaN) Page 28 Revision 0 May, 2019 a Hilcorp Energy Company A -LORD Drilling Procedure 14.6 TIH and tag TOC (approx. 4,400' TMD). Note depth tagged on AM report. 14.7 Drill out ES cementer and cleanout well to float collar. 14.8 CBU and test casing to 3000 psi / 30 min. 'JJ 14.9 Drill out shoe track + rat hole + 20' new formation. 14.10 CBU and condition MW for FIT. 14.11 Conduct FIT to 13.5 ppg EMW. • (13.5 — 9.5) * 0.052 * 6327' tvd = 1316 psi 14.11 Kick Tolerance • (13.5-9.5) * (6327/10187) = 2.5 ,6L ) Note: Offsetfield test data predicts frac gradients at the window to be between 12 ppg and 15 ppg. A 13.5 ppg FIT results in a 2.5 ppg kick tolerance while drilling the interval with a 9.5 ppg fluid density. 14.11 8-1/2" hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. V/ Canrig PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.5 ppg 80/20 Enviromul MOBM Properties: MD Mud Weight Viscosity PV YP HT W WPs ES (PPg) 9,805—16,002' 9.0- 9.5 50-80 25-35 15-22 <5 250-270K >580 Page 29 Revision 0 May, 2019 Hilcorp Energy Company A -LORD Drilling Procedure System Formulation: 80/20 Enviromul MOBM Product Concentration LVT 0.662 bbl Water .172 bbl INVERMUL NT 4 ppb EZ MUL NT 4 ppb GELTONE V 6-10 ppb Lime 7 ppb DURATONE HT 2 ppb Calcium Chloride 21 ppb BAROID 41 9.0 ppg (as needed) BARACARB 5 3-5 ppb BARABLOK 2 ppb BAROTROL PLUS 4 ppb 1. Mud weight: Maintain the density at 9.0 — 9.5 ppg or as directed; use solids control and whole mud dilution. Increase the density as required for hole stability/coal sloughing. Maximize solids control usage. 2. Rheology: Maintain a YP between 15 - 22 or as needed to achieve adequate hole cleaning. Pump high viscosity sweeps throughout the interval as needed, particularly prior to POH for casing. Optimized mud rheology and flow rate will be the primary mechanisms for achieving hole cleaning in this wellbore. Maximize pipe rotation (ideally > 100 RPM). 3. Lubricity: No cuttings will be allowed to be overboarded. Use lubes as required. 4. Other issues: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to reduce the chances for losses and differential sticking. LCM (BARACARBs 5/25/50, STEELSEAL 50/100/400) and shale stabilizers (BAROTROL PLUS, SOLTEX) should be maintained at elevated concentrations while drilling coals to help strengthen the wellbore. Operations Summary Soda ash and citric acid should be used to pretreat for any negative effects of the cement. BARAZAN D+ should be used to maintain rheological parameters. BARACARB 5/25/50 should be maintained at 5 ppb and BAROFIBRE\STEELSEAL 50/100/400 should be maintained at 5 ppb for a total of 10 ppb LCM. BAROTROL PLUS and SOLTEX should be added to help control coal seams. Maintain the mud as clean as possible while drilling. Should sweeps be required, a high viscosity sweep is recommended. Daily additions of X-CIDE 207/ALDACIDE G MUST be made to control bacterial action. PAC L/DEXTRID LT should be used for filtrate control. While drilling, monitor the torque and drag to determine if liquid lubricant is required. If so, approval from town will be required prior to additions of lubricants. When penetrating high -clay content sections, the addition of CON DET PREMIX is recommended to reduce the incidence of bit balling and shaker blinding. Maintain the pH in the 8.5 — 9.5 range with caustic soda or KOH. The system rheology may be relaxed as hole conditions allow. This will also lower the ECD for any possible loss zones which might be found and reduce swab tendencies. However, be prepared to increase the YP if hole cleaning becomes an issue. Stress slow pipe movement to the drillers to reduce surge/swab. Stage pumps up slowly after connections and Page 30 Revision 0 May, 2019 A -LORD Drilling Procedure Hilcorp Enow company begin rotation prior to pumping (this will break the gels and reduce the pressure required to break the gels). If any trips are required, consider spotting a 20 bbl, 20 ppb LCM pill across the loss zone. The pill should consist of base mud with 10 ppb BARACARB 50 and 10 ppb STEELSEAL added. This pill would reduce the effects of tripping back in and allow time for the LCM to "soak" into the zone. STEELSEAL's and BARACARB's will not dehydrate the mud which will allow for lower ECD on the first bottoms up after TIH. Reduce system YP as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what YP value they have targeted). Consider spotting a STEELSEALBAROTROL PLUS/SOLTEX pill (20 ppb of the different sizes of STEELSEAL, 4 ppb BAROTROL PLUS, 4 ppb SOLTEX) prior to running the casing if losses or sloughing have been seen in this interval. Sweeps Utilize high viscosity sweeps or weighted sweeps as needed to clean the hole. Monitor all sweeps pumped and report their effectiveness. The objective of the sweep is to change the flow characteristics/carrying capacity that are inherent with the mud system. Select sweep type accordingly. 14.12 Begin drilling 8-1/2" hole section along approved directional plan. • Begin with light WOB to establish a new bottom hole pattern with the PDC bit. • Work pipe through coal seams as req'd. • Utilize formation type log to identify coal seams and plan directional work accordingly. • Pump sweeps as required for additional hole cleaning. • Ensure solids control equipment functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 8 • Pull wiper trips as hole conditions dictate. A good rule of thumb is to start with wiper trips every 500'. • Take formation samples every 30'.' // „ / / 13 Drill to TD at 16,002' ISGGID / 10,187'TVD. � � / ) .. _ • Exact TD will be determined based on LWD log. r", �7'r� 14 CBU and pull a wiper trip back to the 9-5/8" casing shoe. 15 TOH, drop drift on trip out of hole. Handle BHA as appropriate on trip out of hole. S4� /N- yes , Ao q cc- hi Page 31 Revision 0 May, 2019 A -LORD Drilling Procedure Hilcorp Energy Company 15.0 Running 7" Production Liner 15.1 Test VBR on 7" test joint to 250 / 3000 psi for 5 /5 min. 15.2 M/U and rack cement stand in derrick. • Ensure to drift components prior to M/U. Ensure dart will pass through components. • Confirm largest OD of packer assy will pass through wear bushing. 15.3 RAJ 7" casing running equipment. • Ensure 7" USS-CDC HTQ x 5" NC-50 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all shoe track components. 15.4 P/U shoe joint, visually verify no debris inside joint. 15.5 Continue M/U & thread locking shoe track assy consisting of: • (1) Shoe joint w/ shoe bucked on & threadlocked (coupling also thread locked). • (1) Baker Locked joint • (1) Joint with float collar bucked on pin end & threadlocked (coupling also thread locked). • (1) Joint with landing collar installed INSIDE pin end. • Solid body centralizers will be pre -installed on shoe joint & FC joint. • Install a solid body centralizer on landing collar joint. Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe. 15.6 Continue running 7" prod liner • Fill casing while running using fill up line on rig floor. • Use "Best-O-Life 2000" thread compound. Dope pin end only w/ paint brush. • Install solid body centralizers on every joint across the entire open hole section. Leave the centralizers free floating. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 7" USS CDC-HTO M/U torques Casio OD Minimum Maximum Yield Torque 7" 15,000 ft-lbs 21,000 ft-lbs 30,900 ft-lbs Page 32 Revision 0 May, 2019 Hilcorp Energy Company USS U. S. Steel Tubular Products 7.000" 29.00lbs/ft (0.408" Wall) L80 USS-CDC HTQ® MECHANICAL PROPERTIES Pipe USS-CDC HTQ® Minimum Yield Strength 80,000 psi Maximum Yield Strength 95,000 psi Minimum Tensile Strength 95,000 psi DIMENSIONS Pipe USS-CDC HTQ® Outside Diameter 7.000 7.875 in. Wall Thickness 0.408 - in. Inside Diameter 6,184 6.184 in. Standard Drift 6.059 6.059 in. Alternate Drift — -- in. Coupling Length — 10.000 in. Nominal Linear Weight, T&C 29.00 - Ibs/ft Plain End Weight 28.75 Ibstft SECTION AREA Pipe USS-CDC HTQ* Critical Area 8.449 8.449 sq. in. Joint Efficiency — 100.0 % PERFORMANCE Pipe USS-CDC HTQP Minimum Collapse Pressure 7,020 7.020 psi External Pressure Leak Resistance — 5,620 psi Minimum Internal Yield Pressure 8,160 8.160 psi Minimum Pipe Body Yield Strength 676,000 Ibs Joint Strength 718.000 lbs Compression Rating — 431,000 Ibs Reference Length — 16,506 It Maximum Uniaxial Bend Rating — 33.4 deg/100 ft MAKE-UP DATA Pipe USS-CDC HTQ® Make -Up Loss — 5.00 in. Minimum Make -Up Torque — 15.000 ft-Ibs Maximum Make -Up Torque — 21,000 ft-Ibs Connection Yield Torque — 30,900 ft-Ibs A -LORD Drilling Procedure 5/13r2019 7.57 35 PM 1. Other than proprietary collapse and connecoon values, performance properties have been calculated using standard equations defined by Apt 5C3 and do not incorporate any additional design or safety factors- Catcutabons assume nominal pipe OD. nominal wall thickness and Specified Minimum Yield Strength (Sk1YS). 2. Undaxial bending mating shown is structural only. and equal to compaession efficiency. 3. Torques Crave been calculated assuming a thread compound friction fac!w of 1.0 and are recommended only Field make-up torques may require adjustment based or. actual held condrbons (e.gmake-up speed, temperature. thread compound. etc.). 5. Reference "th is calculated by pint strength divided by nominal threaded and coupled weight w4pr, 1.5 safety factor. 5. connection external pressure teak resistance has been verified to 80% API pipe body collapse pressure falrnving the guidelines of API 5C5 Cat h. Page 33 Revision 0 May, 2019 0 Hilcorp Energy Company A -LORD Drilling Procedure 15.7 Ensure to run enough liner to provide for approx 200' overlap inside 9-5/8" casing. Ensure hanger/pkr will not be set in a 9-5/8" connection. 15.8 Before picking up Baker SDD liner hanger assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 15.9 M/U Baker SDD liner hanger assy. Fill liner tieback sleeve with "Pal mix", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 15.10 RIH one stand and circulate a minimum of one liner volume. Note weight of liner. 15.11 RIH w/ liner on DP no faster than 1-1/2 min / stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 15.12 M/U top drive and fill pipe while lowering string every 10 stands. 15.13 Slow in and out of slips. 15.14 Circulate 1-1/2 drill pipe and liner volume at 9-5/8" shoe prior to going into open hole. Stage pumps up slowly and monitor for losses. Do not exceed 60% of the nominal liner hanger setting pressure. Nominal liner hanger setting pressure is 2500 psi. 60% of this value is 1500 psi. 15.15 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 15.16 Continue to fill the DP every stand down using fill up line on rig floor. Do not stop to fill the drill pipe. 15.17 P/U the cmt stand and tag bottom with the liner shoe. P/U 2' off bottom. Note slack -off and pick-up weights. Record rotating torque values at 10, 20, & 30 rpm. 15.18 Stage pump rates up slowly to circulating rate without exceeding 60% of the liner hanger setting pressure (1500 psi). Circ and condition mud with the liner on bottom. Reduce the low end rheology of the drilling fluid by adding water and thinners. 15.19 Reciprocate & rotate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 34 Revision 0 May, 2019 A-LORD Drilling Procedure 16.0 Cementing 7" Production Liner 16.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement PUMP. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 16.2 Attempt to reciprocate & rotate the liner during cmt operations. 16.3 Cement volume is based on annular volume + 50% open hole excess. Job will be a single stage design. Cement from shoe to TOL. 16.4 Pump 5 bbls 12 ppg tuned spacer. 16.5 Test surface cmt lines to 4500 psi. 16.6 Pump remaining 25 bbls 12 ppg tuned spacer. 16.7 Mix and pump 13.0 ppg class "G" ExpandaCEM curt per below recipe. Ensure cmt is pumped at designed weight. Job is designed to pump 50% OH excess. Cement Calculations 9-5/8" x 5 DP" Overlap: 200' x 0.0489 = 9.8 bbls 9-5/8" x 7" Liner Overlap: 200' x 0.0256 = 5.2 bbls 8-1/2" OH x 7" Liner: (15,882 — 9,605') x 0.0226 x 1.50 = 213 bbls Shoe Track: 120' x 0.038 = 4.6 bbl Total Volume (bbls): 9.8 + 5.2 + 213 + 4.6 = 233 bbls Total Volume (ft3): 233 bbls x 5.615 ft3/bbl = 1308 ft3 Total Volume (sx): s =` 5 Page 35 Revision 0 May, 2019 Hilcorp Esy c—v-y Slurry Information: 16.8 16.9 A-IORD Drilling Procedure Cement Slurry Design (Is' stage cement jobs): System ExpandaCem Density 13.0 lb/gal` Yield �. 3/sk 1,35, Mix Water 10.1 gal/sk Drop DP dart and displace with drilling fluid in mud pits. Reciprocate and rotate liner if hole conditions allow. Reduce pump rate to 3 bpm prior to latching DP dart into liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full displacement rate. Displacement volume can be re -zeroed at this point. 16.10 If elevated displacement pressures are encountered, position liner at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 16.11 Bump the plug and pressure up as required by Baker procedure to set the liner hanger (20% above nominal setting pressure. 2500 psi is nominal setting pressure. Pressure up to 3000 psi to confirm hanger setting. 16.12 Slack off total liner weight plus 20k to confirm hanger set. 16.13 Do not overdisplace by more than shoe track. Shoe track volume is 4.6 bbls. 16.14 Pressure up to 4200 psi to release the running tool (HRD-E) from the liner. 16.15 Bleed pressure to zero to check float equipment. 16.16 Pick up to the high -rate circulation point above the tieback extension, mark the pipe for reciprocation, do not re -tag the liner top, and circulate the well clean. 16.17 Watch for cement returns and record the estimated volume. Rotate & circulate to clear cmt from DP. 16.18 POOH, verify setting tools Page 36 Revision 0 May, 2019 A -LORD Drilling Procedure Hilcorp C—pany Backup release from liner hanger: 16.19 If the HRD-E tool still does not release hydraulically, left-hand (counterclockwise) torque will have to be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure and ensure that the tool is in the neutral position. Apply left-hand torque as required to shear screws. 16.20 NOTE: Some hole conditions may require movement of the drillpipe to "work" the torque down to the setting tool. 16.21 After screws have sheared, the top sub and body of the setting tool will turn 1/4 turn. Then proceed slacking off set -down weight to shear second set of shear screws. The top sub will drop 1-3/4 inches. At this point, the bottom sub no longer supports the collet fingers. Pick straight up with workstring to release collet from the profile. Page 37 Revision 0 May, 2019 0 HilmiT Energy Company 17.0 Wellbore Clean Up & Displacement A -LORD Drilling Procedure 17.1 Remove 7" casing ram. Install and test 4" casing ram for coverage of clean out string. If a different OD workstring is used — install and test corresponding rams in BOP. 17.2 M/U PBR polish mill assy and TIH to liner top. Confirm setting depth of liner top on AM report. Polish PBR and liner top per BOT instructions. TOH. 17.3 M/U liner top packer and TIH. Set packer per BOT instruction. Test annulus to 1500 psi 17.4 M/U casing clean out assy complete with casing scraper assys for each size casing in the hole. • 6" bit or mill • Casing scraper & brush for 7" 29# casing (MI Swaco - Multiback) • +/- 6277' x 4" workstring. • Crossover (No PBR Polish Mills) • Casing scraper & brush for 9-5/8" 47# casing • (2800') 5" DP • Casing scraper & brush for 9-5/8" 47# casing • 5" NC-50 to surface. 17.5 TIH & clean out well to landing collar (+/- 15,882 MD). • Circulate as needed on trip in if string begins to take weight. • Circulate hi-vis sweeps as necessary to carry debris out of wellbore. • Ensure 6" bit is worked down to the landing collar. • Space out the cleanout BHA so that the 6" bit reaches the 7" landing collar when crossover is +/- 30' above the 9-5/8" liner top. 17.6 After wellbore has been cleaned out satisfactorily using mud, test casing to 3500 psi / 30 min. 17.7 Displace drilling fluid in wellbore with a hi-vis pill followed by FIW. • Circulate 3 to 4 B/U until clean-up is satisfactory with water. Do not recirculate fluid, pump and dump. • Pump as fast as feasible. Slow circulating rates will string out the interface and cause a much longer clean up phase. • Short trip the assy to bring the upper 9-5/8" multi -back assy to surface. • RIH again & tag landing collar w/ 6" bit. Continue circulation as necessary until fluid cleans up. Make another short trip if necessary. • Target NTUs are 80 - 100. 17.8 17.9 TOH w/ clean out assy. LDDP & 4" workstring on the trip out. Note any abnormal wear on the clean out assy components. Make CBL logging passes. Log both the 7" prod liner and 9-5/8" casing. Page 38 Revision 0 May, 2019 A-IORD Drilling Procedure Hilcorp Energy Company 18.0 BOP Schematic (12-1/4" and 8-1/2" Hole Sections) Page 39 Revision 0 May, 2019 19.0 Wellhead Schematic 1114"' , kl-t. It Monopod A-10 13 3/8X9 5/8X3 1/2 X 3 1/2 Tree assy, dual block, CIW-F, 115MX31/85MX 3 1/8 5M, prepped on 5 3/64 center, 3" CIW seal pockets, % npt control fine exits Tubing head, CIW-DCB, 13 518 3M X 11 5M, w/ 2- 2 1/16 SM SSO, X-bottom prep Casing head, Shaffer KD, 135/83MX 13 3/8 SOW, w/ 2. 2" 1PO, A -LORD Drilling Procedure Nfonopod Platform A-10 Current 01/03/2014 Tubing hanger, dual, CIW- DCB, 11 5M X 3 Y EUE 8rd lift X 3 % IBT bottom, w/ 3" type H BPV profile, 1/8 non cont control line ports in hangers AW-F, 2 1/16 5M FE, HWO, AA ClW ball valve Page 40 Revision 0 May, 2019 20.0 Days Vs Depth 0 4 -.-- 2000 4000 6000 x 8000 m N 10000 12000 14000 16000 18000 4- 0 Days Vs Depth A-IORD Drilling Procedure 0 RD 5 10 15 20 25 30 35 40 45 50 Days Page 41 Revision 0 May, 2019 0 Hilcorp Energy Company 21.0 Estimated Formation Tops and Pressures 511412019 9:39 KOP Tyonek 2A Tyonek 3A Tyonek 4A Tyonek 2465T Tyonek 26-7ST Tyonek 26-75B Fault-1 Bruin Bay Fault crossing 9 5/8 casing Top Tyonek E Coal 46-6 Top Tyonek F Top Tyonek gas sands Base Tyonek gas sands Coal 39 Tyonek Oil zones (G-zone) Coal 59 Hemlock TD (Lower Hemlock/West Foreland) Lower Tyonek/Hemlock A-IORD Drilling Procedure Drill sidetrack producer ta rgeti ng Lower Tyonek and Hemlock. This is an extension of North Trading Bay field. This well will targetthe Lower Tyo nek/Hem lock in an un-drilled area recently identified on newly acquired seismicdata. LITHOLOGY Kick-off point Sand/shale/coal Sand/shale/coal Sand/shale/coal Sand/shale/coal Sand/shale/coal Coal Sand/Shale/coal Sand sand Coal Sand Coal Sand Out of 13 3/8 1,038 1,016.6 1017 Hydrocarbon/water 857 848.0 -848 Hydrocarbon/water 1,073 1,048.0 -1048 Hydrocarbon/water 1,236 1,196.0 -1196 Hydrocarbon/water 2,121 2,063.0 -1962 Hydrocarbon/water 2,364 2,294.0 -2294 Hydrocarbon/water 2,716 2,595.0 -2533 2,757 2,626.6 -2627 7,555 5,162.8 -5163 9,805 6,327.1 -6327 10,330 6,598.8 -6599 11,605 7,258.6 -7259 11,805 7,362-1 -7362 gas/water 14087.14 8,721.6 -8722 gas/water 14418.19 8,975.2 -8975 14,593 9,109.2 -9109 oil 15126.11 9,517.5 -9518 15298.17 9,649.3 -9649 oil 15,308 9,657.4 -9657 15,868 10,086.4 -10086 2) There are some "shallow" Tyonek sands that produce gas at North Trading Bay Field around 14200VD depth. ° 3) We will be drilling through mostof the Tyonek section atappro)dmately 57 degrees inclination. Page 42 Revision 0 May, 2019 Alaska 101 62.0 8.85 390 0.46 8.69 474 0.45 8.69 541 0.45 8.69 932 0.45 8.69 1037 0.45 8.69 1173 0.45 8.69 1187 0.45 8.69 2334 0.45 8.85 2910 0.46 8.85 3035 0.46 8.85 3339 0.46 8.85 3387 0.46 8.85 4012 0.46 8.85 4129 0.46 8.85 4190 0.46 9.04 4473 0.47 9.04 4535 0.47 9.04 4539 0.47 9.64 4741 0.47 A,.t7 F A -LORD Drilling Procedure Hilcorp Energy Company 22.0 Anticipated Drilling Hazards 12-1/4" Hole Section: Lost Circulation/Hole Cleaning: Maintain the density at 9.2 to 9.6 ppg. Preventing lost circulation, Optimize solids control equipment to maintain density and sand content, Maintain YP between 13-24 to optimize hole cleaning and to control ECD. Pump high viscosity sweeps to enhance hole -cleaning efforts. Monitor sweep effectiveness. Wellbore stability / Coal Drilling: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to reduce the chances for losses and differential sticking. LCM (BARACARBs 5/25/50, STEELSEAL 50/100/400) and shale stabilizers (BAROTROL PLUS, SOLTEX) should be maintained at elevated concentrations while drilling coals to help strengthen the wellbore. PAC L/DEXTRID LT should be used for filtrate control. While drilling, monitor the torque and drag to determine if liquid lubricant is required. If so, approval from town will be required prior to additions of lubricants. When penetrating high -clay content sections, the addition of CON DET PREMIX is recommended to reduce the incidence of bit balling and shaker blinding. Maintain the pH in the 8.5 — 9.5 range with caustic soda or KOH. H2S: H2S is not present in this hole section. No abnormal temperatures are present in this hole section. Page 43 Revision 0 May, 2019 A -LORD Drilling Procedure HilmTEnergy Company 8-1/2" Hole Section: Lost Circulation/Hole Cleaning: Maintain the density at 9.2 to 9.6 ppg. Preventing lost circulation, Optimize solids control equipment to maintain density and sand content, Maintain YP between 13-24 to optimize hole cleaning and to control ECD. Pump high viscosity sweeps to enhance hole -cleaning efforts. Monitor sweep effectiveness. Wellbore stability / Coal Drilling: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to reduce the chances for losses and differential sticking. LCM (BARACARBs 5/25/50, STEELSEAL 50/100/400) avoid using the shale stabilizers and "Black" products while drilling the 8-1/2" hole section if possible. We don't want to put anything in the mud that will adversely affect "skin" and have a negative effect on production from the well bore. PAC L/DEXTRID LT should be used for filtrate control. While drilling, monitor the torque and drag to determine if liquid lubricant is required. If so, approval from town will be required prior to additions of lubricants. When penetrating high -clay content sections, the addition of CON DET PREMIX is recommended to reduce the incidence of bit balling and shaker blinding. Maintain the pH in the 8.5 — 9.5 range with caustic soda or KOH. H2S: J H2S is not present in this hole section. ?-� r No abnormal temperatures are present in this hole section. '41"' J Page 44 Revision 0 May, 2019 A -LORD Drilling Procedure Hilcorp Esr C-p-y 23.0 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 45 Revision 0 May, 2019 0 Hilcorp Energy Company 24.0 Choke Manifold Schematic A-IORD Drilling Procedure r 0 0 0 L Z OU Page 46 Revision 0 May, 2019 Hilcolp Energy Company 25.0 Casing Design Information Calculation & Casing Design Factors Monopod Platform DATE: 5.14.2019 WELL: A-10RD FIELD: Trading Bay DESIGN BY: Monty M Myers Desian Criteria: Hole Size 12-1/4" Hole Size 8-1/2" Drilling Mode MASP (12-1/4" hole): MASP (8-1/2" hole): Production Mode MASP (Sec 2,3,4): A -LORD Drilling Procedure Mud Density: 9.0 ppg Mud Density: 9.0 ppg See attached MASP determination and calculation 660 psi 2500 psi 2500 Collapse Calculation: Section Calculation All Max MW gradient external stress (9.5 ppg) and casing evacuated for the internal stress Calculation/Specification Casing Section 1 2 3 Casing OD 9-5/8" 7" Top (MD) Top (TVD) 0 0 9,605 6,223 Bottom (MD) 9,805 16,002 . . ................. _ Bottom (TVD) _ 6,326 1 10,187 Length 9, 805 6, 397 _._.____.....__...._........___.___.............. __...._._._._..-.._ _.__._- ....._........._.__ Weight (ppf) 47 29 Grade L-80 L-80 Connection DWC/C CDC-HTQ Weight w/o Bouyancy Factor (Ibs) 460,835 185,513 Tension at Top of Section (Ibs) 646,348 185,513 Min strength Tension (1000 Ibs) 1086 676 Worst Case Safety Factor (Tension) r___._.______..._.__......._..........__..__. ..__.__. Collapse Pressure at bottom (Psi) 1.68 __...._._.__..._._........._.... 2,961 3.64 __...__.__.___� ._. 4,768 ..... ___... _... _...... ... ._ Collapse Resistance w/o tension (Psi) 4,750 7,020 Worst Case Safety Factor (Collapse) 1.60 1.47 MASP (psi) 660 2,500 Minimum Yield (psi) 6,870 8,160 Worst case safety factor (Burst) 10.41 3.26 Page 47 Revision 0 May, 2019 A -LORD Drilling Procedure Hilcorp Energy Company 26.0 12-1/4" Hole Section MASP Maximum Anticipated Surface Pressure Calculation Hit 1 12-1/4" Hole Section '!_iIC2 " A-10RD Trading Bay MD TVD Planned Top: 1,095 1,050 Planned TD: 9,805 6,326 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad KOP 1,017 449 Oil +Gas+H2O 8.5 0.460 Tyonek2A 848 390 Oil +H2O 8.8 0.460 Tyonek3A 1,048 474 Oil +H2O 8.7 0.452 Tyonek4A 1,196 541 Oil +H2O 8.7 0.452 Tyonek 2465T 2,063 932 Oil +H2O 8.7 0.452 Tyonek 26-7ST 2,294 1037 Oil +H2O 8.7 0.452 Tyonek 26-75B 2,595 1173 Oil +H2O 8.7 0.452 Fault-1 2,627 1187 Oil +H2O 8.7 0.452 Bruin Bay Fault crossing 5,163 2334 Oil +H2O 8.7 0.452 Offset Well Mud Densities Well MW range Top (TVD) Bottom (TVD) Date A-18 9.9-10.4 1,000 4,000 1968 A-28 9.3-10.4 1,000 4,000 1973 A-28RD 9.5 - 9.9 1,000 4,000 1989 A-09RD 9.5-10.3 1,000 4,000 1981 A-20RD 8.7-9.6 1,000 4,000 19M Assumptions: 1. Fracture gradient at 1,095' MD / 1,050' TVD is estimated at 0.728 psi / ft based on field test data. 2. Maximum planned mud density for the hole section is 9.5 ppg. 3. Calculations assume "Unknown" reservoir contains 100% gas (worst case). 4. Calculations assume worst case event is 2/3 evacuation of wellbore to gas. Remaining 1/3 volume in wellbore remains drilling fluid density. 5. Maximum original pressure in gas sands at 9.2 ppg EMW. Fracture Pressure at shoe considering a full column of gas from shoe to surface: 1,050 (ft) x 0.728(psi/ft)= 765 psi 765(psi)-[0.1(psi/ft)*1,050(ft)]= F660psi MASP from pore pressure (unknown gas sand at TD, at 9.2 ppg (0.4784 psi/ft) 6,327(ft) x 0.4784(psi/ft)= 3027 psi 3027(psi) - [(2/3)*O.1(psi/ft)*6,327(ft)]-[(1/3)*0.4784(psi/ft)*6,327(ft)]= 1596 psi Summary: 1. MASP while drilling 12-1/4" hole is governed by: Fracture gradient at 13-3/8" shoe Page 48 Revision 0 May, 2019 A-IORD Drilling Procedure Hilcorp Energy Company 27.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation Hilco�rp 8-1/2" Hole Section Trading Bay MD TVD �0 a � l Planned Top: 9,605 6,223�r Planned TD: 16,002 10,187��t Antidoated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG I Grad Top TyonekE 6,599 3035 Oil +H2O 8.8 0.460 Coal46-6 7,259 3339 Oil +H2O 8.8 0.460 Top T onek F 7,362 3387 Oil + H2O 8.8 0.460 Top T onek gas sands 8,722 4012 Oil + H2O 8.8 0.460 Baser onek gas sands 8,975 4129 Oil +H2O 8.8 0.460 Coal39 9,109 4190 Oil +H2O 8.8 0.460 Tyonek Oil zones (G-zone) 9,518 4473 Oil +H2O 9.0 0.470 Coal59 9,650 4535 Oil +H2O 9.0 0.470 Hemlock 9,657 4539 Oil +H2O 9.0 0.470 TD (Lower Hemlock/West Foreland) 10,086 4741 Oil +H2O 9.0 0.470 nffsetwell Mud nrncitiPc Well MW range Top (TVD) Bottom (TVD) Date A-18 9.9-10.2 3,000 6,000 1968 A-28 9.9-10.5 3,000 6,000 1973 A-28RD 9.5 - 9.7 3,000 6,000 1989 A-09RD 9.5-10.3 3,000 6,000 1%1 Assumptions: 1. Fracture gradient at 9,805' MD/ 6,327' TVD is estimated at 0.832 psi / ft based on field test data. 2. Maximum planned mud density for the hole section is 9.5 ppg. 3. Calculations assume "Unknown" reservoir contains 100% gas (worst case). 4. Calculations assume worst case event is 2/3 evacuation of wellbore togas. Remaining 1/3 volume in wellbore remains drilling fluid density. Fracture Pressure at shoe considering a full column of gas from shoe to surface: 6,327 (ft) x 0.832(psi/ft)= 5264 5264(psi) - [0.1(psi/ft)"6,327(ft)]= 4631 psi MASP from pore pressure (unknown gas sand at TD, at 9.0 ppg (0.468 psi/ft) 10187(ft) x 0.468(psi/ft)= 4768 psi 4768(psi)-((2/3)*0.1(psi/ft)*10187(ft)]=j(i *(Y468(psijff)'10187(ft)]= z500psi (ummary: 3 1. MASP while drilling 8-1/2" hole is governed by pore pressure minus 2/3 of wellbore evacuated togas (remaining 1/3 remains 9.2 ppg drilling fluid) Page 49 Revision 0 May, 2019 n to �3 '76 A -LORD Drilling Procedure Hilcorp EnaW Company / 1/ 28.0 Spider Plot (NAD 27) '� r S-o1ftD BHL — — 1 1 ! 8.01 BHL-'��' ff3 B"L •ADL035431,',' TBS-014BHL �LiJ � she L , TS-05RDi BHL BHL TS-tRD)BH /✓ i i TS-0.�REZSHFt$ p u rf ' ii&03P>} BHL �' ` 2 BHL t �SA2RD BHL 2DPNiHL ) PL_ B%L ,� r \ ` i ADLO18776 R r / TS BHL ADL392193 IS-07SHL /' s"L s SHL TsosPBeHL N TRADING;' ° ° ,', ADL017597 B,�Y UN1t` ! a ! y ti eta •I5-07 BHL T- OL o �-""' t/ $.07RD BHL / X2WM 14.3?18HL TBS-01-T BH -02 BHL TT t TS-02 BHL ! 1 t f I 1 l A- 3 Bhp '�-d 03 BHL A-09 BHL 1\ •, . t�D ,5 BHL 1,' BHL to sBtTILI,0A-0M2 SHL 17B'B�L 41 BHL A-01RD& /, aa• a \ice BHL l l ✓^1- -� — _ — — — — — ~ i BHL _ *A-03 BHL InTempore_SHL 1 yy l r ADLO18731 TR7 ING r BAY\ NIT 1 1 aa• !, aa• a � 90 l \ , l A-20 • 9 t ` \ l 1 � \ l 1 t d415RD BIiL Trading Bay Unit A-1ORD Well wp04 S-09 BgL In Temporc_TPH a a a InTcmporc_BHL . S009 _a'— See. 2 ADL393693 9 aa' a Legend • In Tempore_SHL ! Other Surface Hole Location X In Tempore_TPH • Other Bottom Hole Location — In Tempore_— — Well Paths BHL 0 1.000 2.000 3,000 Feet ` Alaska State Plane Zone 4, NAD27 Map Date: 511012019 Page 50 Revision 0 May, 2019 Hilcorp Energy Company 29.0 As Built (NAD 27) 'AELL A-31 SLUT 4 GANOPOO PLATFORM ASSUILT SURFACE LOCATION A� a NAU 23 INTSI SECTION LINE NOT TO SCALE (NTSI ? NOTES 1. BASIS OF HORIZONTAL CONTROL: NAO&3 US FEET POSITION {EPOCH 2O10) AND VERTICAi CONTROL (NAVD88) IS AN OPUS SOLUTM FROM NGS STATIONS KENS, AC51 AND ANC2 TO ESTABLISH POINT 43200. THE ALASKA STATE PLANE COORDINATES NAD 83 ZONE 4 IN FEET ARE- N = 2499331,3W E = 1354193 V5 ELEV. - 150.436 (NAVDBBI 2. SECTION LINES SHOWN ARE EXTENSIONS OF PROTRACTED vALLFES. 3. DATUM TRANSFORMATIONS (NAD63 ASPZ4 TO NA027 ASPZA) WERE DONE USING CORPSOON SOFTWARE VERSION &0.1. A -LORD Drilling Procedure SECTION CORNER 1PROTRACTEDt — N: 2S2II6W-590' E: 21"7.740 Ak� SCALE a o nn FEET W Z J 2 O I- 0 1A. fn ' HILLCORP ALASKA, LLC MONOPOD PLATFORM WELL A-31 WE COOK INLET ALASKA MVAN `n AS BUILT SURFACE LOCATION """` . NAD 27 CAPlrtT �,,. Rfi%ls aN $X{:iixx. nK • k�)1 EN4. tifNLL.1Y6�LwrG'i.19! Tlilrorrp AlasLu.11C 1 -.,'. Ti PROTRACTED SEC. 04 T09N R13W SEWARD MERIDIAN, ALASKA �T q I 1 "' Page 51 Revision 0 May, 2019 Hilcorp Energy Company A -LORD Drilling Procedure 26 A-12RD 569 1611 2523125.048 218864.982 60° 53' 48.646" 151' 34' 43.631" 27 A-20RD 558 1598 2523111.633 218875.892 60' 53' 48.516" 151" 34' 43.404" 28 A-2 568 1607 2523120.959 218866.098 60' 53' 48.606" 151° 34' 43.607" 29 A-16RD 565 1603 2523117.315 218869.154 60° 53' 48.571" 151' 34' 43.543" 30 1 A-26 1 563 1159912523112.9311218871.5501 60- 53' 48.528" 151" 34' 43.493" 31 A-10 570 1602 2523116.280 218864.515 60° 53' 48.559" 151' 34' 43.637" 1 32 1 A-502 567 1599 2523112.871 218867.324 60° 53' 48.526" 151' 34' 43.578" rcInc ENGINEERING I MAPPING i SURVEYING I TESTING P O. 8O% 468 SOLDOTNA AK 99E89 VOICE: 19071281J218 FAX 1907,28i126u EMAIL. SAKUJ4E0h1CLANECG.COh1 / 1Tlleorll Alaska., I,11. PROJECT HILLCORP ALASKA, LLC MONOPOD PLATFORM WELLS COOK INLET ALASKA AS BUILT SURFACE LOCATION NAD 27 REVISION DATE 36'3/14 DRAWN BY ice SCALE. WA PROJECT NO 140027 BOOK NO. 14 OB LOCATION PROTRACTED SEC. 04 T09N R13W SEWARD MERIDIAN, ALASKA SHEET OF 2 Page 52 Revision 0 May, 2019 Hilcorp Energy Company 30.0 Offset MW vs TVD Chart IV W vs TVD Offsets 0 1000 2000 3000 4000 51Q O 6000 7000 2DW 9000 1iO 11? 12 A-IORD Drilling Procedure � I. I iA-1S (1968) A-28 (1973) A-2aRD (1999) A-09RD (19$1) -A-20RD (1990) A-31 Planned f I I i i 1 `(t I I i ; � ; i ; 1 � E E I i 3 � 3 I a 9 10 11 12 13 Mead Weight (PPG) 14 15 Page 53 Revision 0 May, 2019 A-IORD Drilling Procedure Hilcorp Energy Company 31.0 Directional Plan (wp04) Page 54 Revision 0 May, 2019 Hilcorp Alaska, LLC BAI"UG HES Location: Cook Inlet, Alaska (Offshore) Slot: slot #31 aGEcompany Field: Trading Bay Field Well: A-10RD F cili : MON POD Pla f rm Wellbore: A-10RD .-I inch=- Easting (ft) -1500 0 1500 3000 4500 6000 7500 9000 10500 7500 6000 A-10RD_wp04_Polygon O 0 4500 A-10RD_wp04_T01 - 71n Casing Z O 3000 S 9.625in Casing y A � 1500 -g225o _ 13.375in Casing 0 _ slot #31 ry 0 Ln3 375in Casing Tie Or� trod of Build 4.10°/100ft End of 3D Arc 4 07°/100ft 2250 End of 3D Arc 4.50"/100ft End of 3D Arc (S) r a 4500 N m O b 9.625in Casing r j 6750 2 F- End of Tangent (S) 3.00°/100ft A-10RD_wPO4_T01 - End of 3D Arc (S) 9000 End of Tangent .b Tin Casing A-10RD w 04_Pol on _ P Y9 -,-End of Tangent � ... 11250 ' 13500 -4500 -2250 0 2250 4500 6750 9000 11250 13500 Vertical Section (ft) Sw 1l-h=« Azimuth 64.97° with reference 0.00 N, 0.00 E Plot reference wellpath is A-10RD_wp04 Grid System: NAD27 / TM Alaska SP, Zone 4 (5004), US feet True vertical depths are referenced to Actual Datum (RKB) North Reference: True north Measured depths are referenced to Actual Datum (RKB) Scale: True distance Actual Datum (RKB) to mean sea level: 101 feet Depths are in feet mean sea level to Mud line (At Slot: slot #31): 0 feet Created by: ulricard on 2019-05-10 Coordinates are in feet referenced to Slot Database: WA ANC Defn Well Profile Data Design Comment MD (ft) Inc (°) Az (°) TVD (ft) Local N (ft) Local E ft DLS (°/100ft) VS (ft) Tie On 1106.00 26.000 245.000 1077.55 -86.56 -160.53 3.03 -182.08 End of Build 1150.00 26.340 245.000 1117.04 -94.76 -178.12 0.77 -201.49 End of 3D Arc 2000.00 8.500 60.000 1943.84 -144.59 -298.34 4.10 -331.50 End of 3D Arc 2300.00 20.500 50.000 2233.79 -99.57 -238.68 4.07 -258.39 End of 3D Arc S 3173.45 58.839 65.259 2894.97 165.63 236.69 4.50 284.53 End of Tangent (S) 13071.55 58.839 65.259 8016.62 3710.47 7929.23 0.00 8754.44 End of 3D Arc (S) 13699.54 40.000 65.170 8423.30 3909.47 8360.32 3.00 9229.25 End of Tangent 15367.46 40.000 65.170 9701.00 4359.69 9333.33 0.00 10301.36 End of Tangent 16001.79 40.000 65.170 10186.93 4530.91 9703.38 0.00 10709.10 Planned Wellpath Geographic Report - including Position Uncertainty • •• • ■ - ■ , • -• 05/10/19 at 09:54 using WellArchitect 5.1 Hilcom Alaska, LLC Cook Inlet, Alaska (Offshore) Trading Bay Field MONOPOD Platform slot#31 A -LORD A-1ORD A -LORD wp04 04/01/2019 SDI <0-900>, MSS <957-7073> at 1106.00 MID U lricard Minimum curvature Ma nelic North is 19.46 degrees East of True North U2.00 Sld Dev WA ANC Defn RAW ■ - • •. ■. ■. ■. • • •■ NAD27 / TM Alaska SP, Zone 4 (5004). US feet True 0,99999 1.38 West Slot Actual Datum (RKB) Actual Datum (RKB) mean sea- 101.00 ft 101.00 ft 101.00 ft E 0.00 ft N 0,00 ft 6497° included 0.00 ft Start ■End 0.00 1 MD 900.00 SDI Kee er -3.56 Positional UncertaintV Model roMWD v1.1 Standard -7.51 SDI <0-900> 216864.52 218872.11 219397.72 Log Name I Comment 2523116.28 4 2523119.66 2521500.60 _ 60°53'48.559"N 60°53'48.594"N 60°53'32.779"N Wellbore A-10 151°34'43.636"W 151°34'43.485"W 151034'32.077"W 0.00 0.00 0.00 0.00 - - 900.00 1106.00 BHI Photomechanical Magnetic (Stan ardL MSS <0-7073'> _ A-10 1106.00 2150.00 SDI Keeper gyroMWD vt.t Standard U date vdth hole sizes A-10RD-- 2150.00 16001.79 BHI OnTrak Standard Update Wth hole sizes A-10RD DiameterString / 17.5in Open Hole ■ 1106.00 End MID 1125.43 interval 19.43 Start TVD 1077.55 End TVD 1095.00 -86.56 -160.53 -90.17 -1611 7 A -LORD - 13.375in Casin 1106.00 1125.43 19.43 1077.55 1095.00 -86.56 -160.53 -90.17 -168.27 _ ,A-10RD A -LORD _ 12.25in O en Hole 1106.00 10000.00 8894.00 1077.55 6427.29 -86.56-160.53 2610.45 5542.10 9.625in Casin 1106.00 10000.00 8894.00 1077.55 6427.29 -86.56-160.53 2610.45 5542.10 A -LORD A-10RD A-1oRD __ _ 8.5in O en Hole 1106.00 16000.00 14694.00 1077.55 10185.56 -B6.56-160.53 4530.42 9702.34 7in Casing 1106.00 , 16000.00 1 14894.00 1077.55 10185.56 -86.56-160.53 4530.42 9702.34 Target Name A-10RD wp04 TO1 4 Pol on A-10RD 0l. ■ 13699.54 0.00 TVD 8423.30 10200.00 North 3909.47 - 4565.33 East 8360.32 10144.63 Grid East 227316.44 229116.00 Grid North 2526823.30 2527436.00 Latitude 60°54'27.028"N 60°54'33.472"N L.ng,tud. 151°31'54.590' 151°31'18.499"W Shape _ _Dint of on Comment ■ 0.00 1 Inclination 0.00 Azimuth 73 35 TVD 0.00 TVDSSOLS -101.00 OAO 0.00 218864.52 2523116.28 60°53'48.559"N 151 °34'43.636" r 0.00 Toolface 73.35 Build Rate rr 0.00 Turn Rate rr 0.00 Vert Sect 0.00 Major Semi 0.00 Minor Semi 0.00 Vert Semi 0.00 Minor Azim Comments 0.00 25.00 0.11 73.35 25.00 -76.00 0.01 0.02 218864.54 2523116.29 60°53'48.559"N 151°34'43.636" 0.44 0.00 0.44 293.40 0.02 0.09 0.09 2.30 163.35 _ _ 50.00 0.21 73.35 50.00 -51.00 0.03 0.09 218864.61 2523116.30 60°53'4E.560"N 151°34'43_635" 0.40 -59.00 0.40 0.00 0.09 0.18 0.17 2.30 163.35 _ 75.00 0.27 56.16 75.00 -26.00 0.07 0.18 218864.70 2523116.35 60°53'48.560"N 151°34'43.633" 0.37 15 -7.98 0.24 -68.76 0.20 0.27 0.26 2.30 340.40 _ 100.00 0.21 49.36 100.00 -1.00 0.14 0.27 218864.79 2523116.41 60°5348.561"N 151°34'43.631" 0.27 -156.70 -0.24 -27.20 0.30 0.37 0.35 2.30 335.99 125.00 0.17 43.41 125.00 24.00 0.19 0.33 218864.85 2523116.46 60°53'48.561"N 151°34'43.630" 0.18 15.70 -0.16 -23.80 0.38 0.46 0.44 2.30 332.11 150.00 0.42 52.82 150.00 49.00 0.27 0.43 218864.95 2523116.54 60°53'48.562"N 151°34'43.628" 1.02 13.27 1.00 37.64 0.50 0.55 0.52 2.30 329.75 175.00 _ 0.66 57.69 175.00 74.00 0.41 0.62 218865.15 2523116.67 60°53'48.563"N 151°34'43.624" 0.98 -13.14 0.96 19.48 0.73 0.64 0.61 2.30 329.10 200.00 0.80 55.36 200.00 1 99.00 0.58 0.89 218865.42 2523116.84 60°53'48.565"N 151°34'43.619" 0.57 -165.03 0.56 -9.32 1.05 0.73 0.70 2.31 328.77 225_00 0.72 53.65 224.99 123.99 0.7E 1.16 218865.69 2523117.03 60°5348.567"N 151°34'43.613" 0.33 93.01 -0.32 -6.84 1.37 0.82 0.79 2.31 328.27 _ 250.00 0.73 66.62 249.99 148.99 0.93 1.43 218865.97 2523117.18 60°53'48.568"N 151°34'43.608" 0.66 127.44 0.04 51.88 1.69 0.92 0.87 2.31 148.53 275.00 0.58 102.03 274.99 173.99 0.97 1.70 218866.24 2523117.21 60°53'48.569"N 151°34'43.602" 1.69 74.66 -0.60 141.64 1.95 1.01 0.96 2.32 150.82 300.00 1.08 145.50 299.99 198.99 0.75 1.96 218866.49 2523116.98 60°53'48.567"N 151 °34'43_597" 3.08 48.04 2.00 173.88 2.09 1.09 1.05 2.32 155.00 325.00 1.70 165.35 324.98 223.98 0.19 2.18 218866.71 2523116.42 60°53'48.561"N 15113443.592" 3.10 68.4479.40 2.06 1.1E 1.14 2.32 159.66 350.00 2.19 187.58 349.97 248.97 -0.64 2.21 218866.72 2523115.59 60°53'48.553"N 151°34'43.592" 3.56 61.31 1.96 88.92 1.74 1.26 1.22 1 2.33 163.37 375.00 3.20 212.01 374.94 273.94 -1.70 1.78 218866.26 2523114.54 60°53'48.543"N 151°34'43.600" 6.03 34.35 4.04 97.72 0.89 1.34 1.31 2.33 164.75 400.00 3.92 218.94 399.89 298.89 -2.96 0.87 218865.32 2523113.30 60°5348.530"N 151 °3443.619' 3.36 40.42 2 8EF 27.72 -0.46 1.43 1.40 2.34 164.70 _ 425.00 4.71 226.71 424.82 323.82 -4.33 -0.41 218864.00 2523111.96 6005348.517"N 151°34'43.645" 3.92 45.16 3.16 31.08 -2.20 1.51 1.49 2.34 164.69 450.00 5.54 234.81 449.72 348.72 -5.73 -2.14 218862.24 2523110.61 60°53'48.503"N 151*34'43.680' 4.40 36.31 3.32 32.40 4.37 1.60 1.58 2.34 164. 00 475.00 6.32 239.86 474.59 373.59 -7.11 -4.32 218860.03 2523109.27 60°53'48.489"N 151'34'43.724"o 3.75 19.20 3.12 20.20 -6.92 1.69 1.66 2.35 165. 77 500.00 7.23 242.36 499.41 398.41 -8.53 -6.90 218857.41 2523107.91 60°53'48.475"N 151°34'43.776' 3.83 1.65 3.64 10.00 -9.87 1.78 1.75 2.35 165.80 525.00 8.28 242.57 524.18 423.18 -10.09 -9.90 218854.38 2623106.43 60°53'48.460"N 151°34'43.836" 4.20 -3.54 4.20 0.84 -13.24 1.87 1.84 2.35 164.41 550.00 9.24 242.20 548.89 447.89 -11.86 -13.27 218850.97 2523104.74 60°53'48.443"N 151*34'43.905' 3.85 -4.75 3.84 -1.48 -17.04 1.96 1.93 2.35 162.21 575.00 9.88 241.89 573.54 472.54 -13.81 -16.94 218847.26 2523102.89 60°53'48.423"N 151°34'43.979" 2.57 -0.63 2.56 -1.24 -21.19 2.05 2.03 2.36 160.6E 600.00 10.37 241.86 598.15 497.15 -15.88 -20.81 218843.33 2523100.91 60°5348.403"N 151°34'44.057" 1.96 3.95 1.96 -0.12 -25.58 2.14 2.12 2.36 161.83 625.00 10.89 242.05 622.72 521.72 -18.04 -24.88 218839.21 2523098.84 60°5348.382"N 151°34'44.139" 2.08 -9.00 2.08 0.76 -30.18 2.22 2.22 2.37 179.95 650.00 11.67 241.44 647.24 546.24 -20.36 -29.19 218834_85 2523696.63 60-53-48.359"N 151°34'44.226" 3.16 5.55 3.12 -2.44 -35.06 2.32 2.32 2.37 238.38 675.00 12.26 241.71 671.70 570.70 -22.83 -33.75 218830.23 2523094.27 60°53'48.335"N 151°34'44.319' 2.37 1.92 2.36 1.08 40.24 2.43 2.41 2.38 242.05 700.00 13.07 241.83 696.09 595.09 1 -25.42 -38.58 218825.34 2523091.80 60°53'48.309"N 151°34'44.416" 3.24 -0.17 3.24 0.48 -45.71 2.54 2.50 2.38 242.37 725.00 13.86 241.82 720.40 619.40 -28.17 43.71 218820.15 2523089.17 60°5348.282"N 151°34'44.520' 3.16 2.10 3.16 -0.04 -51.52 2.66 2.54 2.38 242.49 750.00 14.69 241.94 _ 744.63 643.63 -31.07 -49.15 218814.64 2523086.40 60°53'4E.253"N 151°34'44.630' 3.32 0.35 3.32 0.48 -57.68 2.79 2.69 2.39 242.47 775.00 15.58 241.96 768.76 667.76 -34.14 -54.91 218808.81 2523083.47 60°53'48.223"N 151°34'44.746" 3.56 1.03 3.56 0.08 -64.20 2.92 2.78 2.39 242.40 800.00 16.36 242.01 792.80 691.80 -37.37 -60.98 218802.66 2523080.39 60°53'48.191"N 151°34'44.869" 3.12 1.87 3.12 0.20 -71.06 3.07 2.88 2.40 242.34 825.00 17.08 242.09 816.74 715.74 -40.74 17.33 218796.23 2523077.17 60°53'48.158"N 151'34'44.997" 2.88 3.59 2.88 0.32 -78.25 3.23 2.97 2.40 242.27 Page 1 of 3 3406.00 58.84 65.26 3015.30 2914.30 248.91 417.42 219287.81 2523355.07 60753-51.010N 151°34'35.199' 0.00 0.00 0.00 0.00 483.53 19.83 10.00 7.84 60.56 3506.00 58.84 65.26 3067.05 2966.05 284.73 495.14 219366.36 2523389.00 60°53'51.363"N 151°34'33.628' 0.00 0.00 0.00 0.00 569.10 21.86 10.20 8.24 61.24 3606.00 58.84 65.26 3118.79 3017.79 320.54 572.85 219444.92 23 25422.93 60°53'51.716"N 151°34'32.057' 0.00 0.00 0.00 0.00 654.67 23.93 10.41 8.66 61.76 3706.00 58.84 65.26 3170.53 3069.53 356.35 650.57 219523.47 2523456.86 60°53'S2.068"N 151 °34'30.486' 0.00 0.00 0.00 0.00 740.25 26.02 t0.63 9.11 62.16 3806.00 58.84 65.26 3222.28 3121.28 392.17 728.29 219602_03 2523490.80 60°53'52.421'N 151-34'28.915' 0.00 0.00 0.00 0.00 825.82 28.13 10.85 9.57 62.48 3906.00 58.84 65.26 3274.02 3173.02 427.98 806.01 219680.59 2523524.73 60°53'52.774"N 151°34'27.344' 0.06 0.00 0.00 0.00 911.39 30.26 11.09 10.04 62.75 4006.00 58.84 65.26 3325.77 3224.77 463.79 883.72 219759.14 2523558.66 60°53'53.126"N 151'34'25.773' 0.00 0.00 0.00 0.00 996.96 32.40 11.33 10.53 62.97 4106.00 58.84 65.26 3377.51 3276.51 499.61 961.44 219837.70 7M35W.59 60°53'53.479"N 151°34'24.202" 0.00 0.00 0.00 0.00 1082.53 34.55 11.58 11.03 63.16 4206.00 58.84 65.26 3429.25 3328.25 535.42 1039.16 219916.26 2523626.52 60°53'53.831"N _ 151°34'22.631' 0.00 0.00 0.00 0.00 1168.10 36.71 11.84 11.54 63.32 4306.00 58.84 65.26 3481.00 3380.00 571.24 1116.88 219994.81 2523660.45 60°53'54.184"N 151°34'21.060' 0.00 0.00 0.00 6.00 1253.67 38.88 12.10 12.06 63.46 4406.00 58.84 65.26 3532.74 3431.74 607.05 1194.59 220073.37 1 2523694.39 60053'54.536"N 15103419.488" 0.00 0.00 0.00 0.00 1339.24 41.05 12.37 12.59 63.58 4506.00 58.84 65.26 3584.49 3483.49 642.86 1272.31 220151.92 2523728.32 60°53'54.889"N 151°34'17.917' 0.00 0.00 0.00 0.00 1424.81 43.23 12.64 13.12 63.69 4606.00 58.84 65.26 3636.23 3535.23 678.68 1350.03 220230.48 2523762.25 60053'55.242"N 151034'16.346' 0.00 0.00 0.00 0.00 1510.38 45.41 12.92 6 13.63.78 6 .00 4706 58.84 65.26 3687.97 3586.97 714.49 1427.75 220309.04 2523796.18 60°53'55.594"N 151°34'14.775" 0.00 0.00 0.00 0.00 1595.96 47.59 13.21 14.20 63.87 4806.00 58.84 65.26 3739.72 3638.72 750.30 1505.46 220387.59 9593830.11 60053'55.947"N 151 'Y4'13264'O 0.00 0.00 0.00 0.00 1681.53 49.78 13.50 14.75 63.94 4906.00 58.84 65.26 3791.46 3690.46 786.12 1583.18 220466.15 2523864.04 60°53'56.299"N 151°34'11.633" 0.00 0.00 0.00 1 0.00 1767.10 51.97 13.80 15.31 64.01 5606.00 58.84 65.26 3843.20 3742.20 821.93 1660.90 220544.70 2523897.97 60°53'56.652"N 151°34'10.062' 0.00 0.00 0.00 0.00 1852.67 54.17 14.16 15.86 64.08 5106.00 58.84 65.26 3894.99 3793.95 857.74 1738.62 1 220623.26 2523931.91 60*53'57.004"N 151034'08.491" 0.00 0.00 0.00 0.00 1938.24 56.36 14.40 16.42 64.13 5206.00 58.84 65.26 3:46.69 3845.69 893.56 1816.33 220701.82 2523965.84 60°53'57.357"N 151'34'06.920" 0.00 0.00 0.00 0.00 2023.81 58.56 14.71 16.99 64.19 5306.00 58.84 65.26 3998.44 3897.44 929.37 1894.05 220780.37 2523999.77 60°53'57.710"N 151°34'05.348" 0.00 0.00 0.00 0.00 2109.38 60.76 15.02 17.55 64.24 5406.00 58.84 65.26 4050.18 3949.18 965.18 1971.77 220858.93 2524033.70 60°53'58.062"N 151°34'03.777" 0.00 0.00 0.00 0.00 2194.95 62.96 15.33 18.12 64.28 5506.00 58.84 65.26 4101.92 4000_92 1001.00 2049.48 220937.48 2524067.63 60°53'58.415"N 151 *34'02.206"VV 0.00 0.00 0.00 0.00 2280.52 65.16 15.65 18.69 64.32 _ 5606.00 58.84 65.26 4153.67 2.6 4057 1036.81 2127.20 221016.04 2524101.56 60°53'58.767"N 151°34'00.635" 0.00 0.00 0.00 0.00 2366.09 67.36 15.97 19.26 64.36 5706.00 58.84 65.26 4205.41 4104.41 1072.62 2204.92 221094.60 2524135.49 60053'59.120"N 151033'59.064" 0.00 0.00 0.00 0.00 2451.67 69.57 16.30 19.84 64.40 5806.00 58.84 65.26 4257.15 4156.15 1168.44 2282.64 221173.15 2524169.43 60053'59.472"N 151°3357.492" 0.00 0.00 0.00 0.00 2537.24 71.77 16.62 20.42 64.43 5906.00 58.84 65.26 4308.90 4207.90 1144.25 2360.35 221251.71 2524203.36 60°53'S9.825"N 751°33'S5.921" 0.00 0.00 OAO 0.00 2622.81 73.98 16.95 20.99 64.46 6006.00 58.84 65.26 4360.64 4269.64 1180.06 2438.07 221330_27 2524237.29 60°54'00.177"N 151°33'54.350" 0.00 0.00 0.00 0.00 2708.38 76.19 17.28 21.57 64.49 Page 2 of 3 9306.00 58.84 65.26 6068.19 5967.19 2361.90 5002.74 223922.62_ 2525357.03 60°54'11.807"N. 151°33'02.494" 0.00 0.00 0.00 0.00 5532.22 149.25 29.16 41.15 64.95 9406.00 58.84 65_26 6119.93 6018.93 2397.72 5080.46 224001.17 2525390.96 60°54'12.159"N 151°33'00.922" 0.00 0_00 0.00 0.00 5617.79 151.47 29.54 41.75 64.96 9506.00 58.84 65.26 6171.67 6070.67 2433.53 5156.18 224079.73 2525424.89 60°54'12.512"N 151°32'S9.351" 0.00 0.00 0.00 0.00 5703.36 153.68 29.92 42.35 64.96 9606.00 58.84 65.26 6223.42 6122.42 2469.34 5235.90 224158.28 2525458.82 60°5412.864"N 151°3757.779" 0.00 0.00 0.00 0.00 5788.93 155.90 30.31 42.95 44.97 9706.00 58.84 65.26 6275.16 6174.16 2505.16 5313.61 224,236.84 2525492.75 60°54713.216"N 151°32'56.208" 0.00 0.00 0.00 0.00 5874.51 158.12 30.69 43.56 64.98 9806.00 58.84 65.26 6326.90 6225.90 2540.97 5391.33 224315.40 2525526.69 60°54'13.569"N 151°32'54.636" 0.00 0.00 0.00 0.00 5960.08 160.34 31.07 44.16 64.98 9906.00 58.84 65.26 6378.65 6277.65 2576.78 5469.05 224393.95 2525560.62 60°54'13.921"N 151°32'53.064" 0.00 0.00 0.00 0.00 6045.65 162.55 31.45 44.76 64.99 10006.00 58.84 65.26 6430.39 6329.39 2612.60 5546.77 224472.51 2525594.55 6005414.273"N 151032'51.493" 0.00 0.00 0.00 0.00 6131.22 164.77 31.84 45.36 64.99 10106.00 58.84 65.26 6482.14 6381.14 2648.41 5624.48 224551.07 2525628.48 60°54'14.626"N 151°32'49.921" 0.00 0.00 0.00 0.00 6216.79 166.99 32.22 45.97 65.00 10206.00 58.84 65.26 6533.88 6432.88 2684.22_ 5702.20 224629.62 2525662.41 60°54'14.978"N 151°32'48.349" 0.00 0.00 0.00 0.00 6302.36 169.21 32.61 46.57 65.00 10306.00 58.84 65.26 6585.62 6484.62 2720.04 1 5779.92 224708.18 2525696.34 1 60°54'15.330"N 151°3746.778" 0.00 0.00 0.00 0.00 6387.93 171.43 33.00 47.17 65.01 10406.00 58.84 65.26 6637.37 6536.37 2755.85 1 5857.63 224786.73 2525730.27 1 60°5415.683"N 151°32'45.206" 0.00 0.00 0.00 0.00 6473.50 173.65 33.38 47.78 65.01 10506.00 58.84 65.26 6689.11 6588.11 2791.66 5935.35 224865.29 2525764.21 60°54'16.035"N 151°32'43.634" 0.00 0.00 0.00 0.00 6559.07 175.86 33.77 48.38 65.02 10606.00 58.84 65.26 6740.85 6639.85 2827.48 6013.07 224943.85 2525798.14 60°54'16.387"N 151°32'42.063" 0.00 0.00 0.00 0.00 6644.64 178.08 34.16 48.98 65.02 10706.00 58.84 65.26 6792.60 6691.60 2863.29 6090.79 225022.40 2525832.07 60°54'16.739"N 151°32'40.491" 0.00 0.00 0.00 0.00 6730.22 180.30 34.55 49.59 65.03 10806.00 58.84 65.26 6844.34 6743.34 2899.10 6168.50 225100.96 2525866.00 60°54'17.092"N 151°32'38.919" 0.00 0.00 0.00 0.00 6815.79 182.52 34.94 50.19 65.03 10906.00 58.84 65.26 6896.09 6796.09 2934.92 6246.22 226179.51 2525899.93 60°5417.444"N 151°32'37.348" 0.00 0.00 0.00 0.00 1 6901.36 184.74 35.33 50.80 65.04 11006.00 58.84 65.26 6947.83 6846.83 2970.73 6323.94 _ 225258.07 2525933.86 6005417.796"N 151°32'35.776" 0.00 0.00 0.00 0.00 1 6986.93 186.96 35.72 51.40 65.04 11106.00 58.84 65.26 6999.57 6898.57 3006.54 6401.66 225336.63 2525967.80 6005418.148"N 151°32'34.204" 0.00 0.00 0.00 0.00 7072.50 189.17 36.12 52.01 65.05 11206.00 58.84 65.26 7051.32 6950.32 3042.36 6479.37 225415.18 2526001.73 60°54'18.501"N 151-32'17 r.,43"vv 0.00 0.00 0.00 0.00 7158.07 191.39 36.51 52.61 65.05 11306.00 58.84 65.26 7103.06 7002.06 3078.17 6557.09 225493.74 2526035.66 60°54'18.853"N 151°32'31.061" 0.00 0.00 0.00 0.00 7243.64 193.61 36.90 53.22 55.05 11406.00 58.84 65.26 7154.80 7053.80 3113.98 6634.81 225572.29 2526069.59 60°54'19.205"N 151°32'29.489" 0.00 0.00 0.00 0.00 7329.21 195.83 37.30 53.82 _ 65.06 11506_00 58.84 65.26 7206.55 7105.55 3149.80 6712.53 225650.85 2526103.52 60054'19.557"N 151°32'27.917"W0.00 0.o0 0.00 0.00 7414.78 198.05 37.69 54.43 65.06 11606.00 58.84 65.26 7258.29 7157.29 3185.61 6790.24 225729.41 2526137.45 60°54'19.910"N 151°32'26.345' 0.00 0.00 0.00 0.00 7500.35 200.27 38.09 55.03 65.07 11106.00 58.84 65.26 7310.04 7209.04 3221:42 6867.96 225807.96 2526171.38 60°54'20.262"N 15103224.774' 0.00 0.00 0.00 0.00 7585.93 202.49 38.49 55.64 1 65.07 11806.00 58.84 65.26 7361.78 7260.78 3257.24 6945.68 225886.52 2526205.32 60°54'20.614"N 151°32'23.202' 0.00 0.00 0.00 0.00 7671.50 204.71 38.88 56.25 65.07 11906.00 58.84 65.26 7413.52 7312.52 3293.05 7023.40 1 225965.07 2626239.25 60°54'20.966"N 151°32'21.630' 0.00 0.00 0.00 w-0-0-11 7757.07 206.92 39.28 56.85 1 65.08 12006.00 58.84 65.26 7465.27 7364.27 3328.86 7101.11 226043.63 2526273.18 60°54'21.318"N 151°32'20.058' 0.00 0.00 0.00 0.00 7842.64 _ 209.14 39.68 57.46 1 65.08 12106.00 58.84 65.26 7517.01 7416.01 3364.68 7178.83 226122.19 2526307.11 60°54'21.671'N 151°32'18.486' 0.00 0.00 0.00 0.00 7928.21 211.36 40.08 58.07 1 65.08 12206.00 58.84 65.26 7568.75 7467.75 3400.49 7256.55 226200.74 2526341.04 60°5-422.023"N 151°32'16.915' 0.00 0.00 0.00 0.00 8013.78 213.58 40.48 58.67 65.09 12306.00 58.84 65.26 7620.50 7519.50 3436.30 7334.26 226279.30 2526374.97 60°54'22.375"N 151-32-15.343' 0.00 0.00 0.00 0.00 8699.35 215.80 46M 59.28 65.09 12406.00 58.84 65.26 7672.24 7571.24 3472.12 7411.96 226357.86 2526408.90 60°54'22.727"N 151°32'13.771' 0.00 0.00 0.00 0.00 8184.92 218.02 41.28 59.89 65.09 12506.00 58.84 65.26 1 7723.99 7622.99 3507.93 7489.70 226436.41 2526442.84 2526476.77 60°54'23.079"N 151732'12.199' 0.00 0.00 0.00 0.00 8270.49 220.24 41.69 60.50 65.10 12606.00 58.84 65.26 7775.73 7674.73 3543.74 7567.42 226514.97 60°54'23.432"N 151°32'10.627' 0.00 0.00 0.00 0.00 8356.06 222.46 42.09 61.10 65.10 12706.00 58.84 65.26 7827.47 7726.47 3579.56 7645.13 226593.52 2526510.70 60°54'23.784"N 151°32'09.055" 0.00 0.00 0.00 0.00 8441.64 224.68 42.49 61.71 65.10 12806.00 58.84 65.26 7879.22 7778.22 3615.37 7722.85 226672.08 2526544.63 60°54'24.136"N 151*32'07.483'm 0.00 woo 0.00 0.00 8527.21 226.90 42.90 62.32 65.10 12906.60 58.84 65.26 7930.96 7829.96 3651.18 7800.57 226750.64 2526578.56 60°54'24.488"N 151°32'05.912" 0.00 0.00 0.00 0.00 8612.78 229.12 43.30 62.93 65.11 13006.00 58.84 65.26 7982.71 7881.71 3687.00 7878.29 226829.19 2526612.49 60°54'24.840"N 151'32'04.340' 0.00 0.00 0.00 0.00 8698.35 231.33 43.71 63.54 65.11 13071.55 58.84 65.26 8016.62 7915.62 3710.47 7929.23 1 226880.69 2526634.74 60°5425.071 "N 151 °32'03.309' 0.00 -179.82 1 0.00 0.00 8754.44 232.79 163.94 65.11 End of Tangent (S) 13106.00 57.81 65.26 8034.71 7933.71 3722.74 7955.86 226907.60 2526646.36 60°54'25.192"N 151°32'02.771' 3.00 -179.82 -3.00 -0.01 8783.76 233.55 44.11 64.14 65.11 13206.00 54.81 65.24 8090.18 7989.18 _ 3757.57 8031.41 226983.96 2526679.36 60°54'25.534"N 151°32'01.243' 3.00 -179.81 -3.00 -0.01 6866.95 235.70 44.54 64.73 65.12 13306.00 51.81 65.23 8149.93 8048.93 3791.15 8104.21 227057.55 2526711.18 60°54'25.864"N 151°31'59.770' 3.00 -179.81 -3.00 -0.01 8947.12 237.75 44.99 65.30 65.12 13406.00 48.81 65.22 8213.79 8112.79 3823.39 8174.07 227128.17 2526741.73 60°5426.181"N 151°31'58.357' 3.00 -179.80 -3.00 -0.01 9024.06 239.71 45.45 65.84 65.12 13506.00 45.81 65.20 8281.59 8180.59 3854.21 8240.78 227195.61 2526770.93 60°54'26_484"N 151°31'57.008' : 3.00 -179.79 -3.00 -0.01 9097.55 241.56 45.92 66.34 65.12 13606.00 42.81 65.19 8353.15 8252.15 3883.51 8304.18 227259.69 2526798.69 60°54'26.772"N 151°31'55.725' 3.06 -179.78 -3.00 -0.02 9167.39 243.31 46.40 66.80 65.13 13699.54 40_00 65.17 8423.30 8322.30 3909.47 8360.32 227316.44 2526823.30 60°54'27.028"N 151 °31'54.590" 3.00 0.00 -3.00 -0.02 9229.25 244.85 46.85 67.20 65.13 End of 3D Arc S 13706.00 1 40.00 65.17 8428.25 8327.25 3911.22 8364.09 227320.25 2526824.95 60°54'27.045"N 151°31'54.513' 0.00 0.00 0.00 0.00 9233.40 244.95 46.88 67.23 65.13 13806.00 40.00 65.17 8504.85 8403.85 3938.21 8422.43 227379.22 2526850.53 60°54'27.310"N 151°31'53.333' 0.00 0.00 0.00 0.00 9297.68 246.53 47.35 67.62 65.13 13906.00 40.00 65.17 8581.46 8480.46 3965.20 8480.77 227438.19 2526876.11 60054'27.576"N 151031'52.154' 0.00 0.60 0.06 0.00 9361.96 248.12 47.81 68.02 65.13 14006.00 40.00 65.17 8658.06 8557.06 3992.20 8539_10 227497.16 2526901.69 60°54'27.841"N 151°31'50.974' 0.00 0.00 0.00 0.00 9426.23 249.71 48.28 68.42 65.13 14106.00 40.00 65.17 8734.67 8633.67 4019.19 8597.44 227556.13 2526927.27 60°54'28.106"N 151°31'49.794' 0.00 0.00 0.00 0.00 9490.51 251.30 48.75 68.83 65.14 14206.00 40.00 65.17 8811.27 8710.27 4046_18 8655.78 227615.09 2526952.85 60°54'28.372"N 151°31'48.614" 0.00 0.00 0.00 0.00 9554.79 252.88 49.22 69.23 65.14 14306.00 40.00 65.17 8887.88 8786.88 4073.17 8714.11 227674.06 2526978.43 60054'28.637"N 151031'47.434' 0.00 0.00 0.00 0.00 9619.07 254.47 49.69 69.63 65.14 14406.00 40.00 65.17 8964.48 8863.48 4100_17 8772.45 227733.03 2527004.01 60°54'28.903"N 151°31'46.254" 0.00 0.00 0.00 0.00 9683.35 256.06 50.16 70.03 65.14 14606.00 40.00 65.17 9041.08 8940.08 4127.16 8830.79 227792.00 2527029.59 60°54'29.168"N 151 °31'45.074' 0.00 0.00 0.00 0.00 9747.63 257.65 50.63 70.44 65.14 14606.00 40.00 65.17 9117.69 9016.69 4154.15 8889.12 227850.97 2527055.17 60°54'29.433"N 151°31'43.894' 0.00 0.00 0.00 0.00 9811.90 259.23 51.10 70.84 65.15 14706.00 40.00 65.17 9194.29 9093.29 4181_14 8947.46 227909.94 2527080.75 60°54'29.699"N 151°31'42.714' 0.00 0.00 0.00 OAO 9876.18 260.82 51.58 71.25 6-515 14806.00 40.00 65.17 9270.90 9169.90 4208.13 9005.80 227968.91 2527106.33 60°54'29.964"N 151°31'41.533' 0.00 0.00 0.00 0.00 99 00.46 262.41 52.05 71.66 65.15 14906.00 40.00 65.17 9347.50 9246.50 4235.13 9064.13 228027.88 2527131.91 60°54'30.229"N 151°31'40.353' 0.00 0.00 0.00 0.00 10004.74 264.00 52.53 72.06 65.15 15006.00 40.00 65.17 9424.11 9323.11 4262.12 9122.47 228086.85 252715749 60°54'30.495"N 151°31'39.173" 0.00 0.00 0.00 0.00 10069.02 265.59 53.00 72.47 65.15 _ 15106.00 40.00 65.17 9500.71 9399.71 4289.11 9180.81 228145.81 2527183.07 60°54'30.760"N 151°31'37.993" 0.00 0.00 0.00 0.00 10133.30 267.18 53.48 72.88 65.16 15206.00 40.00 65.17 9577.32 94M.32 4316.10 9239.14 228204.78 2527208.65 60°54'31.025"N 151°31'36.813' 0.00 0.00 0.00 0.00 10197.57 268.77 53.96 73.29 65j6 15306.00 40.00 65.17 9653.92 9552.92 4343.10 9297.48 228263.75 2527234.23 60054'31_291"N 151031'35.633" 0_00 0.00 0.00 0.00 10261.85 270.36 54.43 73.70 65.16 15367.46 40.00 65.17 9701.00 9600.00 4359.69 _ 9333.33 228299.99 2527249.95 60°54'31.454"N 151°31'34.908" 0.00 0.00 0.00 0.00 10301.36 271.33 54.73 73.96 65.16 Endo_f_Tan Tangent 15406.00 40.00 65.17 9730.52_ 9629.52 4370.09 9355.82 228322.72 2527259.81 60°54'31.556"N 151°31'34.453' 0.00 0.00 0.00 0.00 10326.13 271.95 54.91 74.12 65.16 15506.00 40.00 65.17 9807.13 9706.13 4397.08 9414.15 228381.69 2527285.39 60°54'31.821"N 151°31'33.273' 0.00 0.00 0.00 0.00 10390.41 273.54 55.39 74.53 65.16 15606.00 40.00 65.17 9883.73 9782.73 4424.07 9472.49 228440.66 2527310.97 60°54'32.087"N 151'31'32.093" 0.00 0.00 0.00 0.00 10454.69 275.13 55.87 74.94 65.16 15706.00 40.00 65.17 9960.34 _ _9_859.34 4451.07 9530.83 228499.63 2527336.55 _ 60°54'32.352"N 151°31'30.913' 0.00 0.00 0.00 0.00 10518.97 276.72 56.35 75.36 65.17 15806.00 40.00 65.17 10036.94 9935.94 4478.06 9589.16 228558.60 2527362.13 60°54'32.617"N 151°31'29.733' 0.00 0.00 0.00 0.00 10583.24 278.31 56.84 75.77 65.17 15906.00 40.00 65_17 10113.55 10012.55 10186.93 10085,93 4505.05_ 4530.91 _9647.50 9703.38 228617.57 228674.06 2527387.71 252741221 60°54'32.883"N 60°54'33.137"N 151°31'28.553' _ 0.00 151°31'27.422"W 0.00 0.00 0.00 0.00 10647.52 57.32 76.19 65.17 16001.79 40.00 65.17 0.00 0.00 0.00 10709.10 _ _279.90 281.42 57.78 76.59 65.17 End of -Tancent Page 3 of 3 Clearance Summary Report A-10RD_wp04-C1osest Approach Page 1 of 5 BER T% ' GHES GE company IDENTIFICATIONREFERENCE WELLPATH Operator Hilcorp Alaska, LLC Slot slot #31 Area Cook Inlet, Alaska (Offshore) Well A-10RD Field Trading Bay Field Wellbore A-10RD ISDI Facility MONOPOD Platform Sidetrack from <0-900>, MSS <957-7073> at 1106.00 MD IREPORT SETUP INFORMATION Projection System NAD27 / TM Alaska SP, Zone 4 (5004), US feet Software System WellArchitect® 5.1 North Reference True User Ulricard Scale 0.999990 Report Generated 05/10/19 at 09:28 Convergence at slot 1.38' West Database WA ANC Defn WELLPATH LOCATION Local coordinates Grid coordinates Geographic coordinates North[ft] East[ft] Easting[US ft] Northing[US ft] Latitude Longitude Slot Location -3.56 -7.51 218864.52 2523116.28 60°53'48.559"N 151 °34'43.636"W Facility Reference Pt 218872.11 2523119.66 60°53'48.594"N 151 °34'43.485"W Field Reference Pt 219397.72 2521500.50 60°53-32.779"N 151 °34-32.077"W IWELLPATH DATUM Calculation method Minimum Curvature Actual Datum (RKB) to rkb 101.00ft Horizontal Reference Pt Slot Actual Datum (RKB) to mean sea level 101.00ft Vertical Reference Pt Actual Datum (RKB) Actual Datum (RKB) to Mud Line at Slot (slot #31) 101.00ft MD Reference Pt Actual Datum (RKB) Field Vertical Reference Imean sea level POSITIONAL UNCERTAINTY CALCULATION SETTINGS Ellipse Confidence Limit 3.00 Std Dev Start MD .00ft urface Position Uncertain included Declination -Ellipse 19.46' East of TN Di An le ° Ma Field Stren th 55616 nT Slot Surface Uncertaint 1SD Horizontal [713.71 .000ft ertical 0.000ft Facilit Surface Uncertaint lSD Horizontal .000ft ertical 0.000ft Positional Uncertainty values in the WELLPATH DATA table are the projection of the ellipsoid of uncertainty onto the vertical and horizontal lanes Clearance Summary Report A-10RD_wp04-Closest Approach Page 2 of 5 BER T% ' GHES GE company REFERENCE WELLPATH IDENTIFICATION Operator Hilcorp Alaska, LLC Slot slot #31 Area Cook Inlet, Alaska (Offshore) Well A-10RD Field Trading Bay Field Wellbore A-10RD Facility MONOPOD Platform Sidetrack from SDI <0-900>, MSS <957-7073> at 1106.00 MD ANTI -COLLISION RULE Rule Name Hilcorp HSE Stop Drilling ACR Rule Based On Ratio Plane of Rule Closest Approach Threshold Value 1.00 Include Casing & Hole Size yes Apply Cone of Safety no HOLE & CASING SECTIONS - Ref Wellbore: A-10RD Ref Wellpath: A-10RD_wp04 String/Diameter Start MD End MD Interval Start TVD I End TVD I Start N/S Start E/W I End N/S I End E/W ft ft Ift] [ft ft ft ft ft ft 17.5in Open Hole 1106.00 1125.43 19.43 1077.55 1095.00 -86.56 -160.53 -90.17 -168.27 13.375in Casing 1106.00 1125.43 19.43 1077.55 1095.00 -86.56 -160.53 -90.17 -168.27 12.25in Open Hole 1106.00 10000.00 8894.00 1077.55 6427.29 -86.56 -160.53 2610.45 5542.10 9.625in Casing 1106.00 10000.00 8894.00 1077.55 6427.29 -86.56 -160.53 2610.45 5542.10 8.5in Open Hole 1106.00 16000.00 14894.00 1077.55 10185.56 -86.56 -160.53 4530.42 9702.34 Tin Casing 1106.00 16000.00 14894.00 1077.55 10185.56 -86.56 -160.53 4530.42 9702.34 SURVEY PROGRAM - Ref Wellbore: A-10RD Ref Wellpath: A-101110_wp04 I Start MD I End MD jPositional Uncertainty Model I Log Name/Comment Wellbore 0.00 900.00 SDI Keeper gyroMWD v1.1 (Standard) SDI <0-900> A-10 900.00 1106.00 BHI Photomechanical Magnetic (Standard) MSS <0-70735 A-10 1106.00 2150.00 SDI Keeper gyroMWD v1.1 (Standard) Update with hole sizes A-10RD 2150.00 16001.79 BHI OnTrak (Standard) Update with hole sizes A-10RD Clearance Summary Report A-10RD_wp04-Closest Approach Page 3 of 5 BER Ta GHES GE company REFERENCE WELLPATH IDENTIFICATION Operator Hilcorp Alaska, LLC Slot slot #31 Area Cook Inlet, Alaska (Offshore) Well A-10RD Field Trading Bay Field Wellbore A-10RD Facility MONOPOD Platform Sidetrack from SDI <0-900>, MSS <957-7073> at 1106.00 MD CALCULATION RANGE & CUTOFF From: 0.00ft MD To: 16001.79ft MD C-C Cutoff: (none) OFFSET WELL CLEARANCE SUMMARY (61 Offset Wellpaths selected) Ratios are calculated in Closest Approach plane C-C Clearance Distance ACR Separation Ratio Ref Min C-C Diverging Ref MD of Min Min Ratio ACR Offset Offset Offset Offset Offset MD Clear Dist from MD Min Ratio Ratio Dvrg from Status FacilitySlot Well Wellbore Well ath Ift] [ft ft ft ft MONOPOD slot A-10 A-10 SDI <0-900>, MSS <957-7073> 1106.00 0.00 ' 1150.00 1131.27 -1.46 13700.00 FAIL Platform #31 MONOPOD slot A-20RDPB1 A-20RDPB1 PGSS<782-1336'> 1274.36 13.76 1274.36 1274.03 0.62 16001.79 FAIL Platform #27 MONOPOD slot A-25 A-25 MSS <0-7796'> 1986.59 34.21 1986.59 1987.95 0.99 16000.00 FAIL Platform #02 MONOPOD slot A-25RD A-25RD SDI <0-2892>, PGMS <2900-8730> 2111.91 39.89 2111.91 2114.51 1.08 16000.00 PASS Platform #02 MONOPOD slot A-25PB7 A-25PB7 PGMS <0-1400>, MSS <1415-6375> 1985.73 33.89 1985.73 1986.64 1.15 16000.00 PASS Platform #02 MONOPOD slot A-25PB6 A-25PB6 PGMS <0-1400>, MSS <1400-3578> 1929.90 62.87 1929.90 1932.91 1.25 16000.00 PASS Platform #02 MONOPOD slot A-25PB5 A-25PB5 PGMS <0-1400>, MSS <1415-2930> 1929.90 62.87 1929.90 1932.91 1.25 16000.00 PASS Platform #02 MONOPOD slot A-17RD A-17RD GMS <0-5100'> 1106.00 24.43 1106.00 1125.43 1.72 16001.79 PASS Platform #11 MONOPOD slot A-17 A-17 MSS <2656-8535'> 1106.00 24.43 1106.00 1125.43 1.72 16001.79 PASS Platform #11 MONOPOD slot A-24RD A-24RD GMS <0-5450'> 1106.00 33.16 1106.00 1125.43 1.81 16000.00 PASS Platform #14 MONOPOD slot A-9RD A-9RD SDI <0-3000>, MSS <3100-7032> 2630.14 51.78 2630.14 2632.54 1.90 16001.79 PASS Platform #16 MONOPOD slot A-24 A-24 MSS <479 - 9150'> 1106.00 37.85 1106.00 1220.89 2.21 16000.00 PASS Platform #14 MONOPOD slot A-7 A-7 SDI <0-3049>, MSS <3085-6407> 2852.80 67.64 2852.80 2855.60 2.24 13700.00 PASS Platform #22 MONOPOD slot A-13 A-13 MSS <0-7292'> 1106.00 49.35 1106.00 1125.43 2.40 16000.00 PASS Platform #10 MONOPOD slot A-4 A-4 GMS<0-3300'>MSS<3339-10609'> 3444.06 134.41 3444.06 3463.10 2.42 13700.00 PASS Platform #23 MONOPOD slot A-30 A-30 GMS <0-7360'> 1106.00 48.77 1106.00 1106.00 2.98 16000.00 PASS Platform #03 MONOPOD slot A-32 A-32 GMS <0-67505 2215.37 96.07 2215.37 2216.31 3.19 13700.00 PASS Platform #25 MONOPOD slot A-11 A-11 MSS <0-101805 2029.17 110.71 2029.17 2051.15 3.82 14700.00 PASS Platform #19 MONOPOD slot A-23 A-23 GMS<0-4750'>MSS <4900-75305 1106.00 84.69 1106.00 1464.89 3.94 16000.00 PASS Platform #06 MONOPOD slot A-20RD A-20RD SDI <0-506>, PGMS <550-1700>, MWD 1260.55 47.92 1260.55 1268.41 4.03 16001.79 PASS Platform #27 <1763-4977>, MSS <5007-6321> MONOPOD slot A-3 A-3 MSS <486-116375 1106.00 290.26 4306.00 5400.00 4.08 14200.00 PASS Platform #20 MONOPOD slot A-14 A-14 GMS<0-6500>MSS<6581-8070'> 1106.00 74.01 1106.00 1106.00 4.61 14200.00 PASS Platform #09 MONOPOD slot A-26 A-26 MSS <0-8795'> 1106.00 82.18 1106.00 1106.00 4.67 16000.00 PASS Platform #30 OFFSET WELL CLEARANCE .SUMMARY (61 Offset Wellpaths selected) Ratios are calculated in Closest Approach plane C-C Clearance Distance ACR Separation Ratio Ref Min C-C Diverging Ref MD of Min Min Ratio ACR Offset Offset Offset Offset Offset MD Clear Dist from MD Min Ratio Ratio Dvrg from Status FacilitV Slot Well Wellbore Wellpath ft] rftl rftlft ft MONOPOD slot A-3RD A-3RD GMS <0-1600'>MSS <1690-72245 1106.00 288.77 4300.00 4700.00 5.21 13700.00 PASS Platform #20 MONOPOD slot A-5 A-5 GMS<0-1650'>MSS<1690-7646'> 1106.00 84.14 1106 00 1106.00 5.52 13700.00 PASS Platform #32 Clearance Summary Report A-1 0 RD_wp04-Closest Approach Page 4of5 EER BA 0 GE company REFERENCE WELLPATH IDENTIFICATION Operator Hilcorp Alaska, LLC Slot slot #31 Area Cook Inlet, Alaska (Offshore) Well A-10RD Field Trading Bay Field Wellbore A-10RD Facility MONOPOD Platform Sidetrack from SDI <0-900>, MSS <957-7073> at 1106.00 MD CALCULATION RANGE & CUTOFF From: 0.00ft MD To: 16001.79ft MD C-C Cutoff: (none) OFFSET WELL CLEARANCE SUMMARY (61 Offset Wellpaths selected) Ratios are calculated in Closest Approach plane C-C Clearance Distance ACR Separation Ratio Ref Min C-C Diverging Ref MD of Min Min Ratio ACR Offset Offset Offset Offset Offset MD Clear Dist from MD Min Ratio Ratio Dvrg from Status Facility Slot WelL Wellbore Wellpath rftlft ft ft ft MONOPOD slot A-5 RD42 A-5 RD#2 MSS <5544-71015 1106.00 84.14 1106.00 1106.00 5.52 13700.00 PASS Platform #32 MONOPOD slot A-5 RD#1 A-5 RD#1 MSS <6106-7506'> 1106.00 84.14 1106.00 1106.00 5.52 13700.00 PASS Platform #32 MONOPOD slot A3Rd3 A3Rd3 MWD <5982 - 85255 1106.00 288.77 4300.00 4677.80 5.54 13800.00 PASS Platform #20 MONOPOD slot A3Rd2 A3Rd2 MWD<3830-72625 1106.00 288.77 4300.00 4677.80 5.54 13700.00 PASS Platform #20 MONOPOD slot A-29 Rd A-29 Rd GMS <0-86005 1106.00 100.92 1106.00 1249.03 5.96 16000.00 PASS Platform #15 MONOPOD slot A-29 A-29 MSS <5398 - 85775 1106.00 100.92 1106.00 1249.03 5.96 16000.00 PASS Platform #15 MONOPOD slot A-16 A-16 PGMS <0400051VISS <4170'-74605 1106.00 103.41 1106.00 1106.00 7.05 14806.00 PASS Platform #29 MONOPOD slot A-19 A-19 MSS <4379-9259'> 1106.00 133.22 1106.00 1300.00 7.31 16000.00 PASS Platform #17 MONOPOD slot A-19RD A-19RD PGMS <0-73505 1106.00 133.22 1106.00 1300.00 7.31 16000.00 PASS Platform #17 MONOPOD slot A-16RD A-16RD GSS<1 030-18085MWD<1 932- 1106.00 103.62 1106.00 1106.00 7.57 14406.00 PASS Platform #29 68445 MONOPOD slot A-28RD A-28RD PGMS <0-97845 1106.00 340.65 3406.00 5300.00 7.59 13800.00 PASS Platform #01 MONOPOD slot A-15RD2 A-15RD2 MWD (10552.94-13620) 2836.59 182.84 2836.59 2880.67 7.64 15300.00 PASS Platform #13 MONOPOD slot A-15RD A-15RD MWD(1073-12428) 2836.59 182.84 2836.59 2880.67 7.64 15300.00 PASS Platform #13 MONOPOD slot A-15RD21_1 A-15RD21_1 MWD(12663.16-13730.00) 2836.59 182.84 2836.59 2880.67 7.64 15300.00 PASS Platform #13 MONOPOD slot A-15RD21_2 A-15RD2L2 MWD(13366.87-15042) 2836.59 182.84 2836.59 2880.67 7.64 15300.00 PASS Platform #13 MONOPOD slot A-12RD A-12RD PGMS<0-1000'>MSS<1030-8473'> 1106.00 180.75 1800.00 1862.62 7.65 16000.00 PASS Platform #26 MONOPOD slot A-18 A-18 MSS <0-110005 1106.00 300.51 3706.00 4487.36 7.80 13700.00 PASS Platform #18 MONOPOD slot A-8 A-8 PGMS<0-4498'>MSS<4670-70835 1106.00 90.26 1106.00 1500.00 7.94 16001.79 PASS Platform #12 MONOPOD slot A-8RD A-8RD PGSS<3945 - 4074'>MWD<4164 - 1106.00 90.26 1106.00 1500.00 7.94 13700.00 PASS Platform #12 7430'> MONOPOD slot A-8Rd2 A-8Rd2 PMSS <4044-7643'> 1106.00 90.26 1106.00 1500.00 7.94 16000.00 PASS Platform #12 MONOPOD slot A-22 A-22 GMS<0-49005MSS<4958-90665 1106.00 154.81 1106.00 1150.00 8.19 16000.00 PASS Platform #08 MONOPOD slot A-1 Rd A-1 Rd PGSS<11945MWD<1273-65925 3052.69 229.05 3052.69 3133.43 8.40 16000.00 PASS Platform #21 MONOPOD slot A-21 A-21 MSS <0-83105 1106.0 0 141.50 1106.00 1621.65 8.69 16000.00 PASS Platform #07 OFFSET WELL CLEARANCE SUMMARY (61 Offset Wellpaths selected) Ratios are calculated in Closest Approach plane C-C Clearance Distance ACR Separation Ratio Ref Min C-C Diverging Ref MD of Min Min Ratio ACR Offset Offset Offset Offset Offset MD Clear Dist from MD Min Ratio Ratio Dvrg from Status Facilitv Slot Well Wellbore Wellpath rfti rftift ft ft MONOPOD slot A-21 RD A-21 RD MSS <7259-84315 1106.00 141.50 1106.00 1621.65 8.69 16000.00 PASS Platform #07 MONOPOD slot A-28 A-28 GMS<0-64325 1106.00 347.03 3300.00 5200.00 8.96 13700.00 PASS Platform #01 Clearance Summary Report A-10RD_wp04-C1osest Approach Page 5 of 5 EER BA 0 GE company Operator Hilcorp Alaska, LLC Slot slot #31 Area Cook Inlet, Alaska (Offshore) Well A-10RD Field Trading Bay Field Wellbore A-10RD Facility MONOPOD Platform Sidetrack from SDI <0-900>, MSS <957-7073> at 1106.00 MD CALCULATION RANGE & CUTOFF From: 0.00ft MD To: 16001.79ft MD C-C Cutoff: (none) OFFSET WELL CLEARANCE SUMMARY (61 Offset Wellpaths selected) Ratios are calculated in Closest Approach plane Offset Facilitv Offset Slot Offset Well Offset Wellbore Offset Wellpath C-C Clearance Distance ACR Separation Ratio Ref MD Iftlftl Min C-C Clear Dist Diverging Ref MD of from MD Min Ratio [fti Min Ratio Min Ratio Dvrg from ft ACR Status MONOPOD Platform slot #28 A-2 A-2 MSS <0-66695 1106.00 148.31 1106.00 2084.60 9.28 13700,00 PASS MONOPOD Platform slot #26 A-12 A-12 IMSS <1030-7358'> 1106.00 180.65 1106.00 1959.15 10.33 13700.00 PASS MONOPOD Platform slot 424 A-6 A-6 MSS <0-6498'> 1106.00 212.53 1106.00 1106.00 11.99 13700.00 PASS MONOPOD Platform slot #04 A-31 A-31 A-31_awp 1106.00 358.83 1106.00 8403.36 12.92 13700.00 PASS MONOPOD Platform slot #13 A-15 A-15 MSS <0-63405 1106.00 259.02 1106.00 1106.00 13.50 13700.00 PASS MONOPOD Platform slot #02 A-25PB4 A-25PB4 PGMS <0-700'>, MSS <740-1452'> 11106.001 279.721 1106.001 1122.24 13.88 16001.79 PASS MONOPOD Platform slot #05 A-27 A-27 GMS <0-8825'> 11106.001 226.641 1106.001 1106.00114.281 16000.001 PASS MONOPOD Platform slot #05 A27Rd A27Rd MWD <8694 - 126785 1106.00 226.64 1106.00 1106.00 14.28 16000.00 PASS MONOPOD Platform Islot #16 A-9 A-9 IMSS <395 - 6896'> 1106.001 314.871 1106.001 4052.84 14.84 13700.00 PASS MONOPOD Platform slot #27 A-20 A-20 GMS <0-11926'> 1106.00 192.64 1106.00 3200.00 14.99 15700.00 PASS MONOPOD Platform slot #21 A-1 A-1 PGMS <0-4007'>MSS<4124-6509'> 1106.00 254.91 2900.00 3684.02 21.691 13700.00 PASS Schwartz, Guy L (CED) From: Monty Myers <mmyers@hilcorp.com> Sent: Thursday, June 13, 2019 7:10 AM To: Schwartz, Guy L (CED) Cc: Davies, Stephen F (CED); Paul Mazzolini Subject: RE: [EXTERNAL] A-10 RD (PTD 219-076) Thank you Guy, Please see my response in red below. Monty M Myers Drilling Manager 907.538.1168 (c) 907.777.8431 (o) From: Schwartz, Guy L (CED) [mailto:guy.schwartz@alaska.gov] Sent: Friday, May 31, 2019 1:30 PM To: Monty Myers <mmyers@hilcorp.com> Cc: Davies, Stephen F (CED) <steve.davies@alaska.gov>; Paul Mazzolini <pmazzolini@hilcorp.com> Subject: [EXTERNAL] A-10 RD (PTD 219-076) Monty, Couple of items to discuss: 1)For exploration wells we generally do not allow an alternate MASP calculation. In this case the MASP would revert to the .1 psi/ft and get you to 3700 psi (from your proposed 2500 psi) . This would bump the BOPE test pressure up to 4000 psi. ( I will adjust the casing ram test to a lower value). Thank you will note this on the drilling program 2) the 7" liner cement calcs are a bit off (sacks???) . What is the actual yield of the cement ... two are listed. Good catch, the actual yield is 1.33 in the calculations section. Made the change on the drilling program. 3) the FIT minimum for the 12.25" OH (below 13 3/8") is too low. Would like to see this bumped to 13 ppg EWM from 12 ppg. (the FIT results need to be emailed to AOGCC for both casing points. ) Made the adjustment to 13 ppge, test pressure will be 197 psi. 4) Since this is an exploration well a pre -spud meeting is required .... ASAP. Done on 6.11.2019 Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). Kick Tolerance Calculations guy schwartz 5/16/2019 input in yellow areas only A-10RD 219--076 MW (Ppg) 9.5 ppg LOT/FIT (ppg) 13.5 TVD Casing Shoe (ft) 6300 ft TVD If a formation deeper ' then that weaker formations TVD and LOT can be used in place of the casing shoe information for more accurate calculations Kick Intensity (ppg) 0.5 ppg Formation Pore Pressure cannot be less than the MW to have a kick! 0.5 ppg kick tolerance over current MW is a standard assumption Assume that the kick is hydrocarbon gas (not oil or water) TVD of Kick Influx (ft) 10086 ft TVD Gas Gradient (psi/ft) 0.1 psi/ft Change only if gas gradient is known to be different Hole Size (in) 8.5 inches Drill Pipe OD (in) 5 inches BHA OD (in) 4.75 inches Lenth of BHA (ft) 250 ft If the BHA is longer than the open hole, the kick will come to surface very quickly due to the smaller annular capacity 0.0459 bbl/ft Annular Capacity between OH and DP 0.0483 bbl/ft Annular Capacity between OH and BHA 1310.4 psi Maximum Allowable Surface Pressure 262.236 psi Underbalance due to Kick Intensity 1048.164 psi margin before casing shoe is broken down/fractured (or weakest formation below casing shoe) Height of Gas Kick 2660.3 feet Volume of Gas Kick at the influx depth Volume of Gas Kick at shoe depth Volume at influx depth Conversion 128.4 bbl CASE 1 122.1 bbl 103.0 bbl CASE 2 Assume Kick is only around the BHA (not the DP) Assume Kick is only around the DP (not the BHA) KICK TOLERANCE: 103.0 bbl Compare CASE 1 and CASE 2 volumes for the gas influx above. The smallest volume is selected to represent the maximum kick volume allowed without breaking down the shoe (or weakest formation) It is difficult to shut in a well with less than a 10 bbl kick volume Kick Tolerance Calculations guy schwartz 5/16/2019 input in yellow areas only A -LORD 219--076 MW (ppg) 9 ppg LOT/FIT (ppg) 13.0 TVD Casing Shoe (ft) 980 ft TVD If a formation deeper ' then that weaker formations TVD and LOT can be used in place of the casing shoe information for more accurate calculations Kick Intensity (ppg) 0.5 ppg Formation Pore Pressure cannot be less than the MW to have a kick! 0.5 ppg kick tolerance over current MW is a standard assumption Assume that the kick is hydrocarbon gas (not oil or water) TVD of Kick Influx (ft) 6300 ft TVD Gas Gradient (psi/ft) 0.1 psi/ft Change only if gas gradient is known to be different Hole Size (in) 12.25 inches Drill Pipe OD (in) 5 inches BHA OD (in) 8.5 inches Lenth of BHA (ft) 250 ft If the BHA is longer than the open hole, the kick will come to surface very quickly due to the smaller annular capacity 0.1215 bbl/ft Annular Capacity between OH and DP 0.0756 bbl/ft Annular Capacity between OH and BHA 203.84 psi Maximum Allowable Surface Pressure 163.8 psi Underbalance due to Kick Intensity 40.04 psi margin before casing shoe is broken down/fractured (or weakest formation below casing shoe) Height of Gas Kick 108.8 feet Volume of Gas Kick 8.2 bbl CASE 1 Assume Kick is only around the BHA (not the DP) at the influx depth Volume of Gas Kick 13.2 bbl Assume Kick is only around the DP (not the BHA) at shoe depth Volume at influx 2.8 bbl CASE 2 depth Conversion KICK TOLERANCE: 2.8 bbl Compare CASE 1 and CASE 2 volumes for the gas influx above. The smallest volume is selected to represent the maximum kick volume allowed without breaking down the shoe (or weakest formation) It is difficult to shut in a well with less than a 10 bbl kick volume 11 Plug Back for HileorpAlaska,LLC Sidetrack Schematic KB 37', KB to MSL: 101', MSL to Mudline 66' C-Zone D-Zone E Zone KB ELEV = 101' PBTD = 6,750' TD = 7,073' ANGLE thru INTERVAL = 12.7' Trading Bay Unit Well # A-10 PTD: 167-076 API: 50-733-20064-00 Plug Back: 05/18/2019 rAaNr. DFTAII SIZE WT GRADE CONN ID TOP STM. 20" Conductor Pile Surface -264' 13-3/8" 61 K-55 BTC 12.515 Surface 1,095' 9-5/8" 40 J-55 BTC 8.835 1,393' 4,111' 40 N-80 BTC 8.835 4,111' 5,600' 43.5 N-80 BTC 8.755 5,600' 7,053' Tubing Detail: LS 3-1/2" 9.2 N-80 Butt 2.992 4,123' 4434' 2-7/8" 6.4 N-80 Butt 2.441 4435' 5718' SS 3-1/2" 9.2 N-80 Butt 2.992 4,013' 4145' 1 2-7/8" 6.4 N-80 Butt 2.441 4146' 4191' Dip Tube 2-3/8" x 1-1/2" 6.2 N-80 Butt 1.853 4084' 5537' JEWELRY DETAIL NO Depth Dept TVID ID OD Item 1,540' 1,470' CIBP w/ 527' cement 4,008' 3,716' CIBP w/ 373' cement SHORT STRING E 4,044' 3,749' 2.875 5.62 GLM #S4 - Otis RW4 (4.37" Minor OD) F 4,080' 3,781' 2.75 Otis "XA" Sliding Sleeve G 4,145' 3,841' 2.441 Cross over, 3-1/2" X 2-7/8" H 4,146' 3,842' 2.380 8.435 Otis "RTH" Triple Hydraulic Packer (3-1/2"x2-7/8"x2-3/8") 1 4,189' 3,882' 2.205 Otis "XN" Nipple 1 4,191' 3,884' EOT LONG STRING 6 4,147' 3,843' 3.000 8.435 Otis "RTH" Triple Hydraulic Packer (3-1/2"x2-7/8"x2-3/8") 7 4,249' 3,937' 2.75 Otis "XA" Sliding Sleeve 8 4,434' 4,109' Cross over, 3-1/2" X 2-7/8- 9 4,497' 4,168' GLM #L4 - Camco KBMG-LT 10 4,754' 4,874' 4,409' 4,522' Blast Joints 11 S,030' 4,668' GLM #L5 - Camco KBMG-LT 12 5,442' 5,053' GLM #L6 - Camco KBMG-LT 13 5,604' 5,205' 2.313 Otis "XA" Sliding Sleeve 14 5,640' 5,239' Locator Seal Assy. 15 5,641' 5,240' Otis 9-5/8" x 4" "BD" Perm Packer 16 5,685' 5,281' 2.313 1 Otis "X" Nipple 17 5,718' S,312' Mule Shoe. Dip Tubing a. 4,084' 3,785' Top of Dip Tube (1 perforated joint) 4,147' 3,843' 1.940 8.435 b. 4,159' 3,854' 1-1/2" Telescoping Joint C. 4,496' 4,167' GLM #L4 - Camco KBMG-LT d. 4,513' 4,183' 1-1/2" Telescoping Joint e. 5,030' 4,668' GLM #LS - Camco KBMG-LT 2' 5,452 ,068' 1-1/2 t Telescoping Jointf. 54 553 GLMgL6 - Camco KBMG-LT h. 1 5,537' 1 5,142' Bull Plug FISH Date Depth Description 10/05/1978 6,500' Junked Perm Packer 07/16/1973 6,494' 2 Junked Retainers 07/14/1973 6,496' 1/2 of ring from hydraulic packer 08/09/1970 6,503' Guiberson Packer Model A 08/08/1970 6,503' Junked Retainer 07/30/1970 6,515' Junked BP 03/25/1968 6,525' Junked BP 03/21/1968 6525' Junked BP Perforation Details on Next Pag Updated by: JLL05/29/19 Davies, Stephen F (CED) From: Monty Myers <mmyers@hilcorp.com> Sent: Saturday, May 18, 2019 8:33 AM To: Davies, Stephen F (CED) Subject: RE: [EXTERNAL] TB St A-1ORD (PTD 219-076) - Question Good morning Steve! The rig in question is Rig #56. It is the rig that is on Hilcorp's Monopod platform. The A-10 will be separated from the P&A'd wells by the Bruin Bay Fault as depicted below, there is no reason to suspect that we will encounter 1-12S on this well, and in the event that we do see H2S or gas the rig is outfitted with gas monitoring and detection equipment. We will also have a gas buster rigged up that we can divert to in case we see gas. Please let me know if you have any additional questions. Thank you! Monty M Myers Drilling Manager 907.538.1168 (c) 907.777.8431 (o) From: Davies, Stephen F (CED) [mailto:steve.davies@alaska.gov] Sent: Friday, May 17, 2019 1:45 PM To: Monty Myers <mmyers@hilcorp.com> Subject: [EXTERNAL) TB St A-10RD (PTD 219-076) - Question Monty, After reading through Hilcorp's application for a Permit to Drill, I don't recall reading the name of the drilling rig that will be used. Maybe I overlooked it, but could you please provide it? What is the structural relationship of the A-10RD targets to the P&A'd wells to the west (e.g., contiguous but down -dip, fault -separated, etc.)? Based on the existing wells, is there any reason to expect that A-10RD will encounter H2S-bearing strata? Will the rig have sensors and alarms? Just in case, will H2S sequestering agents be available at the rig? Thank you, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e- mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.pov. The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e- mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Remark: AOGCC PTD No. 219-076 Coordinate Check 17 May 2019 INPUT Geographic, NAD27 TB St A-1ORD Latitude: 60 53 48.55900 Longitude: 151 34 43.63600 OUTPUT State Plane, NAD27 5004 - Alaska 4, U.S. Feet z Northing/Y: 2523116.247 Easting/X: 218864.540 Convergence: -1 22 46.34870 Scale Factor: 0.999989935 Corpscon v6.0.1, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME�l�Z PTD: — n7� Development _ Service V Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: �I i lr �.�` iG POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 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 Pilot Hole name ( PH) and API number (50- - - -) from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. f All dry ditch sample sets submitted to the AOGCC must be in no greater ✓ Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sam le intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well to ing pro ip proposed by (Company Name) in the attached applicati; �h, owing well togs are also required for this well: /GJr.�/ Well Logging A4,1P Zj4y' rn1 kk Requirements Per Statute AS 31.05.030(H)(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. Sr�zvr�, Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool Well Name: TRADING BAY ST-A_1ORD Program EXP _ Well bore seg ❑ PTD#:2190760 Company Hilcorp Alaska LLC _ Initial Class/Type EXP / PEND _GeoArea 820 -- __ Unit On/Off Shore Off Annular Disposal Administration 1 Permit -fee attached_ _ NA - - - - - - - - 2 Lease number appropriate_ Yes Surface location in ADL 18731, protion of well passes thru_ADL_393693; - - - 3 Unique well name and number Yes top productive_ interval and TD in AD_L_18776_(all Hilcorp leases). - - - - 4 Well located in_a_d_efined pool No Exploratory (delineation) about 0,6.miles east of three existing wells _(all P&A'd between 10 5 Well located proper distance from_ drilling unit -boundary_ Yes and.50years ago. Red_rill target reportedly identified using newly acquired seismic_data. - 6 Well located proper distance from_ other wells_ - - - Yes Well will reach TD about_ 1_,420' from a property line with an unleased parcel. 7 Sufficient acreage available in -drilling unit_ Yes 8 If_deviated, is_wellbore plat_included Yes - - - - - - - . - - 9 Operator only affected party - Yes - . - 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order - - - - - Yes Appr Date 12 Permit_can be issued without administrativ_e_approval _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 13 Can permit be approved before 15-day wait_ - - - - Yes _ - - - - SFD 5/17/2019 14 Well located within area and strata authorized by Injection Order # (put 10# in -comments) (For_ NA_ 15 All wells_within.1/4_mil_e area_of review identified (For service well only) - - - NA_ - - - - - - - 16 Pre -produced injector_ duration of pre production less than 3 months (For service well only) NA_ - - . - - - - - - 17 Nonconve_n. gas conforms to AS3.1..05.030(i.1_.A),(j.2.A-D) - NA_ - _ _ 18 Conductor string -provided - - - - NA_ Sidetracked well below 13.3/8" surface casing shoe. Engineering 19 Surface casing_ protects all -known_ USDWs NA- _ _ - - - - - - - - - - - - - - - - - 20 CMT_vol_ adequate to circulate -on conductor _& surf _csg - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 21 CMT_vol_ adequate to tie-in long string to surf csg_ - - - - Yes . _ - - - - - 9 5/8"will be fully -cemented to 500 ft and .. UsingES-tool 2 stage .- - 9 22 CMT will cover all known -productive horizons- Yes 23 Casing designs adequate for C, T B &_ permafrost _ - - - - - Yes - - - - - - BTC ca_lc_ are supplied _... no issues._ 24 Adequate tankage or reserve pit - - - - - - - - Yes Rig has steel pits. All waste transported to-offsite-disposal. 25 If_a-re-drill_, has_a_ 10-403 for abandonment been approved _ _ _ _ _ _ _ - - Yes _ _ _ _ A-10 P &_A for redrill_.._ 319-012 26 Adequate wellbore separation_proposed- - - - - - - - - Yes Some close crossing at about 1300 ant_1900 ft and with A-20RDPB1_a_nd A-25 27 If diverter required, does it meet_ regulations_ - - - N_A_ - - - - - Wellhead in place ..._u_sing BOPE . - - - - - - - - - - - - - - - - Appr Date I28 Drilling fluid_ program schematic-&- equip list adequate_ - - - - _N_o_ MAX form pressure = 4768 psi_(9.0 ppg_ EMW) will drill with-9.5 ppg mu_d_ GLS 6/18/2019 29 BOPEs,_dothey meet _regulation --- - - - -- - - - -- Yes - --- - ---- - - - -- -- - -- - - -- --- -- - - -- - --- BOPS_press rating appropriate; test to_(put psig in comments)_ Yes MASP = 3770_psi_ Will_test BOPE To 4000_psi_ (_annular to 2500 psi)_ _ - . - - . i30 31 Chokemanifoldcomplies w/API_RP-53 (May 84)_ - - - _ Yes _ _ _ _ - Casingram test 3000 psi - 32 Work will occur without operation shutdown_ - Yes - - - Sundry -required for well Completion -and perforating.. _ - - - - - - - - - 33 Is presence of H2S gas_ probable - - _ . - - Yes - - - H2S not expected but exploration wells required H2S.monitors and_ alarms.- . 34 Mechanical -condition of wells within AOR verified (For service well only) - - NA.. - - - - - _ - - - - - - - - - - - - - - - - - - - - - - 35 Permit can be issued w/o hydrogen sulfide measures Yes - - H2S not expected in this new_ fault_block. Rig has sensors and alarms. - - - - - - - - Geology 36 Data presented on potential overpressure zones - - - - - Yes - - - - - - - Operator's planned mud -program appears sufficient to control- expected -reservoir pr_ess_ures.(max_imum of-9,0-ppg Appr Date 37 Seismic analysis of shallow gas zones - - NA_ - - - - - - - EMW). Onsite. material will be sufficient to increase to 1_ pp higher higher_than_the maximum - - - SFD 5/20/2019 38 Seabed condition survey -(if off. -shore) - - - - - . - - - - - - - - - NA anticipated_ mud_ weight. No shallow gas_ hazards anticipated: surface casing is -set at 1095' MD (1,068'_ 39 Contact name/phone for weekly -progress reports- [exploratory only] - - - - - Yes - - - - - - TVD & this redrill will -be the_58th_we_II drilled from Monopod.-Contact; Monty Myers 907-777-8431. - Geologic Engineering Public Exploratory (delineation) well drilled to a location east of, and apparently fault -separated from, the oil Middle Kenai and Hemlock Commissioner: Date: Commissioner: Date Commissioner Date Oil Pools as defined by CO 93. Well will lie 0.6 miles east of three nearest wells, which were all P&A'd between 10 and 50 years OT S — �Zc 10 ago. A-10RD will be mud logged and PWD sensors will be utilized. SFD