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Home My WebLink About219-038DATA SUBMITTAL COMPLIANCE REPORT 711 912 01 9 Permit to Drill 2190380 Well Name/No. MILNE PT UNIT M-04 Operator Hilcorp Alaska LLC API No. 50-029-23624-00-00 MD 2706 TVD 2670 Completion Date 4/5/2019 Completion Status WTRSP Current Status WTRSP UIC No REQUIRED INFORMATION Mud Log No ✓ Samples No ✓ Directional Survey Yes DATA INFORMATION List of Logs Obtained: ROP / DGR / EWR / ALD / CTN / MD and TVD Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No ED C 30612 Digital Data ED C 30612 Digital Data ED C 30612 Digital Data ED C 30612 Digital Data ED C 30612 Digital Data ED C 30612 Digital Data ED C 30612 Digital Data ED C 30612 Digital Data ED C 30612 Digital Data ED C 30612 Digital Data ED C 30612 Digital Data ED C 30612 Digital Data ED C 30612 Digital Data ED C 30612 Digital Data Log C 30612 Log Header Scans Well Cores/Samples Information: Name AOGCC Interval OH/ Start Stop CH 110 2706 0 0 Interval Start Stop Sent Received Page 1 of (from Master Well Data/Logs) Received Comments 4/16/2019 Electronic Data Set, Filename: MPU M-04 DGR Sample Set Number Comments Friday, July 19, 2019 EWR ALD CTN.Ias 4/16/2019 Electronic File: MPU M-04 LWD Final MD.cgm 4/16/2019 Electronic File: MPU M-04 LWD Final TVD.cgm 4/16/2019 Electronic File: MPU M-04 Definitive Survey Report.pdf 4/16/2019 Electronic File: MPU M-04—Definitive Survey Report.txt 4/16/2019 Electronic File: MPU M-04_GIS.txt 4/16/2019 Electronic File: MPU M-04 LWD Final MD.emf 4/16/2019 Electronic File: MPU M-04 LWD Final TVD.emf 4/16/2019 Electronic File: MPU M-04 LWD Final MD.pdf 4/16/2019 Electronic File: MPU M-04 LWD Final TVD.pdf 4/16/2019 Electronic File: MPU M-04 LWD Final MD.tif 4/16/2019 Electronic File: MPU M-04 LWD Final TVD.tif 4/16/2019 Electronic File: EMFView3_1.zip 4/16/2019 Electronic File: Readme.txt 2190380 MILNE PT UNIT M-04 LOG HEADERS Sample Set Number Comments Friday, July 19, 2019 DATA SUBMITTAL COMPLIANCE REPORT 7/19/2019 Permit to Drill 2190380 Well Name/No. MILNE PT UNIT M-04 Operator Hilcorp Alaska LLC MD 2706 TVD 2670 INFORMATION RECEIVED Completion Report0 Production Test Information Y 19 Geologic Markers/Tops U COMPLIANCE HISTORY Completion Date: 4/5/2019 Release Date: 3/22/2019 Description Comments: Completion Date 4/5/2019 Completion Status WTRSP Current Status WTRSP API No. 50-029-23624-00-00 UIC No Directional / Inclination Data �Y Mud Logs, Image Files, Digital Data Y /® Core Chips Y /t) Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files( Core Photographs Y / Daily Operations Summary Cuttings Samples vY /O Laboratory Analyses Y / Date Comments Compliance Reviewed By: " ` Date:' AOGCC page 2 of 2 Friday. July 19, 2019 V"ECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Ia. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other Q Abandoned ❑ Suspended❑ . vVt(�SP-W�f�• 62ZJL' zorac 25A 10 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: _ 0 1b. Well Class: ,. .,• U,i+ ✓ ;,� Development ❑ Exploratory ❑ Service ❑� Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Hilcorp Alaska, LLC Aband.: 4/5/2019 219-038 3. Address: 7. Date Spudded: 15. API Number: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 April 1, 2019 50-029-23624-00-00 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 5040' FSL, 771' FEL, Sec 14, T13N, R9E, UM, AK ' April 2, 2019 MPU M-04 Top of Productive Interval: 9. Ref Elevations: KB: 58.2' ' 17. Field / Pool(s): Milne Point Field 538' FNL, 728' FEL, Sec 14, T13N, R9E, UM, AK • GL: 25' BF: 25' Prince Creek Water (TER Undef WTRSP) Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 547' FNL, 718' FEL, Sec 14, T13N, R9E, UM, AK - 2,615' MD / 2,579' TVD - ADL025514 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 533393 • y- 6027889 • Zone- 4 • 2,706' MD / 2,670' TVD • LONS 16-004 TPI: x- 533438 y- 6027591 Zone- 4 12. SSSV Depth MD1TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 533448 y- 6027582 Zone- 4 N/A 1,858' MD / 1,823' TVD 5. Directional or Inclination Survey: Yes � (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MDTrVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) I N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data 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 ROP DGR EWR ALD CTN MD & TVD b^- 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 215.5# X-42 Surface 113' Surface 113' 42" 3270 ft3 10-3/4" 45.5# L-80 Surface 1,766' Surface 1,731' 9-5/8" 40# L-80 1,766' 2,696' 1,731' 2,660' 13-1/2" L - 495 sx / T - 590 sx 40 bbls 24. Open to production or injection? Yes ❑ No 0 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/TVD) Size and Number; Date Perfd): C's p %`"t' ✓` COMPLEVON Ll Z D T Ze( N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No El Per 20 AAC 25.283 (i)(2) attach electronic and printed information VERIFIED DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas fift, etc.): N/A N/A Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Casing Press: I ICalculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 124-Hpr Rate Form 10-407 Revised 5/20171 CONTIN(1Q ON PAGE 2 RBDMS�46—S MAY 0 6 2019 Submit ORIGINIAL only �� s=7& �—+ 28. CORE DATA Conventional Core(s): Yes ❑ No ❑Z - Sidewall Cores: Yes ❑ No ❑✓ - If Yes, list formations and intervals cored (MDfTVD, 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 ❑✓ If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base 1,858' 1,823' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval (not perfed yet) information, including reports, per 20 AAC 25.071. SV5 1,329' 1,304' SV1 1,904' 1,869' UG3 2,494' 2,458' - Formation at total depth: UG3 31. List of Attachments: Wellbore Schematic, Drilling Reports, Defintive 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: Cdlfi er hi1COr .com Authorized Contact Phone: 777.8389 Signature: — - Date: , -10 INSTRUCTIONS General: This form an the required attachme rovide 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 n Hlleorn Alaska. LLC Orig. KB Elev.: 58.2/ GL Elev.: 25.a RKB—THE 29.91' Do on 14 2WA Diesel 'A '' ;1'j n SCHEMATIC TREE & WELLHEAD Milne Point Unit Well: MPU Moose Pad M-04 Last Completed: 4/5/2019 PTD: 219-038 Tree 1 41/16" 5M Tree (Dry Hole Tree) Wellhead 11"5M Wellhead x 7" TXP Top and Bottom Hanger with 7"CIW T' Top BPV profile. 2e@3/8" NPT control lines. OPEN HOLE / CEMENT DETAIL 42" 50 bbls (10 Yards Pilecrete dumped down backside) 13-1/2" 388.5 bbl (495 sx) Lead 10.7 ppg / 122.5 bbl (590 sx) Tail 15.8 ppg Ar yv 6j3C ct�n r ra n CASING DETAIL Size Type Wt/Grade/Conn Drift I Top Btm BPF 20"x34" Conductor (insulated) 215.5/X-42/Weld N/A Surface 113' N/A 30-3/4" 45.5 / L-80 / TXP SR 9.794" Surface 1,766' 0.0961 Surface/Production 95/8" 40/L-80/TXP SR 8.679" 1,766' 2,696' 0.0758 TUBING DETAIL WELL INCLINATION DETAIL KOP @ 300' Max Hole Angle = 18.14deg. 9.6 ppg Mao Brine 143/4^ JEWELRY DETAIL No. Top MD Item Drift ID PERFORATION DETAIL Schrader Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Y� GRAVEL PACK DETAIL GENERAL WELL INFO • 95/8 API: 50-029-23624-00-00 Shoe , Drilled and Cased by Doyon 14 - 4/5/2019 Hole 2,696' TD= 2,706' (MD) / TD = 2,67a(TVD) PB1D=2,615' (MD)/TD=2,579'(TVD) Revised By: STP 4/11/2019 Hilcorp Energy Company Composite Report Well Name: MP M-04 Field: Milne Point Unit County/State: , Alaska (LAT/LONG): avation (RKB): API #: Spud Date: 4/1/2019 Job Name: 1814313D MPU M-04 Drilling Contractor Doyon 14 AFE #: AFE $: Activity Date.' 3131/2019 Please refer to M-11 completion report for more details.;RDMO. Move rig off M-11 and down the pad. Position rig, level and spot onto M-04.; Remove hand rails from M-03 Well house. Install landings and hand rails on stairs.;Skid rig floor into drilling position over Well.;RU steam, air and water to the rig floor. Orient the diverter adapter. Spot the rock washer. Begin to load, strap and tally (including serial numbers) 5" NC50 DP.;Spot third party units. NU the diverter pipe. NU Bell nipple & riser. Prep mud pits for fluid. Work on rig acceptance checklist.;install turn buckles on annular. C/O gear oil on topdrive, inspect saversub, flushed mud pump pop-off lines. Spot upright water tank. Cont working pipe in shed and acceptance checklist. Rig accepted at 03:00 hours.; Pick up 5" NC50 DP and rack in Derrick. Diverter test waived by AOGCC rep Jeff Jones @ 05:33, 04/01/2019.;Hauled 0 bible H2O from L -Pad lake for total = 0 bbls Hauled 0 bbis heated H2O from G&I = 0 Hauled 0 bbls cuttings/liquids to MPU G&I for total = 0 bbls 4/1/2019 Finish P/U 5" Dip & stand back in derrick. 27 stands total. P/U & rack back 6 stands of HWDP & jars.;Slip & cut drilling line. 51'. Service ri .;Perform diverter function test, Test witness was waived by Jeff Jones with AOGCC at 0533 4101/19. Knife valve opened in 17 sec. Annular closed in 30 sec. Accumulator draw down. Starting pressure 3000 psi. 1900 psi after shut in.200 psi increase 42 sec. Full pressure at 156 sec. 6 btls at 2000 avg.;Pertorm full diverter evac drill with full pad muster. All drilling crew accounted for in 3 min 20 sec. All other pad personnel 9 min. 150 personnel muster and accounted for. Good drill. Review lessons Iearned.;M/U 12.25 mill tooth bit and motor on HWDP. RIH & tag at 81'. Engage pumps and wash through ice plug. Shut down and perform pre spud meeting.;Replace TD hyd accumulator on TD before spudding. Old one was leaking. Empty rock washer of all fluids prior to spud.;PIU 2 singles 5" DP. Flood lines and test to rig floor to 3500 psi.;Drill out the conductor with water from 113' to 116'. Displace the well to 8.8 ppg spud mud. PU, SO & ROT = 49K. 350 GPM = 370 psi, 40 PRM = 1K ft -lbs torque and WOB = 2-6K.;POOH from 116to surface and C/O the 12.25" milltooth bit to a 13.5" Kymera. RIH and tag bottom at 116' on depth.;Drill 13.5" surface hole from 116 to 260' (PU = 55K, SO = 55K& ROT= 53K) at 350 GPM = 470 psi, 40 PRM = 1 K ft -lbs torque and WOB = 4-7K.;BROOH to the conductor at 342 GPM -360 psi and 40 RPM. Increase pump rate to 450 GPM - 750 psi, circulate until shakers cleaned up then continue out to 64'. Continue POOH to 35'.;M/U remaining components of BHA #1. 13.5" Kymera Bit, 8" Strataforce Motor ABH @ 1.5% DM, DGR, EW R, PWD, HCIM, ALD & CTN Collam.;Upload MWD tools.;Orient UBHO, M/U x -over and stand of 5" DP. Shallow pulse test the MWD at 420 GPM - Good Test.;Rack stand back and BD TopDrive, PJSM with crew and Sperry & load nuclear sources.;RIH w/ 3x flex collars U 213'.;R/U Gyro, Wash down f/ 213' t/ 269. Tag on depth, no notable fill observed.;Drill 13.5" surface hole from 260' to 309 (309' TVD), 58' with AROP of 96 FPH. 450 GPM = 1120 psi, 40 RPM = 1 K ft-Ibs torque, WOB = 6-15K, MW= 9.0 ppg, Vis = 237, ECD = 9.1 ppg, Max gas = 0 units. PU = 69K, SO = 68K, ROT= 68K. Backream 1 jt prior to connection. Gyro survey at KD.;Hauled 495 bbis H2O from L -Pad lake for total= 495 bbis Hauled 0 bbis heated H2O from G&I = 0 Hauled 57 bbis cuttings/liquids to MPU G&I for total = 57 bbls 4/2/2019 Drill 13-1/2" surface hole from 309' to 910'(903' TVD), 601' with AROP of 100 FPH. 490 GPM, = 1440 PSI, 80 RPM = 4K ft/lbs TO, 8-10K WOB. MW = 9.15 ppg, Vis = 195, ECD = 10.0 ppg, max gas = 6 units. PU = 85K, SO = 89K, ROT = 88K. Backream full stands.;Last gyro survey at 163', never saw any interference. Release gyro at 494' and R/D at 588'.;Drill 13-112" surface hole from 910' to 1627' (1584' TVD), 717' with AROP of 120 FPH. 545 GPM, = 1870 PSI, 80 RPM = 4-5K Rubs TO, 10-12K WOB. MW = 9.2 ppg, Vis = 157, ECD = 9.9 ppg, max gas = 4 units. PU = 105K, SO = 100K, ROT = 105K. Backream full stands.;Built with 3°/100' to 17.26° inclination at 1016' and held to 1301'. Begin drop at 3*1100' from 1301'. Max inclination of 18.14° at 1206'.;Drill 13-1/2" surface hole from 1627' to 2265' (2030' TVD), 638' wit AROP of 106 FPH. 600 GPM, = 1940 PSI, 80 RPM = 4-5K ft/Ibs TO, 3-6K WOB. MW = 9.2 ppg, Vis = 164, ECD = 10.0 ppg, max gas = 23 units. PU = 118K, SO = 111 K, ROT = 115K. Backream full stands.; Base of permafrost at 1860' MD / 1824' TVD. Top of source water at 1906' MD / 1870' TVD. Finished 3°/100' drop to vertical at 2039.;Ddl1 13-1/2" surface hole from 2265to 2706' (2670' TVD), 441' with AROP of 126 FPH. 600 GPM, = 2030 PSI, 80 RPM = 34K ft/lbs TO, 6-7K WOB. MW = 9.2 ppg, Vis = 148, ECD = 9.99 ppg, max gas = 26 units. PU = 138K, $O = 119K, ROT = 126K. Backream full stands.;Base of source water at 2500' MD 12464' TVD. Last survey at 2665.30' MD / 2629.63' TVD, 1.05° Inc., 133.25° t azm., 12.77' from plan, 6.99' north and 10.68' west. TD at 2706' MD / 2670' TVD, 1.05° Inc., 133.25' uni 13.5' from plan, 7.5' north and 11.23' west.;Obtain final MWD survey. Pump 27 bbl high vis sweep vith 8 ppb nut plug. Sweep back 10 bbls late with no increase in cuttings. Nut plug observed across shakers. Circulate 1 additional bottoms up and observed clean shakers. 9636 total strokes for 2.25 bottoms up.;Back ream out of the hole from 2706 to 2170'. 600 GPM Y = 1960 PSI, 80 RPM = 3K ft/lbs TO. ECD = 9.60 ppg, max gas = 15 units. Begin at 10 min/stand increase to 5 min/stand. Log slide intervals at 250 ft/hr (4 ft/min).;Hauled 1540 bbis H2O from L -Pad lake for total = 2035 bbis Hauled 0 bbis heated H2O from G&I for total = 0 bible Hauled 1488 bbis cutting/liquids to MPU G&I for total= 1545 bbls 4/3/2019 Back ream out F/ 2170'T/772'. Pull slow on all slides mad pass at 4 FPM. 600 GPM, 80 RPM,;Pull on elevators clean. Stand back HWDP. Conduct PJSM & remove Nuclear Sources. Down load MWD. Bring casing equipment and pups to rig floor while downloading. UD MWD & Motor. Grade- 1-1-WT-A-E-I-NO-TD No damage visible on BHA. Monitor well at .25 BPH Losses.;Clean and clear rig floor of BHA. Bring up Volard tools and R/U to run 9-5/8 casing.;PJSM, PIU 9- 5/8 Casing and make up with Volant. M/U float shoe, joint #1 & #2, float collar and joints #3 & #4 to 159. Baker Lok first 3 connections. Use strap tongs for back ups. Torque 9-5/8" TXP BTC-SR connections to 21,000 ft/lbs with Doyon Volant tool.;Run 9-518 40# L-80 TXP BTC-SR casing from 159'to 928' filling on the fly wf Volant & pumping through every 10. Install 9-518"x12-112" Expand-o-lizer centralizer free floating on every joint. Torque 9-5/8" TXP BTC-SR connections to 21,000 ft/lbs with Doyon Volant tool. Use strap tongs for back ups.;23 each 9-5/8" full joints, one each 9 and 4' pup joints, 24 each 9-5/8"x12-114" Expand-o-lizer centralizers and 6 stop rings ran. 5 bbis lost over 3 hours of running casing.;UD 9-5/8" elevators and Volant tool. R/U 10-314" elevators and Volant tool. M/U 9-5/9'x 10-3/4" XO sub to 930'. Change strap tongs to 10-3/4".;Run 10-3/4" 45.5# L-80 TXP BTC-SR casing from 930' to 2696' filing on the fly with Volant and pumping through every 10. Work past set depth, observe taking 5K weight at 2702'. Torque 10-314" TXP BTC-SR connections to 23,000 ft/Ibs w/ Doyon Volant tool. Use strap tongs for back ups.;lnstall 10-3/4"x13-1/2" bow spring centralizer across every coupler. 43 each 10-3/4" full joints, one each 9' and 4' pup joints, 41 each 10-3/4"x13.5" bow spring centralizers ran. 6 bbls losses over 5 hours running casing.;Stage up pumps in 1 bbl increments to 8 BPM, 150 PSI. Reciprocate 40' w/ 10 PRM, 13K ft/lbs torque. Increase to 20 RPM, 9K ft/lbs torque. Begin with 9.4 ppg 169 vis in & 9.5 Flog 1265 vis out. Adding 30-50 BPH of water.;Circulate a total of 7320 strokes, 3.4 bottoms up. 67% sand & 33% clay over shakers. 29 BPH losses while circulating.;Hauled 990 bbis H2O from L-Pad lake for total = 3025 bbis Hauled 380 bbis heated H2O from G&I for total = 380 bbis Hauled 1287 bils cuttinallinuids to MPU G&I for total= 2832 bible 414/2019 PJSM, Cmt Job. Shut down & blow down TD. R/U circ hose on cmt swivel. Start pump at 3 -6 BPM. Circulate and condition with ROT at 20 RPMs while waiting on citric pills to get built and pre loaded on all returns trucks due to class 1 returns not being exempt for disposal.;Well cuttings cleaned up but sand started run. Slow rate to 3 bpm. 100 PSI with no rotary. Reciprocate 30'. 128 bbls lost while circulating from 6:OO.;Line up to Halliburton and line up to test lines. Thaw water valve. Pump 5 bbls 8.5 ppg water. Test lines to 1000/ 4500 psi. Good. Line up and pump 10.0 ppg Clean Spacer at 4 BPM, 190 PSI. Break out Volant tool & Drop btm plug.;Perform surface casing cement job as per program. /t Mix and pump 388.5 bbls of 10.7 ppg Perm L cement lead 495 sacks 4.407 fi sit yield at 5 BPM 366 PSI. Mix and pump 122.52 bbis of 15.8 ppg Premium G cement tail 590 sacks, 1.166 ft^31sk yield at 4 BPM 480 PSI.;Drop closing plug. Chase with 20 bbls of 8.4 ppg water at 6 BPM, 363 PSI. Utilize rig pumps to displace with 9.6 ppg spud mud at 6 BPM, 170 PSI ICP, 750 PSI FCP. Reduce rate to 3 BPM, 610 PSI before bumping plug at 2109 strokes, 2122 strokes calculated.;lncrease to 1110 PSI. Bleed off pressure, floats holding. CIP at 17:47. 40 bbls of 10.8 ppg lead cement returned to surface, 93.5 bbls lost during cement job = 87.5% returns.;Remove mousehole. Disconnect diverter line from knife valve. Flush surface annular with black water into the cellar box, function annular 2x times. RID cement and circulation lines. RID 10-3/4" Volant casing running tool.;Safety stand down with all personnel on location. Discussed accident at A-pad. Emphasized the importance of communication. Ensure all parties involved are aware of the task and personnel involved. Perform hazard assessment and mitigation in the pre-job.; Inspect equipment and perform 360" walk around even if exiting the vehicle for a few minutes. If entering a job site, ensure others are aware of your presence. If conditions change, stop the job and re-assess.;Hoist diverter stack. NOS wellhead personnel installed 10-3/4" casing slips. 10OK weight set on slips. Cut 10-3/4" casing and UD cut joint - 25.37'. Sim-ops: empty and clean pits.;Lower diverter stack and re-install diverter line. Clean cement line valves. Install mousehole. Clear rig floor of casing equipment. Mobilize casing scraper BHA to the rig floor. Sim-ops: empty and clean pfts.;M/U stack washing tool on single of 5" drill pipe. Flush diverter with water from pill pit. Blow down the top drive. Sim-ops: empty and clean pfts.;UD drilling jars. M/U 8-112" bit, bit sub, PxP XO, 9-5/8" casing scraper and bit sub to 13'. RIH w/ 17 joints 5" HWDP & 12 joints 5" drill pipe to 916'. M/U PxP XO, 10-3/4" casing scraper and bit sub to 923'. TIH with 5" drill pipe from 92S to 2536'. Sim-ops: empty and clean pits.;Wash down from 2536' with 420 GPM = 590 PSI and tag cement stringer at 2601'. Ream down from 2601' to 2612' (cement plugs on 9-5/8" float collar) with 420 GPM = 590 PSI, 40 RPM = 4K ft/lbs TO. Circulate casing clean with 600 GPM = 1170 PSI, 40 RPM = 4K ft/lbs TO. Sim-ops: empty and clean pits.;Hauled 245 bbis H2O from L-Pad lake for total = 3270 bible Hauled 220 bbis heated H2O from G&I for total = 600 bbls Hauled 1838 bible cuftin /li uids to MPU G&I for total= 4670 bb 4/5/2019 Continue to circulate 9.5/8" x 10-3/4" surface casing clean. 620 GPM = 1100 PSI, 40 RPM = 5K ft/lbs TO, Reciprocate 30'. Sim-ops: continue to clean the mud pits.;Finish cleaning the mud pits then load with seawater.;Displace wellbore to 8.5 ppg seawater. 5-9 BPM = 200-340 PSI, 10 RPM = 3K ft/lbs TQ.;Prepare pits for 9.6 ppg brine. Clean pits, build 30 bbis high viscosity spacer and load brine.;Displace wellbore from 8.5 ppg seawater to 9.6 ppg NaCl brine. 6 BPM, 180 PSI.;Blow down top drive. POOH from 2612' laying down 5" drill pipe & 5" HWDP. UD 10-3/4" and 9-5/6" casing scrapers, bit sub and 8-1/2" bit. Bit grade 1 -1 -WT-A-E-1-PN-BHA.;Pull mouse hole. Remove riser, disconnect diverter line, r� remove diverter and diverter adapter.;lnstall FMC slip lock 11" 5K casing head, 11" 5K tubing spool, tubing head adapter and 4-1/16" dry hole tree. Test casing head seals to 500 PSI for 5 min. and 2000 PSI (80% of 10-314" collapse) for 15 min. - good test. 0b Fill casing and tree with 9.5 bbls of diesel'Pressure test 9-5/8" x 10-3/4" tapered surface casing strina to 2500 PSI for 30 minon chart - good test, 61 gallons ` pumped RID test equipment & secure well. Sim ops: Empty & clean mud pits. Move rock washer, fuel trailer & support shacks. Blow down rig floor utilities. Disconnect top drive wiring.; Final report for M-04. All charges end at 06:00.; Hauled 270 bbls H2O from L-Pad lake for total = 3540 bbls Hauled 0 bbis heated H2O from G&I for total = 600 bible Hauled 1390 bbls cutting/liquids to MPU G&I for total= 6060 bbis 0 bbls daily losses, 229 bbis cumulative losses. Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No. MP M-04 Date Run 3 -Apr -19 County State Alaska Supv. S. Sunderland / C. Demoski CASING RECORD 8urfarn � TO 2,706.00 Shoe Depth: 2,696.00 PBTD: 2,972.00 No. Jts. Delivered 87 No. Jts. Run 66 No. Jts. Returned 21 Fig. Delivered 3,429.31 Fig. Run 2,633.34 Fig. Returned 795.97 Length Measurements W/O Threads Ftg. Cut A. 25.37 Fig. Balance RKB 33.18 RKB to BHF RKB to CHF RKB to THF Csg Wt. On Hook: 130,000 Type Float Collar: Innovex No. Him to Run: 10 Csg Wt. On Slips: 100,000 Type of Shoe: Innovex Casing Crew: Doyon Rotate Csg X Yes No Recip Csg X Yes No 30 Ft. Min. 9.2 PPG Fluid Description: Spud mud Liner hanger Info(Make/Model): Liner top Packer?: Yes _No Liner hanger test pressure: Floats Held X Yes _ No Centralizer Placement: 41 each 10-3/4"x13.5" bow spring centralizers ran cross coupler on joints #1 to #42. 24 each 9-518"x12-1/4" Expand-o-laer centralizers and 6 stop rings ran. One each 10' from each end of the shoe joint (1111), one mid joint 93 and free Boating on joints #4 to #23. CEMENTING REPORT Shoe @ 2696 FC @ 2,615.34 Top of Liner Casing (Or Liner) Detail (psi): 610 Pump used for disp: Rig Bump Plug? X Yes _No Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top 1 Shoe 103/4 50.0 TXP BTC Innovex 1.58 2,696.00 2,694.42 2 Casing 95/8 40.0 L-80 TXPBTC Tenaris 77.79 2,694.42 2,616.63 1 Float Collar 103/4 50.0 TXP BTC Innovex 1.30 2,616.63 2,615.33 21 Casing 95/8 40.0 L-80 TXP BTC Tenaris 823.92 2,615.33 1,791.41 1 Casing Pup Joint 95/8 40.0 L-80 TXP BTC Tenaris 24.16 1,791.41 1,767.25 1 Casing XO 103/4 50.0 TXP BTC 1.58 1,767.25 1,765.67 42 Casing 103/4 45.5 L-80 TXP BTC Tenaris 1,718.55 1,765.67 47.12 1 Casing Cut Joint 103/4 45.5 L-80 TXP BTC Tenaris 15.00 47.12 32.12 Csg Wt. On Hook: 130,000 Type Float Collar: Innovex No. Him to Run: 10 Csg Wt. On Slips: 100,000 Type of Shoe: Innovex Casing Crew: Doyon Rotate Csg X Yes No Recip Csg X Yes No 30 Ft. Min. 9.2 PPG Fluid Description: Spud mud Liner hanger Info(Make/Model): Liner top Packer?: Yes _No Liner hanger test pressure: Floats Held X Yes _ No Centralizer Placement: 41 each 10-3/4"x13.5" bow spring centralizers ran cross coupler on joints #1 to #42. 24 each 9-518"x12-1/4" Expand-o-laer centralizers and 6 stop rings ran. One each 10' from each end of the shoe joint (1111), one mid joint 93 and free Boating on joints #4 to #23. CEMENTING REPORT Shoe @ 2696 FC @ 2,615.34 Top of Liner lush (Spacer) (psi): 610 Pump used for disp: Rig Bump Plug? X Yes _No .. Clean Spacer Density (ppg) 10 Volume pumped (BBLs) 60 1 Slurry 87.5 ant returns to surface? X ,. Permafrost L X Yes No Vol to Surf: Sacks: 495 Yield: 4.41 s'ay, (ppg) 10.7 Volume pumped (BBLs) 388.5 Mixing / Pumping Rate (bpm): 5 Slurry ad Used To Detennine TOC: Returns to surface ,. Premium G Sacks: 590 Yield: 1,w sity (ppg) 15.8 Volume pumped (BBLs) 122.52 Mixing / Pumping Rate (bpm): 4 t Flush (Spacer) Densky (ppg) Rale (bpm): Volume: Spud Mud Density (ppg) 9.6 Rale (bpm): 6 Volume (actual / calculated): 233/2 (psi): 610 Pump used for disp: Rig Bump Plug? X Yes _No Bump press ig Rotated? _Yes X No Reciprocated? X Yes_No % Returns during job 87.5 ant returns to surface? X Yes _No Spacer returns? X Yes No Vol to Surf: 40 ant In Place Al: 17:47 Date: 4/4/2019 Estimated TOC: 37 ad Used To Detennine TOC: Returns to surface Calculated Cml Vol (M 0% excess 329.41 Total Volume cam Pumped: 511.02 Cmt returned to surface: 40 Calculated cement left in wellbore: 471.02 OH volume Calculated: 311.12 OH volume actual: 458.87 Actual % Washout: 147.49 WELLHEAD Make Cameron Type Dry hole tree Serial No. Size 4.06 W.P. 5000 Test head to 2000 PSIG 15 MIN Y OK Remarks: www.weliez.net WellEz Information Management LLC ver 04818br Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-04 500292362400 Sperry Drilling Definitive Survey Report 03 April, 2019 HALLIBURTGN Sperry Drilling Company: Hilcorp Alaska, LLC Project: Milne Paint Site: M Pt Moose Pad Well: MPU M-04 Wellbore: MPU M-04 Design: MPU M-04 Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU M-04 M-04 Actual RKB @ 58.18usft M-04 Actual RKB @ 58.18usfl True Minimum Curvature NORTH US + CANADA Project Milne Point, ACT, MILNE POINT Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well MPU M-04 Well Position +N/ -S +EI -W Position Uncertainty Wellbore Magnetics MPU M-04 Model Name 0.00 usft Northing: 6,027,889.58 usfl 0.00 usft Easting: 533,393.80 usfl 0.00 usft Wellhead Elevation: 25.00 usfl Sample Date Declination (') BGGM2018 9/13/2018 17.00 Design MPU M-04 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) +NIS (usft) (usft) 33.18 0.00 Latitude: 70° 29' 14.0212 N Longitude: 149° 43'37.4048 W Ground Level: 25.00 usft Dip Angle Field Strength (`) (nT) 80.98 57,451.32042705 Tie On Depth: 33.18 +EI -W Direction (usft) (1) 0.00 170.15 Survey Program Date 4/3/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 90.00 163.00 MPU M-04 SDI Gyro (MPU M-04) 2_Gyro-NS-GC_Ddll colt H029Ga: North seeking single shot in drill colla 03/25/2019 215.28 2,665.30 MPU M-04 MWD+IFR2+MS+Sag (1) (MF 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 04/02/2019 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +EI -W Northing Easting DLS Section (usft) (1 0 (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 33.18 0.00 0.00 33.18 -25.00 0.00 0.00 6,027,889.58 533,393.80 0.00 0.00 UNDEFINED 90.00 0.15 288.07 90.00 31.82 0.02 -0.07 6,027,889.60 533,393.73 0.26 -0.03 2_Gyro-NS-GC_Drill collar (1 104.00 0.16 257.88 104.00 45.82 0.02 -0.11 6,027,889.60 533,393.69 0.58 -0.04 2_Gyro-NS-GC_Dnll collar (1 163.00 0.15 258.43 163.00 104.82 -0.01 -0.26 6,027,889.57 533,393.54 0.02 -0.04 2_Gyro-NS-GC_Drill collar (11 215.28 0.12 242.37 215.28 157.10 -0.05 -0.38 6,027,889.53 533,393.42 0.09 -0.02 2_MWD+IFR2+MS+Sag(2) 270.53 0.74 177.95 270.53 212.35 -0.43 -0.42 6,027,889.15 533,393.38 1.26 0.35 2_MWD+IFR2+MS+Sag(2) 361.45 3.41 155.24 361.38 303.20 -3.47 0.74 6,027,886.11 533,394.55 3.02 3.55 2_MWD+IFR2+MS+Sag(2) 453.12 6.24 155.17 452.72 394.54 -10.47 3.97 6,027,879.13 533,397.82 3.09 11.00 2_MWD+IFR2+MS+Sag (2) 547.55 6.78 155.54 546.54 488.36 -20.20 8.43 6,027,869.42 533,402.32 0.57 21.35 2_MWD+IFR2+MS+Sag(2) 640.19 7.36 153.98 638.47 580.29 -30.51 13.30 6,027,859.13 533,407.24 0.66 32.34 2_MWD+IFR2+MS+Sag(2) 732.75 9.28 15939 730.06 671.88 42.85 18.48 6,027,846.82 533,412.47 2.26 45.38 2_MWD+IFR2+MS+Sag(2) 827.27 11.97 165.25 822.95 764.77 -59.48 23.61 6,027,830.21 533,417.67 3.04 62.64 2_MWD+IFR2+MS+Sag(2) 921.47 14.14 171.27 914.71 856.53 -80.30 27.84 6,027,809.41 533,422.00 2.72 83.88 2_MWD+IFR2+MS+Sag(2) 4/3/2019 2:56:38PM Page 2 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU NI -04 Project: Milne Point TVD Reference: M-04 Actual RKB @ 58.18usft Site: M Pt Moose Pad MD Reference: M-04 Actual RKB @ 58.18usft Well: MPU M-04 North Reference: True Wellbore: MPU M-04 Survey Calculation Method: Minimum Curvature Design: MPU M-04 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +El -W Northing Easting DLS Section (usft) (I (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,016.31 17.26 177.05 1,006.01 947.83 -105.81 30.33 6,027,783.92 533,424.60 3.68 109.44 2_MWD+IFR2+MS+Sag(2) 1,110.77 17.39 177.91 1,096.18 1,038.00 -133.91 31.56 6,027,755.82 533,425.96 0.30 137.34 2_MWD+IFR2+MS+Sag(2) 1,206.54 18.14 179.60 1,187.39 1,129.21 -163.12 32.19 6,027,726.62 533,426.72 0.95 166.23 2_MWD+IFR2+MS+Sag(2) 1,301.43 17.33 176,57 1,277.77 1,219.59 -192.00 33.14 6,027,697.75 533,427.80 1.29 194.84 2_MWD+IFR2+MS+Sag(2) 1,394.85 16.32 176.83 1,367.19 1,309.01 -219.00 34.70 6,027,670.76 533,429.48 1.08 221.71 2_MWD+IFR2+MS+Sag(2) 1,491.51 13.87 171.27 1,460.51 1,402.33 -244.02 37.21 6,027,645+76 533,432.10 2.94 246.78 2_MWD+IFR2+MS+Sag(2) 1,585.72 10.64 173.55 1,552.56 1,494.38 -263.82 39.90 6,027.625+96 533,434.88 3.47 266.76 2_MWD+IFR2+MS+Sag(2) 1,680.33 8.27 173.83 1,645.88 1,587.70 -279.27 41.61 6,027,610.53 533,436.66 2.51 282.27 2_MWD+IFR2+MS+Sag (2) 1,776.09 5.65 175.11 1,740.93 1,682.75 -290.82 42.75 6,027,598.99 533,437.85 2.74 293.84 2_MWD+IFR2+MS+Sag (2) 1,870.57 3.75 181.30 1,835.09 1,776.91 -29854 43.08 6,027,591.27 533,438.22 2.08 301.51 2_MWD+IFR2+MS+Sag(2) 1,964.02 1.79 148.05 1,928.43 1,870.25 -302.83 43.78 6,027,586.98 533,438.94 2.63 305.86 2_MWD+IFR2+MS+Sag (2) 2,059.32 0.69 98.83 2,023.71 1,965.53 -304.19 45.14 6,027,585.63 533,440.30 1.51 307.42 2_MWD+IFR2+MS+Sag(2) 2,155.38 0.56 87.31 2,119.76 2,061.58 -304.25 46.18 6,027,585.57 533,441.34 0.19 307.67 2_MWD+IFR2+MS+Sag (2) 2,250.55 0.67 98.22 2,214.92 2,156.74 -304.31 47.19 6,027,585.52 533,442.35 0.17 307.90 2_MWD+IFR2+MS+Sag (2) 2,345.94 0.89 111.20 2,310.31 2,252.13 -304.66 48.44 6,027,585.17 533,443.60 029 308.45 2_MWD+IFR2+MS+Sag(2) 2,440.45 0.89 105.28 2,404.80 2,346.62 -305.12 49.83 6,027,584.72 533,444.99 0.10 309.14 2_MWD+IFR2+MS+Sag(2) 2,535.16 0.81 115.48 2,499.50 2,441.32 -305.60 51.14 6,027,584.24 533,446.31 0.18 309.84 2_MWD+IFR2+MS+Sag(2) 2,629.05 0.96 128.75 2,593.38 2,535.20 -306.38 52.35 6,027.583+47 533,447.52 0.27 310.82 2_MWD+IFR2+MS+Sag(2) 2,665.30 1.05 133.25 2,629.63 2,571.45 -306.79 52.83 6,027,583.06 533,448.00 0.33 311.31 2_MWD+IFR2+MS+Sag(2) 2,706.00 • 1.05 133.25 2,670.32• 2,612.14 -307.30 53.38 6,027,582.55 533,448.55 0.00 311.91 PROJECTED to TD Checked By: Chelsea Wright m m .... Approved By: Mitch Laird - Date: 04-03-2019 4/32019 2:56:38PM Page 3 COMPASS 5000.15 Build 91 11.gQj$ Dnora Oudean Hilcorp Alaska, LLC 3 0 6 2 AK_GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Itihmq, Ah. .0 U.0 Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE: 4/11/2019 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 p . • . RECEIVED rio.FR MT c( APR 16 2019 AOGCC ROP DGR EWR ALD CTN MD & TVD CD: HALLIBURTON 10 APR 2019 Name � Date modified Type Log Viewers 4/1112019 8:30 AM Filefolder CGh4 4/1112019&31 AM Filefolder Definitive Survey 4/11/20198: 32 AM Filefolder EMF 4/11120198: 32 AM Filefolder LAS 4/11/20198:32 AM Filefolder PDF 4/11/20198:32 AM Filefolder TIFF 4/11/20198:32 AM Filefolder Please acknowledge receipt by signing onyl, returning one copy of this transmittal or FAX to 907 777.8510 Received By: y\ J " I/-) q // d I Date: THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Prince Creek Water Pool, MPU M-04 Permit to Drill Number: 219-038 Sundry Number: 319-256 Dear Mr. Chad Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olasko.gov 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, `0—� Daniel T. Seamount, Jr. Commissioner S1 - DATED this 3 day of May, 2019. RBDMS1�JUN 0 3 2019 SCANNED JUN 0 6 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 E(34EIV MAY 17 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Q ' Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP 8 Gravel Pack Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ Stratigraphic ❑ Service 2. 219-038 - 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-23624-00-00 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 D MPU M-04 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL025514 I Milne Point Field / Prince Creek Water (TER Undef WTRSP) it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 2,706' 2,670' 2,615' 2,579' 836 2,615' N/A Casing Length Size MD TVD Burst Collapse Conductor 113' 20" 113' 113' N/A N/A Surface 1,766' 10-3/4" 1,766' 1,731' 5,210psi 2,470psi Surface 930' 9-5/8" 2,696' 2,660' 5,750psi 3,090psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A and N/A N/A and 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: 5"A,7 w�s'L✓ Commencing Operations: 6/8/2019 OIL ❑ WINJ ❑ WTRSP ❑✓ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: 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. T Authorized Name: Chad Helgeson Contact Name: Ian Toomey1--�— Authorized Title: Operations Manager Contact Email: toomeyOfticoracom Contact Phone: 777-8434 Authorized Signature: '1ti Cl—,kt o _,Date: 5/17/2019 COMMISSION USE ONLY Conditions of approvakytify Commission so that a representative may witness Sundry Number: Innnn n/ Plug Integrity ❑ SOP Test Mechanical Integrity Test Location Clearance ❑ /.-❑ Other: 7r �(.fN ��o. �d� ♦/G$1 Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMSI16'' JUN 031019 Spacing Exception Required? Yes ❑ No Subsequent Form Required: to L.10 7 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ! 11 jilcl 51;°[KI sORIGINAL �� / Jl mans Su'" bmA Fonn and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate U Hilmm Alwks, LLC WSW GP Well: MPU M-04 Date:05/17/2019 Well Name: MPU M-04 API Number: 50-029-23624-00-00 Current Status: SI — not perforated Pad: MP M -Pad Estimated Start Date: June 8, 2019 Rig: ASR Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 219-038 First Call Engineer: Ian Toomey (907) 777-8434 (0) (907) 909-3987 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE Number: 1814313C Job Type: WSW GP Current Bottom Hole Pressure: Not perforated Maximum Predicted BHP: 1082 psi at 2458' TVD MPSP: 836 psi (0.10 psi/ft gas gradient) Brief Well Summary: MPU M-04 was drilled to TD at 2706' MD (2670' TVD) by Doyon 14 in April 2019 in the Prince Creek formation for the Moose pad water source well (WSW). The well was cased with 10-3/4" x 9-5/8" tapered casing string and cemented back to surface. Doyon 14 did not run a completion. - Objective• Complete the M-04 WSW well by perforating the upper and lower Prince Creek formation. Run a gravel pack lower completion with and ESP upper completion. Notes Regarding Wellbore Condition • Deviation down to gravel pack (max angle 18.14° @ 1206.54'). • 10-3/4" x 9-5/8" casing was tested to 2550 psi for 30 minutes on 4/06/2019. Pre -Rig Requested: 1. RU slickline. RIH tag top of cement. POOH logging memory GR/CCL. RD slickline. 2. Clear and level pad area in front of well. Spot rig mats and containment. 3. RD well house and flowlines. Clear and level area around well. RWO Procedure: 4. MIRU ASR. RU hardline and flow back tank(s). 5. Hold pre RWO safety meeting reviewing RWO scope and objectives. Review approved Sundry from the AOGCC. 6. Check for pressure and if needed, bleed off any residual pressure off the casing. 7. ND the dry hole tree and tubing head adapter. NU 11", 5M BOPE with 3-1/2" x 6" VBR's in the upper and lower ram cavities. Install the test plug into the tubing spool. 8. PT BOPE and annular to 250/3000 psi (hold each test for 5 minutes). Perform accumulator system test. a. Perform test per ASR BOPE test procedure. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR's and annular with 5" and 5-1/2" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 9. RD BOPE testing equipment. Pull the test plug and install the wear ring. H Hil.n, AI.A., LLC 10. PU and MU sump packer assembly. WSW GP Well: MPU M-04 Date:05/17/2019 11. RIH with the sump packer on 5" DP to just above the TOC at 2600' MD. Recommended MU Torque for 5", 19.5#, 5-135, NC 50 = 30730 ft -lbs 12. Lightly tag the TOC (tagged at 2612' by Doyon 14). 13. Displace the well from 9.6 ppg brine to filtered 8.6 ppg seawater with 3% KCI. 14. POOH and place the top of the sump packer on setting depth at 2510' MD. 15. Set sump packer per HES representative. 16. POOH laying down 5" DP and lay down sump packer setting tool. PJ17. PU and MU -310' of 7", 7052 RDX Razor, 15 SPF TCP gun assembly per SLB representative. x 18. RIH with TCP gun assembly on 5" DP to 2490' MD. 19. Lightly tag the sump packer set at 2510' MD. 20. PU and space out to place the guns on depth; bottom shot at 2484' MD and top shot at 2175' MD. 21. Close the annular or UPR. Pressure up the entire well to -3000 psi and hold for 6 minutes. . 22. Bleed the well bore to 0 psi, open the annular or UPR and allow time for the guns to fire. 23. Once the guns are fired, observe the well for flow (the well should go on a slight vac). 24. Circulate a bottoms up. Ensure the well is static or on a vac. 25. POOH laying down 5" DP and lay down spent TCP gun assembly. 26. PU, MU and RIH with the following gravel pack assembly: a. Gravel pack seal assembly with 10' handling pup, 5-1/2", 17#, L-80, LTC Box x Pin �lG b. (9) Gravel pack screen joints (250 micron), 5-1/2", 17#, L-80, LTC Box x Pin w c. (3) 5-1/2" blank joints, 5-1/2", 17#, L-80, LTC Box x Pin • Recommended MU Torque for 5-1/2", 17#, L-80, LTC = 3410 ft -lbs 27. RU false rotary table and change handling equipment to 3-1/2". 28. PU, MU and RIH with 3-1/2", 9.2#, P110, Hydril 511 inner string. • Recommended MU Torque for 3-1/2", 9.2#, P110, Hydril 511= 140 ft -lbs 29. PU the gravel pack packer assembly. MU the 3-1/2" inner string to the running tool and MU the packer assembly to the blank joint. 30. RD false rotary table. 31. RIH with the gravel pack assembly on 5" DP to -2100' MD. 32. Reverse circulate 1.5 DP volume ("'54 bbls) at 2 BPM (max). 33. Continue to RIH with the gravel pack assembly to the top of the sump packer at 2510' MD. 34. Snap into the sump packer with -6.5K down and snap out with -16K PU. Note: Do not exceed 30K over pull if unable to snap out of the sump packer. 35. PU to neutral weight and drop 1-3/4" setting ball. Allow time for the ball to gravitate to the ball seat. 36. Pressure up and set the gravel pack packer per HES representative. Note: Packer initiation setting pressure = 1840 psi and final set pressure = 3121 psi. 37. PT the IA to 1000 psi for 10 minutes. Continue to pressure up on the IA to 2500 psi to burst the rupture disc. Bleed the IA to 0 psi. 38. Pressure up on the DP to 3000 psi and slowly PU to release the running tool. Once it is verified the running tool is release bleed the DP to 0 psi. i WSW GP Well: MPU M-04 AilmM Alaska, LLC Date: 05/17/2019 39. PU to reverse position. Slowly pressure up to 4700 psi (+/- 500 psi) to shear the ball seat. 40. SO, set down 30K and mark the pipe as circulating position. PU the string weight, close the annular and pressure up the IA to 500 psi. Slowly strip through the annular until the IA pressure dumps, stop and mark the pipe as reverse position. Ensure the IA pressure is 0 psi and open the annular. 41. With the running tool in the reverse position, pump 6.2 bbls of pickle (15% HCI) followed by 23 bbls of t 8.6 ppg seawater with 3% KCI. 42. Line up to take return from the DP. Reverse circulate out the pickle to the flow back tank. 43. SO to circulating position and perform injection step rate test at 1, 2, 4 & 6 BPM. Shut down and monitor the tubing and casing pressures. (p L,44. Pump the gravel pack with —10K lbs of 20/40 Carbolite proppant per HES representative.��5_ 45. PU to reverse position and reverse circulate until returns are clean. 46. Slowly PU and shift the MCS closing sleeve closed. 47. POOH laying down the 5" DP and lay down the running tool. 48. Change handling equipment to 3-1/2". POOH laying down 3-1/2" inner string. 49. RU to run 5-1/2" ESP completion. �V Q 50. RIH with the following ESP completion equipment to —1870' MD installing cross coupling clamps on every connection: a. ESP motor, 650 HP, 3418V, 115.5A b. Lower protector seal c. Upper protector seal d. Intake e. SLB pump f. Discharge Head, 5-1/2", 17#, L-80, LTC box up g. Crossover, 5-1/2", 17#, L-80 IBT Box x LTC Pin h. 1 joint, 5-1/2", 17#, L-80 IBT Box x Pin i. Nipple, HES, 4.562" XN Profile with 4.455" no-go, 10' handling pups above and below. • MU the first 15 joint to the base of the stamped triangle taking note of the required torque for each connection. Calculate the average torque and use that MU torque on the remaining connection. 51. Continue to RIH with the ESP completion on 5-1/2", 17#, L-80, IBTtubing. 52. PU and MU the tubing hanger with the landing joint. Terminate the ESP cable and splice to the penetrator. Ensure all control line ports are dummied off. a. Tubing Hanger, FMC TC -IA -EMS, 11" x5-1/2" TC -II top and bottom with 5" H BPVG b. Crossover Pup, 5-1/2", 17#, L-80 TC -II Pin x IBT Pin 53. Land the tubing hanger with extreme caution to avoid damaging the ESP cable or penetrator. RILDS. 54. Install the TWC. 55. ND the BOP stack. 56. NU the tubing head adapter and PT the tubing hanger void to 250/5000 psi. 57. NU the tree and PT the tree to 250/5000 psi. 58. Install gauges on the tree and secure the cellar. Release and RDMO ASR. 59. Turn the well over to operations via handover form. U Hih-.n, AI.A., LLC Attachments: 1. As -built Schematic 2. Proposed Schematic (Prince Creek) 3. Blank RWO MOC Form WSW GP Well: MPU M-04 Date: 05/17/2019 B flileorP Alaska, LLC Orifi. KB Elev.: 58.2/ GL Elev.: 25.0' RKB—THF:29.91'``n 14 Diesel A 20" 10-3/4' 9,6 VPB NaCl Brine a SCHEMATIC TREE & WELLHEAD Milne Point Unit Well: MPU Moose Pad M-04 Last Completed: 4/5/2019 PTD: 219-038 Tree 41/16" 5M Tree (Dry Hole Tree) Wellhead 11" SM Wellhead x 7" TXP Top and Bottom Hanger with Top 7" CIW "f' BPV profile. Zea 3/8" NPT control lines. OPEN HOLE / CEMENT DETAIL 42" 50 bbls (10 Yards Pilecrete dumped down backside) 13-1/2" 388.5 bbl (495 sx) Lead 10.7 ppg / 122.5 bbl (590 sx) Tail 15.8 ppg CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 20"x34" Conductor (insulated) 215.5/X-42/Weld N/A Surface 113' N/A 10-3/4" 45.5 / L-80 / TXP SR 9.794" Surface 1,766' 0.0961 Surface/Production 95/8" 40/L-80/TXP SR 8.679" 1,766' 2,696' 0.0758 TUBING DETAIL WELL INCLINATION DETAIL KOP @ 300' Max Hole Angle = 18.14deg. JEWELRY DETAIL No. Top MD i Item Drift ID 1 1,767' 1-1/2" x 9-5/8" Cross-over I I PERFORATION DETAIL Schrader Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status GRAVEL PACK DETAIL a GENERAL WELL INFO API: 50-029-23624-00-00 Drilled and Cased by Doyon 14 - 4/5/2019 13-1/2' 9-5/8" Hole Shce @ 2,696' TD= 2,706' (MD) /TD= 2,670'(TVD) PBTD=2,615' (MD)/TD=2,579'(TVD) Revised By: TDF 5/6/2019 H B ilcorp Alaska. LLC orifi. IB Bev.: 5&7/ 61 Elev.: 25.(Y RtB—THF: 29.41' An 14 ^. 20' 51/2" 2 3 4 5 6 7 103/4" I = a PROPOSED SCHEMATIC TREE & WELLHEAD Milne Point Unit Well: MPU Moose Pad M-04 Last Completed: 4/06/2019 PTD: 219-038 Tree 41/1V 5M Tree(Dry Hole Tree) Wellhead 11" SIM Wellhead x 7"TXP Top and Bottom Hanger with 7"CIW T' Top BPV profile. Zea 3/8" NPT control lines. OPEN HOLE /CEMENT DETAIL 42" SO bbls(l0yards Pilecrete dumped down backside) 13-1/2 388.5 bbl (495 sx) Lead 10.7 ping / 122.5 bbl (590 sx) Tail 15.8 ppg CASING DETAIL Size TYpe Wt/ Grade/ Conn Drift ID Top Btm BPF 20'k34" Conductor Qnsulated) 215.5/A-53/Weld N/A Surface 113' N/A 10-3/4"45.5/L-80 N/A /TXP SR 9.794" Surface 1,766' 0.0961 ±1,820' Surface/Production N/A 6 41,821' Upper Protector Seal Section N/A 9 5/8" ±1,833' q 0 / L-80 / TXP SR 8.679" 1,766' 2,696' 0.0758 10 TUBING DETAIL Tubing 17/L-80/[BT-MOD 1 4.892" Surface ±1,900' 0.0232 WELL INCLINATION DETAIL E @ 300' Max Hole Angle = 18.14deg. IFWFI RY DFTAII No. Top MD Item Drift ID 1 ±29' Tubing Hanger, FMC, 5-1/2" TXP Top & Btm with 5" H BPVG 4.892" 2 ±1,752' Nipple, HES, 4.562" XN Profile with 4.455" no-go 4.455 3 ±1,807' Discharge Head N/A 4 ±1,808' Schlumberger Pump N/A 5 ±1,820' Pump Intake N/A 6 41,821' Upper Protector Seal Section N/A 7 ±1,833' Lower Protector Seal Section N/A 8 1 ±1,844' 1 Single ESP Motor (650 HP, 3418V, 115.5A) —Bottom at 1,870' N/A 9 ±1,976' 1 9-5/8" HES VGH Gravel Pack Packer 6.000" 10 ±2,007' Blank Pipe, 5-1/2", 17p, L-80, LTC Blank Pipe, 3 its (120'total length) 4.767" 11 12,127' S-1/2" Gravel Pack Screens (250 Micron), 9 Its (373' total length) 4.767" 12 ±2,510' Snap Latch Seal Assembly 4.640" 13 ±2,510' 9-5/8" HES BWD Sump Packer—Tubing Tail @2,925' 6.000" PERFORATION DETAIL Scher Sands rad Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Upper Prince Ck ±2,175' ±2,266' ±2,139' ±2,230' ±91 Planned Planned Lower Prince Ck ±2,285' ±2,484' ±2,249' ±2,448' ±199 Planned I Planned Upper/Lower Prince Creek -7" 7052 RDX Razor, 15 spf (52 gr) TCP YSW?2'u%I Ra1213S�@ Hok 1 2,696' TD=2,7x6' (MD)/TD=2,67U(M) PBTD=2,615' (MD) /TD= 2579'(TVD) GRAVEL PACK DETAIL UPC/LPC-sands: 10,000 lbs of 20/40 Carbolite proppant behind screen GENERAL WELL INFO API: 50-029-23624-00-00 Drilled and Cased by Doyon 14 -4/06/2019 Revised By: IAT 5/1/2019 HHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Date: May 17th , 2019 Subject: Changes to Approved Sundry Procedure for Well M-04 Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. HAK Step Page Date Procedure Change Prepared B Initials HAK Approved B Initials AOGCC Written Approval Received Person and Date Approval: Prepared: Operations Manager Date Operations Engineer Date THE STATE OIALASKA 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.cilaska.gov Re: Milne Point Field, Tertiary Undefined WTRSP, MPU M-04 Hilcorp Alaska, LLC Permit to Drill Number: 219-038 Surface Location: 5040' FSL, 771' FEL, Sec. 14, T13N, R9E, UM, AK Bottomhole Location: 540' FNL, 729' FEL, Sec. 14, T13N, R9E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this Z Z day of March, 2019. STATE OF ALASKA A.....iKA OIL AND GAS CONSERVATION COMI'i—SION PERMIT TO DRILL 20 AAC 25.005 R E C EL, F '14� I_ MAR 11 2019 1a. Type of Work: 11b. Proposed Well Class: Exploratory - Gas ❑ Service- WAG ❑ Service - Disp ❑ tc. Specify if well is proposed for: Drill Q Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑ Single Zone El Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply El 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 + MPU M-04 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 2,972' TVD: 2,934' Milne Point Field Prince Creek Water 4a. Location of Well (Governmental Section): 7. Property Designation: ��$ Surface: 5040' FSL, 771' FEL Sec 14, T13N, R9E, UM, AK ADL025514 Ttr�l Q•Y u„ ate; Top of Productive Horizon: 8. DNR Approval Number: 1,1111 13. Approximale Spud Date: W ftT5F 540' FNL, 729' FEL, Sec 14, T13N, R9E, UM, AK LONS 16-004 3/29/2019 Total Depth: 9. Acres in Property: , 14. Distance to Nearest Property: 540' FNL, 729' FEL, Sec 14, T13N, R9E, UM, AK 2560 539' to nearest unit boundary , 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 58.7 15. Distance to Nearest Well Open Surface: x-533393 r y- 6027889 Zone -4 GL / BF Elevation above MSL (ft): 25 to Same Pool: 9,850' to MPF -02 ' 16. Deviated wells: Kickoff depth: 280 feel 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 18 degrees ' Downhole: 1210 1 Surface: 917 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) Cord 20" 78.6# A-53 Weld 113' Surface Surface 113' 113' ±270 ft3 13-112" 10-3/4" 45.5# L-80 TXP SR 2,215' Surface Surface 2,215' 2,177' L - 2477 ft3 9-5/8" 40# L-80 TXP SR 757' 2,215' 2,177' 2,972' 2,934' 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): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No ❑Q jnJ Pac-lc- 20. Attachments: Property Plat O BOP Sketch[] Drilling Program 8 Time v. Depth Plot Shallow Hazard Analysis 8✓ Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirementse✓ 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: rpm erS hilCor .Com Authorized Title: Drilling Manager Contact Phone: 777-8431 Z Authorized Signat Date: J i (, tfl Commission Use Only Permit to Drill ' /p 2 o3,8 API Number: 02 Permit Approval See cover letter for other Number: / ^ 50- ZS4' ��'(WJ'" Date: requirements. r�r Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: IJ Other: Samples req'd: Yes [-]No Ly Mud log req'd: Yes ❑ No Er H2S measures: Yes p No [0' Directional svy req'd: Yes [g"No❑ Spacing exception req'd: Yes ❑ No LVJ Inclination -only svy req'd: Yes ❑ No Ill�S �� n r� e 4v CD Post initial injection MIT req'd: Yes ❑ No ❑ Yl� :..a�..�.J /J /f_ J n 0• _i'C% ems. APPROVED BY J � Approved by. COMMISSIONER THE COMMISSION Date: / / J '2 °-Z{ Ci - Submit Form and Form 10-401 Revised 5/201 his per t s valid O 2p ,mss fr�r 'eLl approval per 20 AAC 2 005(g) Attachments in upl'c to 0lul r, Q R�V I A /Z3%f3�a9 Hilcorp Alaska, LLC Milne Point Unit (MPU) M-04 Water Source Well Drilling Program Version 0 March P, 2019 ff Hilcorp �� cm�> Contents Milne Point Drilling Procedure 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 Casing Inspection............................................................................................................................4 6.0 Internal Reporting Requirements..................................................................................................5 7.0 Planned Wellbore Schematic..........................................................................................................6 8.0 Drilling / Completion Sum mary....................................................................................................7 9.0 Mandatory Regulatory Compliance / Notifications.....................................................................8 10.0 R/U and Preparatory Work............................................................................................................9 11.0 N/U 21-1/4" 2M Diverter System.................................................................................................10 12.0 Drill 13-1/2" Hole Section.............................................................................................................11 13.0 Run 10-3/4" X 9-5/8" Surface/Production Casing......................................................................14 14.0 Cement 10-3/4" X 9-5/8" Surface Casing....................................................................................18 15.0 Wellbore Clean Up & Displacement............................................................................................21 16.0 BOP N/U and Test.........................................................................................................................22 17.0 Completion Operations.................................................................................................................23 18.0 Diverter Schematic........................................................................................................................24 19.0 BOP Schematic..............................................................................................................................25 20.0 Wellhead Schematic......................................................................................................................26 21.0 Days Vs Depth................................................................................................................................27 22.0 Anticipated Drilling H azards......................................................................................................28 23.0 Doyon 14 Rig Layout.....................................................................................................................30 24.0 Choke Manifold Schematic...........................................................................................................31 25.0 Casing Design Information...........................................................................................................32 26.0 9-7/8" Hole Section HASP ............................................................................................................33 27.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................34 28.0 Surface Plat (As Built) (NAD 27).................................................................................................35 29.0 Directional Plan (wp 06)...............................................................................................................36 ff Hilcorp �� C.,� 1.0 Well Summary Milne Point Unit M-04 Drilling Procedure Well MPU M-04 Pad Milne Point "M" Pad Planned Completion Type 7" Injection Tubing Target Reservoirs Prince Creek Planned Well TD, MD / TVD 2,972' MD / 2,934' TVD PBTD, MD / TVD 2,800' MD / 2,762' TVD Surface Location (Governmental) 5,040' FSL, 771' FEL Sec 14, T13N, R9E, UM, AK Surface Location (NAD 27 — Zone 4) X=533,393.8 Y=6,027,889.58 Top of Productive Horizon (Governmental) 540' FNL, 729' FEL, Sec 14, T13N, R9E, UM, AK TPH Location (NAD 27) X=533,437.29, Y=6,027,590.05 BHL (Governmental) 540' FNL, 729' FEL, Sec 14, T13N, R9E, UM, AK BHL AD 27) X=533,437.29, Y=6,027,590.05 AFE Number 1814313 AFE Drilling Days AFE Completion Days AFE Drilling Amount AFE Completion Amount AFE Facility Amount Maximum Anticipated Pressure Surface 917 psi Maximum Anticipated Pressure Downhole/Reservoir) 1210 psi KB Elevation above MSL: 33.7 It + 25 ft = 58.7 ft GL Elevation above MSL: 25 ft BOP Equipment 13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams Page 2 Version 0 March, 2019 H Hilmr �,gy 2.0 Management of Change Information Milne Point Unit M-04 Drilling Procedure If Hilcorp Alaska, LLC x pile rp Changes to Approved Permit to Drill Date: March 3, 2019 Subject: Changes to Approved Permit to Drill for MPU M-04 File #: MPU M-04 Drilling Program Any modifications to MPU M-04 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. Approval: Monty M Myers 3.4.2019 Prepared: Drilling Engineer Date Page 3 Version 0 March, 2019 H Hilcorp 3.0 Tubular Program: Milne Point Unit M-04 Drilling Procedure Burst Collapse Tension (psi) I (psi) (k -lbs) Cond 20" 19.25" - 78.6 A-53 Weld 10-3/4" 9.95" 9.794" 11.25" 45.5 13-1/2" X X X X X L-80 TXP/SR 5,210/ 2,470/ 1 916 9-5/8" 8.835" 8.679" 10.625" 40 5,750 3,090 916 V,r E ,-- 4.0 Drill Pipe Information: le Section OD in ID (in) TJ ID (in) TJ OD in #t/t't is S-135 NC50 1 25,900 1 26,800 1 560 ALL 5" 4.276" 3.25" 6.625" 19.5 5.0 Casing Inspection All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 0 March, 2019 H Hilcorp enema como.�y Milne Point Unit M-04 Drilling Procedure 6.0 Internal Reporting Requirements 6.1 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. • Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 6.2 Afternoon Updates • Submit a short operations update each work day to mm, ers e hilcorp.com, pmazzolini(c�r�hilcorp.com , iengelt7a hilcorp.com and cdingerghilcorp com 6.3 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. 6.4 EHS Incident Reporting • Health and safety: Notify EHS field coordinator. • Environmental: Drilling Environmental coordinator • Notify Drlg Manager & Drlg Engineer • Submit Hilcorp Incident report to contacts above within 24 hrs 6.5 Casing Tally • Send final "As -Run" Casing tally to mmyers e.hilcorp.com and cdingerl7a hilcoM.com 6.6 Casing and Cement report • Send casing and cement report for each string of casing to mmyers@hileorp.com hileorp.com and cdinger a hilcoM.com 6.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmyers@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 iengel@hilcorp.com Completion Engineer Paul Chan 907.777.8333 907.444.2881 pchan@hilcorp.com Geologist Kevin Eastham 907.777.8316 907.360.5087 keastham@hilcorp.com Reservoir Engineer Reid Edwards 907.777.8421 907.250.5081 reedwards@hilcorp.com Drlg Environmental Coord Keegan Fleming 907.777.8477 907.350.9439 kfleming@hilcorp.com Safety Manager Chet Starkel 907.777.8344 406.544.7862 cstarkel@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorp.com Page 5 Version 0 March, 2019 Milne Point Unit M-04 Drilling Procedure Hilcorp 8vem Dospmy 7.0 Planned Wellbore Schematic Ort, K8 Elm: 5&7/GL Dei.: 25.7 -THP: 33.7 lel t A 20' I 7' T A r 2 Milne Point Unit Well: MPU Moose Pad M-04 PROPOSED SCHEMATIC Last Completed: Proposed PTD: TBD TREE & WELLHEAD Tree 71/16"SMTree Wellhead 135/8"5M Wellhead x7"TXP Top and Bottom Hanger with 7-CIW"J" Top BPV profile.2ea 3/8" NPTcentrol lines. OPEN HOLE / CEMENT DETAIL 42' 50 bbls (SOYards Pilecrete dumped down backside) 131/2' 650sa 11.7XEdmda,250sa15.8KSwIflCEM CASING DETAII Size a I Type I WV Grade/ Conn 1 Drift ID I Top I Btm I BPF 27k34' I Conductor(Insulated) 78.6/A-53/Weld N/A Surf 1065' N/A 10.3/4' N/A 45.5/L-80/UP SR 9.794' Surface_ 2,215' 0.0961 2,151' Surface/Production ami Nn N/A 6 2,165' Pump Intake N/A 9-5/8' 2,166' 40/L-00/TXP SR 8.679' 2,215' 2,972' 0.0758 11.115=3 Ut I AIL 4 N 7' Tubing 26/L-80/TXP SK 6.151' 1 Surf 2,205' 0.0382 5'a a WELL INCLINATION DETAIL KOP @300 r Max Hde Nlgle = 21.00deg. @ 1,000' MD B 9 Uk rB JEWELRY DETAIL No. Top MD Item Drift to 1 29' Tubing Hanger (7* TXPTop&Sinn) 6.000" 2 2AW 7" XN Profile, 5.875' Puking, Min 1D=5.750" 5.750' 3 2,136' Discharge Mead N/A 4 2,137' Cerddllft Upper Pump WA 5 2,151' Cerdnllft Lower Pump N/A 6 2,165' Pump Intake N/A 7 2,166' Tandem seal Section N/A 8 2,187 Single ESPXP Motor 800 HP) WA 9 2200' MUIR Type E Sensor w 6 fin [entraluer-Bottom @2,205' WA 10 21225' 9-5/8' Gravel Pads Packer (8.250" ID) 8.250- 11 2,245' 7' Blank Pipe, 3 Its (9W total length) 6.151' 12 2,335' 7' 12 -gauge (300 Mluon) Excluder SCreemA Its(247total length) 6.151' 13 2,575' 7'SunnPacker-Tubing Tall@2,5W(6.I5r ID) 6.151' 14 2,580' 9-5/8' Gravel Pack Packer (8.25(r ID) 8.250' 15 2,597 7' Blank Pipe, lits 137 total length 6.151" 16 2,627 7"12-gauge300M Mum) Excluder Screen,10Its (3D0'total length) 6.151" 17 2,927 7' Sump Pack" - Tub] n Tall@ 2,925'(6.15r ID) 6.151" PERFORATION DETAIL Vder Sxnds Top (MD) Btm(MD) Top (TVD) Btm(TVD) FT Date Status Princa k 2,355' 2,570' 1 2,257 2A57 215 1 Planned Planned Lower Prinee0k 2,625' 2,897 I 2,500' 2,757 265 1 Planned Planned Upper/Lown prince Creek -7' 7052 RDX Raz", 15 spf (52 gr)TCP t7 GRAVEL PACK DETAIL GENERAL WELL INFO ri UPC -sands: 15,000Ibs of 20-40 Carbo) to proppau behind screen API: $D -029-23X70(-0000 131/Y @ LPC-sands:I5,0001bs of 2040 Carbollte proppam behind screen Drilled and Cased by Doyon 11 -12/15(2018 H* ZM T1)=2.972' (MD)/TD=2,934'(1%0) P8TD = 2800' (MD) / 7D = 2,762'(TVD) Page 6 Version 0 March, 2019 H �11C� Milne Point Unit M-04 Drilling Procedure 8.0 Drilling / Completion Summary MPU M-04 is a grassroots water source well intended for producing Prince Creek water to be used as injection water on M Pad injection wells. Wellbore is located on "Moose" pad. The directional plan is an "S" shaped well with the kick off point at 280' MD/TVD. Maximum hole angle is 18 degrees. Drilling operations are expected to commence approximately March 29th, 2019. A tapered surface/production casing string will be run to 2,972' MD / 2,934' TVP—and cemented to surface via a singe stage primary cement job. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6 —18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. All waste & mud generated during drilling operations will be hauled to the Milne Point G&I facility located on `B" pad. General sequence of operations: 1. MOB Doyon 14 to well site ` 2. N/TJ 21-1/4" conductor and 16" diverter line. 3. Drill 13-1/2" hole to TD. Run and cmt 10-3/4" X 9-5/8" casing. 4. RU eline to perforate casing. 5. Run gravel pack equipment and perform gravel pack operations. 6. Run upper completion 7. N/D diverter, N/U tree, RDMO. Reservoir Evaluation Plan: 1. Surface hole: No mud logging. On Site geologist. LWD: GR + Res Page 7 Version 0 March, 2019 H Hilcorp Milne Point Unit M-04 Drilling Procedure 9.0 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. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: • There are no variance requests at this time. Summary of Well Control Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 13-1/2" 21-1/4" 2M diverter (Hydril MSP) w/ 16' diverter line Function Test Only • Primary closing unit: NL Shaffer, 6 station, 3000 psi, 180 gallon accumulator unit. r/ • Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is a 30:1 air pump, and emergency pressure is provided by bottled nitrogen. • The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: • 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. Page 8 Version 0 March, 2019 K HE-Wilcorp Regulatory Contact Information: Milne Point Unit M-04 Drilling Procedure AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: iim.regg@alaska.gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz@alaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: Victoria.loepp@alaska.gov Mel Rixse / Petroleum Engineer / (0): 907-793-1231 / (C): 907-223-3605 / Email: melvin.rixse@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: hiip://doa.alaska.gov/oze/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) 10.0 RX and Preparatory Work 10.1 Install conductor. 10.2 Dig out and set impermeable cellar inside existing culvert. 10.3 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 10.4 Install slip-on 16-3/4" 3M "A" section. Ensure to orient wellhead so that tree will line up with flowline later. 10.5 Insure (2) 3" threaded nipples are installed on opposite sides of the conductor with ball valves on each nipple. These will be used to take cement returns to the cellar during the surface cmt job, and also to wash out the diverter and hanger in preparation for running the pack -off. 10.6 Level pad and ensure enough room for layout of rig footprint and R/U. 10.7 MIRU Doyon #14. 0 10.8 Mud loggers WILL NOT be used on M-04. 10.9 Mix spud mud for 13-1/2" surface hole section. Keep mud cool. 10.10 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 10.11 Install 6" liners in mud pumps. • Continental EMSCO FB -1600 mud pumps are rated at 4665 psi, 462 gpm @ 110 spm @ 95% volumetric efficiency. Page 9 Version 0 March, 2019 H Hilcorp 11.0 N/U 21-1/4" 2M Diverter System Milne Point Unit M-04 Drilling Procedure 11.1 NIU 21-1/4" Hydril MSP 2M diverter System (Diverter Schematic at Sec 20 at back of program). • NIU 16-3/4" 3M x 21-1/4" 2M DSA on 16-3/4" 3M wellhead. • N/U 21-1/4" diverter "T". • Knife gate, 16" diverter line. • Ensure diverter RAJ complies with AOGCC reg 20.AAC.25.035(C). • Diverter line must be 75 ft from nearest ignition source • Place drip berm at the end of diverter line. 11.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 11.3 Ensure to set up a clearly marked "warning zone" is established on each side and ahead of the vent line tip. "Warning Zone" must include: • A prohibition on vehicle parking. A prohibition on ignition sources or running equipment. A prohibition on staged equipment or materials. Restriction of traffic to essential foot or vehicle traffic only. 11.4 Set 15.375" ID wear bushing in wellhead. 11.5 Rig & Diverter Orientation: 75' Radius Clear of Ignition Sources Diverter Line 'Drawing Not To le MPU M -Pad Diverter Orientation May Change On Location Page 10 Version 0 March, 2019 n Hilcorp E.e Compevy 12.0 Drill 13-1/2" Hole Section Milne Point Unit M-04 Drilling Procedure 12.1 P/U 13-1/2" directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Be sure to run a UBHO sub so that wireline orientation is possible if necessary. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Workstring will be 5" 19.5# S-135 NC -50 • Run a solid float in the surface hole section. 12.2 Begin drilling out from 20" conductor at reduced flow rates to avoid broaching the conductor. • Drill 13-1/2" hole section to section TD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. • Hold a safety meeting with rig crews to discuss: • Conductor broaching ops and mitigation procedures. • Well control procedures and rig evacuation. • Flow rates, hole cleaning, mud cooling, etc. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Keep mud as cool as possible to keep from washing out permafrost. • Pump at 450-600 gpm. Ensure shaker screens are set up to handle this flowrate. • Keep swab and surge pressures low when tripping. • Make wiper trips if necessary. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. • Take MWD surveys every stand drilled (95' intervals). • Be prepared for GAS HYDRATES at the base of the permafrost. However none were • encountered on M-03 • Do not stop to circulate out gas hydrates — this will only exacerbate the problem by washing out additional permafrost. Attempt to control drill (150 fph MAX) through the zone completely and efficiently to mitigate the hydrate issue. Flowrates can also be reduced to prevent mud from belching over the bell nipple. Consider adding mud products such as Lecithin to allow the gas to break out. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. • Do not stop to circulate on wiper trips with bit across a slide interval, especially not in an area where DLS is > 4. Page 11 Version 0 March, 2019 K �11C0l� Milne Point Unit M-04 Drilling Procedure • Do not slide for 100' MD above the base of the permafrost or 100' below the base. We want to leave this transition as undisturbed as possible. 12.3 13-1/2" hole mud program summary: • Density: 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. We will start with a simple gel + FW spud mud at 8.8 ppg. • PVT System: An electronic PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, and Toolpusher office. • Hydrates: Hydrates have not been encountered on "L" or "M" pad but be prepared and don't stop to circulate out gas. Control drill when hydrates encountered. • Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. • Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM (10 ppb total) BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. • Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high -clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5 — 9.0 range with caustic soda. Daily additions of ALDACIDE G / X-CIDE 207 MUST be made to control bacterial action. • Casing Running: Reduce system YP with DESCO 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). System Type: 8.8 — 9.5 ppg Pre -Hydrated Aquagel/freshwater spud mud Properties: Section Density Viscosity Plastic Viscosity Yield Point API FL Temp I pH Surface 8.8-9.5 75-175 20-40 25-45 <10 < 70° F 8.5-9.0 Page 12 Version 0 March, 2019 H Hilcorp Milne Point Unit M-04 Drilling Procedure System Formulation: Gel + FW spud mud Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 15 - 20 ppb caustic soda 0.1 ppb (8.5 — 9.0 pH) BARAZAN D+ as needed BAROID 41 as required for 8.8 — 9.5 ppg PAC -L /DEXTRID LT if required for <10 FL ALDACIDE G 0.1 ppb 12.4 At TD; pump sweeps, CBU, and pull a wiper trip back to the 20" conductor shoe. 12.5 If hole conditions will not allow the BHA to be pulled out on elevators, prior to initiating backreaming, try to orient motor to high side and attempt to pump out to avoid damaging the wellbore. 12.6 Should backreaming be absolutely necessary to get out of the hole: • Prior to initiating backreaming, ensure at least 3 — 4 B/U have been circulated to get hole as clean as possible. • Pump at full drill rate (450 — 550 gpm), and maximize rotation. • Pull slowly, 5 —10 R / minute. • Monitor well for any signs of packing off or losses. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. • If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 12.7 TOH with the drilling assy, handle BHA as appropriate. 12.8 No open hole logging program planned. Page 13 Version 0 March, 2019 H �11Cc0� Milne Point Unit M-04 Drilling Procedure 13.0 Run 10-3/4" X 9-5/8" Surface/Production Casing 13.1 R/U and pull 15.375" wear bushing. 13.2 Make a dummy run with the 10-3/4" casing hanger. 13.3 R/U Weatherford 9-5/8" casing running equipment. • Ensure 9-5/8" TXP x NC -50 XO on rig floor and M/U to FOSV. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • Consider R/U of CRT if hole conditions require. • R/U a fill up tool to fill casing while running if the CRT is not used. • Ensure all casing has been drifted to 8.75" on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 13.4 P/U shoe joint, visually verify no debris inside joint. 13.5 Continue M/U & thread locking shoe track assy consisting of: • (1) Shoe joint w/ float shoe bucked on (thread locked). Install (2) centralizers on shoe joint over stop collars 10' from each end. • (1) Joint with float collar bucked on pin end & thread locked. Install (1) centralizer mid tube over a stop collar. • Ensure proper operation of float equipment while picking up. • Ensure to record S/N's of all float equipment and stage tool components. 9-5/8" 40# L-80 TXP Make Up Torques: Casing OD Min M/U Torque Max M/U Torque 9-5/8" 18,860 ft -lbs 23,060 ft -lbs 13.6 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Install (1) centralizer across couplings on each joint. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Any packing off while running casing should be treated as a major problem. It is preferable to POH with casing and condition hole than to risk not getting curt returns to surface. Page 14 Version 0 March, 2019 n Hilcorp E-0C—P-EY Milne Point Unit M-04 Drilling Procedure 13.7 At approximately 2,200' make up a 9-5/8" TXP X 10-3/4" TXP crossover and change over equipment to run 10-3/4" casing. • Ensure 10-3/4" TXP x NC -50 XO on rig floor and M/U to FOSV. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • R/U a fill up tool to fill casing while running if the CRT is not used. • Ensure all casing has been drifted to 9.875" on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 13.8 Continue running 10-3/4" surface casing • Fill casing while running using fill up line on rig floor. • Install (1) centralizer across couplings on each joint. • Any packing off while running casing should be treated as a major problem. It is preferable to POH with casing and condition hole than to risk not getting cmt returns to surface. 10-3/4" 45.5# L-80 TXP Make Up Torques: Casing OD Min M/U Torque Max M/U Torque 10-3/4" 20,370 ft -lbs 24,890 ft -lbs 13.9 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 13.10 Slow in and out of slips. 13.11 PIU casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 13.12 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 13.13 Have emergency slips ready to go in the event we cannot land the hanger. 13.14 R/U circulating equipment and circulate B/U. Reduce YP to < 20 to help ensure success of cement job. Ensure adequate amounts of cold WU water are available to achieve this. Elevate hanger slightly above hang off point while circulating to avoid plugging the flutes. 13.15 After circulating, lower string and land hanger in wellhead again. Page 15 Version 0 March, 2019 H �11C0� For the latest performance data, always visit our website: www.tenaris.com TXP® BTC Milne Point Unit M-04 Drilling Procedure ........ 03/0412019 Outside Diameter 9,625 in. Min. Wall 87.5% CannecMn OD Opbun REGULAR Thickness (Grade LBO 61W PERFORMANCE Type, t Wail Thickness 0.395 in. Connection 00 REGULAR Internet Pressure capacity 10 5750A00 Dai Galion be COUPLING WE Body Compressan E9icam, 100% Comirresston strength 91 S.M 0000 Body. Red 1st Band: Red Grade 0 L80 Type Drift AN Standard 1st Ban: Brown 2nd Band'. 2nd BzM. - Brown T7Pe Casing 3rd Band. - 3rd Bare: - 4th Band. - PIPE BODY DATA GEOMETRY nor,nnal OD 9.68 m. Nominal Weight a Was Orifi 8.679 in. Nomnal l0 B."s in. Wall lia.1mss 0395 m. Plain EM Waiht 09.97 bsdl OD Teterence API PERFORMANCE Body Yard Stream 916x1000bs Internal Yield 5750M sMYs 50000ps1 Cultaps, 3090 as. CONNECTION DATA GEOMETRY ConrmcNon OD 10.625 in. Couphn9 Lanae, 10.525... Connection 10 BAS in. Make-up Loss 4.891 In. Threats perm 5 CannecMn OD Opbun REGULAR PERFORMANCE Tension Eduiency IWO % dant Yield StrengSr 919.900 x1000 Internet Pressure capacity 10 5750A00 Dai be Compressan E9icam, 100% Comirresston strength 91 S.M 0000 Max. A Imvatuls Bendm, 39'/100 it os E.temal Pressure Capaoty 3090.000 pin MAKE-UPTOROUES Muimum 1B96UMbs Optimum 20860 kips Maemum 230609bs OPERATION LIMIT TORQUES Overaeno Tom" 35800 Nibs Yield! Teri 43400 NJbs Notes This connection is fully interchangeable with: TXP@ BTC - 9.625 in. - 36 / 43.5 / 47 if 53.5 / 58.4 lbs/ft 111 Internal Pressure Capacity related to structural resistance only. Internal pressure leak resistance as per section 10.3 API 5C31 ISO 10400.2007. Datasheet is also valid for Special Bevel option when applicable - except for Coupling Face Load, which will be reduced. Please contact a local Tenaris technical sales representative. Page 16 Version 0 March, 2019 H Hilcorp an CPmPx For the latest performance data, always visit our website: www.tenaris.com TXP® BTC Milne Point Unit M-04 Drilling Procedure --- 10/17/2018 Collapse 2470 eel CONNECTION DATA GEOMETRY Connection OD 11.750in. Cwping Length 10.825ln. Colon to 993s in Makeup Loss 4.891.. Thne s per in 5 Connection OD Option REGULAR PERFORMANCE Tenzian ETdnmy 100.0% Jom1 YmU Strength 1040.000 n1000 Imornal Pressurecap ty;" 5210.000ink en Campmssmn ENeicnry 100% CentOressim suengln 1010.000.1000 Max.Almxeeftnxling U -1100B be External Pressure Capacity 2470.000 i i MAKE-UP TORQUES Minimum 20370 haps Opentum 22630 nabs Maximum steel fi W OPERATION LIMIT TORQUES Operating Togw 3]300 Mirk Ylekl Tereus 45400 I1abs Notes This connection is fully interchangeable with, TXP® BTC - 10.75 in. - 40.5151 Ibs/f1 111 Internal Pressure Capacity related to structural resistance only. Internal pressure leak resistance as per section 10.3 API SC3I ISO 10400 - 2007. Datasheet is also valid for Special Bevel option when applicable - except for Coupling Face Load, which will be reduced. Please contact a local Terrains technical sales representative. For further information on concepts indicated in this datasheet, download the Dalasheet Manual from www.tenans.com rMMe Ma 6WM II! a4Wn091w 9e.Mrdl nlamalm Wv. ane NO nIp11NUM n lnsaonwMni. n4x5np 1nlMtl FNXM. enr pdRtl. egvatgSaaOigtV ('mIgTNLn+) rot n1mMJ meMWwm NnrCf\d19 V ✓ry oNtr tyM olmnM vtawnmCMalgn apt a pronOCU onan-m,e' bleb. Ho waranfy ie e`en. Tawr1! Ma Ml,rGeptlumndy VCnM1L'aanY mfpnh6Tl ylanV'PICNCCa IW tM Nan MIVMl9ron wm.aMmePVpazc N.an IN Mm pnCwlV hneunM.TM ux MNc hlormlemnmux+ioxn nsF N-0ienaru IXea 1W asawm mYrnrynfe,4ry W laptlyd Yry Faq IpanY 1xa. ammaSew ryvry reyAtq hem. an<omCaOn Mtratty h'Vniatlm emtamM nmetlMer Page 17 Version 0 March, 2019 oublde Oiameler 10.7800/. Min. well 67.5% Thick.... rl Grade Late �I Type 1 Well Thickness 0.400 in. Connection GO REGULAR Option COUPLING PPE BODY Body. Rad 1st Band: Red o Grad. LBO Type t' oHft API Situated 1s1 Bane: Brown 2M Bona: 2M Band: - Brown Type caaiDB 3rd Band: - 31d Band: - 41h Band - PIPE BODY DATA GEOMETRY NanirW OO 10.750 in. NominMwe'tn 45.5 eev Nit 9.796 in, Nonninal to 9950'n. Wan T. cess 0.4000/. Ptah End MON 44.26Its, h OD Tolerance AN PERFORMANCE Bad, Yield seetgh 1040.1000105 Inlerntal Yk01 5210 pv' 6MY6 60000W Collapse 2470 eel CONNECTION DATA GEOMETRY Connection OD 11.750in. Cwping Length 10.825ln. Colon to 993s in Makeup Loss 4.891.. Thne s per in 5 Connection OD Option REGULAR PERFORMANCE Tenzian ETdnmy 100.0% Jom1 YmU Strength 1040.000 n1000 Imornal Pressurecap ty;" 5210.000ink en Campmssmn ENeicnry 100% CentOressim suengln 1010.000.1000 Max.Almxeeftnxling U -1100B be External Pressure Capacity 2470.000 i i MAKE-UP TORQUES Minimum 20370 haps Opentum 22630 nabs Maximum steel fi W OPERATION LIMIT TORQUES Operating Togw 3]300 Mirk Ylekl Tereus 45400 I1abs Notes This connection is fully interchangeable with, TXP® BTC - 10.75 in. - 40.5151 Ibs/f1 111 Internal Pressure Capacity related to structural resistance only. Internal pressure leak resistance as per section 10.3 API SC3I ISO 10400 - 2007. Datasheet is also valid for Special Bevel option when applicable - except for Coupling Face Load, which will be reduced. Please contact a local Terrains technical sales representative. For further information on concepts indicated in this datasheet, download the Dalasheet Manual from www.tenans.com rMMe Ma 6WM II! a4Wn091w 9e.Mrdl nlamalm Wv. ane NO nIp11NUM n lnsaonwMni. n4x5np 1nlMtl FNXM. enr pdRtl. egvatgSaaOigtV ('mIgTNLn+) rot n1mMJ meMWwm NnrCf\d19 V ✓ry oNtr tyM olmnM vtawnmCMalgn apt a pronOCU onan-m,e' bleb. Ho waranfy ie e`en. Tawr1! Ma Ml,rGeptlumndy VCnM1L'aanY mfpnh6Tl ylanV'PICNCCa IW tM Nan MIVMl9ron wm.aMmePVpazc N.an IN Mm pnCwlV hneunM.TM ux MNc hlormlemnmux+ioxn nsF N-0ienaru IXea 1W asawm mYrnrynfe,4ry W laptlyd Yry Faq IpanY 1xa. ammaSew ryvry reyAtq hem. an<omCaOn Mtratty h'Vniatlm emtamM nmetlMer Page 17 Version 0 March, 2019 n Hilcorp Encs C—F-Y Milne Point Unit M-04 Drilling Procedure 14.0 Cement 10-3/4" X 9-5/8" Surface Casing 14.1 Hold a pre job safety meeting over the upcoming curt 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. Ensure vac trucks are on standby and ready to assist. • 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 cmt operation. • Review test reports and ensure pump times are acceptable. • Conduct visual inspection of all iron used to route slurry to rig floor. 14.2 Document efficiency of all possible displacement pumps prior to cement job. 14.3 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. 14.4 R/U cmt head (if not already done so). Ensure top and bottom tapered plugs have been loaded correctly. 14.5 Pump 5 bbls 10.5 ppg tuned spacer. Test surface cmt lines. 14.6 Pump remaining 55 bbls 10.5 ppg tuned spacer. 14.7 Drop bottom plug. Mix and pump curt per below calculations. 14.8 Cement volume based on annular volume + 100% open hole excess. Job will be pumped in a single stage, TOC brought to surface. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol (ft3) Conductor x 10-3/4" casing: 113 x 0.24 bpf = 28 bbls 157 ft3 13-1/2" OH x 10-3/4" casing: (2200'- 113') x 0.06478 bpf x 2 = 271 bbls 1522 ft3 13-1/2" OH x 9-5/8" casing: (2972'- 2200') x 0.08705 bpf x 2 = 135 bbls 758 ft3 9-5/8" Shoe track: 90 x .07582 bpf = 7 bbls 40 ft3 Total: 441 bbls 2477 ft3 6� Page 18 Version 0 March, 2019 V/ H Hilcorp Ev w C®pe�y Cement Slurry Design: Milne Point Unit M-04 Drilling Procedure 14.9 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 14.10 After pumping cement, drop top plug and displace cement with spud mud out of mud pits. 14.11 Ensure rig pump is used to displace cmt. Displacement calcs have proven to be very accurate using 0.101 bps for pump output. 14.12 Displacement calculation: 2200' x .09617 bpf + 682' x .07582 = 263 bbls total 6f -kik . ,- sl 14.13 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 14.14 If plug is not bumped at calculated strokes, double check volumes and calculations. Overdisplace by no more than 3 bbls before consulting with drilling engineer. 14.15 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. 14.16 Be prepared for cement returns to surface. Dump cmt 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 curt. Page 19 Version 0 March, 2019 Slurry System SwiftCEM 'm System Density 15.8 Ib/gal Yield 1.16 ft3/sk Mixed Water 5.04 gal/sk 14.9 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 14.10 After pumping cement, drop top plug and displace cement with spud mud out of mud pits. 14.11 Ensure rig pump is used to displace cmt. Displacement calcs have proven to be very accurate using 0.101 bps for pump output. 14.12 Displacement calculation: 2200' x .09617 bpf + 682' x .07582 = 263 bbls total 6f -kik . ,- sl 14.13 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 14.14 If plug is not bumped at calculated strokes, double check volumes and calculations. Overdisplace by no more than 3 bbls before consulting with drilling engineer. 14.15 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. 14.16 Be prepared for cement returns to surface. Dump cmt 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 curt. Page 19 Version 0 March, 2019 H Hilcorp EWWC� Milne Point Unit M-04 Drilling Procedure 14.17 Flush oul'BPKand clean out above hanger. Remove landing joint. 14.18 M/U pack -off running tool and pack -off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 14.19 Lay down landing joint and pack -off running tool. Ensure to report the following on WeIIEZ: • 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 a. Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure e. Note if pre flush or cement returns at surface & volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As -Run" casing tally & casing and cement report to mm ers .hilcorp.com and cdinger@hLIcorp.com com This will be included with the EOW documentation that goes to the AOGCC. Page 20 Version 0 March, 2019 H Hilcorp E�CMP.FW 15.0 Wellbore Clean Up & Displacement Milne Point Unit M-04 Drilling Procedure 15.1 M/IJ casing clean out assy complete with 9-5/8" casing scraper assys. • 8.5" bit • Casing scraper for 9-5/8" 40# casing. • +/- 800' 5" DP. • Casing scraper for 10-3/4" 45.5# casing. • 5" DP to surface. 15.2 After wellbore has been cleaned out satisfactorily using mud, test casing to 2,500 psi / 30 mi 15.3 Displace drilling fluid in wellbore with a hi -vis pill followed by 8.8 ppg 2% KCl brine. • Consider catching drilling fluid in rain -for -rent tanks for use on a future well if feasible. • Circulate fresh water into wellbore until clean-up is satisfactory. Do not recirculate fluid, • After a couple circulations using 8.8 ppg 2% KCl brine, short trip the assy to bring the 10- 3/4" scraper to surface. Pump a chemical train followed by 8.8 ppg 2% KCl brine. 15.4 TOH w/ clean out assy. Rack back 5" DP. Note any abnormal wear on the clean out assy. Page 21 Version 0 March, 2019 Milne Point Unit M-04 Drilling Procedure Hilcorp ENW C��P&Y 16.0 BOP N/U and st / 16.1 N/D the diverter & N/U 1\dress ubing spool. 16.2 N/U 13-5/8" x 5M BOP as: • BOP configuration frdown: 13- / 5/8" x 5M mud cross Single atu • Double ram should bwith 2 /8" cavity. • Single ram should also be dres • NX bell nipple, install flowline. • Install (1) manual valve & (1) H1 mud cross). • Install (1) manual valve on chole valve. / 16.3 Run 5" BOP test assy, land out • Test BOP to 250/3000 psi f • Ensure to leave "B" sectio build up beneath the test i • We will need to test on t e 5" for DP workstrin 7" for production inl 16.4 R/D BOP test assy. 16.5 Set 10" ID 16.6 Keep 6" liners in mud x 5M annular / 13-5/8" x 5M Double gate / 13- x 5" VBRs in top cavity, blind ram in btm 2-7/8" x 5" VBRs. valve on kill side of mud cross. (manual valve closest to of mud cross. Install an HCR outside of the manual Ist plug (if n t installed previously). 5/5 min. Te annular to 250/2500 psi for 5/5 min. side outlet valve open during BOP testing so pressure does not following sizes: wellhead. p0l.0 Page 22 Version 0 March, 2019 S-U..6q_ H Hilcorp 17.0 Completion Operations Milne Point Unit M-04 Drilling Procedure 17.1 A separate sundry will be submitted to the AOGCC for approval to run a gravel pack completion on this well. AS- - p� 4 �r Page 23 Version 0 March, 2019 H Hilcorp av C—v-y 18.0 Diverter Schematic 21-1/4'2M Riser - 21.114' 2M— Diverler "r 21-114'2h Spacer Spat 16-3!4'W 21-114.2M DSP Seaboard Casinghead, S -22 -AP - 16' SOW x 16-314' 31v (2) ea 2.1116' SM studded outlet Milne Point Unit M-04 Drilling Procedure —16" Full opening Knife Valve �16' Diverter Line Page 24 Version 0 March, 2019 H Hilcorp Encs C—P-y 19.0 Ivu Milne Point Unit M-04 Drilling Procedure BOP Schematic H Hilcorp Eve C -P -y 20.0 Wellhead Schematic CUSTOMER PROVIDED 7 FROM OTHER VEI PER MP 7-1116" 5K (5-1/6 11' 20' COND 10.31, Milne Point Unit M-04 Drilling Procedure Page 26 Version 0 March, 2019 K H Milne Point Unit ure Drilling Procedure 21.0 Days Vs Depth 0 500 1000 6 d v a 1500 v m v 2 2000 25'00 3000 MPU M-04 WSW Days vs Depth 0 2 d 6 a 10 12 Days Page 27 Version 0 March, 2019 0 Hilcorp 22.0 Anticipated Drilling H azards Surface Hole Section: Milne Point Unit M-04 Drilling Procedure Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates Remember that hydrate gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section efficiently— control ROP and avoid loading the hole with gas. Minimize gas belching by reducing flow rate if necessary. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non -pressurized mud scale. The non -pressurized scale will reflect the actual mud cut weight. Add 1.0 — 2.0 ppb DRILTREAT to the system to help thin the mud and release the gas. Isolate/dump contaminated fluid to remove hydrates from the system. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti -Collison: There are a number of adjacent wells in the vicinity. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Discuss offset wellbores with production foreman and consider shutting in adjacent wells if necessary. Monitor drilling parameters for signs of collision with another well. Wellbore stability (Permafrost, running sands and gravel, conductor broaching): Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations btwn surge and swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on this pad. Page 28 Version 0 March, 2019 H Hilcorp Milne Point Unit M-04 Drilling Procedure 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event 1-12S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 29 Version 0 March, 2019 Milne Point Unit M-04 Drilling Procedure Hilcorp 23.0 Dovon 14 Rig Lavout �PIIIIIIII � N J Page 30 Version 0 March, 2019 H Hilcorp F� ��Y 24.0 Choke Manifold Schematic Milne Point Unit M-04 Drilling Procedure Page 31 Version 0 March, 2019 H Hilcorp a.w comwor Milne Point Unit M-04 Drilling Procedure 25.0 Casing Design Information Calculation & Casing Design Factors Hole Size 13-1/2" Hole Size Hole Size Milne Point Unit DATE: 3-8-2019 WELL: MPU M-04 DESIGN BY: Monty M Myers n Criteria: Mud Density: 9.5 Mud Density: Mud Density: Drilling Mode MASP(13-1/2): 917 psi (see attached MASP determination & calculation) Production Mode MASP: 1210 esi (see attached MASP determination & Collapse Calculation: Section Calculation ' 1, 2, 3 Max MW gradient external stress and the casing evacuated for the internal stress Page 32 Version 0 March, 2019 Casing Section Calculation/Specification 1 1 Casing OD 10-3/4" 9-5/8" Top (MD) 0 2,200 Top (ND) 0 2,162 Bottom (MD) 2,200 2,972 Bottom (ND) 2,162 21934 _ Length 2,200 810 Weight (ppf) 45.5 40 Grade L-80 L-80 Connection TXP TXP I Weight w/o Bouyancy Factor (lbs) 100,100 32,400 ' Tension at Top of Section (lbs) 100,100 32,400 Min strength Tension (1000 lbs) 1040 916 Worst Case Safety Factor (Tension) 10.39 28.27 " Collapse Pressure at bottom (Psi) 930 1,262 Collapse Resistance w/o tension (Psi) 2,470 4,790 Worst Case Safety Factor (Collapse) _ 2.66 �_ _ 3.80 MASP (psi) 917 917 Minimum Yield (psi) 5,210 5,750 Worst case safety factor (Burst) 5.68 6.27 Page 32 Version 0 March, 2019 Milne Point Unit M-04 Drilling Procedure Hilcorp �� m 26.0 11 Hilcorp 13-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 13-1/2" Hole Section MPU M-04 Milne Point MD TVD Planned Top: 0 0 Planned TD: 2972 2934 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Base Permafrost 18M 795 Wet 8.5 0.440 Top Sou roe Water 1882 828 Wet 8.5 0.440 Base Source Water 2751 1210 Wet 8.5 0.440 Offset Well Mud Densities Well MW range Top (TVD) Bottom (TVD) Date MPL-43 9.3-9.8 439 6,745 2004 MPB-28 9.0-9.4 Surface 4,435 2016 MPB-29 8.8-9.2 Surface 4,400 2016 Assumptions: j 1. Maximum planned mud density for the 13-1/2" hole section is 9.5 ppg. Fracture Pressure at 10-3/4" shoe considering a full column of gas from shoe to surface: 2934 (ft) x 0.6(psi/ft)= 1761 1761(psi)-[0.1(psi/ft)•2934(ft)]= 1467 psi Drilling Mode MASP MASP from pore pressure (wellbore completely evacuated to gas) 2934(ft) x 0.44(psi/ft)= 1291 psi 1291(psi)-[0.1(psi/ft)'2934(ft)]= 998 psi Summary: 1. MASP while drilling 13-1/2" hole is governed by drilling on diverter. Page 33 Version 0 March, 2019 H Hilc rp ear c�� Milne Point Unit M-04 Drilling Procedure 27.0 Spider Plot (NAD 27) (Governmental Sections) ADL355023 Sec. 11 KUPARUK RIVER UNIT I U0131N009E �1PU \I-04_SHL M -O 84.12' io `"U MOOSE PAD 0 io � o .R LSIII1121=1Yo71211Will" L1 ]11113144iCl 32-14A32-14 it uy ow,wrm,a Page 34 `I MPU Set. 14 Milne Point Unit MPU M-04 Well wp06 Version 0 ADL388235 Sec_ 12 Sec. 13 Legend • MPU M -04 -SHL Other Surface Holes (SHL) X MPU M-04_TPH Ot1ef Bodom Holes (BHL) - - - Other Well Paths hIPU M-04_BHL O 03>nd Gas Una Bwndary r----' Pad Footprint O�FFeet March, 2019 Milne Point Unit M-04 Drilling Procedure Hilcorp ai C.P.Y 28.0 Surface Plat (As Built) (NAD 27) 12 CARD TM PROJECT SEG 12 I SEC 13 SEG it IT I M-10 -SEC.-14 u vAD v 18 � � 0 M-11 I M-12 I 23 19 MINE STE E I I , VICINITY MAP � nTs Xd>f:t6 - I r MIbI I I M-04 t M-03 1 LOCATED WITHIN PROTRACTED SEC. 14. L 13 N.. R. 9 F.. UMIAT MERIDIAN. ALASKA WELL A.S.P. GEODETIC GEODETIC AP'4'FSSipvl.� I MPU MOOSE PAD COORDINATES I POSITION O.DD OFFSETS NOTES, 1. ALASKA STATE PLANE COORMA16 ARE NA027. ZONE 4. M-03 SURVEYOR'S CERTIFICATE 1 HEREBY CERTIFY THAT I AM 2. GEODETIC POSITIONS ARE NA027. GRAPHIC SCALE PROPERLY REGISTERm AND UI SED 3. BASS OF xOMZONTAL AND VERTICAL CONTROL IS NOOSE0 100 200 400 THEPVAX OFPRACTICE ALALASUASURVEYING ANDTHAT PAD MONUMENT CPI. 149.7273014' TNI. AS- . REPRESENTS A SURYEI' 4. MPU MOOSE PAD SCALE FACTOR li 0.99990256. ( N FEET) MADE BY ME OR KINDER MY DIRECT 5. DATE W SURMY: SEPTEMBER 26. 201E T NFN - 200 R SUPERM90N AND THAT ALL AND OAL MEN�S. REFFNENCE FIELD BOOK HC18-04 PP. 23J4. S OF SEPTEMBER 6. 20EB. CIORRECTT A LOCATED WITHIN PROTRACTED SEC. 14. L 13 N.. R. 9 F.. UMIAT MERIDIAN. ALASKA WELL A.S.P. GEODETIC GEODETIC SECTION CELLAR NO. COORDINATES POSITION DMS POSITION O.DD OFFSETS BOX EL M-03 Y= 6,027,889.71 70'29'14.024' 70.4872289' 5,040' FSL 25.0' X= 533,363.90 149'43'38.285 149.7273014' 801' FEL M-04 Y= 6.027,889.58 70'29'14.021' 70.4872281' 5,040' FSL 25.0' X= 533,393.80 149'4337.405 149.7270569' 771' FEL M-10 Y= 6,027,889.65 70'29'13.990 70.4872194' 5,037' FSL 24'9 X= 534,113.80 1'43'16.220' 149.7211722' 51' FEL M-11 Y= 6,027,889.61 ' 0'29'13.993' 70.4872203' 5,037' FSL 25.0' X= 534,023.88 149'43'18.865' 149.7219069' 141' FEL M-,2 r Y= 6.027,889.80 70'29'13.999' 70.4872219' 5.037' FSL 25.0' X= 533,933.89 149'43'21.513' 149.7226425' 231' FEL R h1 AL1 7-1 6 Onmm MILNE POINT, ALASKA MOOSE PAD, WELLS M-03, 04, 10, 11, 12 29y CONDUCTOR AS -BUILT Page 35 Version 0 March, 2019 29.0 Directional Plan (wp 06) Milne Point Unit M-04 Drilling Procedure Page 36 Version 0 March, 2019 Hilcorp Alaska, LLC Milne Point M Pt Moose Pad Plan: MPU M-04 MPU M-04 Plan: MPU M-04 wp06 Standard Proposal Report 26 February, 2019 HALLIBURTON Sperry Drilling Services IALLIBURTON Ferry Drilling Project: Milne Point Site: M Pt Moose Pad Calculation Method: Minimum Curvature Coordinate (TVD) Reference: Well Plan: MPU M-04 True North Error System: ISCWSA � Vertical (TVD) Reference: M-04 Planned RKB (] 58]OusR Scan Method: Closest Approach 3D Measured Depth Reference: M-04 Planned RKB @ 58.70usR Enor Surface: Pedal Curve Calculation Method: Minimum Curvature Warning Method: Error Ratio SECTION DETAILS Well,, /ellbore: Plan: MPU M-04 MPU M-04 17.70 175.19 975.60 17.70 175.19 1438.09 0.00 0.00 1873.70 0.00 0.00 2933.70 -85.07 -232.20 -299.80 -299.80 Sec 1 MD 33.70 Inc 0.00 Am 0.00 TVD 33.70 +N/ -S 0.00 +E/ -W 0.00 Oleg 0.00 TFace 0.00 VSect Target 0.00 Design: MPU M-04 wp06 0.00 2 3 280.00 446.67 0.00 5.00 0.00 150.00 280.00 446.46 0.00 -6.29 0.00 3.63 0.00 3.00 0.00 150.00 0.00 6.74 _ 33.70 800.00 MPU M-04 wp06 2_ N,GC GC_Drill 800.00 2971.75 MPU M-04 wp06 2MWD.IF _MWDMS+; 0 4 650.00 5.00 150.00 649.01 -21.64 12.49 0.00 0.00 23.17 500 Start Dir 4°/100' : 650' MD, 649.01'TVD End Dir : 983.64' MD, 975.6' TVD c 1250 Start Dir 4°/100' : 1469.13' MD, 1438.09TVD 0 a 1500 1800 d D End Dir : 1911.75' MD, 1873.7' TVD d 1750 BPRF _--_- M-04 wp05 CP1 --------------------------------------- m........-._..---------...----------------------------------------------------------- ----- SVi 2nnn UG_Coal t 2500 Total Depth : 2971.75' MD, 2933.70' TVD 9 5/8" x 12 1/4'• I MPU M-04 wp06 -750 -500 -250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 Vertical Section at 172.00' (500 usft/iin) 5 983.64 6 1469.13 7 1911.75 8 2971.75 17.70 175.19 975.60 17.70 175.19 1438.09 0.00 0.00 1873.70 0.00 0.00 2933.70 -85.07 -232.20 -299.80 -299.80 24.07 4.00 34.11 87.60 36.46 0.00 0.00 235.01 42.15 4.00 180.00 302.75 M-04 wp05 CP1 42.15 0.00 0.00 302.75 CASING DETAILS WELL DETAILS: Plan: MPU M-04 TVD NDSS MD Size Ground Level: 25.00 2933.70 2875.00 2971.75 9 5/8" x 12 1/4" +N/S +E/ -W Northing Easting Latittude Longitude 0.00 0.00 6027889.58 533393.80 70.487 -149.727 SURVEY PROGRAM Depth From Depth To Survey/plan Tool 33.70 800.00 MPU M-04 wp06 2_ N,GC GC_Drill 800.00 2971.75 MPU M-04 wp06 2MWD.IF _MWDMS+; 0 FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation Start Dir 3-/100': 280' MD, 280'TVD 1804.70 1746.00 1842.72 BPRF 1881.70 1823.00 1919.75 SVi ,0 2750.70 2692.00 2768.75 UG Ceall End Dir : 446.67' MD, 446.46' TVD 500 Start Dir 4°/100' : 650' MD, 649.01'TVD End Dir : 983.64' MD, 975.6' TVD c 1250 Start Dir 4°/100' : 1469.13' MD, 1438.09TVD 0 a 1500 1800 d D End Dir : 1911.75' MD, 1873.7' TVD d 1750 BPRF _--_- M-04 wp05 CP1 --------------------------------------- m........-._..---------...----------------------------------------------------------- ----- SVi 2nnn UG_Coal t 2500 Total Depth : 2971.75' MD, 2933.70' TVD 9 5/8" x 12 1/4'• I MPU M-04 wp06 -750 -500 -250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 Vertical Section at 172.00' (500 usft/iin) NALLIBURTON Sperry Drilling 25 -125 S-150 Project: Milne Point If WELL DETAILS: Plan: MPU M-04 Site: M Pt Moose Pad Ground Level: 25.00 Well: Plan: MPU M-04 +N/ -S +P6W Nonhmg fasting latift de Longitude Wellbore: MPU M-04 0.00 0.011 6027889.58 533393.80 70.487 -149.727 Plan: MPU M-04 wp06 REFERENCE INFORMATION Caokinate (NIS) Reference: Well Plan: MPU M-04, Tme NOM M,deal (ND) Reference: M-04 Planned RO @ 58.70ush Measured Depth Reference: M-04 Planned RI(8 @ 58,70us0 Calcula0on Mathocl. Minimum Curvature CASING DETAILS ND TVDSS MD Si. Name 2933.70 2875.00 2971.75 9-5/8 9 5/8" x 12 1/4" Start Dir 4"/100':650' MD, 649.OITVD End Dv : 983.64' MD, 975.6 TVD 1000 1250 Start D'u 4"/100' : 1469.13' MD, 1438.09TVD Milne Point_ 500ft Buffer Line �--------— — — — — — — — — — M-04 WPO5 CPI Endow : 191IJYMD, 1873.7 -TVD -3009 5/811 Depth : 297175' MD, 2933.70' TVD 9 5/8" x 12 Il4" 934 MPU M-04 wp 16 / -25 0 25 50 75 100 125 150 175 200 225 250 West( -)/East(+) (50 usfUin) HALLIBURTON Database: NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: Plan: MPU M-04 Wellbore: MPU M-04 Design: MPU M-04 wp06 Halliburton Standard Proposal Report Local Coordinate Reference: Well Plan: MPU M-04 TVD Reference: M-04 Planned RKB @ 58.70usft MD Reference: M-04 Planned RKB @ 58.70usft North Reference: True Survey Calculation Method: Minimum Curvature Project Milne Point, ACT, MILNE POINT Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Position +N/ -S 0.00 usft Northing: +EI -W 0.00 usft Easting: Position Uncertainty 0.00 Usti Wellhead Elevation: Wellbore MPU M-04 Magnetics Model Name Sample Date BGGM2018 9/13/2018 Design MPU M-04 wp06 Audit Notes: Version: 7ection: Phase: Depth From (TVD) (usft) 33.70 6,027,889.58 usft r Latitude: 533,393.80 usft - Longitude: 25.00 usft Ground Level: Declination Dip Angle (') (°) 17.00 80.98 PLAN +N1 -S (usft) 0.00 Plan Sections Dogleg Build i VD +EI -W Site M Pt Moose Pad Rate Vertical TVD $J` (°/100usft) Site Position: Inclination Northing: 6,027,877.65 usft latitude: 70.487 From: Map Easting: 533,363.92usft Longitude: -149727 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16' Grid Convergence: 0.26 ° Well Plan: MPU M-04 0.00 280.00 22130 0.00 Well Position +N/ -S 0.00 usft Northing: +EI -W 0.00 usft Easting: Position Uncertainty 0.00 Usti Wellhead Elevation: Wellbore MPU M-04 Magnetics Model Name Sample Date BGGM2018 9/13/2018 Design MPU M-04 wp06 Audit Notes: Version: 7ection: Phase: Depth From (TVD) (usft) 33.70 6,027,889.58 usft r Latitude: 533,393.80 usft - Longitude: 25.00 usft Ground Level: Declination Dip Angle (') (°) 17.00 80.98 PLAN +N1 -S (usft) 0.00 Plan Sections Dogleg Build i VD +EI -W Measured Rate Rate Vertical TVD $J` (°/100usft) Depth Inclination Azimuth Depth System +NIS (usft) (°) (°) (usft) usft (usft) 33.70 0.00 0.00 33.70 -25.00 0.00 280.00 0.00 0.00 280.00 22130 0.00 446.67 5.00 150.00 446.46 38776 -6.29 650.00 5.00 150.00 649.01 590.31 -21.64 983.64 17.70 175.19 975.60 91690 -85.07 1,469.13 17.70 175.19 1,438.09 1,379.39 -232.20 1,911.75 0.00 0.00 1,873.70 1,815.00 -299.80 2,971.75 0.00 0.00 2,933.70 2,875.00 SS -299.80 Tie On Depth: +EI -W (usft) 0.00 33.70 Direction (°) 172.00 70.487 -149.727 25.00usft Field Strength (nT) 57,451.32042705 2/26!2019 5:08:01PM Page 2 COMPASS 5000.15 Build 91 Dogleg Build Turn +EI -W Rate Rate Rate Tool Face (usft) (°/100usft) (°/100usft) (°/1a0asft) (°) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.63 3.00 3.00 0.00 150.00 12.49 0.00 0.00 0.00 0.00 24.07 4.00 3.81 7.55 34.11 36.46 0.00 0.00 0.00 0.00 42.15 4.00 4.00 0.00 180.00 42.15 0.00 0.00 0.00 0.00 2/26!2019 5:08:01PM Page 2 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: Plan: MPU M-04 Wellbore: MPU M-04 Design: MPU M-04 wp06 Planned Survey Well Plan: MPU M-04 TVD Reference: M-04 Planned RKB @ 58.70usft MD Reference: Measured North Reference: True Vertical Minimum Curvature Depth Inclination Azimuth Depth TVDss (usft) (°) (°) (usft) usft 33.70 0.00 0.00 33.70 -25.00 100.00 0.00 0.00 100.00 41.30 200.00 0.00 0.00 200.00 141.30 280.00 0.00 0.00 280.00 221.30 Start Dir 3°/100' : 280' MD, 2807VD 0.00 6,027,889.58 300.00 0.60 150.00 300.00 241.30 400.00 3.60 150.00 399.92 341.22 446.67 5.00 150.00 446.46 387.76 End Dir : 446.67' MD, 446.46' TVD 533,393.80 4.00 500.00 5.00 150.00 499.59 440.89 600.00 5.00 150.00 599.21 540.51 650.00 5.00 150.00 649.01 590.31 Start Dir 4-1100': 650' MD, 649.0l'TVD 3.00 700.00 6.75 159.58 698.75 640.05 800.00 10.52 168.73 797.60 738.90 900.00 14.41 173.03 895.23 836.53 983.64 17.70 175.19 975.60 916.90 End Dir : 983.64' MD, 975.6' TVD 42.14 1,000.00 17.70 175.19 991.18 932.48 1,100.00 17.70 175.19 1,086.45 1,027.75 1,200.00 17.70 175.19 1,181.71 1,123.01 1,300.00 17.70 175.19 1,276.97 1,218.27 1,400.00 17.70 175.19 1,372.24 1,313.54 1,469.13 17.70 175.19 1,438.09 1,379.39 Start Dir 4-1100': 1469.13' MD, 1438.09T1D 302.75 -299.80 1, 500.00 16.47 175.19 1,467.60 1,408.90 1, 600.00 12.47 175.19 1,564.41 1,505.71 1,700.00 8.47 175.19 1,662.72 1,604.02 1,800.00 4.47 175.19 1,762.06 1,703.36 1,842.72 2.76 175.19 1,804.70 1,746.00 DPRF -299.80 42.15 1,900.00 0.47 175.19 1,861.95 1,803.25 1,911.75 0.00 0.00 1,873.70 1,815.00 End Dir : 1911.75' MD, 1873.7' TVD 302.75 -299.80 1,919.75 0.00 0.00 1,881.70 1,823.00 SVt 0.00 302.75 -299.80 2,000.00 0.00 0.00 1,961.95 1,903.25 2,100.00 0.00 0.00 2,061.95 2,003.25 2,200.00 0.00 0.00 2,161.95 2,103.25 2,300.00 0.00 0.00 2,261.95 2,203.25 2,400.00 0.00 0.00 2,361.95 2,303.25 2,500.00 0.00 0.00 2,461.95 2,403.25 2,600.00 0.00 0.00 2,561.95 2,503.25 2,700.00 0.00 0.00 2,661.95 2,603.25 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU M-04 TVD Reference: M-04 Planned RKB @ 58.70usft MD Reference: M-04 Planned RKB @ 58.70usft North Reference: True Survey Calculation Method: Minimum Curvature -10.32 5.96 6,027,879.29 533,399.80 0.00 11.05 -17.87 10.32 6,027,871.76 533,404.19 0.00 19.13 -21.64 12.49 6,027,868.00 533,406.39 0.00 23.17 -26.28 14.61 6,027,863.37 533,408.53 4.00 28.06 533,418.69 -40.75 18.45 6,027,848.92 Map 4.00 Map 6,027,769.38 -62.06 21.74 +NI -S +El -W Northing 64.48 Easting -85.07 DLS Vert Section (usft) (usft) (usft) -180.94 (usft) 32.14 .25.00 6,027,708.80 0.00 0.00 6,027,889.58 183.66 533,393.80 0.00 0.00 0.00 0.00 6,027,889.58 0.00 533,393.80 -232.20 0.00 0.00 0.00 0.00 6,027,889.58 533,431.30 533,393.80 235.01 0.00 0.00 0.00 0.00 6,027,889.58 533,393.80 4.00 0.00 0.00 -0.09 0.05 6,027,889.49 6,027,623.66 533,393.85 533,434.30 3.00 0.10 -3.26 1.88 6,027,886.33 533,395.70 3.00 3.49 -6.29 3.63 6,027,883.30 41.78 533,397.46 6,027,594.34 3.00 6.74 -10.32 5.96 6,027,879.29 533,399.80 0.00 11.05 -17.87 10.32 6,027,871.76 533,404.19 0.00 19.13 -21.64 12.49 6,027,868.00 533,406.39 0.00 23.17 -26.28 14.61 6,027,863.37 533,408.53 4.00 28.06 533,418.69 -40.75 18.45 6,027,848.92 533,412.43 4.00 42.92 6,027,769.38 -62.06 21.74 6,027,827.62 533,415.82 4.00 64.48 29.59 -85.07 24.07 6,027,804.62 533,418.25 4.00 87.60 -180.94 -90.03 24.49 6,027,799.67 533,418.69 0.00 92.56 -120.34 27.04 6,027,769.38 533,421.38 0.00 122.93 -150.64 29.59 6,027,739.09 533,424.06 0.00 153.29 -180.94 32.14 6,027,708.80 533,426.75 0.00 183.66 -211.25 34.69 6,027,678.51 533,429.44 0.00 214.02 -232.20 36.46 6,027,657.57 533,431.30 0.00 235.01 -241.24 37.22 6,027,648.54 533,432.10 4.00 244.07 -266.13 39.31 6,027,623.66 533,434.30 4.00 269.01 -284.23 40.84 6,027,605.56 533,435.91 4.00 287.15 -295.46 41.78 6,027,594.34 533,436.91 4.00 298.40 -298.14 42.01 6,027,591.66 533,437.14 4.00 301.09 -299.75 42.14 6,027,590.05 533,437.29 4.00 302.70 -299.80 42.15 6,027,590.00 533,437.29 4.00 302.75 -299.80 42.15 6,027,590.00 533,437.29 0.00 302.75 -299.80 42.15 6,027,590.00 533,437.29 0.00 302.75 -299.80 42.15 6,027,590.00 533,437.29 0.00 302.75 -299.80 42.15 6,027,590.00 533,437.29 0.00 302.75 -299.80 42.15 6,027,590.00 533,437.29 0.00 302.75 -299.80 42.15 6,027,590.00 533,437.29 0.00 302.75 -299.80 42.15 6,027,590.00 533,437.29 0.00 302.75 -299.80 42.15 6,027,590.00 533,437.29 0.00 302.75 -299.80 42.15 6,027,590.00 533,437.29 0.00 302.75 228/2019 5:08:01PM Page 3 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US+CANADA TVD Reference: M-04 Planned RKB @ 58.70usft Company: Hill Alaska, LLC North Reference: True Project: Milne Point DLS Vert Section Site: M Pt Moose Pad (usft) (usft) Well: Plan: MPU M-04 -299.80 42.15 Wellbore: MPU M-04 0.00 302.75 Design: MPU M-04 wp06 6,027,590.00 533,437.29 Planned Survey 302.75 -299.80 42.15 Measured 533,437.29 Vertical 302.75 Depth Inclination Azimuth Depth TVOss (usft) (°) () (usft) usft 2,788.75 0.00 0.00 2,750.70 2,692.00 UG_Coall 2,800.00 0.00 0.00 2,761.95 2,703.25 2,900.00 0.00 0.00 2,861.95 2,803.25 2,971.75 0.00 0.00 2,933.70 2,875.00 Total Depth: 2971.75' MD, 2933.70' TVD Targets Target Name Halliburton Standard Proposal Report Local Coordinate Reference: Well Plan: MPU M-04 TVD Reference: M-04 Planned RKB @ 58.70usft MD Reference: M-04 Planned RKB Q 58.70usft North Reference: True Survey Calculation Method: Minimum Curvature -hit/miss target Dip Angle Dip Dir. TVD Map Map -Shape (°) (1) (usft) +N/.S +E/ -W Northing Easting DLS Vert Section (usft) (usft) (usft) (usft) 2,692.00 -85.07 -299.80 42.15 6,027,590.00 533,437.29 0.00 302.75 -299.80 42.15 6,027,590.00 533,437.29 0.00 302.75 -299.80 42.15 6,027,590.00 533,437.29 0.00 302.75 -299.80 42.15 6,027,590.00 533,437.29 0.00 302.75 -hit/miss target Dip Angle Dip Dir. TVD +N/S +E/.W -Shape (°) (1) (usft) (usft) (usft) M-04 wp05 CP1 0.00 0.00 1,873.70 -299.80 42.15 - plan hits target center - Circle (radius 50.00) Casing Points Measured Vertical Depth Depth (usft) (usft) 2,971.75 2,933.70 95/8"x121/4" Formations Measured Vertical Vertical Depth Depth Depth SS (usft) (usft) 1,842.72 1,804.70 BPRF 2,788.75 2,750.70 UG_Coalt 1,919.75 1,881.70 SV1 Name Name Northing Easting 71 (usft) (usft) 6,027,590.00 533,431 I Casing Hole Diameter Diameter 9-5/8 12-1/4 Lithology Local Coordinates +N/S Plan Annotations (usft) Measured Vertical 0.00 Depth Depth -6.29 (usft) (usft) -21.64 280.00 280.00 -85.07 446.67 446.46 -232.20 650.00 649.01 -299.80 983.64 975.60 -299.80 1,469.13 1,438.09 1,911.75 1,873.70 2,971.75 2,933.70 Name Name Northing Easting 71 (usft) (usft) 6,027,590.00 533,431 I Casing Hole Diameter Diameter 9-5/8 12-1/4 Lithology Local Coordinates +N/S +E/ -W (usft) (usft) Comment 0.00 0.00 Start Dir 3-/100': 280' MD, 280'TVD -6.29 3.63 End Dir : 446.67' MD, 446.46' TVD -21.64 12.49 Start Dir 4-1100': 650' MD, 649.01'TVD -85.07 24.07 End Dir : 983.64' MD, 975.6' TVD -232.20 36.46 Start Dir 4°/100': 1469.13' MD, 1438.09'TVD -299.80 42.15 End Dir : 1911.75' MD, 1873.7' TVD -299.80 42.15 Total Depth: 2971.75' MD, 2933.70' TVD Dip Dip Direction 0 oa 0.00 2/26/2019 5:08:01PM Page 4 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt Moose Pad Plan: MPU M-04 MPU M-04 MPU M-04 wp06 Sperry Drilling Services Clearance Summary Anticollision Report 26 February, 2019 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt Moose Pad - Plan: MPU M-04 - MPU M-04 - MPU M-04 wp06 Well Coordinates: 6,027,889.58 N, 533,393.80 E (70' 29' 14.02" N, 149° 43' 37.40" W) Datum Height: M-04 Planned RKB @ 58.70usft Scan Range: 0.00 to 2,971.75 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.15 Build: 91 Scan Type: NO GLOBAL Scan Type: 25.00 LiJ Sp HALLIBURTON Anticollision Report for Plan: MPU M-04 - MPU M-04 wp06 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt Moose Pad - Plan: MPU M-04 - MPU M-04 - MPU M-04 wp06 Scan Range: 0.00 to 2,971.75 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Sumn Site Name Depth Distance Depth Separation Depth Factor I Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft M Pt Moose Pad MPU M-03 - MPU M-03 - MPU M-03 371.95 25.46 371.95 21.86 372.82 7.077 Centre 1 MPU M-03 - MPU M-03 - MPU M-03 400.00 25.63 400.00 21.79 400.86 6.667 Ellipse F MPU M-03 - MPU M-03 - MPU M-03 800.00 35.29 800.00 27.87 802.13 4.755 Clearan Plan: MPU M -23i - M118 - M -23i wp03 1,057.74 39.22 1,057.74 30.26 1,038.91 4.378 Ellipse,' Plan: MPU M -23i - M118 - M-21 wp03 1,075.00 39.79 1,075.00 30.70 1,054.80 4.376 Clearan Slot 10 - Placeholder- Slot 10 - Placeholder- Slot 10 - 536.74 25.92 536.74 20.58 498.49 4.861 Centre 1 Slot 10-Placeholder-Slot 10-Placeholder-Slot 10- 575.00 26.13 575.00 20.46 536.60 4.609 Ellipse: Slot 10-Placeholder-Slot 10-Placeholder-Slot 10- 650.00 27.73 650.00 21.40 611.31 4.377 Clearan Survey fool Program From To (usft) (usft) 33.70 800.00 MPU M-04 wp06 800.00 2,971.75 MPU M-04 wp06 Ellipse error terms are correlated across survey tool tle-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey/Plan 26 February, 2019 - 18:22 Page 2 of 4 Survey Tool 2_Gym-NS-GC_Drill pi 2_MWD+IFR2+MS+Sa 150.00 HALLIBURTON Sperry Drilling EM Pro lilne Point Je Site, M Pt Moose Pad Well: Plan: MPU M-04 Wellbore: MPU M-04 Plan: MPU M-04 wp06 Ladder & S.F. Plots REFERENC RMATION WELL DEA S:PIa :N Do Vetfiate l(TVD) Referent. Plan: Md U M-04,RO@ Tme NOM Venal (N0) Reference:.,-tld Runnel RK8 Q 58.]0ueft Meazuretl Depth Referenm:M-04 Plennetl RHB®59.]Ousft calculation Method: Minimum euntere 0.00 0.00 602 SURVEY PROGRAM NO GLOBAL Depth Fmm Depth To Surrey/Plan Tool 33.70 800.00 MPU M-04 wp06 2_Gyro-NS-GC_Q'il pipe 800.00 2971.75 MPU M-04 w,06 2_MWD+IFR2+MS+Sag TV 2933.' 0120.00 150.00 PU M-03 0120.00 -. M -23i wp03. 90.00 _._.......... _.... _. -. -... _. __. m I i f) N60.00 _. - ___ I ___ i.__. _.. ,__- _-. _... -_ -.. _. .... L) j Slot 10 Place i older � 30.00 MPU M-03 MPU M Op c m U 0.00 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 Measured Depth (400 usf /in) 4.50 - _ to .00 M 3.00— LL c Collision Risk Procedures Req. a Collision Avoidance Req. 1.50 No -Go Zone - Stop Drilling NOERROR _ '.. 0.00 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 Measured Depth (400 usft/in) Schwartz, Guy L (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Thursday, March 21, 2019 1:20 PM To: Schwartz, Guy L (DOA) Cc: Joe Engel Subject: M-04 Changes Good afternoon Guy, As per our conversation concerning M-04, we will not be performing the gravel pack or completing the well with Doyon 14. Therefore, I will propose the following changes to the drilling program. Starting with section 16: -We will not need to NU BOP's. This was going to be done just for perforating and running completion I propose that after section 15.2: the PTD ends with the following steps. -Pump a chemical train followed by 9.6ppg NaCl (for freeze protection) -POOH and LD clean out assembly -RD diverter -NU wellhead and tree -RU and test casing to 2500 psi, test void in wellhead as appropriate -RDMO A separate sundry will be submitted to MIRU the ASR and perform the gravel pack and run the ESP completion. Please let me know if you have any questions. Thank you! Monty M Myers Drilling Manager 907.538.1168 (c) 907.777.8431 (o) TRANSMITTAL LETTER CHECKLIST WELL NAME: M P u M- G+ PTD: 0 3 S Development ✓ Service,_ Exploratory _ Stratigraphic Test —Non -Conventional s'trF1i FIELD: �"�i�ti�. Paihi- POOL: I I"/hre- cre', .k �✓a-ip[^ C."1-erfi'arr ur a-fTwed wRTsPi 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. 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' sample intervals throu h 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 logging program proposed by (Company Name) in the attached application, the following well logs are y/ also required for this well: Well Logging Requirements JPer 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. Revised 2/2015 WELL PERMIT CHECKLIST. Field & Pool MILNE POINT, TERTI UNDEF WTRSP - 525130 Well Name: MLI.N_E PT UNIT M-04 Program SER Well bore seg ❑ PTD#:2190380 Company HILCORP ALASKA LLC Initial Class/Type SER / PEND GeoArea 890 Unit 1132.8 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached- - - - - - - - - - - - - ------ - - - - - - - - - - - --- - - - - -- - NA.... 2 Lease number appropriate. - - - - - - - - - - - - - -- - - - - - - - ---- Yes - 3 Unique well name and number .................................... Yes ....-..-..--- -. 4 Well located in a -defined pool- - - - - - _ _ - - - Yes 5 Well located proper distance, from drilling unit.boundary- - - - - - - - - - - - Yes 6 Well located proper distance from other wells - - - - - - - - - Yes 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.appropdate bond in force - ...... . ... . . . - - - Yes 11 Permit can be issued without conservation order- - - - - - - - - - Yes - Appr Date 12 Permit can be issued without administrativeapproval- - - - - - - Yes ... DLB 3/12/2019 13 Can permit be approved before 15 -day wait... - - - - - - - - - Yes 14 Well located within area and strata authorized byInjectionOrder# (put 10# in comments).(For- NA 15 An wells within 1/4. mile 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 Nonconven. gas conforms to A$31,05,0300,1.A),0,2.A-D) - - - - - - - - - --- - - - - - - - - NA. 18 Conductor string.pfovided - - - -- - - - - - - - - - ----- - - - - - - - - - Yes - - - 20" conductor set at 113 k Engineering 19 Surface casing protects all known USDWs - . - - - - - - NA. _permafrost area - 20 CMT vol. adequate to circulate on conductor $ surf.csg - - - - ... - - - - - _ Yes - - - - tapered. 10.3/4 x 9 5/8"- surface/production casing. 21 CMT. vol adequate to tie-in long string to surf csg- - - - - - - - - - - - - ----- NA- - . pumping 100% excess cement.... - - - 22 CMT will coverall known. productive horizons. - - - - - - - - . - - - - Yes 23 Casing designs adequate for C. T, B &. permafrost- - - - - - - - - - - - - - - - - - - - - - - - - Yes 24 Adequate tankage -of reserve pit . . . ..... . . . . .... . . . - - - ... Yes . - - - - - - rig has steel pits, 25 If a. re -drill, has.a 10-403 for abandonment been approved . . . . . ....... . .. . . . NA 26 Adequate wellbore separation proposed- - . . . . . .. . . . . . ..... . . Yes - - - - 27 If diverter required, does it meet regulations... - - - - - - - - - - ... Yes - - - Well being drilled on Diverter... -not rigging up 13OPE- Appr Date 28 Drilling fluid. program schematic .$ equip list adequate- - . - - - - - _ _ _ - - - - Yes - - - - - - ---- - - - - - ------ - - - GLS 3/21/2019 29 BOPEs, do they meet regulation - - - - - - - ---- - - - - - - - - - , - NA 30 BOPE-press rating appropriate; test to -(put psig in comments)-- - - - - - - - - - -- - - - - - NA - - - ------.... 31 Choke.manifold complies w/API RP -53 (May 84)---------------------------- -NA ..---....--..----...------..- 32 Work will occur without operation sbutdow_n_ - - - - ... - - Yes - ASR 1 will move in after casing is cemented and perform GP and run ESP 33 Js presence of H2S gas probable - - - - --------- - - - - - - - - - - - ---- - - - - - - No.... 34 .Mechanical condition of wells within AOR verified (For service well only) - - - .. - . - - - - . NA ----- - - - - - -- - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - 35 Permit can be issued w/o hydrogen sulfide measures . . . . .... . . . .... . . . . . .. Yes - - - - No H2$ anticipated Geology 36 Data, presented or potantial overpressure zones - ...... - ...... - Yes . - - - - Hydrates. or geopressure not expected from drilling of offset wells. Appr Date 37 Seismic analysis of shallow gas zones-- - - - - - - - ------- - - - --- - - - - - - - NA.... - Planned mud program. appears adequate to control operator's forecast formation pressures.. DLB 3/12/2019 38 Seabed condition survey(ifoff-shore) . ......... . . . ..... . . . ...... . . . . NA ... - - - - - - - - - - - 39 Contact name/phone for weekly -progress reports[exploratoryonly] . . . . ... . . . . .... NA Geologic Engineering Public Water source well. Drilling well on Diverter only. Will be completed with ASR 1 dg later using gravel pack hardware. GIs Commissioner: Date: Commissioner: Date Commissioner Date