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219-099
DATA SUBMITTAL COMPLIANCE REPORT 11/12/2019 Permit to Drill 2190990 Welt Name/No. MILNE PT UNIT E-391-1 MD 12675 TVD 4127 Completion Date 8/12/2019 REQUIRED INFORMATION / Mud Log NOV /' Operator Hilcorp Alaska LLC Completion Status 1WINJ No V DATA INFORMATION List of Logs Obtained: ROP/ABG/DGR/EWR/ADR 2"/5" MO...ABG/DGR/EWR/ADR 2"/5" TVD Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH ED C 31171 Digital Data 105 12676 ED C 31171 Digital Data ED C 31171 Digital Data ED C 31171 Digital Data ED C 31171 Digital Data ED C 31171 Digital Data ED C 31171 Digital Data ED C 31171 Digital Data ED C 31171 Digital Data ED C 31171 Digital Data ED C 31171 Digital Data ED C 31171 Digital Data ED C 31171 Digital Data ED C 31171 Digital Data ED C 31171 Digital Data ED C 31171 Digital Data ED C 31171 Digital Data ED C 31171 Digital Data 7850 12638 Current Status 1WINJ API No. 50-029-23640-60-00 UIC Yes Directional Survey Yes (from Master Well Data/Logs) Received Comments 9/3/2019 Electronic Data Set, Filename: MPU E -39L1 AOGCC Page 1 oft Tuesday, November 12, 2019 LWD Final.las 9/3/2019 Electronic Data Set, Filename: MPU E-391-1 ADR Quadrants All Curves.las 9/3/2019 Electronic File: MPU E-39 LWD Final TVD.cgm 9/3/2019 Electronic File: MPU E-391-1 LWD Final MD.cgm 9/3/2019 Electronic Fife: MPU E-391-1 Actual - Plan.pdf 9/3/2019 Electronic File: MPU E-391-1 Actual - VSect.pdf 9/3/2019 Electronic File: MPU E-391-1_Deflnitive Survey.pdf 9/3/2019 Electronic File: MPU E-391-1 DSR.txt 9/3/2019 Electronic File: MPU E-391-1_Final Surveys.xlsx 9/3/2019 Electronic File: MPU E-391-1_GISAxt 9/3/2019 Electronic File: MPU E-391-1 LWD Final MD.emf 9/3/2019 Electronic File: MPU E-391-1 LWD Final TVD.emf 9/3/2019 Electronic File: MPU E-391-1 Geosteering.dlis 9/3/2019 Electronic File: MPU E-391-1 Geosteedng.ver 9/3/2019 Electronic File: MPU E-391-1 LWD Final MD.pdf 9/3/2019 Electronic File: MPU E-391-1 LWD Final TVD.pdf 9/3/2019 Electronic File: MPU E-391-1 LWD Final MD.tif 9/3/2019 Electronic File: MPU E-391-1 LWD Final TVD.tif AOGCC Page 1 oft Tuesday, November 12, 2019 DATA SUBMITTAL COMPLIANCE REPORT 11/12/2019 Permit to Drill 2190990 Well Name/No. MILNE PT UNIT E -39L1 Operator Hilcorp Alaska LLC API No. 50-029-23640-60.00 MD 12675 TVD 4127 Completion Date 8/12/2019 Completion Status 1WINJ Current Status 1WINJ UIC Yes Log 31171 Log Header Scans 0 0 2190990 MILNE PT UNIT E-391-1 LOG HEADERS Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report (Y Production Test Information Y //i�%A Geologic Markers/Tops (9 COMPLIANCE HISTORY Completion Date: 8/12/2019 Release Date: 7/18/2019 Description Comments: Sample Interval Set Start Stop Sent Received Number Comments Directional / Inclination Data 0 Mud Logs, Image Files, Digital Data Y Core Chips Y�A Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files C) Core Photographs Yp}0 l_ Daily Operations Summary / Cuttings Samples Y / NA% Laboratory Analyses Y I-& Date Comments Compliance ReviewedBy: Date: AOGCC- Page 2 of 2 Tuesday, November 12, 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas El SPLUG ❑ Other ❑ Abandoned ❑ suspended[] 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑✓ WAGE] WDSPL ❑ No. of Completions: 1 Service Q - Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Abend.: 8/12/2019 219-099 ' 3. Address: 7. Date Spudded: 15. API Number: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 July 30, 2019 50-029-23640-60-00 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 3519' FSL, 1863' FEL, Sec 25, T13N, R10E, UM, AK i August 3, 2019 MPU E -39L1 Top of Productive Interval: 9. Ref Elevations: KB: 48.3' ' 17. Field / Pool(s): Milne Point Field 261 1'FSL, 2205' FWL, Sec 36, T13N, R10E, UM, AK GL: 21.7' BF: 21.7' ' Schrader Bluff Oil Pool r Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1799' FNL, 1080' FWL, Sec 6, T12N, RI 1E, UM, AK r 12,650' MD / 4,129' TVD ADL025518 I ADL380110 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MDfrVD: 19. DNR Approval Number: Surface: x- 569284 y- 6016057 Zone- 4 12,675' MD 14,127' TVD LONS 94-017 TPI: x- 568131 y- 6009859 - Zone- 4 12. SSSV Depth MDfTVD: 20. Thickness of Permafrost MDlfVD: Total Depth: x- 567042 y- 6005438 ` Zone- 4 N/A 2,223' MD / 1,780' TVD 5. Directional or Inclination Survey: Yes ✓ (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 7,853' MD / 4,269' TVD 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary RECEIVED ROP/ABG/DGR/EWR/ADR 2"/5" MD ABG/DGR/EWR/ADR 275" TVD SEP 0 5 2019 AOGCC 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 4-1/2" 13.5# L-80 7,903' 12,650' 4,287' 4,129' 8-1/2" Cementless Liner w/ ICDs & Swell Packers 24. Open to production or injection? Yes ❑✓ No ❑ 25. TUBING RECORD If Yes, list each interval open (MDlfVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/TVD) Size and Number; Date Perfd):3-1/2" 8,332' 7,570' MD / 4,155' TVD **` Please see attached schematic for ICD/Swell Packer Detail **` Liner run on 8/8/19 COMPLETION 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. TE Z^11 —G� Was hydraulic fracturing used during completion? Yes ❑ No ✓ Per 20 AAC 25.283 (i)(2) attach electronic and printed information _ VERRI II E,/ DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, 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: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate Form 10-407 Revised 5/2017 JU. (—[TONTI ED ON PAG 2 , BDMS�SEP 1 2��9 Submit ORIGINIAL only 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base 2,223' 1,780' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval SB OA 8,095' 4,335' information, including reports, per 20 AAC 25.071. SB OA 7,998' 4,315' r Formation at total depth: SB OA 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys. 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: cdinger@hilcorg.com Authorized Contact Phone: 777-8389 �t� 7 Signature: — - Date: I • 9 1 INSTRUCTIONS General: This o and the required atta ovide 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 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data 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 H BBesm Alaska. LI.0 Orifi. KB Elev.:483'/Odg. GL Dev.:21.T TD =15,531' (MD) /TD = 4,205'(rVD) PBTD =15515' (MD) / PBTD =42W(TVD) WELLHEAD Wellhead I FMCGenS Milne Point Unit Well: MPU E-39 & L1 Last Completed: 08/14/2019 PTD: 219-096 OPEN HOLE/ CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42" Hole 95/8„ Stg1L-908 sx/T-400 sx Top Stg 2 L —530 sx / T— 270 sx (294 bbls back) WELL INCLINATION DETAIL GENERAL WELL INFO KOP @ 290' MD Apt: 50-029-23640-00/60-00 Max Wellbore Angle= 97.5 deg @ 13,687' MD Drilled and Completed by Innovation Rig —August 2019 CASING DETAIL Size Type Wt/Grade/Conn ID Top Stm 20" Conductor 215/X-42/Welded N/A Surface 107' 9-5/8" Surface 40/L-80/TXP 8.835 Surface 8,557' 4-1/2" Liner "OA" Injection 13.5 / L-80/ Hyd 625 3.920 7,903' 12,650' 5ta 02: Valve —Circ Valve/Date xx/xx/xx[WFRV] Liner w/ [CDs 7774' Sta Ill:Valve — Circ Valve/Date xx/xx/xx[WFRV] 7 7834' 4-1/2" Liner "OB" Injection 13.5 / L-80 / Hyd 625 3.920 8,288' 15,520' PBR Seal assembly (4- Y." holes) Liner w/ ICDs TUBING DETAIL 3-1/2" Tubing/Fieback 1 9.3/L-80/EUE 1 2.441 1 Surface 8,332' JEWELRY DETAIL No Depth Item Upper Completion 1 2430' Ne (ID -2.813') 3-1/2" X-ippl 2 7512' Downhole Gauge 3 7570' 4-1/2"x9-5/8" Retrievable Packer(DLH) 4 7630' 3-1/2" X -Nipple (ID=2.813") GLM Detail: 3-1/2" x 1.5" Camco w/ BK Latch 5 7683' 5ta 02: Valve —Circ Valve/Date xx/xx/xx[WFRV] 6 7774' Sta Ill:Valve — Circ Valve/Date xx/xx/xx[WFRV] 7 7834' 3-1/2" XN-Nipple (Min ID=2.75") 8 8314' No-Go/xover sub 9 8332' PBR Seal assembly (4- Y." holes) OA Lateral 30 7903' Top of Liner Paget Tendeka Water Swell Packer 41-9 Page 2 Tendeka SSD w/ Screen & ICD #1-7 (See Page 2 for Detail) 21 12650' Solid Bull Nose Shoe OR Lateral 22 8288' Liner Top Packer 9-5/8"x4-1/2"Baker ZXP Paget Tendeka Water Swell Packer N3-10 Page 2 Tendeka SSD w/ Screen & ICD N1-10 (See Page 2 for Detail) 34 15,493' OR Lateral 4-1/2" Drillable Pack -off 35 15,515' OR Lateral 4-1/2" WIV 36 15,518' OR Lateral 4-1/2" Btm of Guide Shoe Top of "OB"Window @ 8,557' MD Angle @ top of window is 89 deg Too of "OA" Window @ 2853' MD Angle @ too of window 1s 69 dee Revised By: CID 9/4/2019 Depth MD Depth ND MPE-391CD/Swell Packer Detail 8,583' 4,365' Tendeka Water Swell Packer #10 8,852' 4,353' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.54 bxp 625 Wedge #9 9,212' 4,341' Tendeka Water Swell Packer #9 9,606' 4,327' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge #8 9,840' 4,323' Tendeka Water Swell Packer 48 10,068' 4,320' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge #7 10,467' 4,300' Tendeka Water Swell Packer #7 10,859' 1 4,283' 1 Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.54 bxP 625 WedLe #6 11,299' 4,256' 1 Tendeka Water Swell Packer #6 11,766' 4,227' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge #5 11,993' 4,213' Tendeka Water Swell Packer #5 12,378' 4,192' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge #4 12,727' 4,180' Tendeka Water Swell Packer #4 13,273' 4,209' Tendeka Water Swell Packer #3 13,333' 4,214' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge 43 13,603' 4,210' Tendeka Water Swell Packer #2 13,871' 4,181' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bx2 625 Wedge 42 14506' 4,155' Tendeka Water Swell Packer #I 15,265' 4,183' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge #1 Depth MD Depth ND MPE-39L1 ICD/Swell Packer Detail 7,931' 4,297' Tendeka Water Swell Packer #9 7,992' 4,315' Tendeka Water Swell Packer #8 8,095' 4,335' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge #7 8,160' 4,344' Tendeka Water Swell Packer 47 8,553' 4,331' Tendeka Water Swell Packer #6 8,696' 4,318' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge #6 8,849' 4,305' Tendeka Water Swell Packer 45 9,328' 4,281' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge #5 9,688' 1 4,374' 1 Tendeka Water Swell Packer #4 10,043' 4,267' 1 Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge #4 10,528' 4,240' Tendeka Water Swell Packer #3 10,920' 4,224' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge #3 11,277' 4,201' Tendeka Water Swell Packer #2 11,588' 4,181' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.54 bx 625 Wedge #2 11,945' 4,163' Tendeka Water Swell Packer #1 12,344 4,149' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge #1 Hilcorp Energy Company Composite Report Well Name: MP E-391_1 Field: Milne Point County/State: , Alaska (LAT/LONG): avation (RKB): API #: Spud Date: Job Name: 1913307D MPU E -39L1 Drilling Contractor Innovation AFE #: APE $: Activity irate ;%: Ops Summary 7/30/2019 Cont POOH UD 2 3/8" inner string to pipe shed F/ 5.980' to Slick Stick. UD Baker Slick Stick. Calc Disp 15, actual - 62. Lost 47 bbls.;PJSM UD Baker and Weatherford tools and Equip. Install 5" Hydraulic Elevators. 8 bph static loss.;PJSM P/U Whipstock Assy to rig floor and Pipe Shed.;PJSM P/U WU Whipstock Assy as per Baker Rep onsite. P/U M/U 6.375" Bullnose, 7.375" PBR Pack Off, 8" Stop Sub, 6.375" Unloader, 8.25" Extreme Magnet, 12 as 5" D.P. (379.57'), 1 as 5" Pup 4.69'. 6.375" DBLP Blank Sub, 8.375" Bottom Trip Anchor, 6.375" Safety Disconnect, 6.375" Drain Sub,;6.5" Debris Sub, 8" Gen II Whipstock, 8.5" Window Mill, 8.375" Lower Mill, 6.375" Flex Joint, 8.5" Upper Mill, 1 as 5" HWDP, 6.75" DM Collar, 6.9" HOC, 6.43" Float Sub. (509.42');PJSM RIH Whipstock Assy on 5" D.P. F/ Derrick F/ 509' to 8,149' MD. @ 60 fl in SLK 86K. Shallow hole test at 569' MD 350 GPM, 450 PSI, FO 46% good detection. Fill pipe every 2,500'. Calc Disp 47 bbls, actual 30. Lost 17 bbls.;PJSM Start washing down F/ 8,149'420 GPM, 954 PSI, P/U 142K, SLK 100K. Pumps off P/U 149K, SLK 103K. Receiving good detection showing 90°L. Cont. washing down putting slight rotation in TAG at 8,287' MD. Set down 10K. Tagged 10' into Jnt 123. V less then anticipated.;Confirm orientation at 26' LOHS. Slack off 30K down to 70K to set trip anchor (set at 26K). Pull up to 160K to ensure anchor is set. Slacked off and saw shear at surface on the string at 50K down. P/U to 145K to verify Shear Bolt sheared. (lost 4K) Slacked off and set down 5K to TOW at 7,853' MD.;Started conditioning mud F/ Quickdril to Bamdril.;PJSM Start milling operations as per Baker at 7,853' to 7,862' MD. 350 GPM, 700 PSI, Initial 70 RPM, TRO 8.5 WOB 1 K, First 2'W/ 1-2K WOB at 3 FPH, increase to 2-5K WOB 340 GPM, 700 PSI, FO 47%, 70 RPM, TRQ 9-14K, P/U 142K, SLK 100K, ROT 117K.;Daily hauled 30 bbls to G&I total = 30 bbls Hauled 130 bbls H2O from A -Pad reserve total = 130 bbls Hauled 0 bbls H2O from B -Pad Creek total = 0 bbls Lost 104 bbls to formation Total fluid lost production = 104111 7/31/2019 Continue to mill window from 7862' to 7870' as per BOT Rep. 2.6K WOM @ 3 fph, 340 GPW700 PSI, 90 RPM/13K Tq PUW 142K, SOW 100K Rot 117K.;Continue to drill new formation from 7870' to 7900'. Work Mills through window x 3 with pumps on and no issues. Pump Hi Vis sweep to surface with 25% increase back at shakers. Sweep and circulating hole clean for FIT to 12 ppg EMW. (TOW @ 7853')(BOW @ 7870').;SPR @ 7,836' MD (4,236 TVD) MW 9.15 ppg. MP 1 32-203, 48-252. MP 2 32-213, 48-255.;PJSM Monitor well F/ 10 Min, static. POOH racking back 5" D.P. F/ 7,842' to 75' MD. P/U 98K. No losses.;PJSM UD Mill BHA. All mills in Gauge, Upper mill wear about 6' at top of miIL:PJSM Johnny Whack Stack, flush choke manifold, choke and kill. Blow down same.;PJSM P/U WU 8.5" Smith XR+PS Rerun Bit, 6 3/4" 1.5° Sperry Lobe 6/7-6.0 stg Motor, 6 3/4" DM, 6 3/4" HOC, 6 3/4" Float Sub, 2 ea 6 3/4" FC, 6 3/4" Float Sub, 2 ea 5" HWDP, 6 3/4" SLB Jar and 1 ea 5" HWDP. (243) RFO 3.42/6.75= 182.40°. =;PJSM RIH BHA Motor W/ 5" D.P. F/ 243' to 2,789' MD Shallow hole test MWD at 350 GPM, 730 PSI, FO 46%, P/U 81 K. SLK 68K. No losses. Filling pipe every 2,500'.;PJSM Cont RIH BHA Motor W/ 5" D.P. F/ 2,789' to 7,756' MD P/U 81 K, SLK 68K. No losses. Filling pipe every 2,500'.;PJSM Hang Blocks. Cut and slip drilling line. (100' 16 wraps) Service rig, grease Crown, Blocks, Wash Pipe, Top Drive, Spinners and Drawwroks.;PJSM Cont RIH BHA Motor W/ 5" D.P. F/ 7,756' to 7,840' MD Stage up pumps to 450 GPM, 1,450 PSI Obtain tool face at 20' LOHS to orientate motor. Shut pumps off and slack off through window at TOW 7,853' BOW 7,870' MD saw 4K of drag. Tag at 7,900' no fill.;P/U 145K, SLK 97K. No losses. Filling pipe every 2,509.;PJSM Slide Rotate to gain separation 8.5" Hole W/ Motor F 7,900' to 7,932' MD (4,298' TVD). 450 GPM, 1,450 PSI, FO 56%. WOB 4-10K, P/U 145K, SLK 97K.;Daily hauled 57 bbls to G&I total = 87 bbls Hauled 130 bbls H2O from A -Pad reserve total = 260 bbls Hauled 0 bbls H2O from B -Pad Creek total = 0 bbls Lost 22 bbls to formation Total fluid lost production = 125 bbls 8/1/2019 Continue Slide/ Rotate 1/7932' to 8199 MD 500 gpm, 1700 psi, PUW 142K, SOW 92K, Rot 113K, 80 rpm, 14K Tq, 6-16K wob, Max Gas @ 1622u. Slide intervals without continuous Inc and blind survey Azi down to 8,199' MD where the first IFR corrected survey was taken at 8,162' MD.;CBU from 8199' @ 500 gpm/1660 psi, 80 rpm, 13.5 Tq, Max gas @ 761. Surveys were interpolated and a decision to drill ahead one stand was made by on siteGeologist.;Continue to drill to 8262'. (4,34(Y TVD) to gain separation. Build to 90.49° , 93'/190 Az projected @ bit. 500 gpm, 1700 psi, PUW 142K, SOW 92K, Rot 113K, 80 rpm, 14K Tel, 6-16K wob, Max Gas @ 1622u.;Orient Motor to 26° LOHS, POOH on elevators f/8262' to 7819. Pull through window with no issues. Pump Dry job, Continue to POOH on elevators to BHA. No losses observed. At 17:00 lost hi line power due Operations Turbine issue, swapped to Gen power.;PJSM Rack back Jar and 5" HWDP, and FC's. Pull Pulsar Assy F/ HOC and Directional Probe F/ DM. UD Mud Motor and 8.5" Tricone. Bit Grade 1 -1 -NO-A-E-1-NO- BHA.;PJSM Clean and clear rig floor of BHA components. Prep for RSS BHA.;PJSM Set Top Drive on stops. Check Crown wobble. Grease Crmn.;PJSM P/U RSS BHA. P/U M/U 8.5" NOV SK616 A D Bit, 8.5" NOV NRP, 7600 Geo -Pilot, 6 3/4" ADR/HCIM, 8.5" ILS, 6 3/4" DGR, 6 3/4" PWD, 6 3/4" DM, 6 3/4" TM, 6 3/4" Float Sub, 2 ea 6 3/4" FC, 6 3/4" Float Sub, 2 ea 5" HWDP, SLB Hydra Jars and 1 ea 5" HWDP. (275.7T) Perform shallow hole test, good.;PJSM RIH W/ 8.5" RSS BHA F/ 275'to 7,725' MD. Filling every 2,500'. P/U 140K, SLK 94K. No losses. Break Geo Pilot at 3,800' MD.;PJSM P/U M/U MPD RCD Bearing as per Beyond. Line up and pump 2 bpm checking Iines.;Distance to WP #7: 15.2', 2.51' High, 15.0' Left.;Daily hauled 57 this to G&I total = 144 bbls Hauled 260 bbls H2O from A -Pad reserve total = 520 bbls Hauled 0 bbls H2O from B -Pad Creek total = 0 bbls Lost 0 bola to formation Total fluid lost production = 125 bbls Total Metal 117 It, 8/2/2019 Finish Installing MPD Bushing. Fill pipe. Test MWD lines. Trip through window to 7853' without pumps. No issues. Start MADPASS (no rotary) at 300 fph. 450 gpm, 1500 psi to 7950'. Make connection, SPRs. Resume MADPASS with 60 rpm rotary to 8068' and tag up with 15k WOB.;Attempt working through with/without rotary, no-go. Concerned maybe Jars hanging on Whipstock slide & continue working down from 8068'- 8079' MD. Deflect geo-pilot HS at 100% and continue wash/ream to bottom @ 8262' while reshooting bad surveys from previous run. Back on HiLine 10:OO.;Drill ahead from 8262' to 8297'. 550 GPB, 1840 psi, 4-18 WOB, 100 RPM, 16-18 Tq, PUW 185, SOW 90K, Rot 112K.;Pull short trip bringing Bit to 7860' , 10' inside window with no issues. Trip back to btm @ 8297' with no issues. Did not see set down @ 8068' as before on trip in.;PJSM Drill ahead 8.5" Hole F/ 6,297' to 8,680' MD (4,319' TVD) 383' total (69.6' AROP) 550 GPM, 1,880 PSI, 140 RPM, TRQ ON 20K, TRQ OFF 18-20K, WOB 13-15K, Beyond FO 550 GPM, Max Gas 828U, ECD 10.61, MW 9.25 ppg. P/U 205K, SLK 58K, ROT 105K. Back ream 20' every connection.; First clean survey at 8416' MD. Back in OA -Sand base at 8,578' MD. Build 5°/100, 100% deflection -2.5'/100 to comeback to WP.;Cont drilling ahead 8.5" Hole F/ 8,680' to 9,506' MD (4,293' TVD) 826'total (137.6' AROP) 550 GPM, 1,865 PSI, 140 RPM, TRQ ON 20-22K, TRQ OFF 22-23K, WOB 13-15K, Beyond FO 549 GPM, Max Gas 1,625U, ECD 10.74, MW 9.2 ppg. P/U 230K, SLK 44K, ROT 106K. Back ream 20' every connection.; Drilled up through OA -3, OA -2, and into OA -1 per plan.;Cont drilling ahead 8.5" Hole F/ 9,506' to 10,110' MD (4,265' TVD) 604' total (100.6' AROP) 550 GPM, 1,880 PSI, 110-140 RPM, TRQ ON 20-22.5K, TRQ OFF 22-24K, WOB 8-16K, Beyond FO 549 GPM, Max Gas 1,762U, ECD 10.6, MW 9.2 ppg. P/U 220K, SLK 48K, ROT 106K. Back ream 20' every connection.;Undulaled down to OA -3 per plan to -11,100' MD. Quite a few concretions near OA -3 top.;Distance to WP #6: 34.47', 31.6T Low, 15.74' Right. In zone.;22 concretions have been drilled so far for a total footage of 88' (4.1 % of the lateral). No faults have been crossed so far this lateral. 826' drilled in OA -1, 153' drilled in Oa -2, 592' drilled in OA -3 Total out of zone 588'.; Daily hauled 342 bbls to G&I total = 486 bbls Hauled 520 bbis H2O from A -Pad reserve total = 1,040 bbis Hauled 0 bbis H2O from B -Pad Creek total = 0 bbls Lost 0 bbls to formation Total fluid lost production = 125 bbls Total Metal 161 Ib 8/3/2019 Cont drilling ahead 8.5" Hole F/ 10.110'- T111,096' MD. 986' total (164' AROP) 565/559 In/Out GPM, 20502030 On/Off PSI, 140 RPM, TRQ ON 22K, TRQ OFF 21 K, WOB 8-16K, GPM, Max Gas 1,760u, ECD 10.6, MW 9.2 ppg. P/U 247K, SLK 36K, ROT 102K. Lost do wt @ 10,269' MD.;AOGCC notified of upcoming BOP test via email @ 14:29 8/3/19 (received confirmation email).;Cont drilling ahead 8.5" Hole F/ 11,096'- T/11,921' MD. 825' total (138' AROP) 565/558 In/Out GPM, 2075/2055 On/Off PSI, 120 RPM, TRQ ON 23K, TRQ OFF 22K, WOB 10-20K, GPM, Max Gas 1495u, ECD 11, MW 9.2 ppg. P/U 260K, SLK 36K, ROT 104K. Pump tandem sweep @ 11,100' (on time/10% inc).;Cont drilling ahead 8.5" Hole F/ 11,921' to 12,493' MD (4,146 TVD) 572'total (95.3' AROP) 565 GPM, 2,050 PSI, 100-130 RPM, TRQ ON 20-22K, TRQ OFF 20K, WOB 9-25K, Beyond FO 549 GPM, Max Gas 1,638U, ECD 10.87, MW 9.05 ppg. P/U 172K, SLK 35K, ROT 107K. Back ream 20' every connection.;SPR @ 12,493' MD (4,146' TVD) MW 9.05 ppg. MP 1 32-390,48-455. MP 2 32- 390, 48-455.;PJSM Cont drilling ahead 8.5" Hole F/ 12,493' to 12,675' MD (4,126' TVD) 182' total (182' AROP) 565 GPM, 2,150 PSI, 130 RPM, TRQ ON 19- 21K, TRQ OFF 18-19K, WOB 10-16K, Beyond FO 557 GPM, Max Gas 1,639U, ECD 11.0, MW 9.05 ppg. P/U 174K, SLK 36K, ROT 103K. Back ream 20' every connection.;SPR @ 12,675' MD (4,126' TVD) MW 9.1 ppg. MP 1 32-385, 48-445. MP 2 32-380, 48-440.;PJSM Rotate and Rec F/ 12,675' to 12,620' MD. 565 GPM, 2,070 PSI, 140 RPM, TRQ 19-21 K, Max Gas 1,586U, ECD 10.8 ppg, P/U 185K, SLK 36K, ROT 98K. CBU Max Gas 1,586U. Circ. a total of 3X BU. Pumped a 40 bbl Hi Vis sweep 200 Vis after first BU, 10% increase at Shakers of sand. ECD 10.4 ppg.;Obtain parameters prior to Quickdril P/U 185K, SLK 36K, ROT 98K. Shut down and monitor well through MPD, static. SIMOPS Stage Vac Trucks, Off load Pit 5 and clean, Fill Pill Pits and make SAPP Pills, Clean out under Shakers and Possum Belly.;PJSM Displace well W/ 35 bbl SAPP, 35 bbl Quickdril, 35 bbl SAPP, 35 bbl Quickdril, 35 bbl SAPP and chased W/ 9.1 ppg Quickdril taking returns to Cutting Box. Rotate and Rec F/ 12,675' to 12,620' MD. 350 GPM, 867 PSI, 130 RPM, TRQ 21-22K, Max Gas 11U, ECD 10.25 ppg.;Distance to WP #6: 41.75', 41.58' high, 3.77' Right. In zone.;72 concretions were drilled in this lateral for a total footage of 301' (6.2% of the lateral). No faults have been crossed this lateral. 2,161' drilled in OA -1, 228' drilled in Oa -2, 1,845' drilled in OA -3. Total out of zone 588'.;Daily hauled 1,254 bbis to G&I total = 1,740 bbls Hauled 910 bbls H2O from A -Pad reserve total = 1,950 bbis Hauled 390 bbls H2O from B -Pad Creek total = 390 bbls Lost 0 bbls to formation Total fluid lost production = 125 bbls Total Metal 191 Ib 8/4/2019 PJSM Rotate and Rec F/ 12,675' to 12,620' MD. 350 GPM, 867 PSI, 130 RPM, TRQ 21-22K, Cont. displacing Baredrill to Quickdril. SAPP pils came back as calculated. Weights with mud P/U 174K, SLK 36K, ROT 103K, after 3X BU P/U 185K, SLK 36K, ROT 98K, after Disp PIU 155K, SLK 59K, ROT 100K.;Trq decrease F/ 21.5K to 14.5K. Shut in Beyond and watch Press. for 10 Min. static. SPR at 12,675' (4,126' TVD) MW 9.1. MP 1 32-205, 48-260. MP 2 32-205, 48 265.;PJSM BROOH F/ 12,675' to 9,759' MD. 30-40 ft/min as hole dictated. 550 GPM, 1,480 PSI, 140 RPM, TRQ 14-16K, Beyond FO 549 gpm, ECD 10.1 ppg. Max Gas 118U. P/U 182, SLK 64K, ROT 109K.;PJSM BROOH F/ 9,759'to 8,106' MD. 30-40 ft/min as hole dictated. 550 GPM, 1,475 PSI, 140 RPM, TRQ 14-18K, Beyond FO 549 gpm, ECD 10.1 ppg. Max Gas 508U. P/U 208, SLK 75K, ROT 106K.;Encountered slight press spikes without pack off. Pumped out of hole F/ 8,106' to 7,582' MD. 550 GPM, 1,475 PSI, ECD 10.1 ppg. Pulled BHA through window at 10 ft/min, with no issue.;PJSM Rot and Rec at 7,852' to 7,788' MD 550 GPM, 1,425 PSI, 140 RPM, TRQ 14-18K, Max Gas 315U, Beyond FO 550 GPM, ECD 10.1. Pump 40 bbl Hi Vis Sweep 200 Vis, Sweep back as calculated W/ 25% increase in Sand. Monitor well 10 min through MPD, static.;PJSM Remove MPD Bearing and rack back in Derrick. Monitor well, slight seepage lOss.;PJSM Drop 2.4" OD drift on wire. POOH on Elevators F17,788' to 4,731' MD. PIU 130K, SLK 80K. Calc Disp 25 bbis, actual 30.4, lost 5.4 bbls.;PJSM P/U WU Retrieve OMatic Packer as per Baker Rep onsite. RIH 2 stands 5" D.P. to 141' MD. Hang drill string as per Baker Rep. Rack back 2 stands.;PJSM Drain Stack, M/U running tool and pull Wear Ring. R/U test Equip.;PJSM Perform Koomey draw down test. Initial Press, Accumulator 3,000 PSI, Manifold 1,500 PSI, Annular 1,200 PSI, Final Accumulator 1,500 PSI, Manifold 1,500 PSI, Annular 1,350 PSI. 200 PSI recharge 20 Sec, full charge 86 Sec. 6 bottle Nitrogen Avg 2,316 PSI. Test alarms H2S 10/20 PPM, LEL 20/40%.;Witnessed waive by Jeff Jones.;PJSM Perform BOPE test W/ 3.5" & 5" to 250 PSI low and 3,000 PSI high for 5 Min. Tested Choke Manifold 1-15, 5" Dart, 5" TIW, Dart, Upper and lower IBOP, Mez Kill, HCR and manual Choke and Kill, manual and Super Choke, Upper and lower VRB Rams (2,875!'X 5.5") Blind Rams.;Kill HCR failed and being rebuilt. Dart Valve failed and replaced.;Daily hauled 2,230 bbls to G&I total = 3,970 bbis Hauled 130 bbis H2O from A -Pad reserve total = 2,080 bbis Hauled 390 bbis H2O from B -Pad Creek total = 780 bible Lost 6 bbis to formation Total fluid lost 39-L1 = 6 bbis Total Metal 211 Ib 8/5/2019 PJSM LIDS' test Jnt and breakdown Dart Valve, TIW and Pump In Sub. P/U 3.5" Test Jnt and spare Dart Valve and TIW #2. SIMOPS rebuild HCR Kill VaIve.;PJSM Perform initial body test. Complete BOPE test W/ HCR Kill Valve, Annular, HCR Kill and Lower Pipe Rams (2,875" X 5.5") 250 PSI low and 3,000 PSI high for 5 min on chart. At 9:00 am.;PJSM RID test Equip.;PJSM P/U M/U Over Shot and RIH to 141' MD. Latch onto Retrieve OMatic as per Baker Rep onsite. Took 16 bels to fill hole after Retrieve OMatic was released. POOH and UD. Strip off MPD Bearing F/ Stand in Derrick.;PJSM P/U M/U Hawk Jaw and prep for laying down 5" D.P. SIMOPS Grease BOPE Equip, Break down Bad Dart Valve and send for repair.;PJSM CBU at 4,625' MD. 550 GPM, 1,230 PSI, FO 58%. Max Gas 8U. Pump 11.1 ppg Dry Job.;PJSM POOH UD 5" D.P. to Pipe Shed F/ 4,665' to 275'. Inspect hard bands. Calc Disp 38.9 bbls, actual 45.7. Lost 7 bbls.;PJSM UD BHA as per Spery DD and MWD. Down load MWD tools. Removed Drift and wire. Removed corrosion Ring. Found about 5 1/32" thick metal strips about 1" X 4" to 5" pieces in reference housing Geo Pilot cutters. Pies in ODrive. Bit Grade 2-2-BT-A-X-I-CT-TD.;PJSM Clear rig floor of BHA components. Static loss rate 1 bph.;PJSM P/U M/U Whipstock Hook, 5" HWDP, 6 1/4" Jars, 6 3/4" DM, 6 314" TM and Float Sub. Orientate DM MWD to Whipstock Hook RFO 4.1616.39=234.36°.;PJSM P/U 5 Jnts of 5" HWDP F/ Pipe Shed, RIH 1 stand 5" HWDP and Cont W/ 5" DP F/ 352' to 1,753' MD. P/U 60K, SLK 60K. No losses,;PJSM Cont RIH W/ Whipstock Retrievable BHA F/ 1,753to 7,853' MD. Shallow hole test MWD, good and fill pipe at 3,000' MD. Filling drill string every 2,500'. Calc Disp 66 bbls, actual 60 bbls. Lost 6 bbls.;PJSM Wash down orientate to 154° ROILS P/U 180K, SLK 92K. Wash out Whipstock key hole at 475 GPM, 1,450 - 2,100 PSI. Work string orientation to 30 LOHS" slack down to 75K hook in Whipstock. Picked up 15K over and slacked back down to ensure hook was set. P/U to 200K and shut down pumps.;Slack down 10K to 78K pull up to 270K 90K over and fire jars 1X. Slack down 10K to 78K pull up to 280K 100K over and fire jars 2X to release Whipstock. P/U 202K Whipstock hooked. Took 32 bels to fill hole after Whipstock was released.;lnitial dynamic loss rate 54 BPH. CBU at 330 GPM, 760 PSI. Max Gas 2U. P/U 202K.;Daily hauled 57 bbls to G&I total = 4,027 bbls Hauled 0 bels H2O from A -Pad reserve total = 2,080 bbls Hauled 0 bbls H2O from B -Pad Creek total = 780 bbls Lost 13 bbls to formation Total fluid lost 39-L1 = 19 bels Total Metal 211 Ib 8/612019 Continue circulating bottoms up at 330 gpm/760 psi. Monitor well, static loss rate 44 bph.;Pump dry job, drop 2.4" drift. POOH on elevators from 8303'to 1189. Hole fill calculated 58 bbls, actual 182 bbls.;Cont. to POOH from 1180' to 450'MD. PUW 58K.;UD whipstock. UD 12 joints below whipstock and magnet. 251bs of metal recovered from magnet.;clean and clear rig floor. UD 3rd party tools and hawkjaw.;Service rig: grease crown sheaves, pipe spinnners, blocks, TD, check oil levels. Perform derrick inspection. Inspect welds on TO carnage - good.;Rig up to RIH with liner. rig up Weatherford power tongs. M/U safety joint. M/U bullnose and XO's on slim hole MWD and UD same.; RIH with 45', L-80, 13.5#, 625W liner with ICD's and swell packers as per tally from surface to 4763'. MUT 9600 ft -lbs. PUW 70K, SOW 57K. Calculated displacement 30.5 bbls, act 17.6 bbls. 12.9 bbls Iost.;Pick up hook hanger. WU Back up ball seat sub, circ sub, MWD, XO's, and bullnose for inner string. Measure RFO from MWD to hook hanger = 3.81/4.54 = 302.11 ° M/U hook hanger to liner. RIH 1 stand to 4855'. Shallow pulse test MWD - good.;Continue RIH with 4.5" liner on drill pipe from 4855' to 7850'. Attempt to work through TOW at 7853', SOW 88K, PUW 135K observe 1-2K drag. RIH to 8310', tag upon bottom of SLZXP, top of seal bore extension.;POOH to above TOW at 7821'. Put 1/4 turn in pipe and work down. Attempt to work through top of window.;Daily hauled 0 bbls to G&I total= 4,027 bbls Hauled 0 bbls H2O from A -Pad reserve total = 2,080 bbls Hauled 0 bbls H2O from B -Pad Creek total = 780 bbls Lost 381 bbls to formation Total fluid lost 39 -Ll = 524 bbls Total Metal 236 Ib 8/7/2019 POOH to above TOW at 7821'. Put 1/4 turn in pipe and work down. Attempt to work through top of window @ 7853', working pipe from 7830' to 7900'. Continue to Put 1/4 turn on pipe, working each turn x4 in attempt to pass through window. Put 118th of a turn on pipe and work each turn x4.;PUH above window to 7850' and establish rotation @ 3 rpm 5.6K Tq. Set Tq Limit for 6K. Slack off slowly looking for stall. See stall fid 7863'. (Placing Shoe 10' inside window).;TIH from 7863'. Set down @ 8310'. (Btm of SLZXP PKR/Top of SBE in Mother Bore) TOH to top of window.;Continue attempting to locate and pass through Window. Execute multiple methods of locating window. Contact BOT and have Bent shoe it fabricated with 7" OD centralizers and 12" Bend.;PUH to top of window establish rotation @ 3 rpm. Slack off slowly looking for stall. See 5.9K stall. Release Tq'. TI and tag on E-39 Liner Top.; POOH with liner from 830U to 4802' racking back drill pipe. PUW 86K, SOW 64 K. Hole fill Cal 32.1 bbls, Actual 50.6 bbls.;Rig up Weatherford power tongs. UD bull nose, MWD, back up ball seat and hook hanger. Static loss rate 12 bph.;POOH with 4.5" 625W liner from 4802' to 1376. inspecting ICD's and swell packers (good). PUW 52K, SOW 51 K. Hole fill calc 14.2 bbls, Act. 47.9 bbls. Minimal wear on swell packers./ICD's. Drain bent joint. Clean and clear rig floor.;Service rig. Inspect and grease TD, tongs, cobra heads. Static loss rate 8 bph.;Pick up new bent joint with 12" bend and 3 centralizers. RIH with 4.5", 13.5#, L-80, 625W liner With ICD's and swell packer as per tally to 1192'.;Daily hauled 0 bbls to G&I total = 4,027 bbls Hauled 130 bbls H2O from A -Pad reserve total = 2,210 bbls Hauled 0 bbls H2O from B -Pad Creek total = 780 bbls Lost 241 bbls to formation Total fluid lost 39-L1 = 765 bbls Total Metal 236 lb 8/8/2019 Continue to RIH with 4.5", 13.5#, L-80, 625W liner from 1192' to 4764'.;Swap elevators. Pick up hook hanger and M/U MWD. Measure RFO = 350.48". RIH with 1 stand and shallow pulse test MWD at 115 gpm - good. Clear rig floor of Weatherford tools. B/D TD.;Continue to RIH with 4.5" liner on drill pipe from 4803' to 7911'. Rotate 1/4 turn and attempt to work through window, observe 2-3K drag. Continue to RIH to 8,310', tag out on bottom of SLZXP . PUW 131 K. SOW 90K. Displacement calculated 28, Actual 10K.;POOH with 4.5" liner from 8310' to 791 V.; Establish circulation 115 gpm. Rotate 1/4 turn for TF 114. Work through window at 7853', observing drag down to 7922'. Tag up with 20K, work pipe down to 7924'. Pickup with 20K overpull. Work past 7924' with varying parameters up to 10 rpms, torque limiter set at tOKft-Ibs.;Continue to RIH with liner on DP from 7924' to 12620', RIH on elevators until ICD or swell packer enters window. Tag up on jewelry and work through window, with varying parameters 5-1 Orpms torque limiter set at 10K-ftlbs. PUW 166K, SOW 85K. Calc disp 58 bbls, actual 22 bbls.; Establish circulation 147 gpm/320 psi. Orientate hook hanger with hook on low side 154°R. Slack off and tag up 10K down at 12,650' shoe depth, 7,874' BOW depth. Orientate hook hanger 26°L, high side. Attempt to work past 12,659to verify hook landed, tag up at 12,650' same depth, unable to work;past. Orientate hook back to 154°R, attempt to work hook down setting down 35K, with 20K overpulls. Unable to work past 12,651'. Consult with Baker & Hilcorp engineers. PUW 166K, SOW 75K.;Set 35K down on hook hanger. Drop 29132" ball and pump down at 2 bpm, ballon seat at 1740 strokes. Pressure up to 2800 psi to release hook hanger running tool. Bleed pressure. Pickup and verify liner released, PUW 155K with no overpull. Pressure up to 4650 psi to shear out circ sub.; Rack back three stands to clear tools.;Slip and cut drilling line, inspect line.; Daily hauled 0 bbls to G&I total= 4,027 bbls Hauled 0 bels H2O from A -Pad reserve total = 2,210 bbls Hauled 0 bible H2O from B -Pad Creek total = 780 bbls Lost 139 bbls to formation Total fluid lost 39 -Li = 904 bels County/State: , Alaska (LAT/LONG): ovation (RKB): API #: Hilcorp Energy Company Composite Report Spud Date: Job Name: 1913307C MPU E-391_1 Completion Contractor AFE #: AFE $: Activity Date Ops Summary Well Name: MP E -39L1 Field: Milne Point County/State: , Alaska (LAT/LONG): ovation (RKB): API #: Hilcorp Energy Company Composite Report Spud Date: Job Name: 1913307C MPU E-391_1 Completion Contractor AFE #: AFE $: Activity Date Ops Summary 8/9/2019 Cont. to Slip and cut drilling line - 17 wraps. Static loss rate 8 bph.,POOH laying down drill pipe from 7693' to 6724'. Pump dry job., Rig service. Inspect and grease TD, tongs, draw works, and cobra heads.,Cont to POOH racking back drill pipe from 6724' to surface. Calculated hole fill 64 bbls, actual 100 Wis. UD Bullnose, MWD, XO's and running tool. Clear rig floor., Rig up to RIH with cleanout assembly. rig up Weatherford power tongs, 3-1/2" handling equipment. Bring Baker tools to rig floor and strap. Static loss rate 6 bph.,M/U BHA. 3-1/2" mule shoe, XO, (2) magnets, XO, (15) joints of 3-i/2" 8rd EUE tubing, boot baskets, 8.25" magnet, bumper sub, Oil Jar, (12) HWDP.,RIH with cleanout assembly on drill pipe from 936' to 7803'. PUW 150K, SOW 101 K. Displacement pale 62 bbis, actual 46 bbls.,Work pipe down from 7803' through hook hanger. Tag up at 7910' with 10K down. Muleshoe tracked into lateral and collar on mule shoe is tagging upon cross over below hook hanger. Pickup above hook hanger, turn 1/2" turn and slack off tagging up at same depth. Establish circulation at 6 bpm/280 psi. Pickup and observe pressure drop to 220 psi as mule shoe exits XO and liner joint. Pickup above hook hanger, turn,1/4 turn and attempt to enter mother bore, still stack out at 7910. Attempt multiple times with no success.,POOH from 7850' to 936'. Lay down HWDP to 562'.,UD BHA. UD magnet and clean approximately 0.5 gallon of fine metal shavings recovered. UD boot baskets -no recovery. Clean and clear rig floor., Daily hauled 0 bbl, to G&I total = 4,027 bbis Hauled 0 bbls H2O from A -Pad reserve total = 2,210 bbis Hauled 0 bbis H2O from B -Pad Creek total = 780 bbis Lost 127 bbis to formation Total fluid lost 39-L1 = 1031 bbis Total Metal 2461 8/10/2019 Rig up Weatherford power longs. M/U XO to safety valve. UD 15 joints 3-1/2" EUE tubing. UD magnets, mule shoe.,M/U WILE BHA: mule shoe, (2) joints 3- 1/2" EUE tubing, XO to 4-1/2" 1F.,RIH with wireline entry BHA: pick up, drift and single in the hole to 852'. Continue RIH out of derrick and tag up at 7909'. pick up and space out to 7882'. M/U TIW. PUW 140K, SOW 100K.,Rig up Pollard E -line. M/U E -line tools. RIH with 2-1/2" RCT and CCL on E -Line to 7966' WLM. Log collars on swell packer and 1st 4-1/2" liner joint. Cut mid joint: 7892' WLM, 7905' DP measurement. Attempt to log out, Tool string hanging up in XO.,POOH and rig down Pollard.,POOH on elevators to 7,725'. Monitor well, slight loss. Pump dryjob. Cont to POOH to 6898'. PUW 140K, SOW 100K.,Observe small leak on spinners hydraulic hose. Replace hydraulic hose. Static loss rate 4.4 bph.,Sewice rig. C/O cable tail, cold shot, and cable anchor on cobra head -Cont POOH on elevators from 6698' to suface. U133-1/2" 8rd tubing. Hole fill calculated 53.7 bbis, actual 73.9 bbls.,M/U fishing BHA; Ball seat, HR running tool, Bumper sub and fishing jars., RIH with fishing BHA from 61' to 7886. PUW 141K, SOW 100K.,Dally hauled 57 bbls to G&I total= 4,064 bbis Hauled 0 bbis H2O from A -Pad reserve total = 2,210 bbls Hauled 0 bbis H2O from B -Pad Creek total = 780 bbis Lost 115 bbis to formation Total fluid lost 39-L1 = 1146 bbis Total Metal 246 Ib 8/11/2019 Attempt to engage hook hanger. PUW 141 K, SOW 100K. Slack off and observe 11 K down at 7886'. Pick up with 7K drag falling off. Put 1/4 turn and slack off putting 10K down at 7886. Pickup and observe overpull. Work over pull up to 60K over before breaking over. Continue to Pickup observing 5-15K drag for several feet. Slack off and tag with 10K down - 3' high. Pickup observing 2-3K higher weight.,POOH from 7886' to 78'. Racking back drill pipe. Calculated hole fill 67 bbis, actual 91.6 bbls.,UD BHA, oil jars, bumper. UD recovered hook hanger assembly and 18.08' cut joint.,Pick up cleanout assembly #2: 3-1/2" jetting tool, (2) magnets, 1 joint 3-1/2" tubing, (2) boot baskets, 8.25" OD magnet, Bumper sub, Oil jars. Loss rate 5 bph.,RIH: pick up, drift (3.125") and single in the hole from 129' to 446. PUW 50K, SOW 46K.,Continue to RIH from 445' to 8271' from derrick. PUW 145K, SOW 100K. Calc displacement 64.3 bbis, actual 59.3 bbls.,Wash down from 8,271'to 8,331' inside SBE while displacing to clean brine, work through SBE x 2 at 415 gpm/600 psi.,Monitor well, slight loss. POOH laying down drill pipe from 8,331' to 8,175'. Pump dry job. Continue to POOH laying down drill pipe from 8,175' to 129. Inspecting hard bands in pipe shed. Displacement calculated 67.6 bbis, actual 91.1 bbis., UD BHA, bumper sub, oil jars, 8.25" OD magnet, boot baskets, 1 jnt tubing, (2) magnets, jetting tool. 451bs of fine metal cuttings with a few 1"-2" metal chunks recovered from magnets. (1) 2' piece of rubber recovered on top of boot basket.,Clear rig floor. Pull wear bushing., Rig up to RIH with upper completion. Rig up SLB spooler, hang sheave. Rig up Weatherford. Bring cannon clamps to rig floor.,PJSM RIH with 3.5" EUE L-80 upper completion as per tally from surface to 178'. Make up torque 3200 ft-Ibs.,Daily hauled 699 bbis to G&I total = 4,783 bbis Hauled 0 bbis H2O from A -Pad reserve total = 2,210 bbis Hauled 0 bbis H2O from B -Pad Creek total = 780 bbis Lost 98 bbis to formation Total fluid lost 39 -Li = 1244 bbis IDaily Metal 481bs. Total Metal 294 lb 8/12/2019 Continue to R I H from 178' to 8310' with 3-1/2", 8rd, L-80 upper completion as per tally. Running speed 60 fpm once packer made up. M/U downhole gauge after joint 21 and test - good. Continually monitor gauge while RIH. Calculated displacement 33.1 bbls, actual 18.8 bbls.,Work seals through SBE at 8317, tagging up with 10K down. Establish circulation at 1 bpm 60 psi. Work seals down to 8335' observing a pressure increase as ports are covered. Continue to get returns. Appear to be pumping through the GLM's water flood valves. No -Go at 8335'. Rig up, shut in annular and PT back side 500 psi to ensure seals are engaged - holding pressure.,Space out 2.34' off no-go. L/D three joints, M/U space out pumps and full joint below hanger. Terminate kwire and feed through hanger. Drain stack. RIH and land tubing.,Rig up to reverse circulate corrosion inhibited brine and freeze protect. Attempt to space out with hanger below bag and ports in seal assembly not engaged. Pickup with hanger just below bag. Shut in, attempt to pump through seals, holding pressure, seals still engaged. Open annular. Space out so 1st joint below hanger is at the bag., PJSM, displace annulus with 340 bbls corrosion inhibited brine (I% Congor 100) and 185 bbls diesel for freeze protect. ICP 4.5bpm/450 psi FCP 4 bpm/618 psi. Open bleeder to backside, Open bag, slack off and engage seals. Drain stack. Land tubing hanger. RILDS., Breakout landing joint. M/U pump in sub, TIW and DP pup joint on top of landing joint. Install Ball and rod on top of closed TIW. M/U to hanger, M/U TD. Freeze protect tubing bull heading 22 bbis of diesel clear lines with 10 bbls brine at 1 bpm ICP 480 psi, FCP 700 psi.,Daily hauled 278 bbls to G&I total = 5,061 bbls Hauled 0 bbls H2O from A -Pad reserve total = 2.210 bbls Hauled 0 bbls H2O from B -Pad Creek total = 780 bbls Lost 125 bible to formation Total fluid lost 39-L1 = 1369 bbls Dailv Metal 10lbs Total Metal 304 I 8/13/2019 Open TIW and launch ball and rod with roller stem. Allow to fall on seat for 30 minutes. Pressure up to 3500 psi and hold for 5 minutes to set Tri -Point packer., Rig up to perform Pre -MIT -IA. Flood lines. Pressure up to 700 psi and observe pin hole leak on hose. Change out hose. Pressure up on packer to 3800 psi to ensure set for 5 minutes. Bleed down. Line up on IA and perform pre -MIT -IA to 2120 psi; 2090 after 15 minutes, 2090 after 30 minutes. Took 4.8 bbls to pressure up, 4.0 bbls returned.,Rig down 10' pup, TIW, and pump in sub from landing joint. Set BPV. R/D Weatherford and Schlumberger spooling unit.,Pick up stack washing tool. Wash BOP at 7.5 bpm. Flush and blow down choke, kill and surface lines. De -energize accumulator. Remove drip pan from BOP. Open ram doors and remove rams, prep for inspection. Disassembly MPD hard lines. Clean pipe handling equipment and prep for inspection. Break bolts on BOP. Simops: Continue replacing pinion seal on MP/t1.,N/D MPD RCD. Rig up slings. Pickup RCD with TD and suspend. Set BOP on pedestal. Lower RCD on spacer spool. P/U with tugger and tail to door.,N/D BOP'S: break apart BOP'S for CTI Cat III inspection, measure ram cavities, PT ram close/open position, inspect ram polish rod. SimOps: remove drag chain, remove spinners. Con, to wire wheel welds for MP inspection. Cont. to clean and disassemble rig floor handling equipment for inspection., Daily hauled 731 bible to G&I total= 5,792 bbls Hauled 0 bbls H2O from A -Pad reserve total= 2,210 bbls Hauled 0 bbls H2O from B -Pad Creek total = 780 bbls Lost 10 bbls to formation Total fluid lost 39 -Li = 1379 bbls Daily Metal Obs, Total Metal 3041 Hilcorp Alaska, LLC Milne Point M Pt E Pad MPU E-391-1 500292364060 Sperry Drilling Definitive Survey Report 09 August, 2019 HALLIBURTON Sporry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-39 Project: Milne Point TVD Reference: MPU E-39 Actual RKB @ 48.33usft Site: M Pt E Pad MD Reference: MPU E-39 Actual RKB @ 48.33usft Well: MPU E-39 North Reference: True Wellbore: MPU E-391_1 Survey Calculation Method: Minimum Curvature Design: MPU E -39L1 Database: NORTH US + CANADA Iroject Milne Point, ACT, MILNE POINT iAap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Aap Zone: Alaska Zone 04 Using geodetic scale factor Well MPU E-39 Audit Notes: Well Position +N/S 0.00 usft Northing: 6,016,057.25 usft Latitude: 70° 27' 15.210 N +EI -W 0.00 usft Easting: 569,284.13 usft Longitude: 149° 26'4.636 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 21.70 usft Wellbore MPU E-391_1 Magnetics Model Name Sample Date Declination (') BGGM2018 6/25/2019 16.65 Design MPU E -39L1 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) +NIS (usft) (usft) 26.63 0.00 Dip Angle 80.9E Tie On Depth: +E/ -W (usft) 0.00 Field Strength (nT) 57,425.42522507 7,797.61 Direction (I 190.86 Survey Program Date 8/9/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Dale 100.00 414.00 MPU E-39 NSG -GC Surveys (MPU E-39 2_Gyro-NS-GC_Drill colt H029Ga: North seeking single shot in drill colla 07/08/2019 483.39 7,797.61 MPU E-39 MWD+IFR2+MS+Sag (1) (MF 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 07/12/2019 7,853.00 12,604.71 MPU E-391_1 MWD+IFR2+MS+Sag (1) (12_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 08/09/2019 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (`) (1) (usft) (usft) (usft) (usft) (ft) (ft) (-1100') (ft) Survey Tool Name 26.63 0.00 0.00 26.63 -21.70 0.00 0.00 6,016,057.25 569,284.13 0.00 0.00 UNDEFINED 100.00 0.16 173.75 100.00 51.67 -0.10 0.01 6,016,057.15 569,284.14 0.22 0.10 2 Gyro-NS-GC_Drillmllar(1 165.00 0.27 194.83 165.00 116.67 -0.34 -0.02 6,016,056.91 569,284.11 0.21 0.34 2_Gyro-NS-GC_D6[lwllar(1 226.00 0.65 201.29 226.00 177.67 -0.80 -0.18 6,016,056.45 569,283.96 0.63 0.82 2_Gyro-NS-GC_Drill wllar(1 290.00 1.42 215.29 289.99 241.66 -1.79 -0.77 6,016,055.46 569,283.38 1.26 1.90 2_Gyro-NS-GC_Drill collar (1 350.00 2.52 218.79 349.95 301.62 -3.42 -2.03 6,016,053.81 569,282.14 1.84 3.74 2_Gyro-NS-GC_Drill wllar It 414.00 4.11 222.27 413.84 365.51 -6.22 4.45 6,016,050.99 569,279.74 2.50 6.94 2_Gyno NS -GC _Doll collar (1 483.39 5.69 219.37 482.98 434.65 -10.72 -8.31 6,018,046.46 569,275.93 2.30 12.09 2_MWD+IFR2+MS+Sag(2) 545.28 7.12 223.23 544.48 496.15 -15.88 -12.88 6,016,041.25 569,271.40 2.41 18.02 2_MWD+IFR2+MS+Sag(2) 608.08 9.12 220.18 606.65 558.32 -22.52 -18.76 6,016,034.56 569,265.59 3.26 25.65 2_MWD+IFR2+MS+Sag(2) 659.71 12.39 214.46 667.19 618.86 -31.71 -25.65 6,016,025.31 569,258.78 5.58 35.97 2_MWD+IFR2+MS+Sag(2) 732.21 14.12 212.37 728.02 679.69 43.68 -33.53 6,016,013.27 569,251.01 2.87 49.21 2_MWD+IFR2+MS+Sag(2) 81912019 12:28:55PM Page 2 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-39 Project: Milne Point ND Reference: MPU E-39 Actual RKB @ 48.33usft Site: M Pt E Pad MD Reference: MPU E-39 Actual RKB @ 48.33usft Well: MPU E-39 North Reference: True Wellbore: MPU E-3911 Survey Calculation Method: Minimum Curvature Design: MPU E-391-1 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc AN TVD TVDSS +NI -S +E/ -W Northing Easting OLS Section (usft) (') n (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 796.36 17.22 209.97 789.78 741.45 -58.51 42.46 6,015,998.35 569,242.22 4.94 65.47 2_MWD+IFR2+MS+Sag (2) 860.19 20.43 207.20 850.19 801.86 -76.61 -52.28 6,015,980.16 569,232.57 5.22 85.09 2_MWD+IFR2+MS+Sag (2) 923.22 22.95 206.77 908.75 860.42 -97.37 -62.64 6,015,959.31 569,222.20 4.01 107.47 2_MWD+IFR2+MS+Sag(2) 987.15 24.05 204.62 967.38 919.05 -120.34 -73.88 6,015,936.24 569,211.38 2.18 132.11 2 MWD+IFR2+MS+Sag(2) 1,050.81 26.18 202.06 1,025.02 976.69 -145.15 -84.56 6,015,911.33 569,200.93 3.76 158.49 2 MWD+IFR2+MS+Sag(2) 1,114.19 27.06 199.56 1,081.68 1,033.35 -171.70 -94.64 6,015,884.70 569,191.10 2.25 186.45 2_MWD+IFR2+MS+Sag(2) 1,176.60 30.83 195.70 1,136.29 1,087.96 -200.48 -103.73 6,015,855.83 569,182.28 6.74 216.44 2_MWD+IFR2+MS+Sag(2) 1,241.39 34.65 192.05 1,190.78 1,142.45 -234.50 -112.07 6,015,821.75 569,174.26 6.63 251.41 2_MWD+IFR2+MS+Sag(2) 1,304.06 37.46 190.27 1,241.44 1,193.11 -270.68 -119.19 6,015,785.50 569,167.48 4.78 288.29 2 MWD+IFR2+MS+Sag(2) 1,369.22 40.87 188.73 1,291.96 1,243.63 -311.26 -125.96 6,015,744.86 569,161.08 5.44 329.42 2_MWD+IFR2+MS+Sag(2) 1,432.23 42.43 188.57 1,339.04 1,290.71 -352.66 -132.25 6,015,703.41 569,155.17 2.48 371.26 2_MWD+IFR2+MS+Sag(2) 1,496.09 45.99 187.80 1,384.81 1,336.48 -396.73 -138.58 6,015,659.29 569,149.26 5.64 415.73 2_MWD+IFR2+MS+Sag(2) 1,559.03 49.51 188.24 1,427.12 1,378.79 442.85 -145.09 6,015,613.11 569,143.18 5.62 462.26 2_MWD+IFR2+MS+Sag(2) 1,623.25 52.97 188.47 1,467.32 1,418.99 492.39 -152.36 6,015,563.51 569,136.36 5.39 512.28 2_MWD+IFR2+MS+Sag(2) 1,686.43 56.22 188.70 1,503.92 1,455.59 -543.30 -160.05 6,015,512.53 569,129.15 5.15 563.73 2_MWD+IFR2+MS+Sag(2) 1,750.72 59.42 189.11 1,538.15 1,489.82 -597.05 -168.48 6,015,458.71 569,121.23 5.01 618.10 2_MWD+IFR2+MS+Sag(2) 1,814.09 60.89 189.80 1,569.69 1,521.36 -651.27 -177.51 6,015,404.42 569,112.70 2.50 673.05 2 MWD+IFR2+MS+Sag(2) 1,877.70 60.67 190.03 1,600.74 1,552.41 -705.96 -187.07 6,015,349.65 569,103.65 0.47 728.56 2_MWD+IFR2+MS+Sag(2) 1,941.46 60.78 189.09 1,631.92 1,583.59 -760.80 -196.30 6,015,294.73 569,094.93 1.30 784.16 2_MWD+IFR2+MS+Sag (2) 2,005.54 60.48 189.34 1,663.35 1,615.02 -815.92 -205.25 6,015,239.53 569,086.50 0.58 839.98 2_MWD+IFR2+MS+Sag(2) 2,069.38 57.99 189.39 1,696.00 1,647.67 -870.04 -214.17 6,015,185.33 569,078.08 3.90 894.81 2_MWD+IFR2+MS+Sag(2) 2,132.74 55.16 190.23 1,730.90 1,682.57 -922.15 -223.18 6,015,133.15 569,069.56 4.60 947.68 2_MWD+IFR2+MS+Sag (2) 2,196.24 57.50 190.72 1,766.10 1,717.77 -974.11 -232.79 6,015,081.11 569,060.43 3.74 1,000.52 2_MWD+IFR2+MS+Sag(2) 2,259.77 62.05 190.68 1,798.07 1,749.74 -1,028.03 -242.97 6,015,027.10 569,050.75 7.16 1,055.40 2_MWD+IFR2+MS+Sag (2) 2,323.62 63.55 189.88 1,827.26 1,778.93 -1,083.91 -253.11 6,014,971.14 569,041.14 2.60 1,112.19 2_MWD+IFR2+MS+Sag (2) 2,387.61 64.76 191.07 1,655.15 1,806.82 -1,140.54 -263.58 6,014,914.42 569,031.19 2.53 1,169.77 2_MWD+IFR2+MS+Sag(2) 2,450.95 63.13 190.89 1,882.97 1,834.64 -1,196.40 -274.42 6,014,858.47 569,020.88 2.59 1,226.67 2_MWD+IFR2+MS+Sag(2) 2,514.68 65.54 190.57 1,910.57 1,862.24 -1,252.83 -285.11 6,014,801.94 569,010.71 3.81 1,284.11 2_MWD+IFR2+MS+Sag(2) 2,578.51 65.91 191.37 1,936.82 1,888.49 -1,309.95 -296.18 6,014,744.72 569,000.17 1.28 1,342.30 2_MWD+IFR2+MS+Sag (2) 2,642.23 65.88 191.56 1,962.84 1,914.51 -1,366.96 -307.74 6,014,687.62 568,989.14 0.28 1,400.46 2_MWD+IFR2+MS+Sag (2) 2,706.01 65.29 190.52 1,989.20 1,940.87 -1,423.96 -318.87 6,014,630.53 568,978.55 1.75 1,458.53 2_MWD+IFR2+MS+Sag (2) 2,769.85 65.16 191.46 2,015.96 1,967.63 -1,480.86 -329.92 6,014,573.53 568,968.03 1.35 1,516.49 2_MWD+IFR2+MS+Sag (2) 2,832.93 64.91 191.64 2,042.58 1,994.25 -1,536.88 -341.37 6,014,517.40 568,957.10 0.47 1,573.68 2_MWD+IFR2+MS+Sag (2) 2,897.27 63.29 191.16 2,070.68 2,022.35 -1,593.62 -352.81 6,014,460.57 568,946.19 2.61 1,631.55 2_MWD+IFR2+MS+Sag(2) 2,960.99 64.56 189.56 2,098.69 2,050.36 -1,649.92 -363.09 6,014,404.19 568,936.43 3.01 1,688.78 2_MWD+IFR2+MS+Sag(2) 3,024.66 64.81 189.01 2,125.92 2,077.59 -1,706.72 -372.38 6,014,347.31 568,927.67 0.87 1,746.31 2_MWD+IFR2+MS+Sag(2) 3,088.50 64.75 188.79 2,153.12 2,104.79 -1,763.78 -381.32 6,014,290.17 568,919.27 0.33 1,804.03 2_MWD+IFR2+MS+Sag (2) 3,152.22 64.11 189.91 2,180.62 2,132.29 -1,820.49 -390.65 6,014,233.38 568,910.46 1.88 1,861.49 2_MWD+IFR2+MS+Sag (2) 3,216.03 63.59 190.06 2,208.74 2,160.41 -1,876.90 400.58 6,014,176.88 568,901.05 0.84 1,918.76 2_MWD+IFR2+MS+Sag (2) 3,279.04 62.41 189.28 2,237.35 2,189.02 -1,932.24 410.02 6,014,121.46 568,892.14 2.17 1,974.89 2_MWD+IFR2+MS+Sag(2) 8192019 12:28:55PM Page 3 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-39 Protect: Milne Point TVD Reference: MPU E-39 Actual RKB @ 48.33usft Site: M Pt E Pad MD Reference: MPU E-39 Actual RKB @ 48.33usft Well: MPU E-39 North Reference: True Wellbore: MPU E-3911 Survey Calculation Method: Minimum Curvature Design: MPU E -39L1 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1 -S +E/ -W Northing Easting DLS Section (usft) (1 (1) (usft) (usft) (usft) (usft) (ft) (ft) (-/100-) (ft) Survey Tool Name 3,343.25 61.59 189.64 2,267.49 2,219.16 -1,988.17 -419.33 6,014,065.46 568,883.34 1.37 2,031.57 2_MWD+IFR2+MS+Sag (2) 3,407.04 64.48 189.78 2,296.42 2,248.09 -2,044.20 -428.92 6,014,009.34 568,874.27 4.53 2,088.40 2_MWD+IFR2+MS+Sag (2) 3,470.52 63.88 190.02 2,324.07 2,275.74 -2,100.49 -438.75 6,013,952.97 568,864.98 1.00 2,145.54 2_MWD+IFR2+MS+Sag (2) 3,534.56 62.81 190.01 2,352.79 2,304.46 -2,156.85 448.70 6,013,896.52 568,855.55 1.67 2,202.77 2_MWD+IFR2+MS+Sag(2) 3,597.84 62.04 189.45 2,382.09 2,333.76 -2,212.14 458.18 6,013,841.16 568,846.58 1.45 2,258.85 2_MWD+IFR2+MS+Sag(2) 3,661.91 61.66 189.64 2,412.31 2,363.98 -2,267.85 -467.55 6,013,785.37 568,837.73 0.65 2,315.32 2_MWD+IFR2+MS+Sag(2) 3,725.51 61.86 190.16 2,442.41 2,394.08 -2,323.04 -477.18 6,013,730.09 568,828.62 0.79 2,371.34 2_MWD+IFR2+MS+Sag(2) 3,789.72 61.79 190.11 2,472.73 2,424.40 -2,378.76 -487.14 6,013,674.29 566,819.17 0.13 2,427.94 2 MWD+IFR2+MS+Sag(2) 3,853.22 61.14 190.34 2,503.06 2,454.73 -2,433.66 -497.04 6,013,619.30 568,809.78 1.07 2,483.72 2_MWD+IFR2+MS+Sag(2) 3,917.36 61.51 190.22 2,533.84 2,485.51 -2,489.03 -507.09 6,013,563.85 568,800.26 0.60 2,539.99 2_MWD+IFR2+MS+Sag(2) 3,981.11 64.64 189.38 2,562.70 2,514.37 -2,545.03 -516.75 6,013,507.76 568,791.11 5.05 2,596.82 2_MWD+IFR2+MS+Sag(2) 4,044.65 64.41 189.48 2,590.03 2,541.70 -2,601.62 -526.15 6,013,451.09 568,782.24 0.39 2,654.16 2_MWD+IFR2+MS+Sag(2) 4,108.10 64.27 189.64 2,617.51 2,569.18 -2,658.02 -535.65 6,013,394.62 568,773.27 0.32 2,711.34 2_MWD+IFR2+MS+Sag(2) 4,171.10 64.51 190.19 2,644.74 2,596.41 -2,713.98 -545.43 6,013,338.57 568,764.01 0.87 2,768.14 2_MWD+IFR2+MS+Sag(2) 4,235.37 64.36 190.84 2,672.47 2,624.14 -2,770.99 -556.01 6,013,281.48 568,753.96 0.94 2,826.12 2_MWD+IFR2+MS+Sag(2) 4,298.71 63.98 190.55 2,700.07 2,651.74 -2,827.01 -566.59 6,013,225.36 568,743.90 0.73 2,883.13 2_MWD+IFR2+MS+Sag(2) 4,362.45 63.38 190.53 2,728.33 2,680.00 -2,883.17 -577.04 6,013,169.11 568,733.97 0.94 2,940.26 2 MWD+IFR2+MS+Sag (2) 4,426.23 66.64 190.87 2,755.27 2,706.94 -2,939.97 -587.78 6,013,112.22 568,723.77 5.13 2,998.06 2_MWD+IFR2+MS+Sag (2) 4,489.08 67.84 190.52 2,779.59 2,731.26 -2,996.92 -598.53 6,013,055.18 568,713.55 1.98 3,056.01 2_MWD+IFR2+MS+Sag (2) 4,553.18 66.80 190.92 2,804.30 2,755.97 -3,055.03 -609.53 6,012,996.97 568,703.09 1.72 3,115.16 2_MWD+IFR2+MS+Sag (2) 4,616.52 67.11 191.27 2,829.10 2,780.77 -3,112.22 -620.75 6,012,939.68 568,692.40 0.71 3,173.44 2_MWD+IFR2+MS+Sag(2) 4,679.61 64.83 191.30 2,854.79 2,806.46 -3,168.73 -632.02 6,012,883.08 568,681.66 3.61 3,231.06 2_MWD+IFR2+MS+Sag (2) 4,744.00 64.90 191.74 2,882.14 2,833.81 -3,225.85 -643.67 6,012,825.86 568,670.55 0.63 3,289.35 2_MWD+IFR2+MS+Sag (2) 4,807.79 64.14 190.83 2,909.58 2,861.25 -3,282.32 -654.94 6,012,769.29 568,659.80 1.75 3,346.93 2_MWD+IFR2+MS+Sag (2) 4,871.13 62.53 190.64 2,938.00 2,889.67 -3,337.93 -665.48 6,012,713.59 568,649.78 2.56 3,403.53 2_MWD+IFR2+MS+Sag (2) 4,935.30 62.08 190.21 2,967.83 2,919.50 -3,393.81 -675.76 6,012,657.63 568,640.02 0.92 3,460.35 2_MWD+IFR2+MS+Sag (2) 4,998.60 61.68 190.22 2,997.66 2,949.33 -3,448.75 -685.66 6,012,602.60 568,630.63 0.63 3,516.17 2_MWD+IFR2+MS+Sag (2) 5,062.66 63.68 190.33 3,027.06 2,978.73 -3,504.75 -695.81 6,012,546.51 568,621.00 3.13 3,573.08 2 MWD+IFR2+MS+Sag (2) 5,126.34 64.52 190.21 3,054.88 3,006.55 -3,561.12 -706.03 6,012,490.06 568,611.31 1.33 3,630.36 2_MWD+IFR2+MS+Sag(2) 5,189.87 64.82 190.19 3,082.06 3,033.73 -3,617.63 -716.20 6,012,433.46 568,601.67 0.47 3,687.78 2 MWD+IFR2+MS+Sag(2) 5,253.86 63.67 189.73 3,109.86 3,061.53 -3,674.39 -726.16 6,012,376.61 568,592.23 1.91 3,745.40 2_MWD+IFR2+MS+Sag(2) 5,317.79 62.29 189.64 3,138.90 3,090.57 -3,730.53 -735.75 6,012,320.39 568,583.17 2.16 3,802.34 2_MWD+IFR2+MS+Sag(2) 5,381.29 62.86 189.49 3,168.15 3,119.82 -3,786.11 -745.11 6,012,264.73 568,574.33 0.92 3,858.69 2_MWD+IFR2+MS+Sag(2) 5,445.37 62.51 189.68 3,197.56 3,149.23 -3,842.25 -754.59 6,012,208.51 568,565.37 0.61 3,915.61 2_MWD+IFR2+MS+Sag(2) 5,509.05 62.13 189.99 3,227.14 3,178.81 -3,897.82 -764.22 6,012,152.87 568,556.26 0.74 3,972.00 2_MWD+IFR2+MS+Sag (2) 5,572.69 62.31 189.92 3,256.80 3,208.47 -3,953.27 -773.96 6,012,097.32 568,547.04 0.30 4,028.29 2_MWD+IFR2+MS+Sag(2) 5,636.28 62.43 190.17 3,286.29 3,237.96 4,008.75 -783.78 6,012,041.77 568,537.73 0.40 4,084.63 2_MWD+IFR2+MS+Sag (2) 5,699.38 63.18 190.35 3,315.13 3,266.80 4,063.97 -793.78 6,011,986.45 568,528.25 1.22 4,140.75 2_MWD+IFR2+MS+Sag (2) 5,763.25 64.26 190.75 3,343.41 3,295.08 4,120.27 -804.27 6,011,930.07 568,518.29 1.78 4,198.01 2_MWD+IFR2+MS+Sag(2) 5,826.53 64.41 190.34 3,370.81 3,322.48 4,176.35 -814.70 6,011,873.90 568,508.37 0.63 4,255.05 2_MWD+IFR2+MS+Sag (2) aWO19 12:28:55PM Page 4 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Milne Point M Pt E Pad MPU E-39 MPU E -39L1 MPU E -39L1 Local Co-ordinate Reference: Well MPU E-39 TVD Reference: MPU E-39 Actual IRKS @ 48.33usft MD Reference: MPU E-39 Actual IRKS @ 48.33usft North Reference: True Survey Calculation Method: Minimum Curvature Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) (') (") (usft) (usft) (usft) (usft) (ft) (ft) ('1100') (ft) Survey Tool Name 5,890.02 65.36 190.58 3,397.76 3,349.43 -4,232.88 -825.14 6,011,817.28 568,498.46 1.53 4,312.53 2_MWD+IFR2+MS+Sag(2) 5,953.28 63.74 189.48 3,424.94 3,376.61 4,289.12 -835.09 6,011,760.95 568,489.03 3.00 4,369.65 2_MWD+IFR2+MS+Sag (2) 6,016.58 63.50 189.85 3,453.07 3,404.74 -4,345.03 -844.61 6,011,704.97 568,480.03 0.65 4,426.34 2_MWD+IFR2+MS+Sag (2) 6,080.00 63.74 190.12 3,481.25 3,432.92 4,400.98 -854.47 6,011,648.93 568,470.70 0.54 4,483.15 2 MWD+IFR2+MS+Sag (2) 6,143.80 64.63 190.04 3,509.03 3,460.70 4,457.53 -864.52 6,011,592.30 568,461.18 1.40 4,540.58 2_MWD+IFR2+MS+Sag(2) 6,207.16 64.67 190.05 3,536.16 3,487.83 4,513.91 -874.50 6,011,535.83 568,451.72 0.06 4,597.83 2_MWD+IFR2+MS+Sag(2) 6,270.30 62.98 189.08 3,564.01 3,515.68 4,569.78 -883.92 6,011,479.88 568,442.82 3.01 4,654.48 2_MWD+IFR2+MS+Sag(2) 6,333.47 63.75 188.48 3,592.33 3,544.00 3,625.59 -892.54 6,011,424.00 568,434.72 1.49 4,710.91 2_MWD+IFR2+MS+Sag(2) 6,396.51 64.55 188.55 3,619.82 3,571.49 3,681.69 -900.94 6,011,367.82 568,426.84 1.27 4,767.59 2_MWD+IFR2+MS+Sag(2) 6,461.33 62.17 188.45 3,648.88 3,600.55 3,738.99 -909.50 6,011,310.45 568,418.81 3.67 4,825.48 2_MWD+IFR2+MS+Sag(2) 6,524.83 62.02 188.36 3,678.60 3,630.27 3,794.51 -917.71 6,011,254.87 568,411.13 0.27 4,881.54 2_MWD+IFR2+MS+Sag(2) 6,588.52 61.71 189.03 3,708.63 3,660.30 3,850.02 -926.20 6,011,199.28 568,403.16 1.05 4,937.67 2_MWD+IFR2+MS+Sag(2) 6,652.27 61.72 189.22 3,738.84 3,690.51 3,905.45 -935.10 6,011,143.78 568,394.77 0.26 4,993.78 2_MWD+IFR2+MS+Sag(2) 6,715.48 61.89 189.53 3,768.70 3,720.37 4,960.42 -944.18 6,011,088.74 568,386.21 0.51 5,049.47 2_MWD+IFR2+MS+Sag(2) 6,779.43 62.54 188.84 3,798.51 3,750.18 -5,016.27 -953.21 6,011,032.81 568,377.70 1.39 5,106.02 2_MWD+IFR2+MS+Sag(2) 6,842.93 62.70 189.97 3,827.72 3,779.39 -5,071.89 -962.42 6,010,977.11 568,369.00 1.60 5,162.39 2_MWD+IFR2+MS+Sag(2) 6,905.95 63.01 190.44 3,856.47 3,808.14 -5,127.09 -972.36 6,010,921.83 568,359.58 0.83 5,218.46 2_MWD+IFR2+MS+Sag (2) 6,970.39 62.42 190.24 3,886.01 3,837.68 -5,183.43 -982.64 6,010,865.40 568,349.83 0.96 5,275.73 2_MWD+IFR2+MS+Sag (2) 7,033.67 62.56 191.17 3,915.24 3,866.91 -5,238.57 -993.06 6,010,810.16 568,339.92 1.32 5,331.86 2_MWD+IFR2+MS+Sag (2) 7,097.26 63.77 191.14 3,943.95 3,895.62 -5,294.24 -1,004.04 6,010,754.40 568,329.46 1.90 5,388.60 2_MWD+IFR2+MS+Sag (2) 7,161.01 63.72 191.39 3,972.15 3,923.82 -5,350.31 -1,015.21 6,010,698.23 568,318.81 0.36 5,445.77 2_MWD+IFR2+MS+Sag (2) 7,224.50 63.21 191.43 4,000.51 3,952.18 -5,405.99 -1,026.44 6,010,642.46 568,308.09 0.81 5,502.57 2_MWD+IFR2+MS+Sag (2) 7,287.83 64.01 191.32 4,028.66 3,980.33 -5,461.61 -1,037.63 6,010,586.75 568,297.42 1.27 5,559.29 2_MWD+IFR2+MS+Sag (2) 7,351.53 65.24 192.54 4,055.96 4,007.63 -5,517.92 -1,049.53 6,010,530.33 568,286.05 2.59 5,616.84 2_MWD+IFR2+MS+Sag(2) 7,415.12 62.35 192.27 4,084.04 4,035.71 -5,573.63 -1,061.79 6,010,474.51 568,274.31 4.56 5,673.86 2_MWD+IFR2+MS+Sag (2) 7,478.87 62.47 193.01 4,113.56 4,065.23 -5,628.76 -1,074.15 6,010,419.27 568,262.46 1.05 5,730.34 2_MWD+IFR2+MS+Sag (2) 7,542.91 62.76 193.58 4,143.02 4,094.69 -5,684.10 -1,087.23 6,010,363.82 568,249.90 0.91 5,787.15 2_MWD+IFR2+MS+Sag (2) 7,606.59 65.09 191.98 4,171.01 4,122.68 -5,739.88 -1,099.87 6,010,307.93 568,237.78 4.30 5,844.31 2_MWD+IFR2+MS+Sag(2) 7,670.07 66.51 190.87 4,197.03 4,148.70 -5,796.63 -1,111.34 6,010,251.08 568,226.84 2.75 5,902.20 2_MWD+IFR2+MS+Sag(2) 7,734.06 66.21 192.83 4,222.69 4,174.36 5,854.00 -1,123.37 6,010,193.61 568,215.34 2.84 5,960.81 2_MWD+IFR2+MS+Sag(2) 7,797.61 67.03 193.89 4,247.91 4,199.58 5,910.75 -1,136.85 6,010,136.74 568,202.39 2.00 6,019.09 2_MWD+IFR2+MS+Sag (2) 7,853.00 67.79 193.39 4,269.19 4,220.86 -5,960.45 -1,148.91 6,010,086.94 568,190.80 1.61 6,070.17 2_MWD+IFR2+MS+Sag (3) 7,905.72 69.32 194.65 4,288.46 4,240.13 -6,008.05 -1,160.80 6,010,039.23 568,179.35 3.66 6,119.16 2_MWD+IFR2+MS+Sag (3) 7,966.01 73.46 195.06 4,307.70 4,259.37 -6,063.27 -1,175.45 6,009,983.89 568,165.22 6.90 6,176.14 2_MWD+IFR2+MS+Sag (3) 8,032.01 78.74 195.49 4,323.55 4,275.22 -6,125.05 -1,192.33 6,009,921.96 568,148.92 8.02 6,240.00 2_MWD+IFR2+MS+Sag (3) 8,098.68 80.46 195.92 4,335.58 4,287.25 -6,188.17 -1,210.08 6,009,858.68 568,131.76 2.66 6,305.34 2_MWD+IFR2+MS+Sag (3) 8,161.16 83.95 196.31 4,344.05 4,295.72 -6,247.63 -1,227.26 6,009,799.07 568,115.13 5.62 6,366.97 2_MWD+IFR2+MS+Sag (3) 8,224.45 86.55 196.71 4,349.29 4,300.96 -6,308.10 -1,245.18 6,009,738.44 568,097.78 4.16 6,429.73 2_MWD+IFR2+MS+Sag (3) 8,288.17 88.78 197.10 4,351.89 4,303.56 -6,369.01 -1,263.69 6,009,677.36 568,079.83 3.55 6,493.04 2_MWD+IFR2+MS+Sag (3) 8,351.42 92.36 197.50 4,351.26 4,302.93 5,429.39 -1,282.50 6,009,616.82 568,061.59 5.70 6,555.88 2_MWD+IFR2+MS+Sag (3) M2019 12:26:55PM Page 5 COMPASS 5000.15 Build 91 6 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: MPU E-39 Wellbore: MPU E-3911 Design: MPU E-391-1 Survey MD Inc Azi TVD TVDSS +N/ -S (usft) (1) (1 (usft) (usft) (usft) 8,416.49 95.57 198.76 4,346.76 4,298.43 -6491.07 8,479.09 97.01 200.41 4,339.90 4,291.57 -6,549.69 8,543.72 97.25 199.03 4,331.88 4,283.55 -6,610.06 8,607.54 95.94 196.77 4,324.55 4,276.22 -6,670.38 8,672.00 93.52 193.41 4,319.23 4,270.90 -6,732.40 8,735.05 95.51 192.23 4,314.27 4,265.94 -6,793.68 8,799.20 94.20 190.47 4,308.84 4,260.51 -6,856.34 8,862.27 94.51 189.56 4,304.05 4,255.72 -6,918.27 8,925.95 93.71 190.53 4,299.49 4,251.16 -6,980.81 8,989.41 92.60 192.34 4,296.00 4,247.67 -7,042.92 9,053.95 93.03 194.48 4,292.83 4,244.50 -7,105.62 9,116.52 93.46 192.85 4,289.28 4,240.95 -7,166.32 9,179.84 93.83 192.26 4,285.26 4,236.93 -7,228.00 9,243.56 91.60 191.51 4,282.24 4,233.91 -7,290.28 9,306.65 90.62 191.57 4,281.02 4,232.69 -7,352.08 9,367.69 91.67 193.11 4,279.80 4,231.47 -7,411.69 9,432.50 91.86 194.17 4,277.80 4,229.47 -7,474.65 9,497.52 92.10 194.36 4,275.55 4,227.22 -7,537.62 9,558.47 91.11 192.73 4,273.85 4,225.52 -7,596.85 9,623.50 90.06 190.28 4,273.18 4,224.85 -7,660.57 9,688.08 88.83 189.77 4,273.81 4,225.48 -7,724.16 9,752.34 89.76 189.68 4,274.60 4,226.27 -7,787.49 9,815.73 91.74 191.29 4,273.77 4,225.44 -7,849.81 9,878.66 92.04 193.68 4,271.69 4,223.36 -7,911.21 9,943.79 91.36 193.97 4,269.76 4,221.43 -7,974.43 10,006.02 91.49 194.86 4,268.21 4,219.88 -8,034.68 10,070.14 91.92 194.34 4,266.31 4,217.98 -8,096.70 10,133.50 94.40 194.47 4,262.81 4,214.48 -8,157.97 10,196.46 94.39 195.06 4,257.99 4,209.66 -8,218.67 10,259.32 93.46 194.75 4,253.69 4,205.36 -8,279.27 10,323.51 93.03 193.69 4,250.05 4,201.72 -8,341.40 10,387.29 92.97 193.03 4,246.72 4,198.39 -8,403.36 10,451.29 93.09 192.22 4,243.33 4,195.00 -8,465.73 10,514.74 92.47 192.63 4,240.25 4,191.92 -6,527.62 10,578.07 92.35 192.55 4,237.59 4,189.26 -8,589.37 10,640.70 92.10 192.45 4,235.16 4,186.83 -8,650.47 10,704.87 92.60 192.57 4,232.53 4,184.20 -8,713.07 10,768.30 92.35 192.38 4,229.79 4,181.46 -8,774.94 10,833.19 92.66 193.38 4,226.95 4,178.62 -8,838.14 10,896.81 91.85 193.09 4,224.45 4,176.12 -8,900.02 892019 12:28:55PM Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU E-39 MPU E-39 Actual RKB @ 48.33usft MPU E-39 Actual RKB @ 48.33usft True Minimum Curvature NORTH US + CANADA Map Map +E/ -W Northing Easting DLS (usft) (ft) (ft) ("N00-) -1,302.69 6,009,554.96 568,041.97 5.30 -1,323.55 6,009,496.15 568,021.67 3.49 -1,345.19 6,009,435.59 568,000.59 2.15 -1,364.67 6,009,375.10 567,981.67 4.07 -1,381.39 6,009,312.94 567,965.53 6.41 -1,395.33 6,009,251.53 567,952.16 3.67 -1,407.91 6,009,188.76 567,940.17 3.41 -1,418.85 6,009,126.74 567,929.81 1.52 -1,429.93 6,009,064.10 -1,442.49 6,009,001.89 -1,457.44 6,008,939.06 -1,472.19 6,008,878.23 -1,485.93 6,008,816.43 -1,499.04 6,008,754.04 -1,511.66 6,008,692.13 -1,524.70 6,008,632.40 -1,539.97 6,008,569.31 -1,555.99 6,008,506.20 -1,570.25 6,008,446.84 -1,583.22 6,008,383.02 -1,594.46 6,008,319.33 -1,605.32 6,008,255.91 -1,616.85 6,008,193.49 -1,630.45 6,008,131.97 -1,646.00 6,008,068.62 -1,661.49 6,008,008.23 -1,677.65 6,007,946.07 -1,693.38 6,007,884.66 -1,709.38 6,007,823.82 -1,725.51 6,007,763.07 -1,741.25 6,007,700.81 -1,755.97 6,007,638.72 -1,769.94 6,007,576.23 -1,783.58- 6,007,514.22 -1,797.37 6,007,452.35 -1,810.91 6,007,391.13 -1,824.80 6,007,328.42 -1,838.49 6,007,266.42 -1,852.94 6,007,203.10 -1,867.49 6,007,141.09 Page 6 567,919.31 567,907.33 567,892.96 567,878.77 567,865.61 567,853.09 567,841.04 567,828.56 567,813.87 567,798.45 567,784.73 567,772.36 567,761.71 567,751.44 567,740.49 567,727.47 567,712.50 567,697.58 567,682.00 567,666.84 567,651.40 567,635.84 567,620.68 567,606.54 567,593.15 567,580.09 567,566.88 567,553.90 567,540.60 567,527.48 567,513.62 567,499.65 1.97 3.34 3.38 2.69 1.10 3.69 1.56 3.05 1.66 0.47 3.13 4.10 2.06 1.45 4.03 3.83 1.13 1.44 1.05 3.92 0.93 1.56 1.78 1.04 1.28 1.17 0.23 0.43 0.80 0.49 1.61 1.35 Vertical Section (ft) Survey Tool Name 6,620.26 2_MWD+IFR2+MS+Sag(3) 6,681.76 2_MWD+IFR2+MS+Sag(3) 6,745.12 2_MWD+IFR2+MS+Sag (3) 6,808.04 2_MWD+IFR2+MS+Sag (3) 6,872.09 2_MWD+IFR2+MS+Sag (3) 6,934.90 2_MWD+IFR2+MS+Sag (3) 6,998.81 2_MWD+IFR2+MS+Sag (3) 7,061.69 2_MWD+IFR2+MS+Sag(3) 7,125.20 2_MWD+IFR2+MS+Sag(3) 7,188.56 2_MWD+IFR2+MS+Sag(3) 7,252.95 2_MWD+IFR2+MS+Sag (3) 7,315.35 2_MWD+IFR2+MS+Sag (3) 7,378.51 2_MWD+IFR2+MS+Sag (3) 7,442.15 2 MWD+IFR2+MS+Sag (3) 7,505.22 2_MWD+IFR2+MS+Sag(3) 7,566.22 2_MWD+IFR2+MS+Sag(3) 7,630.92 2_MWD+IFR2+MS+Sag(3) 7,695.79 2_MWD+IFR2+MS+Sag(3) 7,756.65 2_MWD+IFR2+MS+Sag (3) 7,821.66 2_MWD+IFR2+MS+Sag(3) 7,886.23 2_MWD+IFR2+MS+Sag (3) 7,950.47 2_MWD+IFR2+MS+Sag(3) 8,013.85 2_MWD+IFR2+MS+Sag(3) 8,076.72 2_MWD+IFR2+MS+Sag(3) 8,141.73 2_MWD+IFR2+MS+Sag(3) 8,203.82 2_MWD+IFR2+MS+Sag(3) 8,267.78 2_MWD+IFR2+MS+Sag (3) 8,330.92 2 MWD+IFR2+MS+Sag(3) 8,393.54 2_MWD+IFR2+MS+Sag(3) 8,456.10 2_MWD+IFR2+MS+Sag(3) 8,520.08 2_MWD+IFR2+MS+Sag (3) 8,583.71 2_MWD+IFR2+MS+Sag (3) 8,647.59 2_MWD+IFR2+MS+Sag (3) 8,710.94 2_MWD+IFR2+MS+Sag (3) 8,774.18 2_MWD+IFR2+MS+Sag(3) 8,836.74 2_MWD+IFR2+MS+Sag(3) 8,900.83 2_MWD+IFR2+MS+Sag (3) 8,964.17 2 MWD+IFR2+MS+Sag(3) 9,028.96 2_MWD+IFR2+MS+Sag(3) 9,092.48 2_MWD+IFR2+MS+Sag(3) COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-39 Project: Milne Point TVD Reference: MPU E-39 Actual RKB @ 48.33usft Site: M Pt E Pad MD Reference: MPU E-39 Actual RKB @ 48.33usft Well: MPU E-39 North Reference: True Wellbore: MPU E-3911 Survey Calculation Method: Minimum Curvature Design: MPU E -39L1 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 10,960.77 92.35 193.96 4,222.11 4,173.78 -8,962.16 -1,882.44 6,007,078.82 567,485.28 1.57 9,156.32 2_MWD+IFR2+MS+Sag(3) 11,024.21 92.41 194.52 4,219.47 4,171.14 -9,023.60 -1,898.03 6,007,017.25 567,470.26 0.89 9,219.60 2_MWD+IFR2+MS+Sag(3) 11,088.12 93.22 195.07 4,216.33 4,168.00 -9,085.31 -1,914.33 6,006,955.39 567,454.54 1.53 9,283.28 2_MWD+IFR2+MS+Sag(3) 11,151.03 94.33 195.82 4,212.19 4,163.86 -9,145.82 -1,931.05 6,006,894.73 567,438.38 2.13 9,345.85 2_MWD+IFR2+MS+Sag(3) 11,214.25 95.07 195.76 4,207.01 4,158.68 -9,206.45 -1,948.20 6,006,833.95 567,421.81 1.17 9,408.63 2_MWD+IFR2+MS+Sag(3) 11,277.72 95.39 194.46 4,201.23 4,152.90 -9,267.47 -1,964.67 6,006,772.79 567,405.90 2.10 9,471.66 2_MWD+IFR2+MS+Sag(3) 11,341.13 94.95 193.42 4,195.51 4,147.18 -9,328.76 -1,979.89 6,006,711.37 567,391.26 1.77 9,534.72 2_MWD+IFR2+MS+Sag(3) 11,404.54 92.59 190.67 4,191.34 4,143.01 -9,390.63 -1,993.09 6,006,649.38 567,378.64 5.71 9,597.96 2_MWD+IFR2+MS+Sag (3) 11,468.22 93.96 189.80 4,187.70 4,139.37 -9,453.19 -2,004.38 6,006,586.72 567,367.92 2.55 9,661.53 2_MWD+IFR2+MS+Sag (3) 11,531.53 93.28 187.15 4,183.71 4,135.38 -9,515.68 -2,013.69 6,006,524.16 567,359.19 4.31 9,724.66 2_MWD+IFR2+MS+Sag (3) 11,595.28 92.66 183.96 4,180.40 4,132.07 -9,579.04 -2,019.85 6,006,460.75 567,353.62 5.09 9,788.04 2_MWD+IFR2+MS+Sag (3) 11,658.58 93.22 184.06 4,177.16 4,128.83 -9,642.10 -2,024.27 6,006,397.66 567,349.79 0.90 9,850.81 2_MWD+IFR2+MS+Sag(3) 11,721.92 92.60 185.78 4,173.94 4,125.61 -9,705.12 -2,029.70 6,006,334.59 567,344.95 2.88 9,913.72 2_MWD+IFR2+MS+Sag(3) 11,785.49 93.03 188.92 4,170.82 4,122.49 -9,768.08 -2,037.82 6,006,271.56 567,337.42 4.98 9,977.09 2_MWD+IFR2+MS+Sag(3) 11,849.30 93.03 191.93 4,167.44 4,119.11 -9,830.75 -2,049.35 6,006,208.80 567,326.47 4.71 10,040.80 2_MWD+IFR2+MS+Sag(3) 11,912.89 92.10 192.73 4,164.60 4,116.27 -9,892.81 -2,062.92 6,006,146.63 567,313.49 1.93 10,104.30 2_MWD+IFR2+MS+Sag(3) 11,976.02 91.67 193.54 4,162.52 4,114.19 -9,954.25 -2,077.25 6,006,085.06 567,299.72 1.45 10,167.35 2_MWD+IFR2+MS+Sag(3) 12,039.77 90.18 194.41 4,161.49 4,113.16 -10,016.10 -2,092.65 6,006,023.07 567,284.90 2.71 10,230.99 2_MWD+IFR2+MS+Sag (3) 12,102.89 90.87 196.58 4,160.91 4,112.58 -10,076.92 -2,109.51 6,005,962.10 567,268.61 3.61 10,293.90 2_MWD+IFR2+MS+Sag (3) 12,166.65 92.91 198.96 4,158.81 4,110.48 -10,137.60 -2,128.95 6,005,901.25 567,249.73 4.91 10,357.16 2_MWD+IFR2+MS+Sag (3) 12,230.27 93.47 201.40 4,155.27 4,106.94 -10,197.22 -2,150.86 6,005,841.44 567,228.38 3.93 10,419.83 2_MWD+IFR2+MS+Sag (3) 12,293.48 93.77 202.76 4,151.28 4,102.95 -10,255.67 -2,174.58 6,005,782.77 567,205.21 2.20 10,481.71 2_MWD+IFR2+MS+Sag (3) 12,357.80 92.28 203.44 4,147.88 4,099.55 -10,314.75 -2,199.78 6,005,723.47 567,180.57 2.55 10,544.48 2_MWD+IFR2+MS+Sag(3) 12,420.64 93.03 205.82 4,144.97 4,096.64 -10,371.81 -2,225.93 6,005,666.17 567,154.94 3.97 10,605.44 2_MWD+IFR2+MS+Sag(3) 12,484.92 93.96 206.81 4,141.05 4,092.72 -10,429.32 -2,254.38 6,005,608.41 567,127.04 2.11 10,667.28 2_MWD+IFR2+MS+Sag(3) 12,548.76 93.84 207.27 4,136.71 4,088.38 -10,486.05 -2,283.33 6,005,551.42 567,098.62 0.74 10,728.45 2_MWD+IFR2+MS+Sag (3) 12,604.71 94.83 207.11 4,132.48 4,084.15 -10,535.67 -2,308.82 6,005,501.56 567,073.59 1.79 10,781.99 2 MWD+IFR2+MS+Sag (3) 12,675.00 94.83 207.11 4,126.56 4,078.23 -10,598.02 -2,340.74 6,005,438.93 567,042.25 0.00 10,849.23 PROJECTED to TD Checked By: Chelsea Wright!7' m._ Approved By: Mitch Laird Date: 08-09-2019 892019 12.28.55PM Page 7 COMPASS 5000.15 Build 91 I De�raoTe Judean 3800 C Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 itllenq, un.ka. MA. Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 8/30/2019 To: Alaska Oil & Gas Conservation Commission Abby Bell RECEIVED Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 SEP 0 3 2019 AOGCC MPU E-39 PTD 219-096)+ E -39L1 PTD 219-099 CD 1: ROP DGR ABG EWR ADR WELLBORE PROFILE MD AND TVD DEFINITIVE SURVEY CGM 913W20199:14AM Filefolder Definitive Survey 8/30/20l 9 9:14 APA Filefolder EMF S/30/201 9 9:15 AM Filefolder LAS 8/3212319 9:15 AM File folder PDF 8/3020199:15 AM Filefolder TIFF 8(30/2©149;15 AM Filefolder 219099 31171 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Davies, Stephen F (CED) From: Davies, Stephen F (CED) Sent: Monday, July 22, 2019 1:00 PM To: Cody Dinger Cc: Monty Myers (mmyers@hilcorp.com) Subject: RE: [EXTERNAL] MPU E-391_1 (PTD 219-099) - Question Thank you Cody. I will correct the API number in AOGCC's records. Thanks again for your help. Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesCibalaska.gov. From: Cody Dinger <cdinger@hilcorp.com> Sent: Monday, July 22, 2019 12:48 PM To: Monty Myers <mmyers@hilcorp.com>; Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: Joe Engel <jengel@hilcorp.com> Subject: RE: (EXTERNAL] MPU E-391_1 (PTD 219-099) - Question Steve, MPU E -39L1 is going to be a dual lateral (currently drilling the motherbore, E-39). I just received the approved permit (API 50-029-23640-01-00) and I can edit the API number issued on the PTD to a 60 instead of 01. Thanks, Cody Dinger Hilcorp Alaska, LLC Drilling Tech 907-777-8389 From: Monty Myers Sent: Monday, July 22, 2019 12:19 PM To: Cody Clinger <cdineer@hilcorp.com> Subject: FW: [EXTERNAL] MPU E-39L1(PTD 219-099) - Question I believe this is supposed to be a -60 suffix. Can you confirm what we did on 42 and let Steve know? Thank you! Monty M Myers Drilling Manager 907.538.1168 (c) 907.777.8431(o) From: Davies, Stephen F (CED)[mailto:steve.davies@alaska.gov] Sent: Monday, July 22, 2019 9:21 AM To: Monty Myers <mmyers@hilcorp.com> Subject: [EXTERNAL] MPU E-391_1 (PTD 219-099) - Question Monty, This morning I was looking over Hilcorp's approved Permit to Drill application for this MPU E-391-1, and it looks as though we here at the AOGCC made a mistake. Hilcorp's application requested approval for a lateral well branch to be drilled from the MPU E-39 parent well, but AOGCC's cover letter states the approved application is for a redrilled well. This means the API number assigned to MPU E -39L1 by AOGCC is not correct. The currently assigned API number is 50-029- 23640-01-00, with the -01- suffix signifying a redrilled well. But if the wellbore is a lateral well branch, the API number should instead be 50-029-23640-60-00. Please confirm the wellbore type for MPU D-391-1, and (if necessary) I will fix AOGCC's databases and then send you an email specifying the correct API number for Hilcorp's record and databases. Thank you, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesPalaska.gov. The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication maybe legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU E -39L1 Hilcorp Alaska, LLC Permit to Drill Number: 219-099 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. aogc c.o lasko.gov Surface Location: 3519' FSL, 1863' FEL, SEC. 25, TI 3N, RI OE, UM, AK Bottomhole Location: 1550' FSL, 1198' FWL, SEC. 6, T12N, RI IE, UM, AK Dear Mr. Myers: I�1 / a.. /i �4t� � Enclosed is the approved application for the permit to re ' 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 terns and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie L. Chmielowski Commissioner DATED this I � day of July, 2019. STATE OF ALASKA ALHSKA OIL AND GAS CONSERVATION COMNtioSION PERMIT TO DRILL 90 AAO 91, nn5 RE C L. -A VED JUL 1 1 9019 1 a. Type of Work: Drill F Lateral Redrill Reentry ❑ b. Proposed Well Class: Exploratory - Gas ❑ Service- WAG ❑ Service - Disp ❑ Stratigraphic Test ❑ Development - Oil ❑ Service- Winj ❑Q Single Zone ❑Q Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ 1c. Specify1 1 'S�� o(s��d for: Coalbedfdaf=,.=iJL�i RSAiI(tlrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: A Itrq Hilcorp Alaska, LLC �t' '1 5. Bond: Blanket 0 Single Well ❑ Bond No. 022035244 t 11. Well Name and Number: MPU E-391_1 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 6. Proposed Depth: MD: 12,378' TVD: 4,172' 12. Field/Pool(s): Milne Point Field ' Schrader Bluff Oil Pool - 4a. Location of Well (Governmental Section): Surface: 3519' FSL, 1863' FEL, Sec 25, T13N, R10E, UM, AK Top of Productive Horizon: 2591' FSL, 2233' FWL, Sec 36, T13N, R10E, UM, AK Total Depth: 1550' FNL, 1198' FWL, Sec 6, T12N, RV E, UM, AK 7. Property Designation:. ADL025518, ADL380110� 8. DNR Approval Number: LONS 94-017 13. Approximate Spud Date: 7/28/2019 ' 9. Acres in Property: 4997 14. Distance to Nearest Property: 8,720' to nearest unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 569284 y- 6016057 Zone -4 10. KB Elevation above MSL (ft): 48.2 GL / BF Elevation above MSL (ft): 21.7 15. Distance to Nearest Well Open to Same Pool: 880' to MPU E-24 16. Deviated wells: Kickoff depth: 7750 feet Maximum Hole Angle: 94.3 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 1894 Surface: 1438 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) 8-1/2" 4-1/2" 13.5# L-80 Hyd 625 4,628' 7,750' 4,231' 12,378' 4,172' Cementless Injection Liner w/ ICDs + Swell Packers 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/Structura I Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes No F,1 20. Attachments: Property Plat O BOP Sketch Q Drilling Program Q Time v. Depth Plot O Shallow Hazard Analysis Diverter Sketch Q Seabed Report Drilling Fluid Program Q 20 AAC 25.050 requirements Q✓ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein vAll not be Contact Name: Joe Engel Authorized Name: Monty Myers Contact Email: In el a hilcor .com Authorized Title: Drilling Manager Contact Phone: 777-8395 _ F,�R Molv7y rv1YE25 Authorized Signature: Date: 0-1-11-7-011f Commiss n Use Only Permit to Drill p Number: '4 14—O�9 A I tuber: �, I. 50 -oz �a36L�-� —0� rmit Approval Date: See cover letter for other requirements. Conditions of approval : AIf—boo�x is checked, well may not be used o explore for, test, or produce coalbed etha e, gas hydrates, or gas contained in shales: Other: Ur L wee` k'1 /�r�1`v•Is^acplm •&-] �7 y 0"�SI Samples req'd: Yes❑ No EV' Mudlogreq'd:Yes❑ No rl AA.K V � /LJ4-toZ Ops f HzS measures: Yes ❑ No 2' Directional svy req'd: Yes YNo❑ W [ j' 0 d> lkvl C. V d1_ O/DIDN,(ASpacing exception mq'd: Yes ❑ Nou?,� Inclination -only svy req'd: Yes ❑ NOR, Post initial injection MIT req'd: Yes ❑ No ❑ ,L HH Y�v 2a1�A�2� MANURP�r�ic�c, �r i APPROVED BY [� Approved by: COMMISSIONER THE COMMISSION Date:/ �u l 1 v l nn �/11 AA Submit Form and Form 10' 1 Revised 5/2017 This permit is valid for oRef r6rgti-N Lroval per 20 AAC 25.005(8) chments in Duplicate Area of Review MPE-39L1 C6 we 615 to fa CBL Top of CBL Top of Top of SB Top of SB Cement Cement Schrader OA PTD API WELL STATUS OA (MD) OA (TVD) (MD) (TVD) status Zonal Isolation 219-082 50-029-23635-00-00 MPE-42L1 Open 7,890' 4,297' Surface Surface Open Open to Injection Support 200-187 50-029-22867-60-00 MPE-24AL1 Open 9,377' 4,269' Surface Surface Open Open to Injection Support Surface Casing run to 198-039 50-029-22867-00-00 MPE-24 Plugback for Redrill 9,382' 4,272' Surface Surface Closed 10,077' MD / 4,500' TVD (P&A'd) and cemented back to surface. Surface Casing run to 202-204 50-029-23121-00-00 MPS -19 Plugback for Redrill 7,819- 4,343' Surface Surface Closed 8.114' MD / 4,453' TVD (P&A'd) and cemented back to surface. 202-233 50-029-23121-01-00 MPS -19A Shut In 7,820' 4,347' Surface Surface Open Open to Injection Support 202-234 50-029-23121-60-00 MPS-19AL1 Shut In 8,092' 4,340' Surface Surface Open Open to Injection Support C6 we 615 to fa 2 1 S-20 1 S-18 A. S-1 A HILCORP ALASKA LLC E-14 MILNE POINT FIELD EJ 11 j (Pm ) E -42V wp05 \ E-39LI wr 3 I / I E-24 �/ A / \ \'t"7dAL / / 19 J S-90 �. S-15 S- 2 S- 2L1 S-05 S-33 0 17L1 S -05L S-23 1 S -33A S-37 E-29 i S-01 B i S-07 S-01 L1 S-02 S-04 T, S-04L1"N S -10A S-03 S-10 S-03LI A S-09 Hilcorp Alaska, LLC Milne Point Unit (MPU) E -39L1 Drilling Program Version 1 7/11/2019 Table of Contents 1.0 Well Summary.................................................................................................................................2 2.0 Management of Change Information............................................................................................3 3.0 Tubular Program: ........................................................................................................................... 4 4.0 Drill Pipe Information: ................................................................................................................... 4 5.0 Internal Reporting Requirements..................................................................................................5 6.0 Planned Wellbore Schematic..........................................................................................................6 7.0 Drilling / Completion Summary.....................................................................................................7 8.0 Mandatory Regulatory Compliance / Notifications.....................................................................8 9.0 Run Whipstock & Mill Window..................................................................................................10 10.0 Drill 8.5" Hole Section...................................................................................................................13 11.0 Retrieve Whipstock.......................................................................................................................17 12.0 Run 4-1/2" Injection Liner...........................................................................................................18 13.0 Run 3-1/2" Injection Tubing.........................................................................................................23 14.0 RDMO Innovation Rig..................................................................................................................25 15.0 Innovation Rig Diverter Schematic.............................................................................................26 16.0 Innovation Rig BOP Schematic....................................................................................................27 17.0 Wellhead Schematic......................................................................................................................28 18.0 Days Vs Depth................................................................................................................................29 19.0 Formation Tops & Information...................................................................................................30 20.0 Anticipated Drilling Hazards.......................................................................................................32 21.0 Innovation Rig Layout..................................................................................................................33 22.0 FIT Procedure................................................................................................................................34 23.0 Innovation Rig Choke Manifold Schematic................................................................................35 24.0 Casing Design.................................................................................................................................36 25.0 8-1/2" Hole Section MASP............................................................................................................37 26.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................38 27.0 Surface Plat (As Built) (NAD 27).................................................................................................39 28.0 Schrader Bluff OA Sand Offset MW vs TVD Chart ..................................................................40 n Hit=Enap CmnW^Y 1.0 Well Summary Milne Point Unit E-391-1 SB Injector Drilling Procedure Well MPU E -39L1 Pad Milne Point "E" Pad Planned Completion Type 3-1/2" Injection Tubing Target Reservoirs Schrader Bluff OA Sand Planned Well TD, MD / TVD 12,377' MD / 4,171' TVD PBTD, MD / TVD 12,367' MD / 4,171' TVD Surface Location (Governmental) 3519' FSL, 1863' FEL, Sec 25, TUN, R10E, UM, AK Surface Location (NAD 27) X= 569,284.13, Y= 6,016,057.5 Top of Productive Horizon (Governmental) 2591' FSL, 2233' FWL, Sec 36, TON, R10E, UM, AK TPH Location AD 27 X= 568,159.78 Y= 6,009,839.5 BHL Governmental 1550' FNL, 1198' FWL, Sec 6, T12N, RI 1E, UM, AK BHL (NAD 27) X= 567,157.60, Y=6,005,688.3 AFE Number 1913307 AFE Drilling Days 15 days AFE Completion Das 4 days AFE Drilling Amount $3,038,355 AFE Completion Amount $1,705,119 AFE Facility Amount $0 Maximum Anticipated Pressure (Surface) 1438 psig Maximum Anticipated Pressure Downhole/Reservoir) 1894 psig Work String 5" 19.5# S-135 DS -50 & NC 50 KB Elevation above MSL: 26.5 ft+ 21.7 ft = 48.2 ft GL Elevation above MSL: 21.7 ft BOP Equipment 13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams Page 2 Milne Point Unit E-391-1 SB Injector Hilcorp Drilling Procedure U� 2.0 Management of Change Information 0 Hilcorp Alaska, LLC Hjlcorp Hm c� r Changes to Approved Permit to Drill Date: 7/10/2019 Subject: Changes to Approved Permit to Drill for MPU E-391-1 File #: MPU E-391-1 Drilling and Completion Program Any modifications to MPU E -39L1 Drilling & Completion Program will be documented and approved below. Changes to an approved APD will be approved in advance to the AOGCC. Approval: Drilling Manager Prepared: Drilling Engineer Date Page 3 Milne Point Unit E -39L1 SB Injector Hilcorp Drilling Procedure Enugy C®pmY 3.0 Tubular Program: Cond 20" 19.25" X-52 Weld ` si e (,Psi)k-lb Tensio A 12-1/4" 9-5/8" 8.835" 8.679" 10.625" 40 L-80 TXP 5,750 3,090 916 8-1/2" 4-1/2" 3.920 3.795 4.714 13.5 L-80 Hydril625 9020 8540 279 Tubing 3-1/2" 2.992" 2.897" 4.5" 9.3 L-80 TXP-Se 1 9,289 1 7,399 163 4.0 Drill Pipe Information: Hole Section OD in I ID (in) TJ ED in TJ OD in Wt (#/ft)T—cnn Grade CoM/U M/U (Max)(k-lbs) Tension Production 5" 4.276" 3.25" 6.625" 19.5 S-135 I GPDS50 36,1 43,100 561 5" 5" 4.276" 3.25" 6.625" 19.5 5-135 NC50 31,03200 34,136 560k1b All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 4 H Hite orp E,E27 5.0 Internal Reporting Requirements Milne Point Unit E -39L1 SB Injector Drilling Procedure 5.1 Fill out daily drilling report and cost report on WellEz. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area — this will not save the data entered, and will navigate to another data entry. • 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. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolininn hilcoip.com, mmyers@hilcoip, iengel@hilcoa2.com and edinger@hilcoip.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 5.4 EHS Incident Reporting • Health and Safety: Notify EHS field coordinator. • Environmental: Drilling Environmental Coordinator • Notify Drilling Manager & Drilling Engineer on all incidents • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final "As -Run" Casing tally to mmyers@hilcorp,com,ieng_elna hilcoM.com and cdinger@hilcorp.com 5.6 Casing and Cement report • Send casing and cement report for each string of casing to mmyers&hilcorp.com iengel@hilcorp.com and cding_er@hilcorp.com 5.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmvers@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 ieneel@hilcorp.com Completion Engineer Taylor Wellman 907.777.8449 907.907.9533 twellman@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 Drilling Env. Coordinator Keegan Fleming 907.777.8477 907.350.9439 kflemine@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 caiones@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinaer@hilcorp.com Page 5 H Hilcox Fmp C® 6.0 Planned Wellbore Schematic rf I wa-m DN'-09.YI r]16 GLEIN: 21Y II:Z9]Z031:101 m=1.,261' Irw)1 m=4,1Bgt N0 PUTT) = I0,17C JW) / 1`010=A 18dtTW) Page 6 Milne Point Unit E-391-1 SB Injector Drilling Procedure Milne Point Unit Well: MPU E-39 & Ll Last Completed: xx/xx/xxxx PTD: xxx-xxx OPEN HOLE / CEMENT DETAIL WELLHEAD 20' [mt wf 26Dn4 ofArmlz.tlm4T Nm I Welland 1MCGans y,s1g. Stg1L-2219.5ft3/T-aGSh3 HI' fondul.Wr SIB 2L-19371t3/T-314X3 WELL INCLINATION DETAIL GENERALWELLINFO NOP lllpa00' MD APL 5D 029•aanX�BD40 Mae Wallbo+e Angl.•969d.g 0853YM0 DrlB.dartl F—PI01. ,1ral.vall.Rig 8,835 -lune XI39 Size Type CASING DETWL Wt/ Grade/ Conn I ID TOO Btm HI' fondul.Wr 2151X1-42/WNdM N/A Sada. IDT 9 SIE- Sudau M)i,iaJw 8,835 Strhce 11,9517 4312' w k'JxT;a ❑n u^ryvat W n 135/ 501 HTd 625 3.920 37.2517 I2,3M 411Y 0mr •(M'k3actbn 0rierw N:Ds 135/1-90 /X3d fi25 3.930 tz.aaw Ib,181' TUBING DETAIL 8 TBG Seal ass.remlP 3 1/Y T.ba%nlabadc I 93/LED/nJE 1 2.441 sudaCC fB,Elb JEWELRY DETAIL Na I Owl, Item 1 I kLZOr uppar Lanpketlm .. 1 3 VZ' X M.PW 1102913') 2 TBD [vanbde Ga e 3 TBG 41X.9518' Rebl.vabi. Parker A TBD 3 1/2'Y mpple 110=2923') 5tll:Valve-LlrcValve/M[e GIM Mail: 33/2' n 15' Camc. w) BK 1AtM ,.-..-.'.....-..e..,.... .1.1. Iw.I G i00 Sta tll:Valeo- circ wt..%mt. .1.1.]WWI 3 TW 3.11r JNM I. IAfb WaZ.151 B 18D NMtld R4binNlfa.La OB la a al 8 TBG Seal ass.remlP 9 10 TBG Teo OM 1.1D Ndtar Tap N.r ' DBIa'[m195111 91 J2'BrkerUPLI.NNa ar Tmdcka 11'ater Wcll Parser NI 6 Tmdcka 550 wl Sottn & ICG 916 33 190 D8lateml4112`MIIaN. Pack•.O 12 TOD DOLEN i312'WN 13 TOO OB Laf... 14312.Otat d G.W. Skov CA '(C.P.a.ls ba#aad 3.112• ro PMLI..) N TOO CA l9-S,/9'a41r Baker MraW dldaka Wath 5a.O P .r tl1.1T TTOM 21113.1 Saaen& ICO 9131 IS TOO GA lalwal 4.1%2' DrMWft&..H W TOO GA iotrol/]/2'WIY 11 TOO OAlat%2l 43 i2' 9tzn ofGdde Sb.. LATERAL W)NDOW DEtAIL Tcp.YOB-SNntlew LO B, 9517 M0; Oal 08,954 M0; lD cd wlnd.891 d. Tap of'VA` Wlndda' @ T,TA MD e2MM QI T,T50 Mb, AnOln B lap.f WMowis 67 dM 9.vnM 9v: TTW 11912013 ff Hilcorp e...gy.2 7.0 Drilling / Completion Summary Milne Point Unit E-391.1 SB Injector Drilling Procedure MPU E-39 is a grassroots dual lateral injector planned to be drilled in the Schrader Bluff OB/OA sand. E-39 is part of an eight well program targeting the Schrader Bluff sand on E -Pad. This program is for operations for the second lateral, E -39L1 On top of the E-39 liner, a whipstock will be ran and a window milled for the second lateral. An 8.5" hole section will be drilled, and then the whipstock retrieved. A 4.5" injection liner will be ran and landed with a Hook hanger. A 3.5" injection tubing string will be ran, stinging in to the SLZXP of the main bore liner. The Innovation Rig will be used to drill and complete the wellbore. Operations are expected to commence approximately July 28, pending rig schedule. All cuttings & mud generated during drilling operations will be hauled to the Milne Point `B" pad G&I facility. General sequence of operations: 1. Run Whipstock, Mill Window. 2. Drill 8-/2" Lateral to TD. 3. Pull Whipstock. 4. Run 4-1/2" liner with Hook hanger 5. Run 3-1/2" injection tubing Note: Operations prior to E -39L1 were covered on the E-39 PTD. Reservoir Evaluation Plan: 1. Production Hole: No mud logging. On site geologist. LVD: GR + ADR (For geo-steering) Page 7 H Hilcorp Milne Point Unit E-3911 SB Injector Drilling Procedure 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the all applicable AOGCC regulations, specific regulations are listed below. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2) week intervals during the drilling and completion of MPU E -39L1. Ensure to provide AOGCC 24 firs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3000 psi & subsequent tests of the BOP equipment will be to 250/3000 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation or control fluid flow from the well bore, AOGCC is to be notified and we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements". o Ensure the diverter vent line is at least 75' away from potential ignition sources • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: Hilcorp Alaska respectfully requests a variance to 20AAC25.412(b). Uppermost 9-5/8" packer will be set greater d� than 2008 measured depth from open perfs. Proposed distance = 300ft. This is due to where we are going to have our KOP for the OA sand followed by waterflood regulating mandrels and then where that top packer will end up in the completion. Page 8 H Hilcorp Summary of BOP Equipment and Test Requirements Milne Point Unit E -39L1 SB Injector Drilling Procedure Hole Section Equipment Test Pressure(psi) 12 1/4" 13-5/8" 5M CTI Annular BOP w/ 16" diverter line Function Test Only • 13-5/8" x 5M Control Technology Inc Annular BOP • 13-5/8" x 5M Control Technology Inc Double Gate Initial Test: 250/3000 o Blind ram in btm cavity • Mud cross w/ 3" x 5M side outlets 8-1/2" 13-5/8" x 5M Control Technology Single ram • 3-1/8" x 5M Choke Line Subsequent Tests: • 3-1/8" x 5M Kill line 250/3000 • 3-1/8" x 5M Choke manifold • Standpipe, floor valves, etc Primary closing unit: Control Technology Inc. (CTI), 6 station, 3000 psi, 220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an electric triplex pump on a different electrical circuit and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: • Well control event (BOPs utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: 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-xxx-xxxx / Email: melvin.rixse@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors e alaska.goy Test/Inspection notification standardization format: hUp://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 Milne Point Unit E-390 SB Injector Hilco Drilling Procedure .-' cc 9.0 Run Whipstock & Mill Window 11.1 Milling Notes: • Ensure separate 4-3/4" MWD is on location for orientation of whipstock • Ensure whipstock will be placed in between casing collars 1. Plan to set whipstock at top of the sand 2. Use same 5" drill pipe / drill string that previous liner was run on • Ditch magnets to be ran to recover as much metal debris as possible 11.2 Milling Fluid: • 9.0-9.5 ppg Baradrill-N • YP: 40-60 for metal cuttings removal • 6rpm: 8-10 • Ensure fluid properties are sufficient on TOOH after prior liner run 11.3 Review Alignment of liner hanger profile and liner top depth from previous liner run to verify whipstock space out and orientation. Ensure all parties are in agreement. • Target orientation is 30-15 LOHS • Confirm with Baker Rep, and ensure all parties are in agreement 11.4 PU & RIH with whipstock assembly. Ensure all connections are torqued to spec 11.5 PU and MU milling assembly as per Baker BHA tally. • Gauge mills prior to running in hole 11.6 PU whipstock anchor assembly • Adjust orientation between anchor and whipstock as needed • Ensure orientation is documented and agreed upon 11.7 PU remaining workstring and MWD • Document MWD offset with whipstock face • Ensure UBHO for wireline • HWDP, 2-3 string magnets, float sub 11.8 Slowly RIH as per Baker Rep t/ — 45' above setting depth, 7731' MD • Use extreme caution running through BOP and wear bushing to prevent damage to whipstock shear bolt • Running Speed: 1.5-2 min per stand. Ensure work string is stationary prior to setting slips, and removed slowly as well. These precautions are to avoid weakening shear bolt and prematurely setting anchor • Shallow Test MWD 11.9 —45' above whipstock setting depth, establish circulation and work torque out of string, record PU/SOW/ROT/Torque. Obtain MWD Survey • Consider having gyro personnel on standby in event MWD is not working Page 10 n Hilcorp . ar-P Milne Point Unit E -39L1 SB Injector Drilling Procedure 11.10 Orient Whipstock to desired direction by turning DP in'/4 round increments. KU and S/O on DP to work all torque out after oriented. (Being careful not to set trip anchor). Target orientation is 300-150 LOHS. Whipstock Orientation Diagram: 30L Desired orientation of the Whipstock face is 15L to 30L Hole Angle at window interval (7,767 MD) is -67 deg. 11.11 Once Whipstock is in desired orientation, slack off, land anchor, and set. PU 5-7klb max and confirm anchor is latched in liner. Overpull of 35k1b will shear window mill, 40k1b will shear anchor bolts 11.12 Obtain survey of whipstock orientation 11.13 Slack off and shear window mill bolt. Do not apply more than 35klb. • If bolt does not release, work string up to 20k and down to 35k. Excessive down weigh mayjam window mill into casing. 11.14 PU 5/10' above top of whipstock 11.15 CBU and confirm MW in/out • Ensure mud properties are sufficient for transporting metal cuttings • YP: 40-60 for metal cuttings removal • 6rpm: 8-10 • YP: 18-20 11.16 Record PU, SO, ROT weights. Slack off to top of whipstock with lightweight and low torque. 11.17 Mill window as per Baker rep • Maintain AVs 150-200 ft/min for hole cleaning • Do not rush window milling • Clean trays and ditchmagnets frequently while milling windown • Estimated metal cuttings range: 1. 9-5/8" 45.5# L80: 115-235# 11.18 Mill window until uppermost mill has passed across the entire tray. • Dress and polish window as needed • With upper mill at end of tray, 20' of new hole will be drilled 11.19 After window is milled CBU until even MW and hole is clean of metal cuttings Page 11 H Hilcorp E^aq Gm WY Milne Point Unit E-391-1 SB Injector Drilling Procedure 11.20 Shut down pumps and work milling assembly through window watching for drag. 11.21 CBU and reduce properties for drilling 11.22 Pull into 9-5/8" casing and perform FIT t/ 12.0 ppg EMW. Chart Test. 11.23 POOH with milling BHA & LD. • Gauge mills when out of hole. • IF upper mill is under gauge, puck up second mill BHA with same assembly (to ensure same cut pattern) and perform dress off run to ensure window is correct diameter. 11.24 PU stack washer and wash BOPE stack. Cycle all rams to clear any potential milling debris. Page 12 Milne Point Unit E-391.1 SB Injector Hilco Drilling Procedure 10.0 Drill 8.5" Hole Section 10.1 Pick up 8.5" Motor BHA • Motor BHA will be used to ensure kick off and drill enough full gauge OH for the RSS BHA • Motor & MWD 10.2 RIH with Motor BHA t/ 3 stands above whipstock. 10.3 CBU to ensure even MW in/out and mud properties are back to desired for drilling • Double check tally's to make sure bit is well above whipstock to prevent rotatin¢ bit taming whipstock 10.4 Orient motor and continue lowering assembly through window with no flow or rotation • Ensure BHA and DP tally are verified • Circulating can cause the rotating bit to catch the whipstock and result in rotating it or becoming mechanically stuck 10.5 Once through the window and tagged up on bottom, drill ahead to confirm kick off and ensure clearance for RSS BHA. 10.6 Orient motor and pull through the window with no flow or rotary 10.7 POOH and LD Motor BHA 10.8 P/U 8-1/2" RSS BHA. • 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. • Ensure MWD is R/U and operational. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Floats will be solid for MPD 10.9 8-1/2" hole section mud program summary: Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. • Rbeology: Keep viscosifier additions to an absolute minimum (N -VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high Page 13 n Hilcorp � X22 Milne Point Unit E -39L1 SB Injector Drilling Procedure vis sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8.5 (hole diameter) sufficient hole cleaning • Run the centrifuge continuously while drilling the production hole, this will help with solids removal. • Dump and dilute as necessary to keep drilled solids to an absolute minimum. MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, & Toolpusher office. System Type: 8.9 —9.5 ppg Baradrill-N drilling fluid Properties: Section Density Plastic Viscosity Yield Point Total Solids MBT HPHT Production 8.9-9.5 15-25 20-25 <10% <7 <11.0 tBq 4 - System Formulation: Baradrill-N Product Concentration Water 0.955 bbl KCL 11 ppb KOH 0.1 ppb N -VIS 1.0 — 1.5 ppb DEXTRID LT 5 ppb BARACARB 5 4 ppb BARACARB 25 4 ppb BARACARB 50 2 ppb BARACOR 700 1.0 ppb BARASCAV D 0.5 ppb X -GIDE 207 0.015 ppb 10.10 TIH w/ 8-1/2" directional assembly to 2-3 stands above window. Shallow test MWD and LWD on trip in. 10.11 CBU to confirm even MW and properties 10.12 Trip through window with no flow or rotation, to bottom Page 14 n Hilcorp Emgy ComyeY Milne Point Unit E-39LI SB Injector Drilling Procedure 10.13 Begin drilling 8.5" hole section, on -bottom staging technique: • Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8k. • Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations • If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to P/U off bottom and restart on bottom staging technique. If stick slip continues, consider adding .5% lubes 10.14 Drill 8-1/2" hole section to section TD per Geologist and Drilling Engineer. • Flow Rate: 350-550 gpm, target min. AV's 200 ft/min, 385 gpm • RPM: 120+ • Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly wet to maximize solids removal efficiency. Check for holes in screens on every connection. • Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low • Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection • Monitor Torque and Drag with pumps on every 5 stands • Monitor ECD, pump pressure & hookload trends for hole cleaning indication • Surveys can be taken more frequently if deemed necessary. • Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. • Limit maximum instantaneous ROP to < 250 fph. The sands will drill faster than this, but when concretions are hit when drilling this fast, cutter damage can occur. • Target ROP is as fast as we can clean the hole without having to backream connections • Schrader Bluff NB Concretions: Historically 4-6% of lateral • MPD will be used to monitor for abnormal pressure on connections 10.15 Reference: Open hole sidetracking practice: • If a known fault is coming up, put a slight "kick-off ramp" in wellbore ahead of the fault so we have a nice place to low side. • Attempt to lowside in a fast drilling interval where the wellbore is headed up. • Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string back and forth. Trough for approx. 30 min. • Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. 10.16 At TD, CBU at least 4 times at 200 ft/min AV (385+ gpm) and rotation (120+ rpm). Pump tandem sweeps if needed • Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent stream, circulate more if necessary • Ensure mud has necessary lube % for running liner • If seepage losses are seen while drilling, consider reducing MW at TD to 9.Oppg minimum Page 15 n Hilcorp ��2�T Milne Point Unit E-391-1 SB Injector Drilling Procedure 10.17 BROOH with the drilling assembly to 2 stands before the window • Circulate at full drill rate (385 gpm max). • Rotate at maximum rpm that can be sustained. • Limit pulling speed to 5 — 10 min/std (slip to slip time, not including connections). • If backreaming operations are commenced, continue backreaming to the shoe 10.18 If abnormal pressure has been observed in the lateral, utilize MPD to close on connections while BROOH 10.19 CBU minimum two times at 9-5/8" window and clean casing with high vis sweeps. 10.20 Monitor well for flow. Increase mud weight if necessary. If abnormal pressure has been seen, displace to higher MW (determined on closed connections) from surface shoe to surface. • Wellbore breathing has been seen on past MPU SB wells. Perform extended flow checks to determine if well is breathing, treat all flow as an influx until proven otherwise 10.21 Pull through window with no flow or rotation 10.22 Continue to POOH and stand back BHA if possible. Rabbit DP on TOH, ensure rabbit diameter is sufficient for future ball drops. Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any additional logging runs conducted. Page 16 H Hilcorp E ,�22 11.0 Retrieve Whipstock Milne Point Unit E -39L1 SB Injector Drilling Procedure 11.1 PU Baker Fixed lug retrieving tool assembly, as per Baker • Ensure to note orientation of fixed lug 11.2 RIH t/ — 40' above whipstock. Record PU & SO weights 11.3 Orient fixed lug tool, slowly slack off and position tool over whipstock 11.4 With pumps on, clean top section of whipstock. Stop pumping and PU slowly to catch the whipstock retrieving slot. If unable o catch whipstock, rotate tool, lower and try again. 11.5 Ensure to discuss operation of the unloader and expected seal bore length to identify drag while retrieving whipstock 11.6 Attempt straight pull of 40k1b to release anchor. If anchor does not release, continue pull up to 120k max to release shear disconnect sub. • Ensure that retrieving tool is not engaged to casing window • If anchor or disconnect sub cannot be released, contact drilling engineer 11.7 Once whipstock is free, POOH slowly with smooth pipe movement in/out of slips to ensure whipstock does not fall off of lug tool • Confirm whipstock is engaged by comparing PUW before and after • Ensure Baker rep is on rig while POOH to monitor operations so whipstock isn't dropped 11.8 Before LD whipstock, inspect whipstock face for mill track. Page 17 H Hilcorp E� c2x 12.0 Run 4-1/2" Injection Liner Milne Point Unit E-39LI SB Injector Drilling Procedure 12.1 Well control preparedness: In the event of an influx of formation fluids while running the 4- 1/2" liner with ICD and swell packers, the following well control response procedure will be followed: With ICD across the BOP: P/U & M/U the 5" safety joint (with 4-1/2" crossover installed on bottom, TIW valve in open position on top, 4-1/2" handling joint above TIW). This joint shall be fully M/U and available prior to running the first joint of 4-1/2" liner. With 4-1/2" solid joint across BOP: Slack off and position the 4-1/2" solid joint to MU the TIW valve. Shut in ram or annular on 4-1/2" solid joint. Close TIW valve. 12.2 Confine VBR have been tested on 3-1/2" and 5" test joints to 250 psi low/3000 psi high. 12.3 In the event of an influx of formation fluids while running the 2-3/8" inner string inside the 4- 1/2" liner: • P/U & M/U the 5" safety joint (with 4-1/2" x 2-3/8" triple connect crossover installed on bottom, TIW valve in open position on top, 2-3/8" handling joint a ove /U 2-3/8" and then 4-1/2" to triple connect. • This joint shall be fully M/U with crossovers and available prior to running the first joint • Slack off and position the 5" DP across the BOP, shut in ram or annular on 5" DP. Close TIW valve. Proceed with well kill operations. 12.4 R/U 4-1/2" liner running equipment. • Ensure 4-1/2" Hydri1625 x DS -50 crossover is on rig floor and M/U to FOSV. • Ensure the liner has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 12.5 Run 4-1/2" injection liner. • Use API Modified or "Best O Life 2000 AG" thread compound. Dope pin end only w/ paint brush. Wipe off excess. Thread compound can plug the ICDs. • Ensure a bent shoe joint is ran. 10" from straight at end minimum • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Use lift nubbins and stabbing guides for the liner run. • Fill 4-%2" liner with PST passed mud (to keep from plugging ICDs with solids) • Install ICDs and swell packers as per the Running Order • Do not place tongs or slips on swell packer elements or ICDs. • ICD and swell packer placement ±40' • The ICD connection is 4-1/2" 13.5# Hydril 625 • Remove protective packaging on swell packers just prior to picking up • If liner length exceeds surface casing length, ensure centralizers are placed 1/jt for each joint outside of the surface shoe. This is to mitigate difference sticking risk while running inner Page 18 H Hilcorp En Campo, Milne Point Unit E-39LI SB Injector Drilling Procedure • Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10 and 20 rpm 4-1/2" 13.59 L-80 Hydril 625 Casing OD Minimum Optimum MaximumYield Operating Tor ue Torque 4.5" 8,000 ft -lbs 9,600 ft -lbs 12,800 ft -lbs 15,000 ft -lbs Page 19 n Hilcorp Fv Cm For the latest performance data. always visit our website: www.tenarls.corn Wedge 625® Milne Point Unit E-391.1 SB Injector Drilling Procedure n.....12rW201T omwe Diameter 4.500P. Mm. Wall 87.5% 27937011000 Inemal Preswre Capaoty 8020.000.si Thiekness Pl Gvde LBO low w fressim E%,eYOy Type 1 Can im Strewth Well TUiekness 0250 m. Conrredndn OD REGULAR Gp5on COUPLING PIPE BODY 5500-050 ps Body. Red IV Sand: Red Grade LBS Tree 1' I DNB API Standard lv Eana: Rrwn 2nd Rand Mini. 80005-Ihs -no Ban-.- Blom ld u. Type Casino 3: sand: - MHand: - ft Ban? - PIPE BODY DATA GEOMETRY Nmuns 00 A.500se. Nwnna Wergt 13.51)1.1 Rid 3-M.. Nominal ID 3,920 "v1. Wal Thinness Oleo., Ran End Weigh lluls B CD TNeance AN PERFORMANCE Body Ywid strenge 307 AGO)lbs Ink Yield 9020 ps WYE 50000 ps l ] Calyse 5500 Ps l■■■ (1pp1E�TI('N TATO C.n. OC 4714n Cancan ID 3,049 m. Make-up Loss 4,838.0. Tis Pe in 9.59 Cainee8m OD Optan REGUTAR 9gaSB1a:'J1:CBlq Tensim Uciency Me% Jane YNNd Slrengm 27937011000 Inemal Preswre Capaoty 8020.000.si Me w fressim E%,eYOy 585 T. Can im Strewth 250.115.1030 MUAbxable RenanO T1.7 Y1004 lbs Ez9ernal Pnswre Cap" 5500-050 ps MAKE-UP TORQUES Mini. 80005-Ihs Ophinen MIN 114 s ld u. 128W 5abs OPERATION LIMIT TORQUES Ctemev Tmrye 12000 Mbs Yedd Tmpre 15000ftbs Notes For fuller information on concepts indicated in this datasheet dovmload the Datasheet Manual from wwWterrains-corn 12.5 R/U false rotary and run 2-3/8" 4.7 #/ft inner string. 12.6 Before picking up Baker Hook Hanger & HRD Running tool, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. Page 20 H Hilcorp Eungy CamW^Y Milne Point Unit E -39L1 SB Injector Drilling Procedure 12.7 M/U Baker Hook hanger and HRD Running tool, with super slime MWD, to inner string and 4- 1/2" liner. 12.8 Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 12.9 RIH w/ liner on DP no faster than 30 ft/min — this is to prevent buckling the liner and drill string. Watch displacement carefully and avoid surging the hole or buckling the liner. Slow down running speed if necessary. 12.10 The liner and inner string will prevent the DP from auto filling. Fill DP every 5 stands, more frequently if SOW trend indicates. 12.11 Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + S/O depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 12.12 Watch depth of SLZXP and liner shoe to ensure that the liner exits the window. If unable to exit window, orient bent joint and try again. 12.13 If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 12.14 Rig up to pump down the work string with the rig pumps. 12.15 Double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. 12.16 Rig up to pump down the work string with the rig pumps. 12.17 Break circulation and begin displacing wellbore to —9.2 ppg KCINaCl (adjust brine weight if needed). Note the large OD on the ICDs. Begin circulating at —1 BPM and monitor pump pressures. Slowly bring rate up while circulating the lateral clean. 12.18 Monitor pump pressures closely and adjust pump rate if the well appears to be packing off at the ICDs. Note all losses. Catch mud for future use if feasible. 12.19 Monitor the returned fluids carefully and when no more filter cake appears at the shaker begin pumping SAPP pill. 12.20 Mix and pump 3 tandem 40 bbl 10 ppb SAPP pills (120 bbl total SAPP pill) with 50 bbl in between. Keep circulation rate low to keep from packing off around the ICDs. Monitor shakers for returns of mud filter cake and calcium carbonate. Circulate the well clean. 12.21 Repeat pumping SAPP pills as needed until the wellbore is clean. Page 21 n Hilcorp Milne Point Unit E-391.1 SB Injector Drilling Procedure Losses during the cleanup of the wellbore are a good indication that the mud filter cake is being removed, including an increase in the loss rate. Monitor the returned fluids to ensure as much mud and wall cake has been removed from the wellbore as possible so as to not impact wellbore injectivity. 12.22 Displace 1.5 OH & Liner volumes. 12.23 Shut down pumps. Orient hook hanger and land on casing window. Drop release ball down the workstring and pump slowly (1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. Pressure up to 1,500 psi to shift the wellbore isolation valve closed. 12.24 Continue pressuring up to 2700 psi to seat the ball in the HRD tool. Hold for 5 minutes. Slack off 20K lbs to ensure the HRDE setting tool is in compression for release Hook hanger. Continue pressuring up 4100 psi to neutralize and release running tools. 12.25 Bleed DP pressure to zero 12.26 Pickup to verify that the HRD setting tool has released. Compare to PUW before releasing HRD. 12.27 Displace 2-3/8" x Liner, pump 2 circulations. 12.28 POOH, L/D and inspect running tools. If setting of liner hanger/packer proceeded as planned, LDDP on the TOH. L/D 2-3/8" inner string. Rack back enough 5" drill pipe for liner top clean out run 12.29 Make up 3.5" wash tool & RIH on 5" DP to 4.5" liner top. 12.30 Flush liner top at max rate while displacing out well to clean brine. 12.31 POOH LD Remaining 5" DP. Page 22 H Hilcorp UC 13.0 Run 3-1/2" Injection Tubing Milne Point Unit E-391_1 SB Injector Drilling Procedure 13.1 Notify the AOGCC at least 24 hours in advance of the IA pressure test after running the completion as per 20 AAC 25.412 (e). Record pressure test on 10-426 form and email to wrivardghilcorp.com for submission to AOGCC. 13.2 M/U injection assembly and RIH to setting depth. TIH no faster than 90 ft/min. • Ensure wear bushing is pulled. • Ensure 3-'/2" EUE 8RND x NC -50 crossover is on rig floor and M/U to FOSV. • Ensure all tubing has been drifted in the pipe shed prior to running. • Be sure to count the total # of joints in the pipe shed 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. • Monitor displacement from wellbore while RIH. 3-'/z" Upper Completion Running Order • 2.975" Baker Ported Bullet Nose seal (stung into the tie back receptacle, crossed over to 3- 1/2 9.34 EUE 8RND) • 3 joints (minimum, more as needed) 3-%2" 9.3# EUE 8RND tubing • 3-%2" "XN" nipple (less than 70° hole angle) • 3-1/2" x 1.5" GLM x2 (pre -loaded with 0.354" orifice waterflood regulating valves) • X joints 3-%2" 9.3# EUE 8RND tubing • 3-'/z" "X" nipple (pre -loaded with RHC plug body) • 3-1/2", 9.3# EUE x 4-1/2" , 12.6, Vam Top xo pup • 4-1/2" x 9-5/8" Retrievable Packer • 4-1/2", 12.6, Vam Top x 3-1/2", 9.3# EUE xo pup • 3-1/2" Baker gauge mandrel o Cross collar clamps: Every joint for first 10 joints, every other joint beyond this to surface • 3-'/z" 9.3# EUE 8RND tubing • 3-'/2" "X" nipple at 2,500' MD • 3-'/2" 9.3# EUE 8RND space out pups Page 23 H Hilcorp .-,.y Cnm • 1 joint 3-'/z" 9.3# EUE 8RND tubing • Tubing hanger with 3-1/2" EUE 8RND pin down Milne Point Unit E -39L1 SB Injector Drilling Procedure i QUAL9 ubing Spccifici-ifl;iia ;31, � TOOL 3-1/2, 9.30#, L80, EUE 8RD, R2 iPipe 0.203 u ... OD: 3.500 in Connection: ID: 2.992 In Coupling OD: Waght: 9.30 Iba/ft Tool Joint ID: Grade: L60 0.00670 Drift: Tube Wall: 0.254 in Tubing Length- R2 Thread Compound Friction Factor. Maximum MUT: RBW: 0.203 M Optimal MUT: Tube Tensile: 163,178 be Minimum MUT: Tube Collapse: 7,399 ..._......_..._,.......:- psi Tube Internal Burst: 9.289 psi Tubing Assembly Displacement Estimate: 0,00339 bbislft Ondud" TO V W w6 Capacity Estimate: 0.00670 bbsJft Pncw"rod,! 3-1/20 EUE 8RD 4.500 in 2.992 in - 2.807 in 1.0 4,000 R -lbs 31200 ft -las 2,400 ft -lbs 13.3 Locate and no-go out the seal assembly. Close annular and test to 400 psi to confirm seals engaged. 13.4 Bleed pressure and open annular. Space out the completion (+/- 1' to 2' above No -Go). Place all space out pups below the first full joint of the completion. 13.5 Makeup the tubing hanger and landing joint. 13.6 RIH. Close annular and test to 400 — 500 psi to confirm seals are engaged. Bleed pressure down to 250 psi. PU until ports in seal assembly exposed. Page 24 13.7 Reverse circulate the well with brine and 1% corrosion inhibitor. 13.8 Freeze protect the tubing and IA to 3000' MD 13.9 Land hanger. RILDs and test hanger. Milne Point Unit E -39L1 SB Injector Drilling Procedure 13.10 Continue pressurizing the annulus to 2,000 psi and test for 30 charted minutes. i. Note witness notification for this this test must be sent in to the AOGCC representative. 13.11 Set BPV, ensure new body seals are installed each time. ND BOPE and NU adapter flange and tree. 13.12 Pull BPV. Set TWC. Test tree to 5000 psi. 13.13 Pull TWC. Set BPV. Bullhead tubing freeze protect. 13.14 Secure the tree and cellar. 14.0 RDMO Innovation Rig Page 25 H Hilcox Uma, 15.0 Innovation Rig Diverter Schematic 3118' Kill 13518 Techno]M Page 26 Milne Point Unit E -39L1 SB Injector Drilling Procedure Wtrol TechnokM 3518.6M Conbol echnoloV Double Ram •116' Choke Line X16' Dlverler Lim n Hil=M� 16.0 Innovation Rig BOP Schematic 3-118' Kill 9-518" DBL D Seal Casing Hanger S-22 13-5/8" NOM 9-518" BTC Btm x 10.5"-4 SA Pin Top Wl Primary Seal Pa.ae 27 L' Milne Point Unit E -39L1 SB Injector Drilling Procedure 13-518' 5M Control Technology Annular BOP ~-13-518" 5M Control Technology Double Ram 3-1/8' Choke Line X113-5/8" 5M Control Technology Single Ram 13-5/8" x 5M —11"x 5M 2-1116" x 5M 13-518' x 5M \-2-1/16"x 5M 20" Casing -518" Casing H Hilcorp 17.0 Wellhead Schematic Milne Point Unit E -39L1 SB Injector Drilling Procedure V.vc DimnuonY u�fo+m�oen ra�lend cn fh�:.4axiL an cpa�ebl zeua.�eu-.ett_ cnF. Page 28 H Hilcrp ME22 18.0 Days Vs Depth 0 RICQC SC aIC n Iso t :rrr v m 10000 f►DL:r] 14000 .arr Page 29 Milne Point Unit E•3911 SB Injector Drilling Procedure MPU E-39 SB Dual Lat OA/OB Injector OA Lat & Comp Days vs Depth — MPU E-39 SB Dual Lai OA/OB Injector 0 5 10 15 20 Days 19.0 Formation Tops & Information MPU E -39L1 Formations (wp03) MD (ft) Milne Point Unit ND (ft) Formation Pressure (psi) EMW (ppg) E -39L1 SB Injector 1962 Hilcorp 1777 Drilling Procedure 8.46 U 6588 19.0 Formation Tops & Information MPU E -39L1 Formations (wp03) MD (ft) TVDss (ft) ND (ft) Formation Pressure (psi) EMW (ppg) Base Permafrost 1962 1729 1777 781.88 8.46 LA3 6588 3677 3725 1639 8.46 Schrader Bluff NA 7770 4153 4201 1848.44 8.46 Schrader Bluff OA 8040 4258 4306 1894.64 8.46 Page 30 H Hilc02 am+wc�e•"r Milne Point Unit E-391-1 SB Injector Drilling Procedure GENERALIZED GEOLOGICAL FORECAST SS GEOLOGICAL TVD FM LITH DESCRIPTION ai • �ie N Gub Unconsolidated coarse to medium sand and small gravel with «.tor. 600 •'+'• siastone. Heavy gravel conglomerate to 1400'. Wood fragments 1,000` 105minor :p throughout permafrost zone. Abundant pyrite at 1500 ft. Base -411111111 RUNNING GRAVELS 1700. permafrost 2,000' Ste prepared for HYDRATE gas out HYDRATESII C md 2000 to 2500' as (E -lard E-0) Sage nlrktok L AE -10,-17,-228-231). (E-14,.30, -"46' (pl43HYDRATES. -33 8 -410- E-32 GAS CUT MUD A Predominantly clay to .t- 3000' with Interbeds of sand, okays and siltltones with occasional shows of coal. Y 3,000 Continued interbeds of sand, clays and slllslones with occasional shows at coal. Clay, siltstone and sand kmedteds between 3000 and 6000'. Lignite 3400-3500 f - SY irtw%ds mae rally ("muddier")than C are those in the Prudhoe Bay a. sos• UGUH15 SWABBINGlSTICKY L i. t A U{1nU: Thick package -200 to 300 tt in same arem, mostly water-Tllkd at E -pact, although 8 y some zones are tilled wan hydrocarbon. The Ugnu sectlon (inu rbedded fluvial sandstone A M and shaej represents Ilse initial progratleuon d the Ugnu deltaic system over the underlying CLAYIGUMBO: E-204. -28. C 3 z G shallow marine Schrader Bluff section. Fluvlal nature can retake 8 difficult to determine lop D 111 and base of individual unfits. Bottom bounding surface d the slave Ugnu package is pecked -328,12- A j c at the reponal uncontormay MiGs Lase the all bebw)- GAS CUT MUD E-26 AT 3996 3 MSands: Fluvial. deltaic channel sandstones prograded over the underlying shallow TVD; E -13B Q 3618 tvd_ 4,000 .5 e marine sandstones of the Schrader Sluff- The M -Sands are subdivided Into three T1GHTIPACIUNG OFF, E -25A., mw- Idhostratigraphic units 1M&. Mb. Mc from top to bottom) that can be dilllcuh to correlate due A s to their Ruwal-deltsic nature. The M705 marks the lower most boundary. Miami intervals Surface caste seat. 0j 8 are typically coarsening upward packages of varyinngg thicknesses, rangngfrom 50.80`th ck. forSchrader Bluff C C'atur. e All zees are highly unconsolidated sandstones wllh poresMles range in the 30.38`9, and coenpietlon. Tr permeabllltles reaching upwards of 2000-5000 md. Each sksand Inlerval atm as a Laos hydraukcally separate raservolr based on current understanding. TIGHT7LEOGES (COAL) Cill N -Sands: The N -sends are composed of stacked, marine sncaeface untlsdnes that RUNNING SURFACE A p coarsen upwards from thin silty mudsbancs Into thin, tow nel gross very firre to medium- CASING. E -2b, d3 8 -25. A grained sandstones. The NO, NC 8 ND -sends are the best quality reservoir rock W dean B Y m high rceigross fine to medium grained sand9lore- Nsand pordslty rargea from 12J65t and permeabikbes range from 100.3000 md. the NC 8 ND -sands are the primary larger, with E secondary targets In the Ne -sand. The more unconsolidated sands (typically ft* NS, NC 8 J m NO) tend to washout, and the Nater grained silty mudslanes can cause slow ROP. Each N -sand ads as a hydraulically Isolated separate reservoir. Az-" 4c-5 O•Sand3: The O -Sancta consist at stacked.IdN'er Shoelace marine sands that clew A upwards from silty m idstones (intervening shares) to thin bedded, very fine to fife grained sandstones.. These OAand OBsandstones are 25.30'thiok,andthe OAs ndistheprimary a u D larger for horizontal wells at E -pad. O -sand porosities range from 12-36'4. and permeebe'th es U1 In the 013 Band reach upwards of 80D Intl, whereas pemteabilwes in the OA -sand reach only y 350 and TherbAB1) e are underlying OB sands (OBthat correlate aver the region. y C in May contatight nodules and lenses that cause directional collection (especially when halzmUl) and slow ROP. Each O -sand Interval acts as a hydraulically Isolated reservoir. The numerous sub-sasmic 5.30 It faults and the lalenal discontinuity of the NB ds Make h 4800' 0 essentlal for clear pick dendNcadon down through the Ugnu and N -sands, as well as carelul +t- 100' geosmering In hortzodal wells. Page 31 Milne Point Unit E -39L1 S8 Injector Hilcorp Drilling Procedure U C27 20.0 Anticipated Drilling Hazards 8-1/2" Hole Section: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low -vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of> 300 gpm Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: There is at least (1) fault that will be crossed while drilling the well. There could be others and the throw of these faults is not well understood at this point in time. When a known fault is coming up, ensure to put a "ramp" in the wellbore to aid in kicking off (low siding) later. Once a fault is crossed, we'll need to either drill up or down to get a look at the LWD log and determine the throw and then replan the wellbore. H2S: Treat every hole section as though it has the potential for H2S. No 1-12S events have been documented on drill wells on this pad. 1. The AOGCC will be notified within 24 hours if 1-12S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic 1-12S 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. Abnormal Pressures and Temperatures: Abnormal pressure has been seen on E -Pad. Utilize MPD to mitigate any abnormal pressure seen. Anti -Collision There are no wells with a clearance factor <1.0 on this lateral. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic interference with another well. Page 32 H Hilcorp 21.0 Innovation Rig Layout Milne Point Unit E-39Lt SB Injector Drilling Procedure Page 33 n Hilcorp E..w Camgny 22.0 FIT Procedure Formation InteErity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: Milne Point Unit E-391.7 SB Injector Drilling Procedure I . Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1 -minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre -determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre -determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Ensure that casing test and subsequent FIT tests are recorded on the same chart. Document incremental volume pumped and returned during test. Page 34 Milne Point Unit E -39L7 SB Injector Hilco Drilling Procedure U�pP 23.0 Innovation Rig Choke Manifold Schematic Page 35 H Hilcrp X22 24.0 Casing Design 11 Hil= w Calculation & Casing Design Factors Hole Size 12-1/4" Hole Size 8-1/2" Hole Size Drilling Mode MASP: 1438 MASP: Production Mode MASP: 1438 DATE: 7/1112019 WELL: MPU E3911 DESIGN BY: Joe Engel Criteria: Mud Density: 9.2 ppg Mud Density: 9.2 ppg Mud Density: attached MASP determination & attached MASP determination & Milne Point Unit E-391.1 SB Injector Drilling Procedure Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.494 psi/ft) and the casing evacuated for the internal stress Page 36 Casing Section Calculation/Specification 1 2 3 4 Casing OD 95/8" 4-1/2" Top (MD) 0 7,600 Top (TVD) 0 4,172 Bottom (MD) 7,750 12,377 Bottom (TVD) 4,231 4,171 Length 7,750 4,777 Weight (ppf) 40 13.5 Grade LEO LA0 Connection TXP FI625 Weight w/o Bouyancy Factor (lbs) 310,000 64,490 Tension at Top of Section (lbs) 310,000 64,490 Min strength Tension (1000 lbs) 916 279 Worst Case Safety Factor (Tension) 2.95 4.33 Collapse Pressure at bottom (Psi) 2,090 2,060 Collapse Resistance w/o tension (Psi) 3,090 8,540 Worst Case Safety Factor (Collapse) 1.48 4.14 MASP (psi) 1,438 1,438 Minimum Yield (psi)5,750 9,020 Worst case safety factor (Burst) 4.00 6.27 Page 36 25.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation ]ac�rp 8-1/2" Hole Section MPU E-391-1 Milne Point Unit MD TVD Planned Top: 7750 4231 Planned TD: 12377 4171 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff OA Sand 4,231 1959 1 Oil I8.90 0.440 Offset Well Mud Densities Well MW ranee Too fTVD) Bottom (TVD) Date L-50 8.8-9.1 Milne Point Unit Surface 4125 2015 E-391-1 SB Injector 9.0-9.2 Hilco mem MTJ Drilling Procedure 25.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation ]ac�rp 8-1/2" Hole Section MPU E-391-1 Milne Point Unit MD TVD Planned Top: 7750 4231 Planned TD: 12377 4171 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff OA Sand 4,231 1959 1 Oil I8.90 0.440 Offset Well Mud Densities Well MW ranee Too fTVD) Bottom (TVD) Date L-50 8.8-9.1 Surface 4125 2015 L-49 9.0-9.2 Surface 4196 2015 L-48 8.9-9.2 Surface 4147 2015 L-47 8.8-9.0 Surface 4158 2015 L-46 9.0-9.3 Surface 4177 2015 Assumptions: 1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW. 2. Maximum planned mud density for the 8-1/2" hole section is 9.5 ppg. 3. Calculations assume full evacuation of wellbore to gas Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface: 4,231(ft)x 0.78(psi/ft)= 3300 3300(psi) - [0.1(psi/ft)*4231(ft)J= 2877 psi MASP from pore pressure (complete evacuation of wellbore to gas from Schrader Bluff OA sand) 4231 (ft) x 0.44(psi/ft)= 1861 psi 1861(psi) - 0.1(psi/ft)*4231(ft) 1438 psi Summary: 1. MASP while drilling 8-1/2" production hole is governed by pore pressure and evacuation of entire wellbore togas at 0.1 psi/ft. Page 37 26.0 Spider Plot (NAD 27) (Governmental Sections) Milne Point Unit E-39LI SB Injector Drilling Procedure y ADL047438 ; Legend -tl • / ! „/i 1 U3 ) E'[Fsi • MPU E-39U_SHL�-- MPU E -39L1 TPH MPUE-39LI 13HL / Other Surface Holes(SHL) "4-_�`T '� r�--- --- �— _ • Other Bottom Hulas (BHL) _ - Other Well Paths -MPU E -35L 1 51{L _ 0 I t OOil and Gas Urut Bamdary ,E�1;' `~ ! ♦��N` �``- �'F__ Pad Foctprnt Sec. 23 i636; ^ n roU-16 ��..6Pa •.��Ir �' ! � 1 i � / .4Ez'Bl E.o I1.1013N010E 1 U013N011E ADL025318--ADL028231- 1 =_ Baa=Ei E c I,� { E YPE E SSi ! 1 1 +1 MILNE POINT UNIT E -::se 1! • 1 Sec. 35 as Sec. 36 \IPU F-?5LII rPl[j _ MU)1 ♦ e.z6 --�- 1 € sral sxE I1j1 1 F J • 3'I 11 HN11S 1 - 1 e � 1 S1V=H1 S1 k' p //1 - •N /I N V a `%=a wa b'/ �7PU E-3911_BHL - - ISe-_. 1aU012N010E AD 380110 (77) H U012N011E See.5 V t N69La61•`^ t 61" 6RS,S:Oi55_. r 12 ^ , S. WBA ♦ -- I sss_•sm \ Stas s+la / • � su .Ae vas s1s�6 .t Dov. a 4/ r . Milne Point Unit MPE-39L1 Well 0 1.2aO 2.400 Y nlao wm: r.toaHts wnn� Feet Page 38 H Hilcow Enngy Cmnpmy 27.0 Surface Plat (As Builtl (NAD 27) Milne Point Unit E -39L1 SB Injector Drilling Procedure Page 39 �1 • .1 -M - GRID 111111 2Ci 3■ ■6 I !AO L - �I • ]J C • 2 $ T 27 ■ 32; y, 10 ■ 31 T I 26 ■ ■ s i z2 ■ • t 6 IPFIO,IECT 2P1 • ■ 5 Tri v ■ a 28 ■ ■ 3D -N 25 ■ 821 11 ■ ■ 7 MCINITY NAP 8■ ■t8 N.TA YPU H'AD zD ■ ■ z3 24 ■ ■ TS Of ' 3417 T5 ■ •' E-38 E-37 E-39 E -369m E-4/ E -SS ...:. ......... .. .. �... noty Dirt J •• "'�GYSIQiwV /1_0200 �p NOTES- LEGEND T. AI.A9fA STATE PIAE W HAMS ARE 20AE 4. NRD27. + As LT Ca A' 4;nn SURVEYOR'S CERTIFICATE 2. BASS a =AMM 6 W WXdNT3 M-3 ARO E -i. ■ CCNU INEREBY CENT" NAT T AM S SA55 W ELEYARON MC NE PT DAVM YA ON EASRNC PROPERLY RE951ERE0 ANO UCR6E0 a. PS3 AAE N& 1O PRA=TE LAND SURYEYIMC IN THE STATE OF ALASKA AND THAT pm WA F PAp YEAx SCJAE FACidt IS 0.9RSB054 a GRAPHIC SCALE THIS AS -BUILT REPRESENTS A WRWY e. SLR D.ATL MAY 3T, 20TB 4 AXY 1. 298 . p 700 280 App MAGE BY ME M UNDER MY GRECT 7. RDEREME n" BOOL 498-02 Poi 2M29 WPERMYON AND MAT N.L. 9MENS±WS AND OTHER CETA85 AAE NCM -02 PCS 88-73 L W TEET) CORRECT AS OF MAY 31, 2018. nM ]00 TL LOCATED VI"IN PROTRACTED SEC. 25, T. 13 N., R. 10 F, UMIAT MERIDIAN, ALASKA WELL 0.5.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION(OMS) POSITION(O.DD) BOX ELEV. OFFSETS Y=6016,133.24' N=1,824.99' 707713.945" 70.4544292' 3,394'F$L E-33 %- 569-426,37' = 7,a50.02' 149'26'00.438" 149.4334550' 2J 1,720 ' FEL Y- 6,016.156.74' N=1,860.12' 70'2716.178" 70.4344959' 3,817 FSL E-36%= 569.497.52' E- 1 430.03' 149'28'00.984" 749.4336067' 21.7' 1,736' FEL Y�6.016,180Y=6.016,180.37'N=1.840.58' 70'2716.412" 70.4545388' 3.641' FSL E-37 %- 569,388,31' E=1 449.84' 149'26'01.562" 149.433761] 217 1,757 FEL E_38 Y- 6.016.081.06' N=1,690.22' 70'27'15.446" 70.4542906' 218• 31543'F$L X� 569,265.12' E_- 1,2_91,58' 149'26'05.189" 149.4347747 1,581- FEL Y=6 C15,057.23' N. 1,859.75' 70KT15.210' 70.4542250' 21'7 31519• FSL E-39 X= 569 284.73' E= 1,291.52- 749'26.04.836" 149.4346211' 1,883' FEL Y-6,616,034.09' 029-93 1 70'2714,961" 70.4541614' 3,496'FSL E-41 .90' E_+. 291.66' 144'26'04.091" 144.6344697 21.8' Hilcorp Alaska �+ wm 4 1 8 MYII . MILNE POINT, ALASKA NP E -PAD, HELLS 3& 36, 37. J8. 39 k 41 T o T AEa p,AYW,�.vr '� +�`ro' - _.__. p„"�,®�` m 1• . 2pp CONDUCTOR AS-BU4.T Page 39 ' 1 844' FEL 28.0 Milne Point Unit E -39L1 SB Injector Drilling Procedure Schrader Bluff OA Sand Offset MW vs TVD Chart Page 40 Schrader Bluff OA Sand Offset MW vs ND MW,PPg 8.5 8.7 8.9 9-1 9.3 9.S 9.7 9.9 10.1 10.3 10.5 0 1 It'll m 1030 1500 2000 J= C 2500 3000 3500 1-0 0 4500 —MPU L-46 (2015) —MPU L-47 (2015) —MPU L-48 (2015) MPU L-49 (2015) —MPU L.-50 (2015) —MPU F-106 (2017) —MPU F-107 (2017) —MPU F-108 (2017) —MPU F-109 (2017) —MPU F-110 (2017) Hilcorp Alaska, LLC Milne Point M Pt E Pad Plan: MPU E-39 MPU E -39L1 Plan: E -39L1 wp03 Standard Proposal Report 25 June, 2019 HALLIBURTON Sperry Grilling Services HALLIBURTON Sperry Drilling Project: Milne Point Site: M Pt E Pad Well: PIan:MPU&39 Wellbore: MPU E-3911 Design: E490 wp0.1 HIWrp Masai, LLC CnI VIMM Abllnod: M'mmum C-ewm Erma S'..: ISCWSAdd Senn Mnnel: Cbl AWWO 3D Errs Surface: PeMI C.- Wem00 Ma": Emr Ralro SECTION DETAILS SecMO Axi WO -NI.S -EI-W Oleg Vans VSe Target 1 ]]50.00 6,j 190.95 4231.29 -58]].11 -1112.30 0.00 000 5979.64 2 7]67.00 69.21 190.95 4237.63 -5892.60 -1115.30 1300 0.00 5995.41 3 7797.00 69.21 190.95 4248.28 -5920.13 -1120.62 000 000 6023.45 4 830433 94.32 19459 4320.37 -6405.62 -1231.16 5.00 8.49 652132 5 066963 94.32 19459 4292.85 -675824 -1322.91 0.00 0.00 608535 6 8]068] 92.50 194.24 4290,65 -6A4O4 -1332.12 500 -16925 692239 7 10306.67 92.50 194.24 422086 -043.41 -185.32 000 000 851968 E391-1 wp93 CPI 8 1014.08 92.28 194.24 4220.55 4350.68 -1]2].14 3.00 179.03 852].0] 9 11141.32 92.28 194.24 4187Z7 .9151.76 -1930.52 0.00 0.00 9353.10 10 11316.15 91.10 19095 4182.52 -9322.28 -196862 2.00 -109.63 952]02 11 11916.15 91.10 190.95 4171.00 -9911.25 -208257 0.00 0.00 10127.58 E -39L1 up03 CP2 12 12321.65 88.70 204.59 41]1.80-10349.6] -2223.06 3.00 99.84 10585.72 E4811 w,03 Toe OVA Fmm tt4NTh 6wvepF�n Tool .VO.W )7mW I.WN E.'6,vOnv(MPIIE ]MN�r FRhY. IO1a50W yF0.00 EJnr yO]IMGU E.AII IrMNO_Fiap AtvftBq 1 .a5 ]aL1pNIMW E]Yll 3MNO�IFRZ�I6�Svp C-nsne a (NAT) RON- Well Pbn: MPU E30, True NonN VeNcal(VDI Ref s :Preim RM®4820mil(Inn atlon) Memm Depb Reference: Prelim RKB ®40.20uM1(Fv Uon)'AFS eEl-W NOMin4 Calculan MednW! Minimum Cuvamre 0O0 0.00 TACalculation FORMATON TOP DETAILS 430412 a 0 .A TvD xfi Weinh F -..n .2 42 CM 000449 8chabr Be, OA Annotation Start Dlr 13°1100':]]SP MD, 4231]9'N O'RTTF End Dir : 776T MD, 4237.63' TVD Sled Ter SI100':T 97 MD, 424836904 End DB :8304.23' MD, 4320.3T TVD Stan Dir 5'/IDS': 8669.0' MD, 4291.854VD End Dir :8]066]' MD, 429065' TVO Start Dir 3°1100: 1008.6]' MD, 422186'TVD End Dlr :10314.00' M4 4220.55' TVD Start Dir MISS! 11141M' MD, 4187.67N0 EM Dir :11316.15' MD, 4182.52' TVO Start Dir 301100':11916.15' MD, 4171 WD Tolal DepN : 123]].65' MO, 41718' TVD LL DETAILS: Plan: MPU E3. Ground L 1p 21 ]0 Eaa4n9 bYtluEe .male 5692a4.13 ]0. 2]'15210N 149'M'1535W TVD.. MO Six. Name 41MOO "50.00 9418 9se' TOW 412360 123]].65 4.tn 41.-v. I.' 0•05 M1 q ,,e.,qx.10 R.' �O- 5� 4'16 ,t<p >'A0 so TP f11 v6 .P, i1 \*e• g �1 0'p , .1 6 T\A1 eaP 96\ M166�op g4�64,g1 ea0.,g aos,te�ao c c, 9 WA OA- - e, n MFUE-30.y07 E 7811 .y03 ) $, 8 o a s'.. g 8 E-39 11 3 CP1 S4kl y03 CP2 E-3911 vy0.l Tw 2400 3200 40M 4800 5600 8400 7200 woo 0800 9600 10400 11200 12000 12800 13600 14400 15200 Vertical Section at 192.12' (1600 usftAn) 1 MALLIBURTON 0 EiFe"Y Orillin9 -1033 -2067 -3100 -4133- -5167 R -6200 0 C -7233- 0 n -826]- -9300- -10333- -11367- -12400- -13433— IA Ym Project: Milne Point Site: M Pt E Pad Well: Plan: MPU E-39 Wellbore: MPU E -39L1 Plan: E-391-1 wp03 WELL DETARS: Plan: MPU E39 Gmund Uvel: 21.70 +N/ -S +E -W Nmddn FxrinRR Ltidade Wn9imdc 0.00 0.00 6016057.25 569284, ]0° 2T 15.210 N 14V 26 4.636 W REFERENCE INFORMATION C raffinate (WE) Reference: Well Ran: MPU E-39, nue NUM Vesical (IVD) Reference: Prelim RKa @ 48 20ueft (Innwauonl Meanm.d Depth Reference: Prelim RK6 ® 49.28®fi flnnovalidn) Lalwlalian MCWad: Minium Curvature CASING DETAIIS WD TVDSS MD Size Name 4231.29 4183.09 7750.00 9-518 9 5/8" TOW 4171.80 412360 12377.65 4-12 412"x812" E-39LI wp03 E-39LI%p03 CP2 E -39L1 wpD3 Toe S3 3250 3500 ]50 4000 Stan Dir 13°/100': 7750' MD, 4231.29WD: 0" RT TF - - - End Dir : 776T MD, 423].63' TVD qts S. Dv Film,: 7797 MD, 4248.28TVD End Dir : 8304.23' ivD. 4320.37 TVD Sten Dir Pilar: 8669.63' MD. 4292.85n'VD End Dir : 8706.67 1,m, 4290.65' TVD 3P1 Sran Dir 3°/100': 10306.67' MD, 4220.86WD End Dir :10314.08' MD, 4220.55' WD Sian Dir 2°1100' : IIIA 3T MD, 4187.67WD /I.DkY/", MDir11316.IT MD, 4182.5TWD : 1191&15' MD, 4171 TVD >1 --Tarsi Depth: 123]].65' MD, 4171.8' TVD C7 wPo3 9 wp07 -7233 -6200 -5167 -4133 -3100 -2067 -1033 0 1033 2067 3100 West( -)/Fast(+) (1550 usfVln) HALLIBURTON Database: NORTH US+CANADA Company: Hilcorp Alaska, LLC Proiect: Milne Point Site: M Pt E Pad Well: Plan: MPU E-39 Wellbore: MPU E-391-1 Design: E -39L1 wp03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well PlanMPU E-39 Prelim RKB @ 48.20usft (Innovation) Prelim RKB @ 48.20usft (Innovation) True Minimum Curvature Protect Milne Point, ACT, MILNE POINT Tie On Depth: - - -- Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Direction Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point (I Map Zone: Alaska Zone 04 Using geodetic scale factor 192.12 Dogleg Build Site M Pt E Pad, TR -13-10 Depth Inclinatio Site Position: Northing: 6,013,798.68 usft Latitude: 70° 26' 52.982 N From: Map Eastina: 569,440.72 waft Longitude: 149° 26' 0.655 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.53 ° (usft) usft (usft) (usft) well Plan: MPU E-39 (o/100usft (°) Well Position +N/S 0.00 usft Northing: 6,016,057.25 usft Latitude: 70" 27'15.210 N 4,183.09 +E/ -W 0.00 usft Easting: 569,284.13 usft Longitude: 149° 26'4.636 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 21.70 usft 69.21 190.95 4,237.63 4,189.43 Wellbore MPU E-3911 13.00 13.00 Mapmtics Model Name Sample Date Declination Dip Angle Field Strength 190.95 4,248.28 n (7 (ron -1,120.62 BGGM2018 6125/2019 16.65 80.96 57,425.42522507 0.00 8,304.23 94.32 194.59 Design Audit Notes: Version: Vertical Section: E-3911 wp03 Phase: PLAN Tie On Depth: 7,750.00 Depth From (TVD) -NIS +E1 -W Direction (usft) (usft) (usft) (I 26.50 0.00 0.00 192.12 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclinatio Azimut Depth System +N/ -S +E/ -W Rate Rate Rate Tool Face (usft) n In (usft) usft (usft) (usft) (^/toousft) (o/i OOusft (o/100usft (°) 7,750.00 67.00 190.95 4,231.29 4,183.09 -5,877.11 -1,112.30 0.00 0.00 0.00 0.00 7,767.00 69.21 190.95 4,237.63 4,189.43 5,892.60 -1,115.30 13.00 13.00 0.00 0.00 7,797.00 69.21 190.95 4,248.28 4,200.08 -5,920.13 -1,120.62 0.00 0.00 0.00 0.00 8,304.23 94.32 194.59 4,320.37 4,272.17 -6,405.62 -1,231.16 5.00 4.95 0.72 8.49 8,669.63 94.32 194.59 4,292.85 4,244.65 -6,758.24 -1,322.91 0.00 0.00 0.00 0.00 8,706.67 92.50 194.24 4,290.65 4,242.45 -6,794.04 -1,332.12 5.00 -4.91 -0.93 -169.25 10,306.67 92.50 194.24 4,220.86 4,172.66 -8,343.41 -1,725.32 0.00 0.00 0.00 0.00 10,314.08 92.28 194.24 4,220.55 4,172.35 -8,350.58 -1,727.14 3.00 -3.00 0.05 179.03 11,141.32 92.28 194.24 4,187.67 4,139.47 -9,151.76 -1,930.52 0.00 0.00 0.00 0.00 11,316.15 91.10 190.95 4,182.52 4,134.32 -9,322.28 -1,968.62 2.00 -0.67 -1.88 -109.63 11,916.15 91.10 190.95 4,171.00 4,122.80 -9,911.25 -2,082.57 0.00 0.00 0.00 0.00 12,377.65 88.70 204.59 4,171.80 4,123.60 -10,349.67 -2,223.06 3.00 -0.52 2.95 99.94 625/2019 5:19:20PM Page 2 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Protect: Milne Point Site: M Pt E Pad Well: Plan: MPU E-39 Wellbore: MPU E -39L1 Design: E -39L1 wp03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Surveil Calculation Method: Halliburton Standard Proposal Report Well Plan: MPU E-39 Prelim RKB @ 48.20usft (Innovation) Prelim RKB @ 48.20usft (Innovation) True Minimum Curvature Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NIS +PJ -W Northing Easting DLS Vert (usft) (1) (1) (usft) usft (usft) (usft) (usft) (usft) 51.80 Section 100.00 0.00 0.00 100.00 51.80 0.00 0.00 6,016,057.25 569,284.13 0.00 0.00 200.00 0.00 0.00 200.00 151.80 0.00 0.00 6,016,057.25 569,284.13 0.00 0.00 300.00 0.60 220.00 300.00 251.80 -0.08 -0.07 6,016,057.17 569,284.06 0.60 0.09 400.00 3.60 220.00 399.92 351.72 -2.89 -2.42 6,016,054.34 569,281.73 3.00 3.33 500.00 6.60 220.00 499.51 451.31 -9.70 -8.14 6,016,047.48 569,276.09 3.00 11.19 600.00 9.85 213.73 598.49 550.29 -20.85 -16.89 6,016,036.25 569,267.44 3.36 23.93 700.00 13.55 206.19 696.40 648.20 -38.48 -26.81 6,016,018.52 569,257.68 4.00 43.26 800.00 17.39 201.89 792.76 744.56 -62.87 -37.56 6,015,994.04 569,247.16 4.00 69.35 900.00 21.28 199.11 887.11 838.91 -93.89 -49.07 6,015,962.91 569,235.94 4.00 102.10 1,000.00 25.21 197.16 978.97 930.77 -131.40 -61.29 6,015,925.30 569,224.07 4.00 141.34 1,100.00 29.15 195.70 1,067.92 1,019.72 -175.21 -74.17 6,015,881.37 569,211.60 4.00 186.88 1,200.00 .33.11 194.57 1,153.50 1,105.30 -225.11 -87.64 6,015,831.36 569,198.59 4.00 238.50 1,300.00 37.07 193.66 1,235.31 1,187.11 -280.86 -101.63 6,015,775.49 569,185.12 4.00 295.94 1,400.00 41.04 192.89 1,312.94 1,264.74 -342.17 -116.08 6,015,714.04 569,171.24 4.00 358.92 1,500.00 45.02 192.25 1,386.03 1,337.83 -408.77 -130.92 6,015,647.32 569,157.03 4.00 427.15 1,600.00 49.00 191.68 1,454.20 1,406.00 -480.31 -146.07 6,015,575.65 569,142.55 4.00 500.28 1,700.00 52.98 191.18 1,517.14 1,468.94 -556.46 -161.45 6,015,499.37 569,127.87 4.00 577.96 1,800.00 56.96 190.73 1,574.52 1,526.32 -636.84 -177.01 6,015,418.85 569,113.07 4.00 659.81 1,900.00 60.95 190.32 1,626.09 1,577.89 -721.06 -192.65 6,015,334.50 569,098.21 4.00 745.43 2,000.00 63.44 190.08 1,672.01 1,623.81 -808.49 -208.31 6,015,246.94 569,083.37 2.50 834.20 2,100.00 63.44 190.08 1,716.72 1,668.52 -896.55 -223.96 6,015,158.74 569,068.54 0.00 923.59 2,200.00 63.44 190.08 1,761.44 1,713.24 -984.61 -239.62 6,015,070.54 569,053.70 0.00 1,012.98 2,300.00 63.44 190.08 1,806.16 1,757.96 -1,072.68 -255.27 6,014,982.34 569,038.87 0.00 1,102.37 2,400.00 63.44 190.08 1,850.87 1,802.67 -1,160.74 -270.92 6,014,894.15 569,024.04 0.00 1,191.76 2,500.00 63.44 190.08 1,895.59 1,847.39 -1,248.81 -286.58 6,014,805.95 569,009.20 0.00 1,281.14 2,600.00 63.44 190.08 1,940.31 1,892.11 -1,336.87 -302.23 6,014,717.75 568,994.37 0.00 1,370.53 2,700.00 63.44 190.08 1,985.02 1,936.82 -1,424.94 -317.89 6,014,629.55 568,979.54 0.00 1,459.92 2,800.00 63.44 190.08 2,029.74 1,981.54 -1,513.00 -333.54 6,014,541.35 568,964.70 0.00 1,549.31 2,900.00 63.44 190.08 2,074.46 2,026.26 -1,601.07 -349.20 6,014,453.16 568,949.87 0.00 1,638.70 3,000.00 63.44 190.08 2,119.17 2,070.97 -1,689.13 -364.85 6,014,364.96 568,935.04 0.00 1,728.08 3,100.00 63.44 190.08 2,163.89 2,115.69 -1,777.20 -380.50 6,014,276.76 568,920.20 0.00 1,817.47 3,200.00 63.44 190.08 2,208.61 2,160.41 -1,865.26 -396.16 6,014,188.56 568,905.37 0.00 1,906.86 3,300.00 63.44 190.08 2,253.32 2,205.12 -1,953.33 -411.81 6,014,100.36 568,890.54 0.00 1,996.25 3,400.00 63.44 190.08 2,298.04 2,249.84 -2,041.39 -427.47 6,014,012.17 568,875.70 0.00 2,085.64 3,500.00 63.44 190.08 2,342.76 2,294.56 -2,129.45 443.12 6,013,923.97 568,860.87 0.00 2,175.03 3,600.00 63.44 190.08 2,387.47 2,339.27 -2,217.52 -458.77 6,013,835.77 568,846.04 0.00 2,264.41 3,700.00 63.44 190.08 2,432.19 2,383.99 -2,305.58 474.43 6,013,747.57 568,831.20 0.00 2,353.80 3,800.00 63.44 190.08 2,476.91 2,428.71 -2,393.65 490.08 6,013,659.37 568,816.37 0.00 2,443.19 3,900.00 63.44 190.08 2,521.62 2,473.42 -2,481.71 -505.74 6,013,571.18 568,801.54 0.00 2,532.58 4,000.00 63.44 190.08 2,566.34 2,518.14 -2,569.78 -521.39 6,013,482.98 568,786.71 0.00 2,621.97 4,100.00 63.44 190.08 2,611.06 2,562.86 -2,657.84 -537.05 6,013,394.78 568,771.87 0.00 2,711.35 4,200.00 63.44 190.08 2,655.77 2,607.57 -2,745.91 -552.70 6,013,306.58 568,757.04 0.00 2,800.74 4,300.00 63.44 190.08 2,700.49 2,652.29 -2,833.97 -568.35 6,013,218.38 568,742.21 0.00 2,890.13 4,400.00 63.44 190.08 2,745.21 2,697.01 -2,922.04 -584.01 6,013,130.19 568,727.37 0.00 2,979.52 4,500.00 63.44 190.08 2,789.92 2,741.72 -3,010.10 -599.66 6,013,041.99 568,712.54 0.00 3,068.91 625/2019 5:19:20PM Pace 3 COMPASS 5000.15 Build 91 HALLIBURTON Halliburton Standard Proposal Report Database: Company: Protect: site: Well: Wellbore: Design: NORTH US + CANADA Hilcom Alaska, LLC Was Point M PI E Pad Plan: MPU E-39 MPU E-3911 E-39LI wp03 Local Co-ordinate Reference: Well Plan: MPU E-39 TVD Reference: Prelim RKB @ 48.20usft (Innovation) MD Reference: Prelim RKB @ 48.20usft (Innovation) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss -N/-S +FJ -W Northing Seeing DLS Vert (usft) r) (•) (usft) usft (usft) (usft) (usft) (usft) 2,786-4 Section 4,600.00 63.44 190.08 2,834.64 2,786.44 -3,098.16 -615.32 6,012,953.79 568,697.71 0.00 3,158.30 4,700.00 63.44 190.08 2,879.36 2,831.16 -3,186.23 -630.97 6,012,865.59 568,682.87 0.00 3,247.68 4,800.00 63.44 190.08 2,924.07 2,875.87 -3,274.29 -646.62 6,012,777.39 568,668.04 0.00 3,337.07 4,900.00 63.44 190.08 2,968.79 2,920.59 -3,362.36 -662.28 6,012,689.20 568,653.21 0.00 3,426.46 5,000.00 63.44 190.08 3,013.51 2,965.31 -3,450.42 -677.93 6,012,601.00 568,638.37 0.00 3,515.85 5,100.00 63.44 190.08 3,058.22 3,010.02 -3,538.49 -693.59 6,012,512.80 568,623.54 0.00 3,605.24 5,200.00 63.44 190.08 3,102.94 3,054.74 -3,626.55 -709.24 6,012,424.60 568,608.71 0.00 3,694.63 5,300.00 63.44 190.08 3,147.66 3,099.46 .3,714.62 -724.90 6,012,336.41 568,593.87 0.00 3,784.01 5,400.00 63.44 190.08 3,192.37 3,144.17 -3,802.68 -740.55 6,012,248.21 568,579.04 0.00 3,873.40 5,500.00 63.44 190.08 3,237.09 3,188.89 -3,890.75 -756.20 6,012,160.01 568,564.21 0.00 3,962.79 5,600.00 63.44 190.08 3,281.81 3,233.61 -3,978.81 -771.86 6,012,071.81 568,549.37 0.00 4,052.18 5,700.00 63.44 190.08 3,326.52 3,278.32 -4,066.87 -787.51 6,011,983.61 568,534.54 0.00 4,141.57 5,800.00 63.44 190.08 3,371.24 3,323.04 -4,154.94 -803.17 6,011,895.42 568,519.71 0.00 4,230.95 5,900.00 63.44 190.08 3,415.96 3,367.76 -4,243.00 -818.82 6,011,807.22 568,504.88 0.00 4,320.34 6,000.00 63.44 190.08 3,460.67 3,412.47 .4,331.07 -834.47 6,011,719.02 568,490.04 0.00 4,409.73 6,100.00 63.44 190.08 3,505.39 3,457.19 -4,419.13 -850.13 6,011,630.82 568,475.21 0.00 4,499.12 6,200.00 63.44 190.08 3,550.11 3,501.91 -4,507.20 -865.78 6,011,542.62 568,460.38 0.00 4,588.51 6,300.00 63.44 190.08 3,594.82 3,546.62 4,595.26 -881.44 6,011,454.43 568,445.54 0.00 4,677.90 6,400.00 63.44 190.08 3,639.54 3,591.34 -4,683.33 -897.09 6,011,366.23 568,430.71 0.00 4,767.28 6,500.00 63.44 190.08 3,684.26 3,636.06 -4,771.39 -912.75 6,011,278.03 568,415.88 0.00 4,856.67 6,600.00 63.44 190.08 3,728.97 3,680.77 4,859.46 -928.40 6,011,189.83 568,401.04 0.00 4,946.06 6,700.00 63.44 190.08 3,773.69 3,725.49 -4,947.52 -944.05 6,011,101.63 568,386.21 0.00 5,035.45 6,800.00 63.44 190.08 3,818.41 3,770.21 -5,035.59 -959.71 6,011,013.44 568,371.38 0.00 5,124.84 6,900.00 63.44 190.08 3,863.12 3,814.92 -5,123.65 -975.36 6,010,925.24 568,356.54 0.00 5,214.22 7,000.00 63.44 190.08 3,907.84 3,859.64 .5,211.71 -991.02 6,010,837.04 568,341.71 0.00 5,303.61 7,100.00 63.44 190.08 3,952.56 3,904.36 -5,299.78 -1,006.67 6,010,748.84 568,326.88 0.00 5,393.00 7,200.00 63.44 190.08 3,997.27 3,949.07 -5,387.84 -1,022.32 6,010,660.64 568,312.04 0.00 5,482.39 7,300.00 63.44 190.08 4,041.99 3,993.79 -5,475.91 -1,037.98 6,010,572.45 568,297.21 0.00 5,571.78 7,400.00 63.44 190.08 4,086.71 4,038.51 -5,563.97 -1,053.63 6,010,484.25 568,282.38 0.00 5,661.17 7,500.00 63.72 190.15 4,131.41 4,083.21 -5,652.04 -1,069.29 6,010,396.04 568,267.54 0.29 5,750.56 7,600.00 67.00 190.95 4,172.68 4,124.48 -5,741.55 -1,086.07 6,010,306.39 568,251.59 3.36 5,841.60 7,700.00 67.00 190.95 4,211.75 4,163.55 -5,831.93 -1,103.56 6,010,215.87 568,234.95 0.00 5,933.63 7,750.00 67.00 190.95 4,231.29 4,183.09 -5,877.11 -1,112.30 6,010,170.60 568,226.63 0.00 5,979.64 Start Dir 13°/100' : 7750' MD, 4231.29 -TVD: 0° RT TF - 9 518" TOW 7,767.00 69.21 190.95 4,237.63 4,189.43 -5,892.60 -1,115.30 6,010,155.09 568,223.78 13.00 5,995.41 End Dir : 7767' MD, 4237.63' TVD 7,797.00 69.21 190.95 4,248.28 4,200.08 .5,920.13 -1,120.62 6,010,127.51 568,218.71 0.00 6,023.45 Start Dir 5°/100' : 7797' MD, 4248.28'T1fD 7,800.00 69.36 190.97 4,249.34 4,201.14 -5,922.89 -1,121.16 6,010,124.75 568,218.20 5.00 6,026.26 7,900.00 74.31 191.74 4,280.51 4,232.31 .6,016.01 -1,139.87 6,010,031.47 568,200.36 5.00 6,121.24 8,000.00 79.25 192.47 4,303.37 4,255.17 -6,111.17 -1,160.28 6,009,936.14 568,180.83 5.00 6,218.55 • 8,004.49 79.48 192.50 4,304.20 4,256.00 -6,115.48 -1,161.24 6,009,931.82 568,179.92 5.00 6,222.97 Schroder Bluff OA 8,100.00 84.21 193.17 4,317.75 4,269.55 -6,207.63 -1,182.24 6,009,839.48 568,159.78 5.00 6,317.48 8,200.00 89.16 193.87 4,323.54 4,275.34 -6,304.66 -1,205.57 6,009,742.25 568,137.35 5.00 6,417.25 6252019 5:19:20PM Page 4 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US+CANADA Company: Hilcorp Alaska, LLC Protect: Milne Point Site: M Pt E Pad Well: Plan: MPU E-39 Wellbore: MPU E -39L1 Design: E-390 wp03 Planned Survey Measured Well Plan: MPU E-39 TVD Reference: Vertical Depth Inclination Azimuth Depth (usft) (1) (') (usft) 8,300.00 94.11 194.56 4,320.69 8,304.23 94.32 194.59 4,320.37 End Dir : 8304.23' MD, 4320.37' TVD 8,400.00 94.32 194.59 4,313.16 8,500.00 94.32 194.59 4,305.63 8,600.00 94.32 194.59 4,298.10 8,669.63 94.32 194.59 4,292.85 Start Dir 5°/100' : 8669.63' MD, 4292.85'TVD 8,700.00 92.83 194.30 4,290.96 8,706.67 92.50 194.24 4,290.65 End Dir : 8706.67' MD, 4290.65' TVD 8,800.00 92.50 194.24 4,286.58 8,900.00 92.50 194.24 4,282.22 9,000.00 92.50 194.24 4,277.86 9,100.00 92.50 194.24 4,273.49 9,200.00 92.50 194.24 4,269.13 9,300.00 92.50 194.24 4,264.77 9,400.00 92.50 194.24 4,260.41 9,500.00 92.50 194.24 4,256.05 9,600.00 92.50 194.24 4,251.68 9,700.00 92.50 194.24 4,247.32 9,800.00 92.50 194.24 4,242.96 9,900.00 92.50 194.24 4,238.60 10,000.00 92.50 194.24 4,234.24 10,100.00 92.50 194.24 4,229.87 10,200.00 92.50 194.24 4,225.51 10,300.00 92.50 194.24 4,221.15 10,306.67 92.50 194.24 4,220.86 Start Dir 3-1100': 10306.67' MD, 4220.86'TVD 10,314.08 92.28 194.24 4,220.55 End Dir : 10314.08' MD, 4220.55' TVD 10,400.00 92.28 194.24 4,217.14 10,500.00 92.28 194.24 4,213.16 10,600.00 92.28 194.24 4,209.19 10,700.00 92.28 194.24 4,205.21 10,800.00 92.28 194.24 4,201.24 10,900.00 92.28 194.24 4,197.26 11,000.00 92.28 194.24 4,193.29 11,100.00 92.28 194.24 4,189.31 11,141.32 92.28 194.24 4,187.67 Start Dir -°/700': 11141.32' MD, 4187.677VD 11,200.00 91.88 193.14 4,185.54 11,300.00 91.21 191.25 4,182.84 11,316.15 91.10 190.95 4,182.52 End Dir : 11316AW MD, 4182.52' TVD Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU E-39 TVD Reference: Prelim RKB @ 48.20usft (Innovation) No Reference: Prelim IRKS @ 48.20usft (innovation) North Reference: True Survev Calculation Method: Minimum Curvature 0/15/2019 5:19:20PM Pam 5 COMPASS 5000.15 Build 91 Map Map TVDss +N/S +E/ -W Northing Easting DLS Vert usft (usft) (usft) (usft) (usft) 4,272.49 Section 4,272.49 -6,401.53 -1,230.10 6,009,645.16 568,113.73 5.00 6,517.11 4,272.17 -6,405.62 -1,231.16 6,009,641.07 568,112.70 5.00 6,521.32 4,264.96 -6,498.04 -1,255.21 6,009,548.44 568,089.52 0.00 6,616.73 4,257.43 -6,594.54 -1,280.32 6,009,451.71 568,065.31 0.00 6,716.36 4,249.90 -6,691.04 -1,305.43 6,009,354.99 568,041.10 0.00 6,815.98 4,244.65 -6,758.24 -1,322.91 6,009,287.64 568,024.24 0.00 6,885.35 4,242.76 -6,787.59 -1,330.47 6,009,258.23 568,016.95 5.00 6,915.63 4,242.45 -6,794.05 -1,332.12 6,009,251.75 568,015.37 5.00 6,922.29 4,238.38 -6,884.42 -1,355.05 6,009,161.18 567,993.28 0.00 7,015.47 4,234.02 -6,981.26 -1,379.63 6,009,064.13 567,969.61 0.00 7,115.31 4,229.66 -7,078.09 -1,404.20 6,008,967.08 567,945.93 0.00 7,215.14 4,225.29 -7,174.93 -1,428.78 6,008,870.03 567,922.26 0.00 7,314.98 4,220.93 -7,271.76 -1,453.35 6,008,772.98 567,898.59 0.00 7,414.82 4,216.57 -7,368.60 -1,477.93 6,008,675.93 567,874.92 0.00 7,514.65 4,212.21 -7,465.43 -1,502.50 6,008,578.88 567,851.25 0.00' 7,614.49 4,207.85 -7,562.27 -1,527.08 6,008,481.83 567,827.58 0.00 7,714.33 4,203.48 -7,659.10 -1,551.65 6,008,384.77 567,803.91 0.00 7,814.16 4,199.12 -7,755.94 -1,576.23 6,008,287.72 567,780.24 0.00 7,914.00 4,194.76 -7,852.77 -1,600.80 6,008,190.67 567,756.56 0.00 8,013.84 4,190.40 -7,949.61 -1,625.38 6,008,093.62 567,732.89 0.00 8,113.67 4,186.04 -8,046.44 -1,649.95 6,007,996.57 567,709.22 0.00 8,213.51 4,181.67 -8,143.28 -1,674.53 6,007,899.52 567,685.55 0.00 8,313.35 4,177.31 -8,240.11 .1,699.10 6,007,802.47 567,661.88 0.00 8,413.18 4,172.95 -8,336.95 -1,723.68 6,007,705.42 567,638.21 0.00 8,513.02 4,172.66 -8,343.41 -1,725.32 6,007,698.95 567,636.63 0.00 8,519.68 4,172.35 -8,350.58 -1,727.14 6,007,691.76 567,634.88 3.00 8,527.08 4,168.94 -8,433.80 -1,748.26 6,007,608.36 567,614.53 0.00 8,612.87 4,164.96 -8,530.65 -1,772.85 6,007,511.30 567,590.85 0.00 8,712.72 4,160.99 -8,627.49 -1,797.43 6,007,414.23 567,567.17 0.00 8,812.57 4,157.01 .8,724.34 -1,822.02 6,007,317.17 567,543.48 0.00 8,912.43 4,153.04 -8,821.19 -1,846.60 6,007,220.10 567,519.80 0.00 9,012.28 4,149.06 -8,918.04 -1,871.19 6,007,123.04 567,496.12 0.00 9,112.13 4,145.09 -9,014.89 -1,895.77 6,007,025.97 567,472.44 0.00 9,211.98 4,141.11 .9,111.74 -1,920.36 6,006,928.91 567,448.76 0.00 9,311.84 4,139.47 -9,151.76 -1,930.52 6,006,888.80 567,438.97 0.00 9,353.10 4,137.34 -9,208.73 -1,944.40 6,006,831.71 567,425.63 2.00 9,411.71 4,134.64 .9,306.44 -1,965.51 6,006,733.82 567,405.42 2.00 9,511.67 4,134.32 -9,322.28 -1,968.62 6,006,717.95 567,402.46 2.00 9,527.82 0/15/2019 5:19:20PM Pam 5 COMPASS 5000.15 Build 91 HALLIBURTON Halliburton Standard Proposal Report Database: Company: Proiect• Site: Well: Wellbore: Design: NORTH US + CANADA Hilcorp Alaska, LLC Milne Point M Pt E Pad Plan: MPU E-39 MPU E-3911 E -391L1 wp03 Dip Dir. TVD Local Co-ordinate Reference: Well Plan: MPU E-39 TVD Reference: Prelim RKB @ 48.20usft (Innovation) MD Reference: Prelim RKB @ 48.20usft (Innovation) North Reference: True Survey Calculation Method: Minimum Curvature +EI -W Planned Survey Basting -Shape {') (I (usft) (usft) (usft) (usfl) (usft) Measured 0.00 Vertical 4,171.80 -10,349.67 -2,223.06 Map Map - plan hits target center Depth Inclination Azimuth Depth TVDss +N/S +E/ -W Northing Basting OLS Vert (usft) (1) (1) (usft) usft (usft) (usft) (usft) (usft) 4,132.71 Section 11,400.00 91.10 190.95 4,180.91 4,132.71 -9,404.59 -1,984.55 6,006,635.50 567,387.30 0.00 9,611.63 11,500.00 91.10 190.95 4,178.99 4,130.79 -9,502.75 -2,003.54 6,006,537.18 567,369.23 0.00 9,711.59 11,600.00 91.10 190.95 4,177.07 4,128.87 -9,600.91 -2,022.53 6,006,438.86 567,351.15 0.00 9,811.56 11,700.00 91.10 190.95 4,175.15 4,126.95 -9,699.07 -2,041.52 6,006,340.53 567,333.07 0.00 9,911.52 11,800.00 91.10 190.95 4,173.23 4,125.03 -9,797.23 -2,060.51 6,006,242.21 567,315.00 0.00 10,011.48 11,900.00 91.10 190.95 4,171.31 4,123.11 -9,895.39 -2,079.51 6,006,143.88 567,296.92 0.00 10,111.44 11,916.15 91.10 190.95 4,171.00 4,122.80 -9,911.25 -2,082.57 6,006,128.00 567,294.00 0.00 10,127.58 Start Dir 3°1100' : 11916.15' MD, 4171'TVD 12,000.00 90.67 193.43 4,169.71 4,121.51 -9,993.19 -2,100.27 6,006,045.91 567,277.06 3.00 10,211.41 12,100.00 90.14 196.38 4,169.00 4,120.80 -10,089.81 -2,125.99 6,005,949.06 567,252.25 3.00 10,311.28 12,200.00 89.62 199.34 4,169.20 4,121.00 -1Q184.98 -2,156.66 6,005,853.62 567,222.47 3.00 10,410.77 12,300.00 89.10 202.29 4,170.31 4,122.11 -10,278.44 -2,192.18 6,005,759.84 567,187.82 3.00 10,509.60 12,377.65 88.70 204.59 4,171.80 4,123.60 -10,349.67 -2,223.06 6,005,688.34 567,157.61 3.00 10,585.72 Total Depth : 12377.65' MD, 4171.8' TVD Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD -NI-S +EI -W Northing Basting -Shape {') (I (usft) (usft) (usft) (usfl) (usft) E-3911 wp03 Toe 0.00 0.00 4,171.80 -10,349.67 -2,223.06 6,005,688.34 567,157.61 - plan hits target center - Point E-39Ll wp03 CP1 0.00 0.00 4,220.86 -8,343.41 .1,725.32 6,007,698.95 567,636.63 - plan hits target center - Point E-39-1 waW CP2 0.00 0.00 4,171.00 .9,911.25 -2,082.57 6,006,128.00 567,294.00 - plan hits target center Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usftl Name (") (^I 7,750.00 4,231.29 95/8"TOW 9-5/8 12-1/4 12,377.65 4,171.80 41/2"x81/2" 4-1/2 8-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology V) (1) 8,094.49 4,304.20 Schrader Bluff OA 6252019 5:19:20PM Pare 6 COMPASS 5000.15 Build 91 HALLIBURTON Halliburton Standard Proposal Report Database: Company: Project: Site: Well: Wellbore: Design: NORTH US + CANADA Hilcorp Alaska, LLC Milne Point M Pt Pad Plan: MPU E-39 MPU E-391-1 E-3911 wp03 Local Ca -ordinate Reference: Well Plan: MPU E-39 TVD Reference: Prelim RK8 @ 48.20usft (innovation) MD Reference: Prelim RKB @ 48.20usft (Innovation) North Reference: True Survey Calculation Method: Minimum Curvature Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 7,750.00 4,231.29 -5,877.11 -1,112.30 Start Dir 13°/100': 7750'MD, 4231.29'TVD : 0* RT TF 7,767.00 4,237.63 -5,892.60 -1,115.30 End Dir : 7767' MD, 4237.63' TVD 7,797.00 4,248.28 -5,920.13 -1,120.62 Start Dir 5°/100': 7797' MD, 4248.28'TVD 8,304.23 4,320.37 -6,405.62 -1,231.16 End Dir : 8304.23' MD, 4320.37' TVD 8,669.63 4,292.85 -6,758.24 -1,322.91 Start Dir 5'/100': 8669.63' MD, 4292.85'TVD 8,706.67 4,290.65 -66,794.05 -1,332.12 End Dir :8706.6T MD, 4290.65' TVD 10,306.67 4,220.86 -8,343.41 -1,725.32 Start Dir 3°/100' : 10306.67' MD, 4220.86'TVD 10,314.08 4,220.55 -8,350.58 -1,727.14 End Dir : 10314.08' MD, 4220.55' TVD 11,141.32 4,187.67 -9,151.76 -1,930.52 Start Dir 2°/100': 11141.32'MD, 4187.67'TVD 11,316.15 4,182.52 -9,322.28 -1,968.62 End Dir : 11316.15' MD, 4182.52' TVD 11,916.15 4,171.00 -9,911.25 -2,082.57 Start Dir 3°/100': 11916.15'MD, 4171'TVD 12,377.65 4,171.80 -10,349.67 -2,223.06 Total Depth : 12377.65' MD, 4171.8' TVD 6252019 5:19:20PM Pane 7 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt E Pad Plan: MPU E-39 MPU E -39L1 E-391-1 wp03 Sperry Drilling Services Clearance Summary Anticollision Report 25 June, 2019 closest Approach Oo Proximity Scan on current survey Data IMiyhaide Reference) Reference Design: M PI E Pad Plan: MPU E-39 MPU E39L1 E-391.1 wp03 Well Lo ordinates: 6,016,057.25 N. 569.i0C.13 E (70' 37' 15.21"N,149. 26' 04S4 W) Datum Height: Prelim RKB(d 46.20usft Orrovatioul Scan Range: 2j50.00 to 12,377.65 usf. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is Delimited Geodetic Scale Factor Applied Version: 5000.15 Build 91 Septa type: Scan Type: 2500 r HALLIBURTON Sperry Drilling Services NALLIBURTON Anticollision Report for Plan: MPU E-39 - E-391.1 wp03 HilearP Alaska, LLC Milne Point Closest Approach 30 Pmalmity Seen an Current Survey Data IRlabslde Reference) 625.23 2,25000 Reference Design: MPt E Pad - Plan: MPU E49 -MPU EJ91.1-E-39L1 woos 8,050.22 2,575 Seen Range: 7,250.00 to 12,377.55 all Measured Depth. Pass - esto.00 Scan Radius is Unlimited. Clearance Factor consists Unlimited Maa Ellipse Separation Is Unlimited 8,550.00 477.84 Measure Minimum ®Measure Ellipse (Measure Claanre Summary Basetl SitName d Distance d Separation tl Factor on Minimum Separation Warning Co Companion Well Name - Wellbore Name -Ceagn Denm wsm Denrn mxxl g.,•eh M Pt E Pad MPE-24 - MPE- 2 4 - MPE-24 MPE-24-MPE-24 -MPE-24 MPE-24 - MPE-24A- MPE-24A MPE-24 - MPE-24A- MPE-24A MPE-24-MPE-24ALI -MPE-24AL1 MPE-24 - MPE-24ALl - MPE-24ALl MPE-25 - MPE-25 - MPE-25 MPE-25 - MPE-25 - MPE-25 MPE-29 - MPE-29 - MPE-29 Plan: MPU E -39 -MPU E -391 -MPU Ea9 wp07 Plan: MPU E-39- MPU E -39i- MPU E-39 wp02 Plan: MPU E-39 -MPU Ed9i-MPU E-39 Wp02 Rin: MPU E42- MPU E42- MPU E42 RIO: MPU E42 -MPU E -42 -MPU E42 Ry: MPU E42. MPU E42 -MPU E42 Rio: MPU E42 -MPU EA21.1 -MPU E42L1 Rin: MPU E42- MPU E42L1- MPU E42LI w,06 Rin: MPU E42 -MPU E42L1-MPU E42L1 wN6 RIO: MPU E42 - MPU E42L1-MPU E42L1 Wg06 M Pt S Pad MPS-I2-MPS-12PB1 -MPS-12PB1 MPS -19 - MPS -19 - MPS -19 MPS -19 - MPS -19A- MPS -19A MPS -19 - MPS-19AL1-MPS-19AL1 MPS -I9- MPS -1 Will - MPS-I9AP81 2,250.00 625.23 2,25000 412.98 8,050.22 2,575 Ellipse Saloum Pass - esto.00 294.39 8,550.00 477.84 81809.11 2.510 Clearance Factor Pass - 2,250.00 625.23 2,25.Oo 41466 8,042.32 2.591 Ellipse Separation Pass - 11,925.00 922.14 11,925.00 549.88 12,250.06 2.302 Cleaance Factor PasS- 2,250.00 625.23 2,250.00 41441 8,042.32 2.589 Ellipse Sepamlbn Pass - 12,000.00 1,048.69 12,0)0.00 623.45 12,343.66 2466 Clearance Factor Pass - 8,23865 1,407.5 81238.85 1,124.68 10,55000 4.925 Centre Distance Pass - 8,250.00 1,402.62 8,25000 1,124.60 10,55000 4.924 Clearance Factor Pass - 7,750.00 1,290.62 2,25.00 1,014.49 8,085.70 4.624 Clamor. Factor Pass - 8.050.00 33.16 8105.00 30.45 8,050.23 12.266 Cenlre Distance Pass - 11,300.00 60.46 11,30000 3029 11,318.51 2.038 Clearance Fehr Pass - 11.400.00 52.78 11,400770 30.37 11,418101 2.108 Ellipse Salamanca PasS- 9,753.10 939.04 9,253.10 245112 10,012.28 4.640 Centre Distance Pass - 10,025.00 946.65 10,875.00 736.11 11,119.45 4.4% Ellipse Sepaation Pass - 11,700.00 921.60 11,700.00 232.53 11,969.00 4.022 Clears. Factor Pass - 7,250.00 994,62 7,250.00 832.82 2,810.00 6149 Clearance Factor Pass - 11150.5 948.93 11,15000 733.04 11,403.78 4.395 Centre Distance Pass - 11,200.00 9411.44 11,20000 73268 11,453]7 4.380 Ellipse Separation Pass - 11700.00 97566 11,700.5 749.97 11,950.51 4.323 Canaan. Factor Pass - 12,37765 1,329.23 12,377.65 1,152.18 8,22]00 6.211 Claiance Factor Pass - 12,377.65 898.17 12,322.65 652.02 2,462.63 3,649 Cleansnce Faciar Pass - 12,37765 898.17 12,377.65 652.39 7,468.B3 3.654 Clearance, Factor Pass - 12,377S5 898.17 12,377.65 65224 7,468.83 3.652 Comerms Factor Pass - 12.322.65 898.17 12,372.65 652.54 2,468.83 3,657 Clearer. Factor Pass - 25 June, 2019 . 17:13 Page 2 of5 COMPASS HALLIBURTON Anticollision Report for Plan: MPU E-39 - E -39L1 wp63 Survov tool oroorem Fra. To SurveylPlan Survay Tool Iusfo lu¢RI 26.50 550.00 2_GymNS-GC_Dnll collar 550.00 7,750002_MWD+IFR2+MS+Sag 7,750.00 8,0,10.00 E-39Lt wp03 2—MWD InterpAv+Sag Ismail 12,377.65 E39Lt wp03 2MWD+IFR2+MS+Sag Ellipse smar terms are correlated acmes survey bol fie -on points. Calculated ellipses incorparete surface errors. Separation is the actual distance between elllpsoids. Distance Between causes is the might line distance been wellbore centres. Clearance Factor= Distance B.hasen Profiles I (Distance Between Profilea - Ellipse Separation). All stafian coordinates were wicolaled using the Minimum Curvature memod. Hilcorp Alaska, LLC Milne Point 25 June, 2019 _ 17:13 Page 3 af5 COMPASS MALI.IBURTON r Project: Milne REFERENCE INFORMATION WTII. OET.NSFI WUEl9 NAn 1921INA ONICOVN$I pMhab.. PtE Site: MPtEPa� °^^^'^10'al1"°nw.. ww RM: wuau.9•.NeM 9o..ry o.rnrna Well: Plan: MPUE-39 E-39 1xN+r(rwlwnroo.: amlm nr(B®W.]exRllvrvnwhwl uw^d l�v.c v.10 ue.,•.e own Ruew� R,.em ala ase52onnl I .an +rr.w N„m,„ t�6rn,e• Wellbore: MPU EJ9L1 ^aan LebPi°•'"°"e0'-L"'"'Nn C1rva°"8 a99 oW W166t1.i+ sw±9l.0 1a•±>1E21oN 149°2s4cxw 4"'1 Plan: E-391-1 wPB3 SURVEY PROGRAM w NO GLOBAL FILTER: Uay uwr cefirod selection 6 ]JUH, N. Oepifi Frcm Cepa To SurveWPMn TOG EM ]]SO.W To 123]].65 CASING DETAILS IB 50 5'XW MPII E.t99¢0i 2_Gy ...DIM.. Ladder/S.F. Plots X00 ]150X0 MW EIM vRa? 2MWD+IFR2+Ms+$W ND TVDSs MD Size Name 4231.29 418309 1150.00 95/8 9Sm. TOW ]]50.00 S0W.00 LO9L1 wg1] W. Ed9L1) 2_1AW0I.M AG+S=2 SOaO.W 43]]25 E59LI nyp3(MW E -39L1) 2 MWDNFR2+MS+Se9 W ILM 4123.60 123]).65 4-1a 412'18 IM 180.00 X150 00 N 1 o m120 00 ( I — 1 ' O I r C 90X0 W N MRU E49 ] PU E wy07 ao 6040 1-- MPI Ea9 wp0 MPU I=a9 p0] v,07) U MPU E-39 1 8 al I I c 30.00 I U I r 0.00 I 7200 ]500 )800 8100 0400 8700 9000 9300 9600 9900 10200 10500 10800 11100 11400 11700 12WO 12300 12600 Measured Depth (600 usR/In) 4.00 u IL I i r 3.00 O r n Collision Risk Procedures Req. 2.00 Collision Avoidance Req I i i No-Oo Zone -Stop Drill 1 J I NOERRORS ', D.Do 7200 7500 7800 8100 8400 8700 9000 9300 9600 9900 10200 10500 10800 11100 11400 11 70D 12000 12300 12600 Measured Depth (600 U in) WELL PERMIT CHECKLIST Field & Pool MILNE POINT, SCHRADER BLFF OIL- 525140 Well Name: MILNE PT UNIT E-391_1 Program SER___ __ __ _ Well bore seg ❑ I PTD#:2190990 Company Hilcorp.Alaska_LLC Initial Class/ Type _. SER / PEND GeoArea 890 Unit 11328 On/Off Shore On _ Annular Disposal ❑ Geologic 2 Lease number appropriate.... ...... ..... ... _ _ Yes Commissioner: Date: 3 Unique well. name and number _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes ! e f - 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 appropriate bond in force _ _ _ _ _ _ _ _ Yes 11 Permit can be issued without conservation order.. _ _ _ _ _ ........ Yes Appr Date 12 Permit can be issued without administrative_ approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ 13 Can permit be approved before 15 -day wail ... ..... ...... ... Yes DLB 7/12/2019 14 Well located within area and. strata authorized by Injection Order # (put 10# in comments)_ (For. Yes Area Injection Order No. 10-B 15 All wells within 1/4 mile area. of review identified (For service well only)_ _ .. _ ... Yes ............ . 16 Pre -produced injector; duralionof pre -production less than. 3 months, (For service well only) Yes 17 Nonconven, gas conforms to AS31.05.030Q..1.A),0 2.A -D) . . . . . ... . . ......... NA.. X18 Conductor string. provided ... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ NA This lateral is in.zone targeting SB. CA sands from parent well �. Engineering 19 Surface casing. protects all.known USDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA.... Parent well surface casing will be fully cemented 20 CMT vol adequate to circulate on conductor & surf csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA..... This lateral is in zone targeting SB OA sands from parent well _ i21 CMT vol adequate to tie-in long string to surf csg...................... NA _ _ ........ . 22 CMT. will coverall known, productive horizons_ _ _ _ _ _ _ _ _ _ Yes Exit from fully cemented. surface casing in zone, swell packer completion in reservoir 23 Casing designs adequate for C,.T, B & permafrost.. _ _ _ _ _ _ Yes 24 Adequate tankage. or reserve pit _ _ _ _ _ _ Yes _ _ Innovation Rig Ongoing operations after drilling parent lateral 25 If a re -drill has. a 10-403 for abandonment been approved NA _ New grassroots well. 26 Adequate wellbore separation proposed _ _ _ ....... Yes ... Wellpath passes all Hilcorp separation criteria 27 If diverter required, does it meet regulations. _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA Drilling production holo only Appr Date 28 Drilling fluid program schematic & equip list adequate _ ... _ .... _ _ Yes All fluids overbalanced to reservoir...... _ .29 BOPEs, do they meet regulation _ _ _ .. ........ _ Yes 5M 13-5/8" 3 ram, 1 annular stack.. 30 BOPE press rating appropriate; test to (put psig in comments)_ _ _ _ _ _ Yes 5M stack, tested to 30Wpsi... . 31 Choke manifold complies w/API RP -53 (May 84) _ _ _ _ _ _ _ _ Yes 32 Work will occur without operation shutdown _ _ .......... .. Yes Innovation is ongoing operations with good truck support I33 Is presence of H2S gas probable _ . No .. .. .. 34 Mechanical condition of wells within AOR verified (For service well only) _ _ _ _ . _ _ Yes X35 Permit can be issued w/o hydrogen sulfide measures _ _ _ _ _ _ _ _ Yes _ _ _ _ H2S not anticipated from drilling of offset wells; however, rig will have H2S sensors and alarms._ _ Geology 36 Data. presented on potential overpressure zones ... _ . . . ............ Yes ..... Appr Date 37 Seismic analysis of shallow gas zones _ .................... .... NA DLB 7/12/2019 38 y ............................ Seabed condition survey (if off -shore) ..... NA... ______ __.. __.._....... _... 39 Contact name/phone for weekly_ progress reports [exploratory only] .............. NA. Geologic Engineering Public Commissioner: Date: Commissi ner: Date Date Commissioner D?S 7 ! e f -
