Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
219-091
DATA SUBMITTAL COMPLIANCE REPORT 10/14/2019 Permit to Drill 2190910 Well Name/No. MILNE PT UNIT E -42L1 Operator Hilcorp Alaska LLC MO 11875 TVD 4143 Completion Date 7/8/2019 Completion Status 1 -OIL Current Status 1 -OIL REQUIRED INFORMATION Mud Log No I/ Samples Nov/� DATA INFORMATION List of Logs Obtained: ROP/ABG/OGR/EWR/ADR 2"15' MD ... ABG/DGR/EWR/ADR 2"/5" TVD Well Log Information: Logi Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH ED C 31013 Digital Data 105 11875 ED C 31013 Digital Data ED C 31013 Digital Data ED C 31013 Digital Data ED C 31013 Digital Data ED C 31013 Digital Data ED C 31013 Digital Data ED C 31013 Digital Data ED C 31013 Digital Data ED C 31013 Digital Data ED C 31013 Digital Data ED C 31013 Digital Data ED C 31013 Digital Data ED C 31013 Digital Data ED C 31013 Digital Data ED C 31013 Digital Data ED C 31013 Digital Data Log 7/19/2019 31013 Log Header Scans 7800 11837 0 0 API No. 50.029-23635-60-00 UIC No Directional Survey Yes (from Master Well Data/Logs) Received Comments _ 7/19/2019 Electronic Data Set, Filename: MPU E-421-2 AOGCC Pagel oft Monday, October 14, 2019 DGR ABG EWR ADR.las 7/19/2019 Electronic Data Set, Filename: MPU E-421-1 ADR Quadrants All Curves.las 7/19/2019 Electronic File: MPU E-421-1 LWD Final MD.cgm 7/19/2019 Electronic File: MPU E-421-1 LWD Final TVD.cgm 7/19/2019 Electronic File: MPU E-421-1 - Definitive Survey.txt 7/19/2019 Electronic File: MPU E421.1 - Definitive Survey_Signed.pdf 7/19/2019 Electronic File: MPU E-4211 - GIS.txt 7/19/2019 Electronic File: MPU E-421-1 Actual - Plan.pdf 7/19/2019 Electronic File: MPU E-421-1 Actual - VSect.pdf 7/19/2019 Electronic File: MPU E-4211 LWD Final MO.emf 7/19/2019 Electronic File: MPU E421-1 LWD Final TVD.emf 7/19/2019 Electronic File: MPU E4211 Geosteering.dlis 7/19/2019 Electronic File: MPU E-021-1 Geosteering.ver 7/19/2019 Electronic File: MPU E-421-1 LWD Final MD.pdf 7/19/2019 Electronic File: MPU E-421-1 LWD Final TVD.pdf 7/19/2019 Electronic File: MPU E-421-1 LWD Final MD.tif 7/19/2019 Electronic File: MPU E-421-1 LWD Final TVD.tif 2190910 MILNE PT UNIT E-421-1 LOG HEADERS AOGCC Pagel oft Monday, October 14, 2019 DATA SUBMITTAL COMPLIANCE REPORT 10/14/2019 Permit to Drill 2190910 Well Name/No. MILNE PT UNIT E -42L1 Operator Hilcorp Alaska LLC MD 11875 TVD 4143 Completion Date 7/8/2019 Completion Status 1 -OIL Current Status 1 -OIL Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report O Production Test Information NA Geologic Markers/Tops LJ COMPLIANCE HISTORY Completion Date: 7/8/2019 Release Date: 6/18/2019 Description Comments: API No. 50-029-23635-60-00 UIC No Directional / Inclination Data Mud Logs, Image Files, Digital Data Y! fA Core Chips Y / Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files O Core Photographs Y / Daily Operations Summary Y� Cuttings Samples Y I pn / Laboratory Analyses Y /4 Date Comments Compliance Reviews y: _ AOGCC Page 2 of 2 Monday, October 14, 2019 ::qa iPw R.d' 'A V , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOCA 1a. Well Status: Oil 0 Gas SPLUG ❑ Other ❑ Abandoned ❑ Suspended L] 20AAC 25.105 20AAc 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: _ 1 1b. Well Class: Development Q Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or Abend'7/8/2019 14. Permit to Drill Number / Sundry: 219-091 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: June 28, 2019 15. API Number: 50-029-23635-60-00 4a. Location of Well (Governmental Section): Surface: 3704' FSL, 2008' FEL, Sec 25, T13N, R1oE, UM, AK Top of Productive Interval: 2068' FNL, 1380' FWL, Sec 36, T13N, R10E, UM, AK Total Depth: 582' FNL, 455' FWL, Sec 6, T1 2N, R11 E, UM, AK 8. Date TO Reached: July 1, 2019 • 16. Well Name and Number: MPU E-421_1 9. Ref Elevations: KB: 48.4' GL: 21.5' BF: 21.5' 17. Field / Pool(s): Milne Point Field Schrader Bluff Oil Pool ' 10. Plug Back Depth MD/TVD: 11,875' MD / 4,143' TVD 18. Property Designation: ADL025518, ADLO 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 569137 y- 6016241 Zone- 4 TPI: x- 567301 y- 6010452 Zone- 4 Total Depth: x- 566406 y- 6006650 Zone- 4 11. Total Depth MDf VD: • 11,875' MD / 4,143' TVD 19, DNR Approval Number: LONS 94-017 12. SSSV Depth MD/ VD: N/A 20. Thickness of Permafrost MDITVD: 2,154' MD / 1,778' TVD 5. Directional or Inclination Survey: Yes L4J (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 7,805' MD / 4,291' 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 ROP/ABG/DGR/EWR/ADR 2"/5" MD ABG/DGR/EWR/ADR 2"/5'• TVD 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 4-1/2" 13.5# L-80 7,795' 11,851' 4,289' 4,144' 8-1/2" Cementless PreDrilled Liner 24. Open to production or injection? Yes El No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Pend): 4-1/2" PreDrilled Liner 76 holes/ft run on 7/5/19 7,958' - 11,813' MD / 4,31 V- 4,147' TVD COMPLETION �- SALTt VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 2-7/8" 7,666' MD N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 7/21/2019 Method of Operation (Flowing, gas lift, etc.): ESP Date of Test: 7/25/2019 Hours Tested: 24 Production for Test Period Oil -Bbl: 1522 Gas -MCF: 1057 Water -Bbl: 95 Choke Size: N/A Gas -Oil Ratio: 694 Flow Tubing Press. 213 Casing Press: 250 Calculated 24 -Hour Rate .J. Oil -Bbl: 1522 Gas -MCF: 1057 Water -Bbl: 95 Oil Gravity-API(corr): 18 Form 10-407 Revised 5/2017 CONTINUED ON PAG 2 Submit ORIGINAL on z� �9 �o/�f RBDMS AUG 1 2 2019 A� I 28. CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base 2,154' 1,778' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval SB OA 7,958' 4,310' information, including reports, per 20 AAC 25.071. SB OA 7,910' 4,307' Formation at total depth: 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: Cdlrl er hilcor .conn Authorized Contact Phone: 777-8389 Signature: — Date: $ • �. INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 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 Milne Point Unit Well: MPU E-42& L1 Schematic Last Completed: Hilcoro Alsake,LLC PTD: 219-082 & 219-091 WELLHEAD Wellhead I FMC Gen5 Cing. KB Elev.: 48.4'/ Cing. GL Elev.: 215' OPEN HOLE / CEMENT DETAIL WELL INCLINATION DETAIL ,cticset I cmt in 42" Hole KOP @ 350' MD sx / T -400 sx Max Wellbore Angle = 92.4 deg @ 8,386' MD sx/ T - 270 sx TD=11,950' (MD) / TD=4,223'(TVD) PBTD =11,945' (MD) / PBTD = 4,223(TVD) CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 215/X-42/Welded N/A Surface 107' 9-5/8" Surface 40/L-80/TV 8.835 Surface 8,311' 7-5/8" Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 7,769' 8 Liner "OA" Upper Tandem Seal: GSB3DB H6 SB/AB PFSA 9 7,629' Lower Tandem Seal: GSB3DB H65B/AB PFSA 4-1/2" Predrilled w/ 13.5 / L-80 / Hyd 625 3.920 7,795' 11,852' 12 76 holes/ft Centralizer: Bottom @ 7,666' 13 7,769' Sealbore Receptacle (ID=6,00") 14 Liner "OB" 7"x9-5/8" SLZXP Liner Top Packer 15 7,795' OA Lateral LEM to (Lateral Entry Module) (I13=3,68") 4-1/2" Predrilled w/ 13.5 / L-80 / Hyd 625 3.920 7,852' 11,960' 18 76 holes/ft 7"x9-5/8" MLZXP Liner Hanger Packer w/ Sealbore Receptacle (ID=4.75") TOL 19 7,884' Bottom of locator seal assembly(ID=3.875") TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 1 2.441 1 Surface 1 7,666' JEWELRY DETAIL No Depth Item 1 128' ST 2: 2-7/8" GLM w/ 1" DPSOV BK Latch 2 7,414' ST 1: 2-7/8" GLM w/ DV, BK Latch 3 7,534' 2-7/8" XN Profile - 2.205" No -Go 4 7,586' Discharge Head: PMP 400P 5 7,587' Pump: 538PMSXD 93 Flex47 HS 6 7,609' Pump: 538PMSXD 20 H6 7 7,619' Gas Separator: Gas Avoider 538GS 8 7,622' Upper Tandem Seal: GSB3DB H6 SB/AB PFSA 9 7,629' Lower Tandem Seal: GSB3DB H65B/AB PFSA 10 7,636' Motor: 562 XP- 400Hp/ 2,785V/ 88A 11 7,661' Sensor: Zenith 12 7,664' Centralizer: Bottom @ 7,666' 13 7,769' Sealbore Receptacle (ID=6,00") 14 7,761' 7"x9-5/8" SLZXP Liner Top Packer 15 7,795' OA Lateral LEM to (Lateral Entry Module) (I13=3,68") 16 7,795' 7x9-5/8" RAM Hanger (Lateral Drift ID=5.960")(Mainbore Drift ID=3.688") TOL 17 7,799' 4-1/2"x9-5/8" RAM Sealbore Diverter(SBD)(Sealbore ID=3.68") 18 7,852' 7"x9-5/8" MLZXP Liner Hanger Packer w/ Sealbore Receptacle (ID=4.75") TOL 19 7,884' Bottom of locator seal assembly(ID=3.875") 20 11,927' OB Lateral 4-1/2" Drillable Packoff Sub 21 11,959' OB Lateral 4-1/2" WIV Valve LTC BXB (1" Ball on Seat/Closed) LATERAL WINDOW DETAIL Top of "OA" Window @ 7,805' MD; Bottom @ 7,822' MD; Angle @ top of window is 79 deg GENERAL WELL INFO API: 50-029-23635-00-00 & 50-029-23635-60-00 Drilled and Completed by Innovation Rig -7/8/19 Revised By: GD 8/6/2019 Hilcorp Energy Company Composite Report Spud Date: Job Name: 1912791D MPU E -42L1 Drilling Contractor AFE #: AFE $: Activity OAtE... Ops s4mmafy 6/27/2019 Continue TIH w/ 2-3/8" inner string on 5" drill pipe F/ 10.418'- T/ 11 900' MD. 143k PIU, 88k 5/O.;Displace 4.5" liner from 9# mud to 9.2 brine. 230 gpm, 2800 psi w/ 34% flow. Circulate 90 bbls total.;POOH F/ 11,900' - T/ 7865' MD racking back 5" drill pipe. Hole took proper displacement.;Displace out 9.2 brine back to 9# Baradril drilling fluid F/ liner top to surface. Circulate (Rot 15 rpm) and flush orientation lug on MLZXP at max rate 7 bpm, 3280 psi. Pumped 45 hi vis spacer, displaced w/ 629 bbis 9# Baradril "N" mud. 105k up, 89k do (pumps on).;POOH racking back 5" drill pipe F/ 7866- T/ 4058' MD.;PJSM, R/U Weatherford casing equipment, tongs, elevators and slips. POOH laying down 2-318" inner string assy F/ 4058' - T/ surface. Ready 5" safety joint and stage in shed. No Iosses.;PJSM Break down MWD X/O's. Clean and clear rig floor of Weatherford tools and Equip.;PJSM for P/U WU Whipstock. Load tools in Pipe Shed, M/U 7 318" MLHR Drilling anchor snaps in at 5K snaps out at 40K, 5" Pup, 7 1/2" Sleeve Packoff, 61/8" Ext, 6 3/8" Safety Disconnect set 120K, 6 3/8" Unloader, 8 3/8" String Magri 3/8" Blank Sub, 6 3/8" Drain Sub, 6 3/8" Debris Sub.;Whipstock 5.88'to key slot and 17' slide, 8 1/2 Window Mill, 8 3/8" Lower Mill, 4 7/8" Flex Joint, 8 1/2 Upper Mill, 1 jnt 5" HWDP, DM Collar, TM Collar, Float Sub, 2 as NM FC, Float Sub and 2 5" HWDP Total length 260.86'. Orientated Anchor to Whipstock and Whipstock to DM ROF 459/674= 245.16'.;Conl RIH W/ 5" D.P. F/ Derrick F/ 260' to 2,165' MD. Shallow hole test at 572' MD 400 GPM, 560 PSI, good. P/U 72K, SLK 62K;Hauled 0 balls Fluid to MP G&I total = 0 bbls Hauled 0 bbls H2O from A -Pad reserve total = 0 bbis Hauled 0 bbis H2O from L -Lake total = 0 bbis Hauled 130 bbis H2O from B -Pad Creek total = 130 bbis Lost 0 bbis to formation Total fluid lost production = 0 bbls 6/28/2019 Cont RIH W/5" D.P. F/ Derrick F12,166 - T/ 7,828' MD. 141 k up, 93k do (no pumps). 60 fpm max running speed. Easy on/off slips.;Wash down F/7828 slowly allowing for multiple toolfaces of 9° Right. Obtain parameters w/ pumps - 145k up, 96k dn, 9 bpm, 875 psi. Wash down and lag @7864'(12.4 swallow to helix) putting TOL @ 7852' MD. Observed TF walk left from 9"R to final TF of 30" LOHS.;Set do 10k in 5k increments. P/U 10k over indicating good latch w/ anchor. Set do 30k string wt, observed whipstock shear. P/U after shear 140k clean (lost 5k up wt). TOW @ 7805' MD, BOW @ 7822' MD.;PJSM F/ 7,805'to 7,809' MD Mill window as per Baker Rep onsite. 400 GPM, 920 PSI, 80 RPM, free TRQ 11K, TRQ 15-18K, PIU 140K, SLK 98K, ROT 117K. Cont milling window F/ 7,809' to 7,822'450 GPM, 1,120 PSI, 100 RPM, TRQ 14-18K, WOB SK.;Cont. milling and making new hole F/ 7,822' to 7,845' MD 450 GPM, 1,200 PSI, 100 RPM, TRQ 15K, WOB 12K.;Pump 40 bbls Hi Vis Sweep at 525 GPM, 1,500 PSI, 100 RPM, TRQ 15K while working milling Assy through window. Sweep came back on time W/ 10% increase sand and clay, no increase of metal. Reamed through window 6X during pumping sweep.;Shut down rotary and worked string through 2X 525 GPM, 1,500 PSI PIU 152K, SLK 91 K with 3K dreg. Worked through window 2X at 84 GPM, 190 PSI, P/U 156K W/ 2K drag and SLK 94K W/ 4K drag. Was able to collect about 175# of metal during milling.;PJSM UD working single and rack back 1 stand of 5" D.P. to 7,769 MD (4,299' TVD) Flush Choke and lines. R/U test Equip. Close Upper Pipe Rams and perform FIT to 12 ppg EMW 659 PSI W/ 9.05 ppg MW. Pumped 2 bbis, bled back 1.5 bbls.;PJSM Cut 100'16 wraps of drilling line. Check brake air gap, good.;PJSM Grease Crown and Blocks. Service rig. SIMOPS New crew perform hazard hunt.;PJSM POOH 5" D.P. on Elevators W/Milling BHA F/ 7,769' to 1,300' MD . UD 1 bad joint of 5" D.P. Calc. disp 48 bbls, acutal 54 bbls.;Hauled 117 bbis Fluid to MP G&I total = 838 bbis Hauled 0 bible H2O from A -Pad reserve total = 0 bbis Hauled 0 bbls H2O from L -Lake total = 0 bbis Hauled 0 bbis H2O from B -Pad Creek total = 0 bbis Lost 0 bbis to formation Total fluid lost production = 0 bbis 6/29/2019 Stand back flex DC's. B/O and UD Baker mills. Starter mill 1/3" under gauge and upper mill still full gauge. Stripped magnets, captured a total of 190 lbs metal for milling operations. Clean and clear rig floor.;M/U Johnny whacker and flush BOP equipment. Flush choke and kill lines while flushing stack. B/O and UD same.;M/U 8.5" Smith Milltooth w/ 1.5' Mtr easy. M/U MWD and scribe same (346/676x360=184.26" RFO). Shallow pulse test (test good) 450 gpm.;Trip in w/ 8.5" drilling assy F/ 243'- T/ 7683' MD on 5" dp out of derrick. Fill pipe every 2500' MD. 165k up, 92k dn. Line up choke and stack for drilling operations.;Obtain parameters and orient 30L TF. 450 gpm, 1400 psi, 56% flow. 165k up, 92k dn. Trip thru window clean. Establish parameters once bit/mtr cleared window, 450 gpm, 1510 psi, 51 % flow.;Rot & slide ahead F/ 7845'- T/ 8,126' w/ mtr easy 450 gpm, 1,400 psi, 56% How, 30 rpm, trq 14-16k, wob 15k. Gain 9.08" and 31' of separation from mainbore. 92.64" Inc, 189.07" Azm. SPR at 8,12T MD (4,311' TVD) 9.0 ppg MW. MP #1 32-227, 48-284. MP #2 32- 226, 48-286.;Rot and reciprocate F/ 8,126' to 8,067' MD CBU 500 GPM, 1,660 PSI, 100 RPM, TRQ 16K, RF 53%, Max Gas 1,721 U. Monitor well for 10 Min, static.;PJSM Orientate motor to 18" L TF. POOH on elevators W/ 5" D.P. F/ 8,127' to 7,747' MD. P/U 160K, SLK 90K. Pulled through window clean.;Pump Dry Job. Cont POOH on elevators W/ 5" D.P. F/ 7,747' to 4,500' MD, P/U 160K, SLK 90K. Calc Disp 38 bbis, actual 43 bbls, lost 5 bbls.;PJSM POOH on elevators W/ 5" D.P. F/ 4,500' to 243' MD. Calc Disp 29.5 bible, actual 32.5 bbls, lost 3 bbls.;PJSM Rack back NM FC, 5" HWDP and Jars. UD 8.5" Tri Cone, 1.5" Mud Motor, TM and DM. Clean and clear rig floor of BHA components. Bk Grade 1-1-NO-A-E-I-NO-BHA.;PJSM P/U M/U RR 8%z'"' NOV SK616M-J7 D PDC, New Geo Pilot, 6'/." ADR/HCIM Collar, 6'/." DGR Collar, 6'/." PWD, 6'/." DM Collar and 6%' TM Collar to 83' MD. Download MWD tools.;Distance to WP6 = 5.92', 5,28' High, 2.68' Left Total Metal collected 20#, Total 210#.; Hauled 137 bbis Fluid to MP G&I total = 975 bbis Hauled 130 bbis H2O from A -Pad reserve total = 130 bbis Hauled 0 bbis H2O from L -Lake total = 0 bbls Hauled 0 bbis H2O from B -Pad Creek total =130 bbis Lost 0 bbis to formation Total fluid lost production = 0 bbis 6/3012019 Finish Downloading MWD. M/U Flex DC's, Jars w/ 3x HWDP. Install corrosion ring. Shallow pulse test MWD (test good).;PJSM RIH BHA 7 W/ 5" D.P. F/ 275'to 7,779' MD. Filling every 2,500'. Break in seals on Geo Pilot. P/U 155K, SLK 85K.;PJSM Service rig, Blocks, TO and Crown. C/O spinner joystick on drillers console.;PJSM Pull riser and install MPD RCD Bearing.;PJSM RIH F/ 7,779'to 7,842' MD. No issue going through window. Start MADPass F/ 7,842' to 8,125' MD. 450 GPM, 1,280 PSI, 80 RPM, TRQ 16K, P/U 152K, SLK 84K, ROT 114K. SPR at 7,902' MD (4,306' TVD) MW 9.15 ppg MP #1 32-229, 48-283 MP #2 32-225. 48-280.;PJSM Drill ahead 8.5" Hole F/8,129 to 8,990' MD ( 4,276' TVD) 865' total (144.2' AROP) 475 GPM, 1,460 PSI. 145 RPM, TRQ ON 18.5K, TRQ OFF 18K, WOB 101K, Max Gas 2,319U, ECD 10.65, MW 9.2 ppg. P/U 170K, SLK 66K, ROT 105K. Back ream 30' every connection.;SPR at 8,538' MD (4,301' TVD) MW 9.05. MP #1 32-285,48-334 MP #2 32-281, 48-332.;PJSM Drill ahead 8.5" Hole F/8,990' to 9,160' MD (4,264' TVD) 170' total (113.3' AROP) 455 GPM, 1,350 PSI. 145 RPM, TRQ ON 19.51K, TRO OFF 18K, WOB 8-14K, Max Gas 1,771U, ECD 10.5, MW 9.1 ppg. P/U 175K, SLK 68K„ ROT 105K. Back ream 30' every connection.;SPR at 9,052' MD (4,273' TVD) W/ 9.1 ppg MW. MP #1 32-265, 48-320 MP #2 32-265, 48-325.;At 9,160' MD Pump Press fell F/ 1,350 PSI to 730 PSI. Found GeoSpan PVR was not engaging. Swapped out to back up GeoSpan. Sent downlinks and back up GeoSpan was not working correctly, may due to wiring or air lines reversed. Swapped back to original GeoSpan and readjusted air regulalor.;Sent down links without issue. Calling to replace back up. Cont. drilling ahead.;PJSM Drill ahead 8.5" Hole F/9,160' to 9,385' MD ( 4,250' TVD) 225' total (99 AROP) 475 GPM, 1,435 PSI, 145 RPM, TRQ ON 19.31K, TRQ OFF 18K, WOB 8-15K, Max Gas 1,767U, ECD 10.5, MW 9.1 ppg. P/U 178K, SLK 62K„ ROT 105K. Back ream 30' every connection.; Distance to WP6 = 10.39', 6.32' High, 8.24' Left In zone. 7 concretions have been drilled so far for a total of 27' (1.9% of the lateral). Total Metal collected 40#, Total 250#.;Hauled 231 bbis Fluid to MP G&I total = 1,206 bbis Hauled 390 bbls H2O from A-Pad reserve total = 520 bbls Hauled 0 bbis H2O from L-Lake total = 0 bbis Hauled 0 bbis H2O from B-Pad Creek total =130 bbis Lost 4 btols to formation Total fluid lost production = 4 bbis 7/1/2019 Drill ahead 8.5" Hole F/9,385' to 10,199 MD, 814' total (136' AROP) 500 gpm, 1675 psi, 150 rpm, 22.3K tq on, 21k tq off, 10-15k wob, Max Gas 2051u, 10.8 ECD's, MW 9.1 ppg. P/U 210K, SLK 36K, ROT 101 K. Back ream 30' every connection.;Drill ahead 8.5" Hole F/10, 1 99'to 11,155' MD, 956' total (160' AROP) 480 gpm, 1620 psi on, 125 rpm, 24K tq on, 24.5k tq off, l Ok wob, Max Gas 1823u, 10.9 ECD's, MW 9.0 ppg. P/U 221K, SLK 36K, ROT 103K. Back ream 30' every connection.;Pump 10% lube pill (40 bbis) @ 10,326' MD. Saw 2k reduction in tq for next 120' but then returned to high tq (24k/125 rpm).;PJSM Drill ahead 8.5" Hole F/ 11,156to 11,875' MD (4,142' TVD) 720'total (120' AROP) 479 GPM, 1,610 PSI, 125 RPM, TRQ ON 27K, TRQ OFF 26K, WOB 15K, Max Gas 1,846U, ECD 10.87, MW 9.05 ppg. P/U 217K, SLK 35K, ROT 101K. Back ream 30' every connection.;Pump 10% 50 bbl Lube Pill at 11,515' MD saw 2K reduction on TRQ. At TO obtain final MWD survey and send GeoPllot to home position. SIMOPS Take Pit 5 of active and start cleaning for Brine. SLP @ 11,532' MD (4,159' TVD) MW 9.0. MP #1 32-385, 48-446 MP #2 32-381, 48-444.;PJSM Rot and Rec F/ 11,875'to 11,812' MD CBU 5X at 500 GPM, 1,690 PSI, 90 RPM, TRQ 19-21 K. Max Gas 1636U, ECD 10.6 ppg. P/U 171, SLK 47K, ROT 98K. SIMOPS Clean Pill Pits 1 & 2 and Pit 5 and take on 9.2 ppg Viscosified 3% Lube Brine. Stage Vac Trucks. Monitor well with MPD, no Press.;PJSM Rot & Rao F/ 11,875'to 11,812' MD Pump Chem train pills (3 ea 35 bbis Sapp Pills W/ 35 bbls Brine in between) Chase W/ 9.2 ppg Viscosified 3" Lube Brine at 420 GPM, 1,090 PSI, 80 RPM, TRQ 18.51K, ECD 10.3 ppg. Max Gas 172U.; Distance to WP6 = 19.26, 19.19' High, 1.69 Left In zone. 27 concretions were drilled for a total footage of 111' (2.7%) of the OA-lateral. Total Metal collected 3011, Total 345#.; Hauled 1,096 bbis Fluid to MP G&I total = 2,302 bbls Hauled 910 bbis H2O from A-Pad reserve total = 1,430 bbis Hauled 0 bbis H2O from L-Lake total = 0 bbis Hauled 0 bbls H2O from B-Pad Creek total =130 bbis Lost 4 tools to formation Total fluid lost production = 4 bbis 7/2/2019 Cont. chasing 3 Sapp pills W/9.2 ppg Viscosified 3" Lube Brine. Rot & Rao F/ 11,875'to 11,812' MD. 510 GPM, 1,375 PSI, 80 RPM, TRQ 15K, ECD 10.2 ppg, Max Gas 32U. P/U Parameters prior to CBU P/U 217K, SLK 36K, ROT 101K, After CBU 5X P/U 171K, SLK 47K, ROT 98K.;After displacement to 9.2 ppg Viscosified 3% Lube Brine P/U 147K, 75K, ROT 103K. Lost 40 bbis during Disp.;SPR @ 11,875' MD (4,142' TVD) W/ 9.2 ppg MW. MP #1 32-265, 48- 315 MP #2 32-265, 48-320.;PJSM BROOH F/ 11,785' to 9,752' MD 500 GPM, 1,265 PSI, 120 RPM, 9K TRQ, ECD 10.3 ppg, Max Gas 27U.. Pull speed 40- 60 ft/min. P/U 140, SLK 76K, ROT 108K. Calc Disp 23 bbls, actual 44 bbis. Lost 21 bbls.;PJSM BROOH F/ 9,752' to 8,097' MD 500 GPM, 1,200 PSI, 120 RPM, 8K TRQ, ECD 10.0 ppg, Max Gas 44U.. Pull speed 40-60 ft/min. P/U 150, SLK 97K, ROT 103K. Calc Disp 8 bbis, actual 33 bbls. Lost 25 bbls.;POOH on elevators F/ 8,097'to 7,779' MD. Went through window with issue. P/U 150K, SLK 97K. Lost 5 bbls.;PJSM Pump 40 bbis, 300 Vis sweep, came back on time W/ 25% increase of sand at Shakers. 500 GPM, 1,200 PSI, 80 RPM, 7K TRQ. Lost 15 bbls.;PJSM Remove RCD and install trip nipple. Recenter Stack. Static loss 10 BPH.;Pump Dry Job and blow down TD. Lost 5 bbls.;PJSM POOH on elevators F/ 7,779' to 4,467' MD. P/U 133K, SLK 105K.;PJSM UD 5" D.P. to Pipe shed F/ 4,46T to 275' MD. P/U 103K, SLK 88K. Calc Disp 62 tools, actual 78 bbls. Lost for trip 16 bbls.;PJSM UD 5" HWDP, Jars, Float Subs and start down loading MWD tools.;PJSM Cont. down loading MWD tools. UD TM, DM, DGR, Geo Pilot, Bit Sleeve and 8.5" Bit. Bit Grade 2-2-CT-A-X-I-BT-TD. Clear rig floor of components.;PJSM Service rig. Grease Crown, TD, Blocks and traveling Equip. Static loss rate 2.5 bph.;PJSM P/U M/U Whipstock retrieval BHA Whipstock Hook, lea 5" HWDP, 6 1/4" Oil Jars, 6 3/4" OM Collar, 6 3/4" TM Collar and Float Sub 73.19' as per Baker Rep onsite. Orientate hook 180° of high side. RFO 150+655=82.4". RIH W/ 5" D.P. to 188' MD and shallow hole test MWD.;PJSM RIH Whipstock BHA on 5" D.P. F/ 188' to 2,746' MD. Filling pipe every 2,500'. P/U 102K, SLK 67K. Clac Disp 18 bols, actual 15 bbis, Lost 3 bbls.;Hauled 1,933 bbls Fluid to MP G&I total = 4,235 bbis Hauled 260 bbls H2O from A-Pad reserve total = 1,690 bbis Hauled 0 bbis H2O from L-Lake total = 0 bbis Hauled 0 bbis H2O from B-Pad Creek total =130 bbis Lost 136 tools to formation Total fluid lost production = 136 bbis Total Metal: 345# 7/3/2019 Continue TIH with Whip Stock Retrieval BHA f/2746'to 7815'. Fill pipe every 2500'. PUW 140K, SOW 104K Lost 11 bbls on TIH.;Odent Wash port 150 deg Right on MWD/Retrieval tool to Whip Stock Key Hole Slot and wash Key Hole @ 550 gpm working pipe slow across Key Hole Slot.;Orient Whip Stock Hook to Key Way. Set 10k down on Key Way @ 7811'. PUH to 7807 to 180K (40k over pull) See weight fall off to normal PUW. PUH 30' with no drag/over pulls. Set back Down 10k, PUH to 170K (30K over pull) See wt fall off to PUW, PUH 30' again with no Drag.;Orient wash port to Key Way and wash key way slot again.;Continue fish Whip Stock. Locate Hook with Key Way. PUH and engage Key Way see 15-20k over pull. PUH 30' with 8-12k drag. POOH W/ Whip Stock.;PJSM, Pump Dry Job. Drop 2.375" rabbit down string. POOH W/ Whipstock 7,815' to BHA. No down ward motion, pulling speed 90 ft/min. Calc Disp 62 bbls, actual 80 bbis. Lost 18 bbls.;PJSMfor UD Whipstock. As per Baker Rep onsite. UD Hook , Jars and MWD tools. Set Hadler over Whipstock slide. UD Whipstock components. Retrieved about 20# of metal from Magnet. Slide showed minimal wear on center of ramp and very little wear on edges of ramp.;PJSM Service Rig. Grease Crown, Blocks, TD and traveling Equip.;PJSM P/U Seal Bore Diverter and flow test for release of FJD tool W/ TD as per Baker Rep, 450 GPM, 700 PSI tool released. 400 GPM, 555 PSI tool stayed engaged. Confirmed flow rates W/ Sperry MWD for flow detection. UD Seal Bore Diverter.;PJSM Rig down 5" Elevators. P/U Weatherford Power Tongs. Static loss rate about 1.5 BPH.;PJSM P/U WU RAM ML Anchor, 3.563" Camco OSDB Nipple and Seal Bore Diverter W/ FJD running tool as per Baker Rep onsite. M/U 4.5" IBT connections and BakerLoc. Weatherford. M/U TRQ 4K. Double check orientation on tools to anchor and window opening.;P/U Sperry MWD and orientate to anchor. RFO 310 +676=165.09°. Total BHA 119.12'. RIH 2 stands of 5" D.P. to 242' MD. Shallow hole test MWD to 320 GPM, 520 PSI to achieve detection.;PJSM RIH W/ Diverter Seal Bore BHA W/ 5" D.P. F/ Derrick F/ 242' to 5,276' MD. P/U 102K, SLK 83K. Filling every 2,500' MD. Ensure not to exceed 400 GPM. Running speed 60 ft/min. Calc Disp 78 bbls, actual 73 bbis. Lost 5 bbis.; Hauled 0 bbls Fluid to MP G&I total = 4,235 bbis Hauled 260 bbls H2O from A -Pad reserve total = 1,950 bbis Hauled 0 bbls H2O from L -Lake total = 0 bbis Hauled 0 bola H2O from B -Pad Creek total =130 bbis Lost 117 bbis to formation Total fluid lost production = 253 bbis Total Metal: 345# 7/4/2019 RIH W/ Diverter Seal Bore BHA W/ 5" D.P. F/ Derrick F/ 5,276' to 7,845' MD. P/U 133K, SLK 102K. Filling every 2,500' MD. Ensure not to exceed 400 GPM. Running speed 60 ft/min. Calc Disp 21 bbis, actual 18 bbis. Lost 3 bbls.;PJSM Establish Circ at 390 GPM, 1,130 PSI. P/U 133K, SLK 103K. RIH W/ Sealbore Assy to 7,887.51' MD. Set down 30K, 25K over pull. Bring pump rate up to 5500 GPM, 1,700 PSI to unlatch from Sealbore Assy. Work string 3X to confirm orientation at 9' LOHS.;P/U and CBU. Top of Sealbore Diverter at 7,887.51' MD.;PJSM POOH F/ 7,799' to 7,751' MD. Slip and cut drilling line. (82' Cut) Check Brake gap and Dead man bolts. Grease Crown, Blocks, Spinners, Cobra Head, and check oil in TD. Check welds on cradle, good. Static loss rate 1.5 bph.;PJSM POOH W/ FJD Running Tool on 5" D.P. F/ 7,751' to 44' MD . P/U 136K, SLK 101 K. Calc Disp 65 bbls, actual 76 bbis. Lost 11 bbls. C/O Elevators F/ Hydraulic to Manual.;PJSM UD Float Sub, TM, DM and FJD Running Tool as per Baker Rep & Sperry onsite.;PJSM R/U Weatherford tools and Equip. M/U Safety Jnt and Triple Connect. C/O personnel for 4th of July BBQ. Static loss rate 1.5 bph.;PJSM RIH 4.5" 13.5# L-80 625 Wedge Pre Drilled Liner to 4,063' MD as per tally. Calc Disp 20 bbls, actual 14 bbls. Lost 6 bbis. Performed kick while tripping drill W/ safety Jnt, 4 min. P/U 68K, SLK 58K.;PJSM P/U 3.5" handling Equip. M/U RAM Hanger as per Baker Rep onsite. RIH W/ 1 stand 5" D.P. and Circ at 2 bpm, 80 PSI to ensure no obstructions. P/U 72K, SLK 62K.; PJSM RIH 4.5" Liner and RAM Hanger on 5" D.P. F/ 4,063'to 7,756' MD. Running speed 90 Rlmin. P/U 119K, SLK 90K.;Obtain parameters prior to going into open hole. 210 GPM, 435 PSI, 5 RPM 4.2K TRQ, 10 RPM 4.6K TRQ, 15 RPM 4.7K TRQ. Attempt to pass through window, set down 15K. Taking weight at 7,819 MD. ROT at 5 RPM, 2.5K TRQ pass through window without issue.; RIH 4.5" Liner and RAM Hanger on 5" D.P. F/ 7,756' to 11,851' MD. Running speed 90 ft/min. P/U 144K, SLK 92K. TOL at 7,794' MD.;Hauled 124 bola Fluid to MP G&I total = 4,359 bbis Hauled 130 bbls H2O from A -Pad reserve total = 2,080 bbls Hauled 0 bbis H2O from L -Lake total = 0 bbis Hauled 0 bbis H2O from B -Pad Creek total =130 bbis Lost 36 bbis to formation Total fluid lost production = 289 bbis Total Metal: 345# 7/5/2019 PJSM At 11,851.52' tag top of Seal Bore Diverter. PUW 144K, SOW 94K. Set Dn 20K, P/U in 10K increments ans unlatch @ 175K (31 K Over )run back in hole, set Dn 20K & confirm Depth. Pull to 163K to confirm Iatch.;Break out and Drop Baker Lite Phenolic 1" ball. Chase ball on seat @ 5 bpm slowing to 1.5 bpm. Ball seated on depth @ 2150 stks. Press up to 4450 psi w/test pump and unlatch from RAM Hgr Assy. PUH and back down to confirm Re entry into Main Bore. Tag out @ 7822'. PUH above RAM Top for displacement.;Dispalce well from Quick Drill Viso Brine to 9.2 ppg clean brine. 465 gpm/730 psi.;PJSM, Pump Dry Job, blow down TD. POOH on elevators (/7822' to surface. UD RAM Liner Running Tool.;PJSM Test BOPE S' and 2 7/8" Test Jnt 250 Psi low and 3,000 PSI high for 5 Min on chart. Choke Manifold 1-15 valaves, Upper and Lower VRBS 2 7/8" X 5.5" Rams, 5" Dart, FOV Upper and Lower IBOP, Kill and Choke HCR & Manual, Manual and Super Choke to 2,000 PSI,Hi and low PVT, 20 ppm H2S, 40% LEL.;Flow Paddle alarms. Pass fail on Blind Rams due to trapped air.;Koomey draw down initial Manifold 1,600 PSI, Acc 3,100 PSI, Annular 1,325 PSI, After function Man 1,375 PSI, Acc 1,550 PSI, Ann 1,325 PSI. 200 PSI increase 23 Sec, full 87 Sec. 6 bottle Nitrogen Avg 2,336 PSI. Witnessed waived by AOGCC Austin McLeod.;PJSM Break down test Equip. Blow down TD, Kill and Choke lines and Choke Manifold.;PJSM Service rig. Grease and inspect Crown, Blocks, Spinners and Top Drive.;PJSM P/U M/U LEM and SLZXP as per Baker Rep onsite. 72' MD. Lost 13 bbis for tour. Static loss about 1 bph.;PJSM RIH W/ LEM and SLZXP on 5" D.P. F/ 72' to TOL at 7,761' MD. P/U 137K, SLK 105K. Calc Disp 65.1 bbis, actual 65.1 bbis. lost 0 bbls.;Hauled 746 bbis Fluid to MP G&I total = 5,105 bbis Hauled 0 bbls H2O from A -Pad reserve total = 2,080 bbls Hauled 0 bbis H2O from L -Lake total = 0 bbls Hauled 0 bbis H2O from B -Pad Creek total =130 bbis Lost 20 bbls to formation Total fluid lost production = 309 bbis Total Metal: 3450 Hilcorp Energy Company Composite Report Well Name: MP E-421_1 Field: County/State: , Alaska (LAT/LONG): avation (RKB): API #: Spud Date: Job Name: 1912791C MPU E-421_1 Completion Contractor AFE #: AFE $: Activity Date Ops Summary _ 7/6/2019 Continue RIH with SLZXP/LEM on 5" DP, Tag top of RAM Liner Top @ 7822' MD_ PUW 137K, SOW105K. Set Dn 20K and P/U 10K over, work in and out x2 & confirm latch. Drop 1.375" Ball and Chase on seat at 5 bpm staging down to 1.5 bpm. W/ball on seat walk pressure up and see PKR set @ 2450 psi, shear neutralizer @ 3100 psi. Release from PKR @ 3500 psi. Blow ball seat @ 4150 psi. P/U and confirm Release.,PT Casing to top of PKR to 1500 psi on chart for 10 min. Good Test. P/U 50' to confirm release form PKR. New TOL @ 7761.50 -Monitor well, Well static. Pump 15 bbl slug and chase with FW to flush pipe. R/U Hawk Jaw. R/D Manual Elevators and R/U Hyd Elevators. POOH UD DP from 7721' to 4255' MD. Lost 3 bbls.,Continue to UD DP V4255 to surface. UD BOT SLZXP PKR running tool. Lost 6.6 bbls.,Drain Stack. Pull Wear bushing. R/D hawk Jaw 7 remove from floor. Remove BOT tools.,C/O Upper Pipe Rams f/VBR's to 7 5/8" Solid body.,PJSM R/U test Equip. M/U 7 5/8" test Jnt. Test Upper 7 518" Rams to 250 PSI low and 3,000 PSI high for 5 Min on chart. Good.,PJSM P/U M/U Weatherford tools and Equip. R/U Torque Turn.,PJSM M/U Tie Back Assy to 7.625" 29.79 L-80 W521 and RIH to 851' MD. Torque Turn set 10,100 fUlb. P/U 54K, SLK 54K. Calc Disp 8.6 bbls, actual 6.8 bbis. Lost 1.8 bbls.,PJSM RIH Tie Back Assy on 7.625" 29.7# L-80 W521 F/ 851' to 4,885' MD. Torque Turn set 10,100 %Ib. P/U 126K, SLK 105K. Calc Disp 51 bbis, actual 46 bbis. Lost 5 bbls.,Hauled 0 bbls Fluid to MP G&I total = 5,105 bbis Hauled 0 bbls H2O from A -Pad reserve total = 2,080 bbls Hauled 0 bbis H2O from L -Lake total = 0 bible Hauled 0 bbis H2O from B -Pad Creek total =130 bbls Lost 10 bbls to formation Total fluid lost production= 319 bbis Total Metal: 345# 7/7/2019 P/U and RIH w/ 7 5/8" Wedge 521, 29.7# L-80 casing f/ 4448'to 7763' MD (TOL). Lost 3 bbls.,Land on no go with Tag joint # 195, 18.50'in . Set down 10K verify tag. UD jts. 195, 194 & 193. M/U Space out pups (14.84')(14.86') and It 193 placing No -Go 3.38' off when landed. M/U Landing joint and Hanger. Land Hanger as per NOS Rep onsite, XO landing It to DP, M/U 5' DP Pup to landing It, M/U Top Drive. PUW 165K, SOW 115K.,Rig up to reverse circulate. Close bag and PT Annulus to 300 psi to ensure proper space out and seal engagement, strip up hole until pressure dumps, exposing seal ports to annulus. Using the Kill Line, Establish reverse circulation through ported seals with fluid from rig pits. Line up on and pump 100 bbls Corrosion inhibited 9.2 ppg KCL 5 bpm/480 psi, Line up on VAC Truck with DSL and Reverse in 60 able DSL 4 bpm/500.,chase surface lines with 10 bbis Brine. Strip in hole and land out Tie back seals Assy 3.38' off no go w/ Mule Shoe @ 7769'. (TOL @ 7763') PU/SO 165W115k. 82K on hanger.,Open lower annulus valve, Open bag, drain stack, R/D Reversing equipment, Pull & UD 7 5/8" landing joint, MU pack off running tool to It of 5" DP. Land and lest pack off to 500/5000 psi. 10 min ea. Rig up test pump. Test 9-5/8" x 7-5/8" annulus to 1000 psi for 30 minutes - good. Pumped 1 bbl, bled back 1 bbl. Rig down testing equipment.,Shut blinds. Bleed of accumulator. C/O UPR's from 7-518" SB to 2-7/6'4.5" VBR's. Re-energize accumulator.,Pick up 2-7/8" TJ. Set test plug. Rig up testing equipment. Test UPR's on 2-718" test joint 250/3000 psi. Had a leak on DS Ram Door. Tighten door. Pull test plug. UD test joint.,PJSM P/U R/U ESP and CAP Sheave. Pull ESP and 318" CAP through sheave to rig floor. Spot and plug in spooling unit. R/U Weatherford tools and Equip. P/U M/U Baker ESP 5.85" Centralizer, Motor Gauge (Zenith) and 562XP Motor 400 HP as per tally. Static loss rate 1.5 bph.,PJSM Cont. P/U Ml 5.13" Lower and Upper Tandem Seal, 5.38" Gas Separator, 538PMSXD Pump, 538PMSXD 93 Flex 47 HS Pump, Ported Discharge Head, Bolt on Discharge Head and 10'2 7/8" handling pup 90.51' MD. Attached Pothead to MTR Assy and Installed ESP cable.,Installed 3/8" CAP to Check Valve on Centralizer. Ran Discharge 1/4" Press line F/ Sensor and terminate at discharge port. Perform initial ESP continuity and press. reading test, good. MTR Clamp -4, Seal Clarri Pump Clamps.,PJSM RIH ESP Pump, ESP round Cable and 3/8" CAP line W/ 2 7/8" 6.5# L-80 EUE 8rd F/ 90.51' to 569' MD. XN between Jnt i & 2, GLM W/ Dummy Valve between Jnt 4 & 5. P/U 40K, SLK 40K. Install Cannon Clamps every Jnt for ESP and CAP. Weatherford TRQ to 2,300 ft/lb. Lost 6 bbis for tower.,Hauled 228 bbls Fluid to MP G&I total = 5,333 bbis Hauled 0 bible H2O from A -Pad reserve total = 2,080 bbls Hauled 0 bible H2O from L -Lake total = 0 bbls Hauled 0 bbis H2O from B -Pad Creek total =130 able Lost 12 bbis to formation Total fluid lost production = 331 bbls Total Metal: 345# 7/812019 PJSM RIH ESP Pump, ESP round Cable and 3/8" CAP line W/ 2 7/8"6.59 L-80 EUE 8rd F/ 569' to 2,155' MD. P/U 48K, SLK 45K. Install Cannon Clamps every Jnt for ESP and CAP. Weatherford TRQ to 2,300 ft/lb. Lost 6.5 bbis. At 725' MD pinched CAP line in TD Cradle during P/U Jnt. Spliced and tested CAP. Test ESP and CAP every 1,000'.,PJSM RIH ESP Pump, ESP round Cable and 3/8" CAP line W/ 2 7/8" 6.59 L-80 EUE 8rd F/ 2,159 to 7,637' MD. P/U 76K, SLK 58K. Install Cannon Clamps every other Jnt at 2,155' MD for ESP and CAP. Weatherford TRQ to 2,300 f 1lb. Lost 1.5 bbls. Fill 2 7/8', Test ESP and CAP every 2,000'.,WU GLM 1" Side Pocket KBMM W/ DPSOV between Jnts 245 & 246 as per tally. SIMOPS Fill in subsiding area around cellar box under Mat Boards.,PJSM At 7,637' P/U M/U Tubing Hanger W/ 2 7/8" landing joint. Baker terminate ESP and CAP lines. Splice penetrator plug to ESP cable. M/U CAP to Hanger penetration. Total Cannon Clamps = 162, Motor Clamps = 4, Deal Clamps = 4 and Pump Clamps 6. SIMOPS lower ESP and CAP line to Spooler.,PJSM Cont W/ ESP splice. Baker check continuity on ESP after installing to Penetrator. Drain stack and land hanger as per NOS Rep onsite. ESP at 7,666' MD. RILDS. Set BPV. Baker checked continuity on ESP after landing, good. P/U 73K, SLK 54K. Weight in Wellhead 19K.,PJSM UD running tools. Remove sheave from Derrick. Start flushing all surface llnes,TD and Stack. Start loading 5" D.P. in Pipe Shed.,PJSM N/D BOPE. Remove Riser, Choke and Kill Lines. Install RCD Plug. R/D Beyond hard lines. SIMOPS Start cleaning Pits. Cont loading 5" D.P.,Hauled 25 bbis Fluid to MP G&I total = 5,358 bbis Hauled 0 bbis H2O from A -Pad reserve total = 2,080 bbis Hauled 0 bbis H2O from L -Lake total = 0 bbls Hauled 0 bbis H2O from B -Pad Creek total =130 bbls Lost 14 bbls to formation Total fluid lost production = 345 able Total Metal: 3459 7/9/2019 Cont. to N/D BOPE. raise MPD rotating head with top drive. R/U bridge cranes. Remove safety chains. N/D and set BOP stack on stump. Lower rotating head. Remove DSA. Install tree flange and master valve. Test tubing void 500/5000 psi - good. SimOps: finish cleaning pits. BID steam and water. R/D pits interconnect. RID tongs. Lay mats and herculite for EJ9.,Bridle up and scope derrick down. Went on Gen power at 14:30. Start jacking up Mods. Peak trucks on location at 17:OO.,Pull mods away from sub base. Jack up sub base and remove rig mats to fill in subsiding area around cellar. Spot mats. Walk sub base off E-42. Attach steering arm to sub tires. Sim Ops: inspect mud pump 2. Change out Geo-Spans in lower utilidoor. Release Rig from MP E-42 at 0:00 7/10/19. Final report for E-42.,Hauled 554 bbls Fluid to MP G&I total = 5,912 bbls Hauled 0 bbls H2O from A-Pad reserve total = 2,080 bbis Hauled 0 bbls H2O from L-Lake total = 0 bbls Hauled 0 bbls H2O from B-Pad Creek total =130 bbis Lost 0 bbls to formation Total fluid lost production = 345 bbis Hilcorp Alaska, LLC Milne Point MPtEPad MPU E-421-1 500292363560 Sperry Drilling Definitive Survey Report 05 July, 2019 HALLIBURTON Sperry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E42 Project: Milne Point Survey Dale TVD Reference: MPU E-42 Actual RKB @ 48.43usft (Innovation) - Site: M Pt E Pad 7,800.37 MPU E-42 MWD+IFR2+MS+Sag(1)(MP MD Reference: MPU E-42 Actual RKB @ 48.43usft (Innovation) Well: MPU E-42 2_ MWD_Interp Azi+Sag North Reference: True Wellbore: MPU E-421_7 A013Mb: IIFR dec & multi -station analysis +sag Survey Calculation Method: Minimum Curvature Design: MPU E-421_1 +N/S Database: NORTH US+CANADA Project Milne Point, ACT, MILNE POINT Section (usft) (°) Map System: US Stale Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) (ft) r/100') Using Well Reference Point Map Zone: Alaska Zone 04 0.00 26.93 Using geodetic scale factor 0.00 0.00 6,016,241.23 569,137.72 0.00 Well MPU E-42, Dual Let 0.120 65.42 100.00 Well Position -NIS 0.00 usft Northing: 6,016,241.23 usft Latitude: 70° 27' 17.033 N 0.16 +E/ -W 0.00 usft EaMing: 569,137.72 usft Longitude: 149" 26'8.887 W Position Uncertainly 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 21.50 usft Wellbore MPU E-421_1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2018 6/28/2019 16.64 80.96 57,425.13231737 Design MPU E -42L1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,800.37 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 26.93 0.00 0.00 193.90 Survey Program From (usft) 100.00 668.47 7,805.00 8,024.70 Date 7/52019 To (usft) Survey(Wellbom) Tool Name Description Survey Dale 603.00 MPU E-42 SDI Gyro (MPU E-02) 2_Gyro-NS-GC_Drill collar H029Ga: North seeking single shot in drill collar 06/05/2019 7,800.37 MPU E-42 MWD+IFR2+MS+Sag(1)(MP 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec&multi-station analysis +sag 06/11/2019 7,961.08 MPU E -42L1 MWD+Interp AZl+sag(MPU 2_ MWD_Interp Azi+Sag H003Mb: Interpolated azimuth +sag correction 06/242019 11,805.80 MPU E-421_1 MWD+IFR2+MS+sag (MPU 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sag 06242019 Survey Map Map vertical MD Inc Azi TVD TVDSS +N/S +E/ -W Northing Easting DIS Section (usft) (°) (1 (usft) (usft) (usft) (usft) (ft) (ft) r/100') (ft) Survey Tool Name 26.93 0.000 0.00 26.93 -21.50 0.00 0.00 6,016,241.23 569,137.72 0.00 0.00 UNDEFINED 100.00 0.120 65.42 100.00 51.57 0.03 0.07 6,016,241.26 569,137.79 0.16 -0.05 2_Gyro-NS-GC_DnII collar (1) 165.00 0.180 310.79 165.00 116.57 0.13 0.05 6,016,241.36 569,137.77 0.39 -0.14 2_Gyro-NS-GC_Dnll collar (1) 228.00 0.250 312.78 228.00 179.57 0.28 -0.12 6,016,241.51 569,137.60 0.11 -0.25 2_Gy.-NS-GC_Drill collor(1) 291.00 0.420 307.78 291.00 242.57 0.52 -0.41 6,016,241.75 569,137.31 0.27 -0.41 2_Gym-NS-GC_Drill CD113T(1) 353.00 1.640 231.20 352.99 304.56 0.10 -1.28 6,016,241.32 569,136.44 2.57 0.21 2_Gym-NS-GC_Dnli collar (1) 416.00 4.250 220.90 415.90 367.47 -2.23 -3.51 6,016,238.97 569,134.23 4.21 3.00 2_Gym-NS-GC_Dn1I collar (1) 478.00 6.440 221.40 477.63 429.20 -0.57 -7.31 6,016,234.59 569,130.47 3.53 8.14 2_Gyro-NS-GC_DHII collar (1) 540.0 8.540 220.76 539.09 490.66 -12.67 42.62 6,016,228.45 569,125.22 3.39 15.33 2_Gym-NS-GC_QnII collar (1) 603.00 9.830 221.43 601.29 552.86 -20.24 -19.23 6,016,220.81 569,118.68 2.05 2427 2_Gye,NS-GC_Dnll collar (1) 66847 11.480 219.93 665.62 617.19 -29.43 -27.11 6,016,211.55 569,110.89 2.56 35.08 2_MWD+IFR2+MS+Sag(2) 7/5/2019 1:46:08PM Page 2 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E42 Project: Milne Point TVD Reference: MPU E-42 Actual RKB @ 48.43usft (Innovation) Site: M Pt E Pad MD Reference: MPU E-42 Actual RK13 @ 48.43usft (Innovation) Well: MPU E42 North Reference: True Wellbore: MPU E -42L1 Survey Calculation Method: Minimum Curvature Design: MPU E421-1 Database: NORTH US+CANADA Survey 7/5/2019 1:46:08PM Page 3 COMPASS 5000.15 Build 91 Map Map Vertical MD Inc Azt TVD TVDSS +NIS +El -W Northing Easting DLS Section (usft) (1) (1 (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 729.76 11.880 220.53 725.65 6T.22 38.90 -35.12 6,016,202.01 569,102.96 0.68 46.20 2_MWD+iFR2+MS+S89(2) 79238 13.920 215.38 786.68 738.25 49.94 43.68 6,016,190.89 569,094.51 3.74 58.97 2_MWD+IFR2+MS+Sag(2) 857.25 16.800 209.63 849.23 800.80 -64.46 -52.83 6,016,176.29 569,085.49 5.02 75,26 2_MWD+IFR2+MS+Sag(2) 920.91 19.460 207.02 909.73 861.30 -81.91 -6220 6,016,158.76 569,076.29 4.37 9445 2_MWD+IFR2+MS+Sag(2) 984.60 20.830 206.10 969.52 921.09 -101.53 -72.00 6,016,139.05 569.066.67 2.21 115.85 2_MWD+IFR2+MS+Sag(2) 1,49.15 24.270 204.00 1,029.13 980.70 -123.96 -82.45 6,016,116.52 569,056.43 5.47 140.14 2_MWDAFR2+MS+Sag(2) 1,113.10 26.560 202.89 1,086.89 1,038.46 -149.14 -93.36 6,016,091.24 569,045.76 3.66 167.20 2_MWD+IFR2+MS+Sa9(2) 1,177.05 31.010 201.68 1,142.92 1,094.49 -177.64 -105.01 6,016,062.65 569,034.37 7.02 197.66 2_MWD+IFR2+MS+Sag(2) 1,240.07 34.640 200.46 1,195.87 1,147.44 -209.51 -117.27 6,016,030.66 569,022.41 5.65 231.55 2_MWD+IFR2+MS+Ssg(2) 1,303.41 38.730 198.69 1,246.65 1,198.22 -245.16 -129.92 5,015,994.89 569.010.09 6.67 269.20 2_MWD+IFR2+MS+Sag(2) 1,367.02 43.080 197.63 1,294.72 1,246.29 -284.74 -142.88 6,015,955.21 568,997.50 6.92 310.72 2_MWD+IFR2+MS+Sag(2) 1,430.27 44.170 197.95 1,340.50 1,292.07 -326.29 -156.22 6,015,913.54 568,984.55 1.76 354.26 2_MWD+IFR2+MS+Sa9(2) 1,494.48 47.010 198.36 1,385.43 1,337.00 -369.87 -170.51 6,015,869.83 568,970.67 4.45 400.00 2_MWD+IFR2+MS+Sag(2) 1,557.55 47.170 198.77 1,428.37 1,379.94 413.66 -185.22 6,015,825.91 568,956.37 0.54 446.04 2_MWD+IFR2+MS+Sag(2) 1,621.14 47.650 199.10 1,471.41 1,422.98 457.94 -200.41 6.045,781.50 566,941.59 0.85 492.67 2_MWD+IFR2+MS+Sag(2) 1,68437 50.4W 19896 1,513.13 1,464]0 -503.35 -216.07 6,015,735.95 568,926.35 4.33 540.52 2_MWD+IFR2+MS+Sa9(2) 1,749.15 52.260 198.71 1,553.35 1,504.92 -550.92 -232.30 6,015,688.23 568,910.57 2.90 590.59 2_MWD+IFR2+MS+Sag(2) 1,812.58 54.300 198.49 1,591.28 1,542.85 -599.11 -248.51 6,015,639.90 568,894.80 3.23 641.26 2_MWD+IFR2+MS+Sag(2) 1,874.88 56.620 198.08 1,626.60 1,578.17 -647.83 -264.61 6,015,591.03 568,879.16 3.76 692.43 2_MWD+IFR2+MS+Sag(2) 1,939.92 57730 197.87 1,661.85 1,613.42 -699.82 -281.47 6,015,538.90 568,862.78 1.73 746.94 2_MWD+IFR2+MS+Sag(2) 2,004.37 58.080 197.99 1,696.10 1,647.67 -751.77 -298.28 6,015,486.80 568,846.45 0.57 801.41 2_MWD+IFR2+MS+Sag(2) 2,067.46 56.390 196.55 1,730.24 1,681.81 -802.42 -314.04 6,015,436.01 568,831.17 3.30 854.36 2_MWD+IFR2+MS+Sag(2) 2,130.86 56.230 196.37 1,765.41 1,716.98 -853.01 -328.98 6,015,385.28 568,816.70 0.35 907.06 2_MWD+IFR2+MS+Sag(2) 2,194.94 57.770 197.17 1,800.31 1,751.88 -904.46 -344.49 6,015,333.69 568,801.67 2.62 960.73 2_MWD+IFR2+MS+Sag(2) 2,258.70 57.690 197.05 1,834.35 1,785,92 -955.99 -360.36 6,015,282.03 568,786.28 0.20 1,014.56 2_MWD+IFR2+MS+Sag(2) 2,320.87 58.880 197.84 1,867.03 1,818.60 -1,006.44 -376.21 6,015,231.44 568,770.90 2.20 1,067.35 2_MWD+IFR2+MS+Ssg(2) 2,385.63 57.330 198.30 1,901.25 1,852.82 -1,058.71 393.26 6,015,179.02 568,754.33 2.47 1,122.18 2_MWD+IFR2+MS+Sag(2) 2,449.12 58970 198.60 1,934.75 1.886.32 -1,109.87 410.33 6,015,127.71 568,737.74 2.61 1,175.94 2_MWD+1FR2+1VIS+Sag(2) 2,513.13 59.570 199.22 1,967.46 1,919.03 -1,161.92 -428.16 6,015,075.50 568,720.40 1.25 1,230.75 2 MWD+IFR2+MS+Sag(2) 2,576.48 61.350 199.29 1,998.69 1,950.26 -1,213.95 -046.34 6,015,023.31 568,702.71 2.81 1,285.62 2_MWD+IFR2+MS+Sag(2) 2,639.95 60.790 199.62 2,029.40 1,980.97 -1,266.33 464.84 6,014,970.77 568,684.69 0.99 1,340.91 2_MWD+IFR2+MS+Sag(2) 2,703.65 60.170 200.38 2,060.78 2,012.35 -1,318.41 483.80 6,014,918.51 568,666.22 1.42 1,396.03 2_MWD+IFR2+MS+Sag(2) 2,766.87 57.770 200.27 2,093.37 2,44.94 -1,369.21 -502.61 6,014,867.55 568,647.88 3.80 1,449.86 2_MWD+IFR2+MS+Sa9(2) 2,831.08 60.350 200.26 2,126.38 2,077,95 -1,420.87 -521.69 6,014,815.72 568,629.29 4.02 1,504.59 2_MWD+IFR2+MS+Sag(2) 2,894.74 60.500 200.35 2,157.80 2,109.37 -1,472.79 540.90 6,014,763.62 588,610.56 0.27 1,559.61 2_MWD+IFR2+MS+Sag(2) 2,958.25 61.110 198.72 2,188.78 2,140.35 -1,525.04 -559.44 6,014,711.21 568,592.51 2.44 1,614.78 2_MWD+IFR2+MS+Sag(2) 3,021.82 60.340 198.32 2,219.87 2,171.44 -1.577.62 -577.05 6,014,658.47 568,575.39 1.33 1,670.05 2_MWD+IFR2+MS+Sag(2) 3,085.63 60.270 198.16 2,251.48 2,203.05 -1,630.27 -594.40 6,014,605.67 568,558.53 0.24 1,725.32 2_MWD+IFR2+MS+Sag(2) 3,148.98 59.370 197.83 2,283.32 2,23489 -1,682.35 -611.32 6,014,553.44 568,542.10 1.49 1,779.94 2_MWD+IFR2+MS+Sag(2) 3,212.81 57820 198.45 2,316.58 2,268.15 -1,734.12 -628.28 6,014,501.52 568,525.62 2.57 1,834.27 2_MWD+IFR2+MS+Sag(2) 7/5/2019 1:46:08PM Page 3 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Project: Site: Well: Waltham: Design: Hilcorp Alaska, LLC Milne Point M Pt E Pad MPU E-42 MPU E421-1 MPU E4211 Local Coardinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU E-42 MPU E42 Actual RKB @ 48.43usft (Innovation) MPU E-42 Actual RKB @ 48.43usft (Innovation) True Minimum Curvature NORTH US+CANADA Survey Map Map vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) M (1) (usft) (usft) (usft) (usft) (ft) (ft) (°Hoo') (ft) Survey Tool Name 3,276.35 59.740 198.52 2,349.52 2,30109 -1,785.65 -M5.50 6,014,449.83 568,508.87 3.02 1,888.43 2 MWD+IFR2+MS+Sag(2) 3,339.94 59.050 198.57 2,381.89 2,333.46 -1,837.54 -662.91 6,014,397.79 568,491.95 1.09 1,942.98 2_MWD+IFR2+MS+Sag(2) 3,403.24 59.290 198.74 2,414.33 2,36590 -1,889.04 -680.30 6,014,346.14 568,475.04 0.44 1,997.15 2_MWD+IFR2+MS+Sag(2) 3,46148 59.970 199.35 2,446.81 2,398.38 -1,941.43 -698.38 6,014,293.59 568,457.45 1.34 2,052.35 2_MWD+IFR2+MS+Sag(2) 3,531.39 59.650 198.73 2,478.95 2,430.52 -1,993.65 -716.41 6,014,241.21 568,439.91 0.99 2,107.37 2_MWD+IFR2+MS+Sag(2) 3,595.28 59.000 199.13 2,511.54 2,463.11 -2,045,63 -734.23 6,014,189.07 568,422.57 1.15 2,162.11 2_MWD+IFR2+MS+Ssg(2) 3,659.17 57.760 198.84 2,54504 2,496.61 -2,09107 -751.93 6,014,137.47 568,405.35 1.98 2,216.30 2_MWD+IFR2+MS+Sag(2) 3,722.71 59.100 198.90 2,578.30 2,529.87 -2,148.30 -76044 6,014,086.09 568,388.32 2.11 2,270.23 2_MWD+IFR2+MS+Sag(2) 3,786.56 59.050 199.17 2,611,12 2,562.69 -2,200.08 -787.30 6,014,034.15 568,370.94 0.37 2,324.78 2_MWD+IFR2+MS+Sag(2) 3,850.03 58.770 200.07 2,643.89 2,595.46 -2,251.27 -805.55 6,013,982.79 568,353.17 1.29 2,378.86 2_MWD+IFR2+MS+Sag(2) 3,913.72 59.630 198.18 2,676.51 2,628.08 -2,302.96 -823.47 6,013,930.95 568,335.73 2.88 2,433.34 2 MWD+IFR2+MS+Sag(2) 3,978.01 59.900 197.84 2,708.88 2,660.45 -2,355.78 -840.65 6,013,877.97 568,319.05 0.62 2,488.74 2_MWD+IFR2+MS+Saq(2) 4,041.17 59.340 198.15 2,740.82 2,692.39 -2,407.60 -85148 6,013,826.00 568,302.70 Des 2,543.09 2_MWD+IFR2+MS+Sag(2) 4,104.31 58280 198.38 2,773.52 2,725.09 -2,458.89 -874.41 6,013,774.56 566,286.25 1.71 2,596.95 2_MWD+IFR2+MS+Sag(2) 4,168.21 58.920 198.72 2,806.81 2,758.38 -2,510.60 -891.76 6,013,722.70 568,269.38 1.10 2,651.31 2_MWD+IFR2+MS+Sag(2) 4,231.85 58.260 198.96 2,839.98 2,791.55 -2,562.01 -909.30 6,013,671.14 568,252.32 1.09 2,705.42 2_MWD+IFR2+MS+Sag(2) 4,295.51 58.680 199.39 2,873.27 2,824.84 -2,613.26 -927.12 6,013,619.73 568,234.98 0.88 2,759.45 2_MWD+IFR2+MS+Sag(2) 4,35966 58.150 19933 2,906.87 2,85844 -2,664.81 -945.24 6,013,568.01 568,217.34 0.83 2,813.85 2_MWD+IFR2+MS+Sag(2) 4,423.27 59.220 198.64 2,939.93 2,891.50 -2,716.20 -962.91 6,013,516.47 568,200.14 1.92 2,867.98 2_MWD+IFR2+MS+Saq(2) 4,487.40 58.860 198.24 2,972.92 2,92449 -2,768.37 -980.31 6,013,464.15 566,183.24 0.78 2,922.80 2_MWD+IFR2+MS+Sag(2) 4,550.98 59.060 198.63 3,005.70 2,957.27 -2,820.05 -997.53 6,013,412.31 568,166.49 0.61 2,977.10 2_MWD+IFR2+MS+Sag(2) 4,614.50 56.860 199.10 3,039.40 2,990.97 -2,871.00 -1,014.94 6,013,361.21 568,149.56 3.52 3,030.74 2 MWD+IFR2+MS+Sag(2) 4,677.75 58.850 198.61 3,073.05 3,024.62 -2,921.68 -1,032.24 6,013,310.38 568,132.73 3.21 3,064.09 2_MWD+IFR2+MS+Sag(2) 4,741.46 59.120 198.68 3,105.88 3,057.45 -2,973.41 -1,049.70 6,013,258.49 568,115.75 0.43 3,138.51 2_MWD+IFR2+MS+Sag(2) 4,805.42 59.530 198.59 3,138.51 3,090.08 -3,025.54 -1,067.28 6,013,206.20 568,098.66 0.65 3,193.33 2_MWD+IFR2+MS+Sag(2) 4,869.03 58,340 199.25 3,171.33 3,122.90 -3,077.08 -1,084.94 6,013,154.50 568,081.48 2.07 3,247.61 2_MWD+IFR2+MS+Sag(2) 4,932.88 59.680 198.26 3,204.21 3,15578 -3,128.91 -1,102.54 6,013,102.52 568,064.37 2.48 3,302.15 2_MWD+IFR2+MS+Sag(2) 4,995.97 59.140 198.56 3,236.31 3,187.88 -3,180.44 -1,119.69 6,013,050.64 568,047.70 0.95 3,356.29 2_MWD+IFR2+MS+Sag(2) 5,060.18 59.130 198.37 3,269.26 3,220.83 -3,232.72 -1,137.15 6,012,998.40 568,030.73 0.25 3,411.23 2_MWD+IFR2+MS+Sag(2) 5,124.30 59.460 198.78 3,302.00 3,253.57 -3,264.98 -1,154.71 6,012,945.99 568,013.65 0.75 3,466.18 2_MWD+IFR2+MS+Sag(2) 5,187.84 59,410 199.10 3,334.31 3,285.88 -3,336.73 -1,172.47 6,012,894.08 567,996.38 0.44 3,520.68 2_MWD+IFR2+MS+Sag(2) 5,25105 61.120 197.82 3,365.66 3,317.23 x,388.79 -1,189.84 6,012,841.87 567,979.49 3.23 3,575.39 2_MWD+IFR2+MS*Sag(2) 5,314.67 61.050 197.51 3,396.42 3,347.99 -3,441.85 4,206.74 6,012,788.66 567,963.08 0.44 3,630.95 2_MWD+IFR2+MS+Sag(2) 5,378.25 61.470 197.32 3,426.99 3,378.56 -3,49504 -1,22342 6,012,735.32 567,946.90 0.71 3,686.60 2_MWD+IFR2+MS+Sag(2) 5,442.06 61.840 197.91 3,457.29 3,408.86 -3,548.57 -1,240.42 6,012,681.64 567,93040 1.00 3,742.64 2_MWD+IFR2+MS+Sag(2) 5,505.96 61.010 198.09 3,487.85 3,439.42 -3,601.94 -1,257.76 6,012,628.12 567,913.56 1.32 3,798.61 2_MWD+IFR2+MS+Sag(2) 5,569.28 59.560 198.05 3,519.24 3,470.61 -3,654.22 -1,274.82 6,012,575.69 567,896.99 2.29 3,853.46 2_MWD+IFR2+MS+Sag(2) 5,633.03 58.330 197.61 3,552.12 3,503.69 -3,70621 -1,291.54 6,012,523.55 567,880.75 2.02 3,907.94 2_MWD+IFR2+MS+Sag(2) 5,697.02 58.480 198.00 3,585.65 3,537.22 -3,758.10 -1,308.21 6,012,471.51 567,864.56 0.57 3,962.32 2 MWD+IFR2*MS+Sag(2) 5,760.39 59.240 198.11 3,618.42 3,569.99 -3,809.67 -1,325.02 6,012,419.79 567,848.24 1.21 4,016.41 2_MWD+IFR2+MS+Sag(2) 7/572019 1:46:08PM Page 4 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilmrp Alaska, LLC Local Coordinate Reference: Well MPU E42 Project: Milne Point TVD Reference: MPU E-42 Actual RKB @ 48.43usft (Innovation) Site: M Pt E Pad MD Reference: MPU E-42 Actual RKB @ 48.43usft (Innovation) Well: MPU E-42 North Reference: True Wellbore: MPU E-4211 Survey Calculation Method: Minimum Curvature Design: MPU E-0211 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E1 -W Northing Easting OLS Section (usft) r) (1) (usft) (usft) (usft) (usft) (ft) (ft) r1low) (ft) Survey Tool Name 5,823.75 58.260 197.26 3,651.29 3,602.86 -3,86127 -1,341.47 6,012,368.04 567,832.26 1.93 4,070.46 2_MWD+IFR2+MS+Seg(2) 5,887.40 58.460 197.64 3,684.68 3,636.25 -3,912.97 -1,357.72 6,012,316.20 567,816.49 0.60 4,124.55 2_MWD+IFR2+MS+Sag(2) 5,951.38 58.420 197.94 3,718.16 3,669.73 -3,964.88 -1,374.38 6,012,264.14 567,800.32 0.40 4,178.94 2 MWD+IFR2+MS+Sag(21 6,015.04 58.360 197.93 3,751.53 3,703.10 4,016.46 -1,391.07 6,012,212.42 567,784.11 0.10 4,233.02 2_MWD+IFR2+MS+Sag(2) 6,078.96 58.240 198.16 3,785.12 3,736.69 4.068.17 -1,407.92 6,012,160.56 567,767.74 0.36 4,287.26 2_MWD+IFR2+MS+Sag(2) 6,142.40 58.060 198.62 3,818.60 3,770.17 4,119.30 -1,424.92 6,012,109.27 567,751.22 0.68 4,340.98 2_MWD+IFR2+MS+Sag(2) 6,206.58 58.130 199.09 3,852.52 3,804.09 -0,170.86 -1,442.53 6,012,057.56 567,734.09 0.63 4,395.26 2_MWD+IFR2+MS+Sag(2) 6,27037 58.470 199.28 3,885.04 3,837.61 4,222.12 -1,460.36 6,012,006.14 567,716.73 0.59 4,449.30 2 MWD+IFR2+MS+Sag(2) 6,333.91 57.910 199.70 3,919.53 3,871.10 4,273.02 -1,478.38 6,011,955A8 567,699.19 1.05 4,503.04 2_MWD+IFR2+MS+Sag(2) 6,397.75 511,930 198.39 3,952.96 3,904.53 4,324.43 -1,496.12 6,011,903.51 567,681.93 2.37 4,557.21 2_MWD+IFR2+MS+Sag(2) 6,459.84 59.190 198.26 3,984.88 3,936 AS 4,374.99 -1,512.87 6,011,852.81 567.666.66 0.46 4.610.30 2_MWD+IFR2+MS+Sag(2) 6,524.75 59.850 199.09 4,017.81 3,969.38 4,427.98 -1,530.78 6,011,799.66 567,648.24 1.50 4,666.05 2_MWD+IFR2+MS+Sag(2) 6,586.71 62.270 199.38 4,047.79 3,999.36 4,479.17 -1,548.64 6,011,748.31 567,630.85 3.93 4,720.03 2_MWD+IFR2+MS+Sag(2) 6,652.49 61.730 199.55 4,078.67 4,030.24 4,533.93 -1,566.00 6,011,693.37 567,612.01 0.85 4,777.84 2_MWD+IFR2+MS+Sag(2) 6,715.28 65.260 198.48 4,106.69 4,058.26 4,587.05 -1.586.29 6,011,640.09 567,594.21 5.82 4,833.80 2_MWD+IFR2+MS+Sag(2) 6,780.34 68.710 198.12 4,132.12 4,083.69 4,643.89 -1,605.09 6,011,583.08 567,575.94 5.33 4,893.49 2_MWD+IFR2+MS+Sag(2) 6,843.97 71.340 198.51 4,153.86 4,105.43 4.700.66 -1,623.88 6,011,526.15 567,557.68 4.17 4,953.11 2_MWD+IFR2+MS+Sag(2) 6,907.48 75.220 198.36 4,172.12 4,123.69 4.758.35 -1,643.11 6,011,466.28 567,538.99 6.11 5,013.73 2_MWD+IFR2+MS+Sag(2) 6,971.45 80.310 196.90 4,185.68 4,137.25 -0,817.92 -1,662.03 6,011,408.56 567,520.62 8.26 5,076.10 2_MWD+IFR2+MS+Sag(2) 7,035.26 81.840 195.17 4,195.58 4,147.15 4,878.50 -1,679.44 6,011,347.82 567,503.78 3.59 5,139.09 2_MWD+IFR2+MS+Sag(2) 7,099.07 83.570 192.70 4,203.68 4,155.25 4,939.92 -1,694.68 6,011,286.26 567,489.11 4.70 5,202.37 2_MWD+IFR2+MS+Sag(2) 7,160.77 83.150 192.46 4,210.81 4,162.38 4,999.74 -1,708.03 6,011,226.33 567,476.32 0.78 5,263.64 2_MWD+IFR2+MS+Sag(2) 7,226.26 83.020 192.82 4,218.70 4,170.27 -5,063.17 -1,722.25 6,011,162.77 567,462.68 0.58 5,328.64 2_MWD+IFR2+MS+Sag(2) 7,290.11 82.530 193.41 4,226.73 4,178.30 -5,124.86 -1,736.63 6,011,100.96 567,448.88 1.20 5,391.98 2_MWD+IFR2+MS+Sag(2) 7,353.89 83.130 192.73 4,234.69 4,186.26 -5,186.51 -1,750.94 6,011,039.19 567,435.15 1.42 5,455.25 2_MWD+IFR2+MS+Sag(2) 7,417.85 82.830 193.68 4,242.51 4,194.08 -5,248.31 -1,765.44 6,010,977.26 567,421.22 1.55 5,518.73 2_MWD+IFR2+MS+Sag(2) 7,481.54 82.490 194.00 4,250.64 4,202.21 -5,309.64 -1,780.55 6,010,915.80 567,406.68 0.73 5,581.89 2_MWD+IFR2+MS+Sag(2) 7,545.28 83.240 193.26 4,258.56 4,210.13 -5,371.10 -1,795.45 6,010,854.20 567,392.35 1.65 5,645.14 2_MWD+IFR2+MS+Sag(2) 7,608.70 83.690 193.97 4,265.78 4,217.35 -5,432.34 -1,810.28 6,010,792.84 567,378.09 1.32 5,708.14 2_MWD+IFR2+MS+Sag(2) 7,672.42 83.320 193.84 4,272.99 4,224.56 -5,493.80 -1,825.50 6,010,731.25 567,363.45 0.62 5,771.46 2_MWD+IFR2+MS+Sag(2) 7,736.11 82.630 194.48 4,280.78 4,232.35 5,555.09 -1,840.96 6,010,669.82 567,348.56 1.47 5,834.67 2_MWD+IFR2+MS+Sag(2) 7,800.37 79.790 194.23 4,290.59 4,242.16 -5,616.60 -1,856.71 6,010,608.17 567,333.39 4.44 5,898.16 2_MWD+IFR2+MS+Sag(2) 7,805.00 79.730 194.24 4,291.42 4,242.99 -5,621.02 -1,857.83 6,010,603.74 567,332.31 1.31 5,902.72 2 -MWD Interp Azi+Sag(3) 7,894.94 82.620 191.87 4,305.22 4,25679 -5,707.58 -1,877.89 6,010,517.01 567,313.05 4.14 5,991.57 2_ MWD_Interp Azi+Sag(3) 7,961.08 86.860 190.25 4,311.28 4,26285 -5,772.21 -1,890.52 6,010,452.28 567.301.02 6.86 6,057.33 2_MWD_Interp Azi+Sag(3) 8,024.70 88.640 188.69 4,313.78 4,265.35 -5,834.91 -1,900.98 6,010,389.49 567,291.15 3.72 6,120.71 2 MWD+IFR2+MS+Sag(4) 8,088.38 92.640 189.07 4,313.07 4,264.64 -5,897.81 -1,910.80 6,010.326.51 567,281.90 6.31 6,184.13 2_MWD+IFR2+MS+Sag(4) 8,152.72 91.610 188.69 4,310.68 4,262.25 -5,961.33 -1,920.73 6,010,262.90 567,272.57 1.71 6,248.17 2_MWD+IFR2+MS+Sag(4) 8,216.12 90.130 189.17 4,309.72 4,261.29 -6,023.95 -1,930.57 6,010,200.19 567,263.31 2.45 6,311.33 2_MWD+IFR2+MS+Sag(4) 8,279.71 89.880 190.52 4,309.71 4,26128 -6,086.61 -1,941.44 6,010,137.45 567,253.02 2.16 6,374,76 2_MWD+IFR2+MS+Sag(4) 7/5/2019 1:46:08PM Page 5 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 E42 MPU E -421L1 MPU E421-1 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU E-42 MPU E-42 Actual IRKS @ 48.43usft (Innovation) MPU E-42 Actual RKB @ 48.43usft (Innovation) True Minimum Curvature NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/ -W Northing Easting DLS Section (usft) (1) V) (usft) (usft) (usft) (usft) (ft) (ft) (°/low) (ft) Survey Tool Name 8,343.70 90.070 192.24 4,309.74 4,261.31 -6,149.33 -1,954.07 6.010,074.61 567,240.98 2.70 6,438.68 2_MWD+IFR2+MS+S8g(4) 8,407.25 91.680 193.76 4,308.77 4,260.34 -6,211.24 -1,968.36 6,010,012.58 567,227.26 3.48 6,502.21 2_MWD+IFR2+MS+Sag(4) 8,471.12 92.360 194.16 4,306.52 4,258.09 -6,273.19 -1,983.76 6,009,950.50 567,212.44 1.24 6,566.04 2_MWD+IFR2+MS+Sag(4) 8,534.30 93.030 194.15 4,303.55 4,255.12 -6,334.38 -1,999.19 6,009,889.17 567,197.58 1.06 6,629.15 2_MWD+IFR2+MS+Sag(4) 8,598.68 93410 194.18 4,299.93 4,251.50 -6,396.71 -2,014.92 6,009,826.71 567,182.43 0.59 6,693.43 2_MWD+IFR2+MS+Sag(4) 8,661.16 93.340 194.30 429625 4,247.82 -6,457.16 -2,030.26 6,009,766.12 567,167.65 0.22 6,755.80 2_MWD+IFR2+MS+Sag(4) 8,725.62 92.350 193.77 4,293.05 4,244.62 -6,519.62 -2,045.88 6,009,703.52 567,152.62 1.74 6,820.18 2_MWD+IFR2+MS+Sag(4) 8,788.89 93.220 193.89 4,289.98 4,241.55 -6,580.98 -2,060.98 6,009,642.03 567,138.08 1.39 6,883.37 2_MWD+IFR2+MS+Sag(4) 8,853.02 94.270 194.18 4,285.79 4,237.36 -6,643.06 -2,076.50 6,009,579.81 567,123.14 1.70 6,947.37 2_MWD+IFR2+MS+Sag(4) 8,915.95 93.960 193.40 4,281.27 4,232.84 -6,704.02 -2,091.46 6,009,518.72 567,108.75 1.33 7,010.13 2_MWD+IFR2+MS+Sag(4) 8,9T.53 93.780 193.20 4,277.12 4,228.69 -6,763.81 -2,105.60 6,009,458.81 567,095.17 0.44 7,071.57 2_MWD+IFR2+MS+Sag(4) 9,042.85 93.090 194.16 4,273.20 4,224.77 6,827.17 -2,121.02 6,009,395.32 567,080.34 1.81 7,136.T 2_MWD+IFR2+MS+Sag(4) 9,106.55 94.900 195.14 4,268.77 4,220.34 .608.64 -2,137.09 6,009,333.71 567,064.84 3.23 7,200.31 2_MWD+IFR2*MS+Sag(4) 9.170.82 95.520 195.32 4,262.93 4,214.50 -6,950.40 -2,153.90 6,009,271.80 567,048.61 1.00 7,264.29 2_MWD+IFR2*MS+Sag(4) 9,234.02 94.330 194.31 4,257.50 4,20907 -7,011.27 -2,170.00 6,009,210.79 567,033.07 2.47 7,327.25 2_MWD+IFR2*MS+Sag(4) 9,297.63 95.260 195.57 4,252.19 4,203.76 -7,072.51 -2,186.34 6,009,149.40 567,017.30 2.46 7,390.63 2_MW041FR2+MS+Sag(4) 9,361.41 95.010 195.70 4,246.48 4,198.05 -7,133.69 -2,203.46 6,009,088.08 567,000.75 0.44 7,454.12 2_MWD+IFR2+MS+Sag(4) 9,425.95 94.200 195.88 4,241.30 4,192.87 -7,195.59 -2,220.97 6,009,026.02 566,983.83 1.29 7,518.42 2_MWD+IFR2+MS+Ssg(4) 9,489.72 94.770 195.68 4,236.31 4,187.88 -7,256.77 -2,238.26 6,008,964.69 566,967.11 0.95 7,581.96 2_MWD+IFR2+MS+Sag(4) 9,551.75 93.210 194.73 4,231.99 4,183.56 -7,316.48 -2,254.48 6,008,904.84 566,951.43 2.94 7,643.82 2_MWD+IFR2+MS+Sag(4) 9,616.90 91.610 192.85 4,229.25 4,180.82 -7,379.69 -2,270.00 6,008,841.49 566,936.51 3.79 7,708.90 2_MWD+IFR2+MS+Sag(4) 9,680.75 90.500 192.62 4,228.08 4,179.65 -7,441.96 -2,284.07 6,008,779.10 566,923.02 1.78 7,772.73 2_MWD+IFR2+MS+Sag(4) 9,744.39 90.870 193.45 4,227.32 4,178.89 -7,503.95 -2,298.42 6,008,716.98 566.909.24 1.43 7,836.36 2_MWD+IFR2+MS+Sag(4) 9,805.73 91.060 193.10 4,226.29 4,177.86 -7,563.65 -2,312.51 6,008,657.17 588,895.71 0.65 7,897.68 2_MWD+IFR2+MS+Sag(4) 9,871.75 92.110 194.02 4,224.46 4,176.03 -7,627.80 -2,327.98 6,008,592.88 566,880.84 2.11 7,963.68 2_MWD+IFR2+MS+Sag(4) 9,935.64 92.100 194.02 4,222.11 4,173.68 -7,689.74 -2,34345 6,008,530.80 566,865.95 0.02 8,027.52 2_MWD+IFR2+MS+Sag(4) 9,999.30 92.110 194.42 4,219.77 4,17134 -7,751.41 -2,359.07 6,008,469.00 566,850.89 0.63 8,091.14 2_MWD+IFR2+MS+Sag(4) 10,062.51 91.660 195.02 4,217.58 4,169.15 -7,812.51 -2,375.13 6,008,407.76 566,835.41 1.03 8,154.30 2_MWD+IFR2+MS+Sag(4) 10,126.43 92040 195.24 4,215.41 4,166.98 -7,874.18 -2,391.80 6,008,345.94 566,819.31 0.44 8,218.17 2_MWD+IFR2+MS+Sag(4) 10,189.92 92.170 196.16 4,213.08 4,164.65 -7,935.26 -2,408.97 6,008,284.71 566,802.71 1.46 8,281.59 2_MWD+IFR2+MS+Sag(4) 10,25321 92.290 196.49 4,210.61 4,162.18 -7,995.95 -2,426.75 6,008,223.86 566,785.50 0.55 8,344.77 2_MWD+IFR2+MS+Ssg(4) 10,317.66 92.600 196.22 4,207.87 4,159.44 -8,057.74 -2,444.88 6,008,161.92 566,767.95 0.64 8,409.11 2_MW0+IFR2+MS+Ssg(4) 10,381.12 92.480 196.06 4,205.05 4,156.62 -8,118.63 -2,462.50 6,008,100.86 566,750.89 0.31 8,472.45 2_MWD+IFR2+MS+Sag(4) 10,445.14 92.100 195.25 4,202.50 4,154.07 -8.180.23 -2,479.76 6,008,039.12 566.734.20 1.40 8,536.39 2_MWD+IFR2+MS+Sag(4) 10,509.13 92.110 195.99 4,200.14 4,151.71 -8,241.81 -2,496.98 6,007,977.38 566,717.56 1.16 8,600.31 2_MW13+1FR2+MS+Sag(4) 10,573.01 92.100 195.83 4,197.80 4,149.37 -8,303.21 -2,514.48 6,007,915.83 566,700.63 0.25 8,664.11 2_MWD+IFR2+MS+Sag(4) 10,636.59 91.420 195.43 4,195.85 4,147.42 -8,364.41 -2,531.60 6,007,854.48 566,684.08 1.24 8,727.63 2_MWD+IFR2*MS+Sag(4) 10,700.22 90.370 193.99 4,194.85 4,146.42 -8,425.94 -2,547.76 6,007,792.81 566,668.50 2.80 8,791.24 2_MWD+IFR2+MS+Sag(4) 10,764.12 90.500 191.12 4,194.37 4,145.94 -8,488.30 -2,561.64 6,007,730.33 566,655.19 4.50 8,855.12 2_MWD+IFR2+MS+Sag(4) 10,828.08 90.750 191.15 4,193.67 4,145.24 -8,551.06 -2,574.00 6,007,667.47 566,643.42 0.39 8,919.00 2_MWD+IFR2+MS+Sag(4) 7/5/2019 1:46:08PM Page 6 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E42 Project: Milne Point TVD Reference: MPU E-42 Actual RKS @ 48.43usft (Innovation) Site: M Pt E Pad MD Reference: MPU E-42 Actual IRKS @ 48.43usfl (Innovation) Well: MPU E42 North Reference: True Wellbore: MPU E-4217 Survey Calculation Method: Minimum Curvature Design: MPU E-421-1 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/ -W Northing Easting DLS Section (usft) (1) (1 (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 10,891.43 90.690 191.67 4,192.87 4,144.44 -8,613.15 -2,586.53 6,007,605.27 566,631.47 0.83 8,982.28 2_MWD+IFR2+MS+Seg(4) 10,954.80 91.680 193.71 4,191.56 4,143.13 -8,674.95 -2,600.44 6,007,543.34 566,618.13 3.58 9,045.62 2_MWD+IFR2+MS+Sag(4) 11,018.76 90.500 193.07 4,190.35 4,141.92 -8,737.16 -2,615.25 6,007,481.00 566,603.90 2.10 9,109.56 2_MWD+IFR2+MS+Sag(4) 11,082.23 92.610 193.81 4,188.62 4,140.19 -8,798.87 -2,630.00 6,007,419.17 566,589.73 3.52 9,173.01 2_MWO+IFR2+MS+Sag(4) 11,146.24 94.590 195.79 4,184.60 4,136.17 -8,860.63 -2,646.31 6,007,357.27 566,573.99 4.37 9,236.87 2_MWD+IFR2+MS+Sag(4) 11,20989 94.580 196.84 4,179.52 4,131.09 -8,921.52 -2,664.14 6,007,296.22 566,556.73 1.64 9,300.26 2_MWD+IFR2+MS+Sag(4) 11,273.61 94.090 197.69 4,174.70 4,126.27 -8,982.19 -2,682.99 6,007,235.38 566,538.44 1.54 9,363.69 2_MWD+IFR2+MS+Sag(4) 11,337.22 92.910 197.05 4,170.82 4,122.39 -9,042.79 -2,701.95 6,007,174.62 566,520.05 2.11 9.427.06 2_MWD+IFR2+MS+Sag(4) 11,400.57 93,710 195.60 4,167.16 4,118.73 -9,103.48 -2,719.73 6,007,113.77 566,502.64 2.61 9,490.25 2_MWD+IFR2+MS+Sag(4) 11,464.96 93.720 194.23 4,162.99 4,114.56 -9,165.57 -2,736.26 6,007,051.54 566,486.88 2.12 9,554.49 2_MWD+IFR2+MS+Sag(4) 11.528.69 92720 191.92 4,159.41 4,110.98 -9,227.54 .2,750.66 6,006,989.44 566,47306 3.94 9,618.11 2_MWD+IFR2+MS+Sag(4) 11,591.91 91.730 190.15 4,156.95 4,10852 -9,289.54 -2,762.75 6,008,927.33 566,461.55 3.21 9.681.20 2_MWD+IFR2+MS+Sa9(4) 11,655.45 92.110 190.83 4,154.82 4,106.39 .9,351.98 -2,T4.31 6,006,864.79 566,450.57 1.23 9,744.59 2_MWD+IFR2+MS+Sag(4) 11,719.10 92.170 191.06 4,15244 4,104.01 -9,41,tA3 -2,786.38 6,006,602.24 566,439.07 0.37 9,808.11 2_MWD+IFR2+MS+Sag(4) 11,783.57 93.350 192.72 4,149.34 4,100.91 -9,477.44 -2,799.65 6,006,739.11 566,426.39 3.16 9,872.47 2_MWD+IFR2+MS+Sag(4) 11,605.80 94.220 193.38 4,147.87 4,09944 -9,499.05 -2,80466 6,006,717.46 566,421.59 4.91 9,894.64 2_MWD+IFR2+MS+Sag(4) 11,875.00 .94.220 193.38 4,142.78 4,094.35 .9,566.19 -2,820.63 6,006,650.18 566,406.24 0.00 9,963.65 PROJECTED bTD michael.calkins2@halli a..�.+-.W,�...•u..--s- Checked By: Mitch Laird Approved By: burton.com ^»^= Date: 7/5/2019 73/2019 1:46.-08PM Page 7 COMPASS 5000.15 Build 91 2190;1 Debra Oudean Hilcorp Alaska, LLC 3 1 0 1 3 GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Irh„,p :u,,A., Ll.c Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 07/18/2019 To: Alaska Oil & Gas Conservation Commission Abby Bell Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 MPU E-42 PTD 219-082)+ E -42L1 PTD 219-091 CD 1: Log Viewers 7/18/2019 1D:23AM RECEIVE® MPUE-42 7/18/201910:25 AM JUL 19 2019 MPU E -42L1 7/18/201910:26 AM / O G C C Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: �) I n Date: A� n //� 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 -42L1 Hilcorp Alaska, LLC. Permit to Drill Number: 219-091 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 W ww. oogcc.a lasko.gov Surface Location: 3704' FSL, 2008' FEL, Sec. 25, TI 3N, RI OE, UM, AK Bottomhole Location: 658' FNL, 434' FWL, Sec. 6, TI 2N, RI IE UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 219-082, API No. 50-029- 23635-00-00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie L. CMielowski Commissioner DATED this -1 day of June, 2019. R .,, t _o C... It CY h U STATE OF ALASKA f A_ jKA OIL AND GAS CONSERVATION COMN„_jION JUN 14 2019 PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work:1 b. Proposed Well Class: Exploratory - Gas Service - WAG L1 Service - Disp E]ic. Specify ifwell rs pmp r: Drill Drill [I Stratigraphic Test ❑ Development - Oil ❑� 'Service - Winj ❑ Single Zone ❑Q Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11. Well Name and Number: Hilcorp Alaska, LLC Bond No. 022035244. MPU E-421_1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 11,948' TVD: 4,157' Milne Point Field Schrader Bluff Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 3704' FSL, 2008' FEL, Sec 25, T13N, R1 OE, UM, AK • *ADL025518 / ADL380110 ' (OA Lateral) Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 1888' FNL, 1432' FWL, Sec 36, T13N, R10E, UM, AK LONS 94-017 6/28/2019 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 658' FNL, 434' FWL, Sec 6, T12N, R11 E, UM, AK 4997 9802' to nearest unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 47.3 • 15. Distance to Nearest Well Open Surface: x-569137 y- 6016240 Zone -4 GL / BF Elevation above MSL (it): 20.8 to Same Pool: 40' TVD to MPU E-42 16. Deviated wells: Kickoff depth: 7,775 feet • 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 92.3 degrees Downhole: 1885 1 Surface: 1458 - 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) 8-1/2" 4-1/2" 13.5# L-80 Hyd 625 4,188' 7,760' 4,285' 11,948'. 4,157' Cementless PreDrilled Liner W 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes[—] No ❑a 20. Attachments: Property Plat O BOP Sketch Drilling Program D Time v. Depth Plot a Shallow Hazard Analysis B 8 B B Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. t hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Joe Engel Authorized Name: Monty Myers Contact Email: jenclelahilcorp.com Authorized Title: Drilling Manager Contact Phone: 777-8395 14, ` Authorized Signature: zll,,s Date: f Commission Use Only Permit to Drill API Number: Permit Approve 10 1 See cover letter for other Number: Z Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed e—Ane gas hydrates, or gas contained in shales: �f Other: �t n� /� /_ Samples req'd: Yes ❑ No� Mud log req'd: YesNo L� RNo HzS measures: Yes ❑ No f Directional svy req'd: Yes El Spacing exception req'd: Yes ❑ No ff Inclination -only svy req'd: Yes ❑ No LvU Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BY t0( Approved by: COMMISSIONER THE COMMISSION Date: 9��pJ/f 1 Revised 5/2017 L This �/ ' (� • f permit is va id for 2 5 r rgval per 20 AAC 25.005(g) Submit Form and Attachmentsun Duplicat, Hilcorp Alaska, LLC Milne Point Unit (MPU) E -42L1 Drilling Program 2 (2 -00— Version 1 6/14/2019 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 & Run Seal Bore Diverter..........................................................................17 12.0 Run 4-1/2" Production Liner........................................................................................................18 13.0 Run Lateral Entry Module & SLZXP.........................................................................................22 14.0 Run 7-5/8" Tieback.......................................................................................................................23 15.0 Run ESP Completion....................................................................................................................26 16.0 RDMO Innovation Rig..................................................................................................................27 17.0 Innovation Rig Diverter Schematic.............................................................................................28 18.0 Innovation Rig BOP Schematic....................................................................................................29 19.0 Wellhead Schematic......................................................................................................................30 20.0 Days Vs Depth................................................................................................................................31 21.0 Formation Tops & Information...................................................................................................32 22.0 Anticipated Drilling Hazards.......................................................................................................34 23.0 Innovation Rig Layout..................................................................................................................35 24.0 FIT Procedure................................................................................................................................36 25.0 Innovation Rig Choke Manifold Schematic................................................................................37 26.0 Casing Design.................................................................................................................................38 27.0 8-1/2" Hole Section MASP............................................................................................................39 28.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................40 29.0 Surface Plat (As Built) (NAD 27).................................................................................................41 30.0 Schrader Bluff OA Sand Offset MW vs TVD Chart..................................................................42 H Hilco�r 1.0 Well Summary Milne Point Unit E-421-1 SB Producer Drilling Procedure Well MPU E -42L1 ' Pad Milne Point "E" Pad Planned Completion Type ESP on 2-7/8" Production Tubing Target Reservoir(s) Schrader Bluff OA Sand - Planned Well TD, MD / TVD 11,948' MD / 4,157' TVD PBTD, MD / TVD 11,798' MD / 4,157' TVD Surface Location (Governmental) 3704' FSL, 2008' FEL, Sec 25, T13N, R10E, UM, AK Surface Location AD 27) X= 569,137.33, Y= 6,016,240.99 Top of Productive Horizon (Governmental) 1888' FNL, 1432' FWL, Sec 36, T13N, R10E, UM, AK TPH Location (NAD 27) X= 567,350.66 Y= 6,010,632.34 BBL (Governmental) 658' FNL, 434' FWL, Sec 6, T12N, RI IE, UM, AK BHL (NAD 27) X= 566,385.99, Y=6,006,574 AFE Number 1912791 AFE Drilling Das 13 days AFE Completion Das 4 days AFE Drilling Amount $2,509,381 AFE Completion Amount $1,835,242 AFE Facility Amount $0 Maximum Anticipated Pressure (Surface) 1458 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1885 psig Work String 5" 19.5# S-135 DS -50 & NC 50 KB Elevation above MSL: 26.5 ft + 20.8 ft = 47.3 ft GL Elevation above MSL: 20.8 ft BOP Equipment 13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams Page 2 2.0 Management of Change Information H Hilcorp Alaska, LLC Hilcorp E�C� Changes to Approved Permit to Drill Date: 5/3012019 Subject: Changes to Approved Permit to Drill for MPU E -42L1 File #: MPU E-4211-1 Drilling and Completion Program Any modifications to MPU E -42L1 Drilling & Completion Program will be documented and approved Approval: Drilling Manager Prepared: Drilling Engineer Date Page 3 Milne Point Unit E-421-1 SB Producer Hilcorp E. 499 Drilling Procedure 2.0 Management of Change Information H Hilcorp Alaska, LLC Hilcorp E�C� Changes to Approved Permit to Drill Date: 5/3012019 Subject: Changes to Approved Permit to Drill for MPU E -42L1 File #: MPU E-4211-1 Drilling and Completion Program Any modifications to MPU E -42L1 Drilling & Completion Program will be documented and approved Approval: Drilling Manager Prepared: Drilling Engineer Date Page 3 3.0 Tubular Program: Milne Point Unit E-42LI SB Producer Drilling Procedure Hole action OD (in) ID I in Drift in Conn OD in Wt 0/ft) Grade Conn Burst (psi) Collapse (psi) Tensio k -lbs Cond 20" 19.25" - - - X-52 Weld 12-1/4" 9-5/8" 8.835" 8.679" 10.625" 40 L-80 TXP 5,750 3,090 916 Tieback 7-5/8" 6.875" 6.75" 7.947 29.7 L-80 Hydril521 6,890 4,790 683 8-1/2" 4-1/2" 3.920 3.795 4.714 13.5 L-80 Hydril625 9020 8540 279 4.0 Drill Pipe Information: Hole ection OD ID (in) TJ ID TJ OD Wt in in iu,,,.,,. . ,. _ Grade Conn ,.,;, . -.. M/U Min MaiTension x -lbs Production 5" 4.276" 3.25" 6.625" 19.5 5-135 GPDS50 36,100 43,100 560klb 9' 4.276" 3.25" 6.625" 19.5 5-135 NC50 31,032 34,136 560klb All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 4 U Hilcorp W� 5.0 Internal Reporting Requirements Milne Point Unit E-42LI SB Producer 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 omazzolini@hilcorp.com, mmyers e hilcorl, ienael@hilcorp.com and cdin er .hilcorp com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by lam on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 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 mmyers2hilcorp,com icneel@hilcoM.com and edinger@hilcorp.com 5.6 Casing and Cement report • Send casing and cement report for each string of casing to mmyers@hilcorp.com a engel@hilcorp.com and cdinger@hilcorp.com 5.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmyers@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 lenge)@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 kfleming@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 cdinger@hilcorp.com Page 5 6.0 Planned Wellbore Schematic Milne Point Unit Well: MPU E-42 PROPOSED Last Completed: xx/xx/RM PTD: xxx-xxx eEc :: 3 v CLEw.: MY OPEN HOLE/ CEMENT DETAIL WELL INCLINATION DETAIL jj�20' '27083mf lam{n4r llole IWP@350 MD 4,11W8--- 1L-1873.5fWT-45M Marl =92.4*&@3,388 MD_ s,3L AFL=2f" o f. ' *• 31 1 V' L'ffi n to ryn� 23 45 r [F IYeu TO=u,�'t�l /TD=4m'RVp P8T0=11A49'trvT)I (P6(p=4„223')1VOJ Page 6 ____________ CASING DETAIL Na I Depth tern Milne Point Unit Type jl /Gmdeed Conn ID E-421-1 SB Producer MM Hilco2 E,a.gy Compuy Drilling Procedure 6.0 Planned Wellbore Schematic Milne Point Unit Well: MPU E-42 PROPOSED Last Completed: xx/xx/RM PTD: xxx-xxx eEc :: 3 v CLEw.: MY OPEN HOLE/ CEMENT DETAIL WELL INCLINATION DETAIL jj�20' '27083mf lam{n4r llole IWP@350 MD 4,11W8--- 1L-1873.5fWT-45M Marl =92.4*&@3,388 MD_ s,3L AFL=2f" o f. ' *• 31 1 V' L'ffi n to ryn� 23 45 r [F IYeu TO=u,�'t�l /TD=4m'RVp P8T0=11A49'trvT)I (P6(p=4„223')1VOJ Page 6 r____-- 1 ____________ CASING DETAIL Na I Depth tern Size Type jl /Gmdeed Conn ID Top MM 21' Cardattor 215/x42fwd&d WA Surf. 107 4vr Sart. MILE0JTv 8.835 Surfs¢ &tw 75/8' Tieback XL71L-JLWM &835 Sodom 0,625' 4Jfr Li. , w, P HI;edw/ l6 holes7J1 135/L-8D/Dgt625 1920 t7,7W 11,947 4112' Liner "08" Predrilled wJ 76Mlealtl l35/1.-W/tWQS 1920 17,82S' 11,950'• 13 17,750 TUBING DETAIL M 17,760 ? 6S/r SI2xPU.Tap Pother 2-7/r I Tub'm I 6.511,4D/EUC I 1"I 17e 17,400' -- r____-- 1 ____________ ____________________________________________ JEWELRY DETAIL Na I Depth tern 1 1160' STL-2-70GLMw/ 1'DPX7.t B6Latth 2 JAM STI- 2-7/W' GLM a/DV, Bx Loch 3 1y700 2-7/8^x14Pmfil,2_205-14 f 4 27,317 Dmh IkM:PMP4 S 173M Puny:SMPMPM6 . SYD 6 17,33K Puny:9 FM910 7 17,3N9 Gm Seaveum.: Gas Awitler538G5 8 17,357 Upper Tandem Seal: GSBIDSIKSWAB PMA 9 17,3&8' Lvxer Tantlem Seal: G5030BIMSB%AB PPSA 10 17,370 8lctor:5621P aO: W2,78WIM It x7,398' Senwr.Ienith 12 1T,40D Centralaer. Bottom @KIaQ; 13 17,750 SC4IbY.0 PecePLacle UDODT M 17,760 ? 6S/r SI2xPU.Tap Pother IS 17,780 OAlareral LD.1 B111mral Gory Module) llR-168"I 16 17,&VYf95)8"&Vyl llatger iLaremiCNr10=5.9EO�tbuiphm MR10, .69K) 17 17,810 4-Wl2 5/8^ RATA Santa¢ Dwrter IMD115ea1t9t_ 10--3.68") 18 17,820 DBN' le 10=356YI 19 x7,835' Ya9-5jr ML�PLiner llay},Puler w/ 5CaW1rA 8acepatde nD=4 x-1 M 17,845' Raft rn d I=tw seal a�mN 110c3.875'I 21 11i.SW OALateral4-3 YNiHaMe8xkff Sub 12 xIIBM' C.'.Lateral4-ifr WIVVaW LTC M II'BaII. 5eetlCI.d 13 sl3yW CB Lateral4-L70rillahle J.xkn$Sub 24 1 11fy45` I C Latera14.1/Y WNV.A LTC PBSI"&illon5eat/CIsM) "_______-....W6-"----.----..i GENERAL WELLINEO API:50-029-famx-0D00 Orilkd and[pnpleted hylmor48on B' -Date TBO F uvi:ed5: JL S; ]S; 3619 H Hilcorp E., Co.2 7.0 Drilling / Completion Summary Milne Point Unit E -42L1 SB Producer Drilling Procedure MPU E-42 is a grassroots ESP dual lateral producer planned to be drilled in the Schrader Bluff OB/OA sand. E-42 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 -42L1 On top of the E-42 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 seal bore diverter will be ran prior to running the 4.5" liner with a RAM junction. A lateral entry module will be ran, followed by 7-5/8" tieback and ESP completion The Innovation Rig will be used to drill and complete the wellbore. Operations are expected to commence approximately June 28, 2019, 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. Run Seal Bore Diverter 4. Run 4-1/2" liner with RAM Hanger 5. Run Lateral Entry Module & SLZXP 6. Run 7-5/8" Tieback 7. Run ESP Completion Note: Operations prior to E -42L 1 were covered on the E-42 PTD. Reservoir Evaluation Plan: 1. Production Hole: No mud logging. On site geologist. LWD: GR + ADR (For geo-steering) Page 7 H Hilcorp Er Cmn2 Milne Point Unit E -42L1 SB Producer 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-42LL Ensure to provide AOGCC 24 hrs 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 Cc Man office. AOGCC Regulation Variance Requests: None requested Page 8 H Hilcorp Eveegy C®pmy Summary of BOP Equipment and Test Requirements Milne Point Unit E -42L1 SB Producer 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-I/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: jim.regg@alaska.gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guv.schwartz@alaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: Victoria.loeppaalaska.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@alaska.gov Test/Inspection notification standardization format: hgp:Hdoa.alaska.gov/ogc/forms/TestWitnessNotif.htmi Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 9.0 Run Whipstock & Mill Window 13.1 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 13.2 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 13.3 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 15 LOHS 13.4 PU & RIH with whipstock assembly. Ensure all connections are torqued to spec 13.5 PU and MU milling assembly as per Baker BHA tally. • Gauge mills prior to running in hole 13.6 PU whipstock anchor assembly • Adjust orientation between anchor and whipstock as needed • Ensure orientation is documented and agreed upon 13.7 PU remaining workstring and MWD • Document MWD offset with whipstock face • Ensure UBHO for wireline • HWDP, 2-3 string magnets, float sub 13.8 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. E?nsure 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 13.9 —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 Milne Point Unit E -42L1 SB Producer Hilcorp ComY^r Drilling Procedure 9.0 Run Whipstock & Mill Window 13.1 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 13.2 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 13.3 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 15 LOHS 13.4 PU & RIH with whipstock assembly. Ensure all connections are torqued to spec 13.5 PU and MU milling assembly as per Baker BHA tally. • Gauge mills prior to running in hole 13.6 PU whipstock anchor assembly • Adjust orientation between anchor and whipstock as needed • Ensure orientation is documented and agreed upon 13.7 PU remaining workstring and MWD • Document MWD offset with whipstock face • Ensure UBHO for wireline • HWDP, 2-3 string magnets, float sub 13.8 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. E?nsure 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 13.9 —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 EunBY C PmY Milne Point Unit E-421-1 SB Producer Drilling Procedure 13.10 Orient Whipstock to desired direction by turning DP in'/4 round increments. P/U and S/O on DP to work all torque out after oriented. (Being careful not to set trip anchor). Target orientation is 30°LOHS. or- Whipstock f Whipstock Orientation Diagram: WIN Desired orientation of the Whipstock face is 15L to 30L, target is 15 LOHS Hole Angle at window interval (7,776 MD) is —83 deg. 13.11 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, 40klb will shear anchor bolts 13.12 Obtain survey of whipstock orientation 13.13 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 may jam window mill into casing. 13.14 PU 5/10' above top of whipstock 13.15 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 13.16 Record PU, SO, ROT weights. Slack off to top of whipstock with light weight and low torque. 13.17 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# 13.18 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 13.19 After window is milled CBU until even MW and hole is clean of metal cuttings 13.20 Shutdown pumps and work milling assembly t mow g for drag. 13.21 CBU and reduce properties for drillin 13.22 Pull into 9-5/8" casing and perfo T t/ 12.0 ppg EMW. Chart Test. Page 11 1 L ��'2� 13.23 POOH with milling BHA & LD Milne Point Unit E -42L1 SB Producer Drilling Procedure • 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. 13.24 PU stack washer and wash BOPE stack. Cycle all rams to clear any potential milling debris. Page 12 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 rotating bit tagging 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. • Rheology: Keep viscosifier additions to an absolute minimum (N -VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high Page 13 Milne Point Unit E-421-1 SB Producer Hilco �Z4�7 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 rotating bit tagging 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. • Rheology: Keep viscosifier additions to an absolute minimum (N -VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high Page 13 H Hilcorp E� X22 Milne Point Unit E -42L1 SB Producer Drilling Procedure vis sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8.5 (hole diameter) for sufficient hole cleanine 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 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-CIDE 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 H Hilcorp En W Cumpmy Milne Point Unit E-42LI SB Producer 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 H Hilcorp Ev C,a Milne Point Unit E -42L1 SB Producer 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 11.0 Retrieve Whipstock & Run Seal Bore Diverter 13.1 PU Baker Fixed lug retrieving tool assembly, as per Baker • Ensure to note orientation of fixed lug 13.2 RIH t/ — 40' above whipstock. Record PU & SO weights 13.3 Orient fixed lug tool, slowly slack off and position tool over whipstock 13.4 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. 13.5 Attempt straight pull of 40klb 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 13.6 Once whipstock is free, POOH slowly with smooth pipe movement in/out of slips to ensure whipstock does not fall off of lug tool 13.7 Before LD whipstock, inspect whipstock face for mill track. Verify offset between anchor lug and whipstock, face for upcoming Seal Bore Diverter run. 13.8 PU and RIH with sea] bore diverter (SBD), production anchor, seal assembly, and FJD running tool • Ensure that the anchor orientation is the same as the whipstock that was used to mill the window 13.9 PU MWD and remainder of running string • Ensure MWD & FJD flow rates do not interfere 13.10 RIH with SBD assembly, shallow test MWD • Do not approach FJD activation flow rate while testing MWD • Do not pump viscous pills while RIH 13.11 RIH t/ — 30' from landing. Work torque out of string and obtain parameters 13.12 Obtain MWD orientation, align SBD within 15 degrees of required orientation 13.13 Slack off and latch anchor. PU to confirm latch. Confirm orientation with MWD 13.14 Once orientation is correct, increase flow rate, activate FJD and PU to release running tool. 13.15 After tool is released, CBU and condition mud • Consider pumping a viscous pill across SBD to keep debris and cement out of profile. This is not required 13.16 POOH with SBD running string. LD Same. J Page 17 Milne Point Unit E -42L1 SB Producer Hilco•TTy Hilt y Drilling Procedure 11.0 Retrieve Whipstock & Run Seal Bore Diverter 13.1 PU Baker Fixed lug retrieving tool assembly, as per Baker • Ensure to note orientation of fixed lug 13.2 RIH t/ — 40' above whipstock. Record PU & SO weights 13.3 Orient fixed lug tool, slowly slack off and position tool over whipstock 13.4 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. 13.5 Attempt straight pull of 40klb 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 13.6 Once whipstock is free, POOH slowly with smooth pipe movement in/out of slips to ensure whipstock does not fall off of lug tool 13.7 Before LD whipstock, inspect whipstock face for mill track. Verify offset between anchor lug and whipstock, face for upcoming Seal Bore Diverter run. 13.8 PU and RIH with sea] bore diverter (SBD), production anchor, seal assembly, and FJD running tool • Ensure that the anchor orientation is the same as the whipstock that was used to mill the window 13.9 PU MWD and remainder of running string • Ensure MWD & FJD flow rates do not interfere 13.10 RIH with SBD assembly, shallow test MWD • Do not approach FJD activation flow rate while testing MWD • Do not pump viscous pills while RIH 13.11 RIH t/ — 30' from landing. Work torque out of string and obtain parameters 13.12 Obtain MWD orientation, align SBD within 15 degrees of required orientation 13.13 Slack off and latch anchor. PU to confirm latch. Confirm orientation with MWD 13.14 Once orientation is correct, increase flow rate, activate FJD and PU to release running tool. 13.15 After tool is released, CBU and condition mud • Consider pumping a viscous pill across SBD to keep debris and cement out of profile. This is not required 13.16 POOH with SBD running string. LD Same. J Page 17 Milne Point Unit E -42L1 SB Producer Drilling Procedure 12.0 Run 4-1/2" Production Liner 12.1 Well control preparedness: In the event of an influx of formation fluids while running the 4- 1/2" liner, the following well control response procedure will be followed: 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". 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. 12.2 Well control preparedness: 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 point b e TIW). M/U 2-3/8" and then 4-1/2" to triple connect. This joint shall be fully M/U with crossovers prior to running the first joint of wash pipe. 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. 12.3 R/U 4-1/2" running equipment. • Ensure 4-1/2" x DS -50 crossover is on rig floor and M/U to FOSV. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 12.4 Run 4-1/2" production liner — Reference handling and running procedure. • Use API Modified or "Best O Life 2000 AG" thread compound. Dope pin end only w/ paint brush. Wipe off excess. • Use Hydril 625 stabbing guide • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Run packoff and float shoe on bottom. • 4-1/2" pre drilled liner should auto —fill, top off with completion brine if needed • Swell packers will not be required on this completion unless the well is drilled out of zone J Page 18 0 Hilcorp Erna®C®pwy 4-1/2" 13.5 4 L-80 Hvdril 625 Torane Milne Point Unit E-421.1 SB Producer Drilling Procedure Wedge 625(8) Ere.e.. 10/312077 Outside Diameter OD Minimum MaximumO eratin Torque 4.5" 8,000 ft -lbs 11,300 ft -lbs 11,300 ft -lbs Wedge 625(8) Ere.e.. 10/312077 Outside Diameter 4.580 in. Min. Wall 87.5% GEOMETRY Thickness r) Grade L80 Nammal OD 4.500 in. Nominal Weight 13.5011,sHi Type 1 3.795 in. Wall Thickness 0,780 q1. Connection OD REGULAR CWPLNG PIPE BODY OD Tole. API Option PERFORMANCE Body : Red 1st Band: Red Grade L80 Type 1` Drift API Standard 1st Band: Brown 2rM Bond. calapse esw Psi 2nd Band: - Brown CONNECTION DATA Type Casing 3rd Band: - 3rd Band: - GEOMETRY 4th Band: - PIPE BODY DATA GEOMETRY Nammal OD 4.500 in. Nominal Weight 13.5011,sHi DDR 3.795 in. Nominal ID 3920 in. Wall Thickness 0290 in. Plain EM Weight 13.051b51e OD Tole. API PERFORMANCE Body Yield S gth 307 x1 DOD lbs internal Yield 9020 psi SMYS 40000 psi calapse esw Psi CONNECTION DATA GEOMETRY C neehw OO 4.714in. Connealon ID 3.e49in. Makeup Loss 4-30in. - hmads per in 3.59 Connection OD Option REGULAR PERFORMANCE Tension ESooienpy 910% Joinc Yield Svength 279.370 x1000 Internal Pressure capac'4y W20-00 psi lbs Compression Elfieenry 94.5% Cpmpresson Strerglh 290.115 x1000 Max. AOcaable Ben kng 73.7 'AM ft lbs Extemal Pressure Capaaty 8540000 psi MAKE-UP TORQUES Mininwm 8000 ft -lbs Opimum 9800 n,lbs Maximum 12800 Nbs OPERATION LIMIT TORQUES Operating14,;- 12800 a-Ibs Yield Torque 15000 T0s Page 19 H Hilcorp Milne Point Unit E-421.1 SB Producer Drilling Procedure Note: Blank Pipe and Swell Packers may be ran if any out of zone excursion occur during lateral drilling 12.5 Pick up enough liner to provide to account for a liner hanger depth of --7600' MD. • AOGCC regulations require a minimum 100' overlap between the inner and outer strings as per 20 AAC 25.030(d)(6). Do not place liner hanger/packer across 9-5/8" connection. 12.6 R/U false rotary and run 2-3/8" 6.4 # Inner String _ • Drift 2-3/8" inner string with minimum 1.5" drift (WIV closing ball 1.25") 12.7 Before picking up Baker RAM hanger / packer assembly, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 12.8 M/U RAM hanger inner string and 4-1/2" liner. Fill liner tieback sleeve with "Pal mix", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 12.9 Note PUW, SOW, ROT and torque. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 12.10 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. 12.11 The liner and inner string will prevent the DP from auto filling. Fill DP every 5 stands, more frequently if SOW trend indicates. 12.12 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. 12.13 CBU and Obtain up and down weights of the liner above whipstock and before entering open hole. Record rotating torque at 10, & 20 rpm 12.14 If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 12.15 RIH until RAM hanger is — 30 above SBD. Obtain parameters. 12.16 Rig up to pump down the work string with the rig pumps. 12.17 Break circulation and begin displacing wellbore to 2% KCl/NaCl brine, ensure weight matches MW or previous brine weights. Begin circulating at —1 BPM and monitor pump pressures. Slowly bring rate up while swapping the lateral to brine. Pump train as follows: 20 bbl high vis Page 20 H Hilcorp �r� Milne Point Unit E-42LI SB Producer Drilling Procedure sweep / 2 x OH volume brine / 40 bbl SAPP pill #1 / 50 bbl brine / 40 bbl SAPP pill #2 / 50 bbl brine / 40 bbl SAPP pill #3. 12.18 Ensure circulation pressures do not exceed set pressure for liner hanger pusher tool. 12.19 Monitor pump pressures closely and adjust pump rate if the well appears to be packing off at the swell packers (if run). Note all losses. Confirm all circulating pressures with Baker. Capture mud for reconditioning and reuse if possible 12.20 Monitor the returned fluids carefully during displacement. 12.21 Circulate out SAPP pills prior to setting the hanger and packer. 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. 12.22 Land RAM hanger on the SBD. PU to confirm engagement. Re -land RAM hanger. 12.23 Shutdown pumps. Drop setting 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 to pressure up and release from RAM hanger. Verify HRD running tool is released. 12.25 Verify RAM alignment by tagging guide nose shoe in ID of SBD. 12.26 PU inner string above RAM hanger. Pressure up and blow ball seat and then circulate SBD clean 12.27 POOH with liner running tool and inner string. LD Same. Do not pump a dry job prior to running tubing string, as LEM and tieback still need to be ran and dry job can impact profiles. 12.28 Inspect running tools Page 21 H Hilcorp F� ,m 13.0 Run Lateral Entry Module & SLZXP 13.1 PU & MU LEM, seals, and SLZXP Assembly 13.2 MU MWD. Ensure necessary orientations are recorded. Milne Point Unit E -42L1 SB Producer Drilling Procedure • Ensure MWD flow rates do not approach running tool pressures and interfere with operation sequence 13.3 RIB — 30ft/min or as directed by Baker rep • Shallow test MWD 13.4 RIH until seals are — 40' above RAM Hanger. Obtain parameters. 13.5 Obtain necessary orientation through MWD surveys 13.6 Slack off and land LEM 13.7 Drop setting ball and pump slowly, slow pumps before ball seats. 13.8 Continue pressuring up to 2700 psi to set the SLZXP packer. Hold for 5 minutes. Slack off 20K lbs on the SLZXP to ensure the HRDE setting tool is in compression for release from the SLZXP liner hanger/packer. Continue pressuring up to 4500 psi to activate the hydraulic pusher tool to set the SLZXP packer. This will also release the HRDE running tool. 13.9 Bleed DP pressure to zero, Pick up to expose Rotating Dog Sub and set down 50k# without pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20 rpm and set down 50k# again, 13.10 PU to neutral weight, close BOP and test annulus to 1500 psi for 10 min and chart record same. 13.11 Bleed off pressure and open BOPE. Pickup to verify that the HRD setting tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. / 13.12 P/U above liner top packer and displace well to completion fluid. 13.13 POOH. Inspect running tools. Page 22 H Hilcorp E� C—Pa" 14.0 Run 7-5/8" Tieback Milne Point Unit E-42LI SB Producer Drilling Procedure 14.1 RIH with mule shoe on 5" DP to Liner Top and circulation Liner Top and SBE clean. POOH. 14.2 R/U and pull wear bushing. Get an accurate measurement of RKB to tubing hanger load shoulder to be used for tie -back space out calculation. Install and test 7-5/8" (250/3000 psi) solid body casing rams. 14.3 R/U 7-5/8" casing handling equipment. • Ensure XO to DP made up to FOSV and ready on rig floor. • Rig up computer torque monitoring service. • String should stay full while running, r/u fill up line and check as appropriate. 14.4 PIU tieback seal assembly and set in rotary table. Ensure 7-5/8" seal assembly has x4 1" holes above the first seal. These holes will be used to spot diesel freeze protect in the 9-5/8" x 7-5/8" annulus. 14.5 M/U first joint of 7-5/8" to seal assy. 14.6 Run 7-5/8" 29.7# H521 tieback to position seal assembly two joints above tieback sleeve. Record up & down weights. • Following running procedure outlined above. Page 23 Wedge 5210 Milne Point Unit E-421.1 SB Producer HHCOTp Drilling Procedure Wedge 5210 ....... IV(59Mt8 OlseMe Diindtt 7.625-n. Nin, WWI Thift.es Grad. L!6 INW- TVW t Well Thictmn;v 0.375 n. Conwn,bon OD REGULAR Opli.. COIIPLJNG PIPE BODY Dodr Red 1.10 .. Red Gntli LA0 Type 1• Dtik Atn 5tanmrtl 1s Bard: Brown 2rd Baia: gni Dail • Brown TYPe Casing 3rd Banc. • Sd Bard. SIh Bard. PIFs yf.DY 1 GEOMETRY 1 Vimna ]C 7.625 n Yominal'Hepnr 29_To¢sV1 Lmll fi.is in Ynrtna'_p SA75.n. Ylall TGcdness OATS, Paan EPa 444441 29.0616119 oc �c:eace att PERFORMANCE a:s]r y4d Svenalh 1163.1 CCG Ih: .i wY.a10 6996 .I sws 90489 Pii C.alifcC 47% Psi GEOMETRY ranned.r. CG 7.9i7 r .,Rnnennn 10 11.801 r. Male �p Loa. 3.706 m. Tb�s W 1,1 339 CRnn.o. W CQ, BEGIILAR PERFORMANCE Tarsgn E9cMruy 7131. Janl red S9 qlh 4915.296.1C[0 vt.m Pnnaa. OaPa[kr fi99690O Ps Ihs Camprcssna EntMn[y 974% Cniti'..n slmmgc. 597.826.90 W. Aerm00k 9.'Mvg 343'i1630 106 ¢ramal ErasuiC Cif+ -11r 4796.6159 PL MANE -UP TORQUES &I"M m 9400 h, -0s Opamum 1010094hs ala.imum 14Tb➢n19s OPERATION UNIT TORQUES GPcfa4p T.,. 35006 lid. Viald Tm0aa 53M1,lvs Notes Thas connection is iuBy interchangeable with: Wedge 521£ - 7.625 in. - 26A ; 33.7139 Iba t Connections with @3pelessO Technology are 6uBy compatible with the same connection in its Standard version Page 24 14.7 M/U 7-5/8" to DP crossover. 14.8 M/U stand of DP to string, and M/U top drive. 14.9 Break circulation at 1 bpm and begin lowering string. Milne Point Unit E -42L1 SB Producer Drilling Procedure 14.10 Note seal assembly entering tieback sleeve with a pressure increase, Stop pumping and bleed off pressure, leave standpipe bleed off valve open. 14.11 Continue lowering string and land out on no-go. Set down 5 — l0k lbs. Mark the pipe at this depth as "NO-GO DEPTH". 14.12 P/U string & remove unnecessary 7-5/8" joints. 14.13 P/U hanger assembly and space out. M/U (or L/D) necessary joints and pup joints to position seal assembly 1 ft above "NO-GO DEPTH" when tie -back hanger lands out in wellhead. 14.14 Ensure circulation is possible through 7-5/8" string. 14.15 RU and circulation corrosion inhibited brine in the 9-5/8" x 7-5/8" annulus. 14.16 With seals stabbed into SBE, Spot diesel freeze protection from 2500' to surface in 7-5/8" x 9- 5/8" annulus by reverse circulating through the holes in the seal assembly. Ensure annular pressure are limited to prevent casing collapse of 7-5/8", verify collapse pressure of 7-5/8" tie back. 14.17 Slack off and land hanger. 14.18 Confirm hanger has seated properly in wellhead. Make note of actual weight on hanger on morning rpt. 14.19 Back out landing joint. M/U packoff running tool and install packoff on bottom of landing joint. Set tubing hanger pack off. RILDS. Test void to 3000 psi / 10 min. 14.20 R/D casing running tools. / 14.21 Test 7-5/8" x 9-5/8" production annulus to 1000 psi / 30 min. 1 14.22 Set test plug and change top rams from 7-5/8" to 2-7/8" x 5-1/2" VBR. Test annular and lower rams to 2-7/8" test joint, 250 low / 3000 psi high. Page 25 0 Hilco�p Milne Point Unit E -42L1 SB Producer Drilling Procedure 15.0 Run ESP Completion 15.1 RU spooler with ESP power cable and heat trace. RU two 3/8" capillary string spoolers. The capillary strings should be filled with hydraulic fluid. 15.2 Verify the ESP components as per Centrilift. Verify that the length of the motor lead flat cable will place the splice between the discharge head and the 10' handling pup collar. A Centrilift rep shall be on the rig floor at all times during the running of the ESP. 15.3 Makeup new ESP assembly with new motor lead extension, seal section and motor. 15.4 Run the 2-7/8" ESP Completion as noted below. The completion includes two 3/8" capillary tube from surface to the centralizer on the motor. The capillary tube will be secured to the tubing with Cannon clamps. Function test the capillary tube every 2,000' by pumping -2 gallons of hydraulic oil through the check valves. Record the pressure at each testing point 15.5 M/U ESP assy and RIH to setting depth. i. Ensure appropriate well control crossovers on rig floor and ready. ,,-ii. Monitor displacement from wellbore while RIH. • Centrilift ESP Assembly with bottom of assembly @ predetermined depth • 10' 2-7/8" 6.5#, L-80 Pup Joint • 1 joint 2-7/8" 6.5#, L-80 EUE 8rd tubing • 2-7/8" "XN" nipple (2.313" packing bore/ 2.205" No -Go ID) ,� • 3 joints 2-7/8" 6.5#, L-80 EUE 8rd tubing 10' 2-7/8" 6.5#, L-80 Pup Joint V • GLM 2-7/8" x 1" GLM w/ dummy installed • 10' 2-7/8" 6.5#, L-80 Pup Joint • 2-7/8" 6.59, L-80 EUE 8rd tubing • 10' 2-7/8" 6.54, L-80 Pup Joint • GLM 2-7/8" x 1" w/ SO @ -140' MD • 10' 2-7/8" 6.5#, L-80 Pup Joint • 3 joints 2-7/8" 6.5#, L-80 EUE 8rd tubing • Tubing Hanger o Check the conductivity of electric cable every 2,000' and every new splice while running in hole. o Function test the capillary tube every 2,000' when checking the conductivity of the electric cable. Page 26 H Hilcorp Milne Point Unit E -42L1 SB Producer Drilling Procedure o Use Cannon clamps on every joint to secure the capillary tube. o The makeup torque values for 2-7/8" L-80 6.5# EUE 8rd tubing are: Minimum: 1,730 ft -lb, Optimum: 2,300 ft -lb, and maximum: 2,800 ft -lb. o The 2-7/8" L-80 6.54 EUE 8rd tubing performance properties are: Body Yield: 145,000#, Burst: 10,570 psi, Collapse: 11,160 psi. 15.6 Fill tubing while splicing cable, mid -cable splices and tubing hanger splices. After tubing is full, break circulation by pumping 10 bbls down the tubing to clear any debris. 15.7 Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. 15.8 MU tubing hanger and landing joint. Splice ESP power cable and terminate control lines. Test cable. Install a brass -shipping cap on the ESP penetrator. 15.9 Land tubing with extreme care to minimize damaging the ESP penetrator, pigtail and alignment pin. 15.10 RILDS and test hanger. LD landing joint. 15.11 Install BPV and N/D BOP. 15.12 NIU tree / adapter and tree. Test tubing hanger void to 500 psi low / 5000 psi high. Terminate the cap strings. 15.13 Circulate diesel freeze protection down 2-7/8" x 7-5/8" annulus (Volume should equal capacity of tubing to 2500' + tubing annulus to 2500'). Connect IA to tree and allow diesel freeze protect to "U-tube" into position. Note — this may be done post -rig. 15.14 Pull BPV. Set TWC. Test tree to 250 psi low / 5000 psi high Pull TWC Set BPV 15.15 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 16.0 RDMO Innovation Rig Page 27 17.0 Innovation Rig Diverter Schematic 3118' U 13-% Teono4y Page 28 ;ontrol Technology 358' 5M Contra ethnology Double Ram -118' Choke Line 16' Diverler Line Milne Point Unit E-421.7 SB Producer Hilco e.."C � Drilling Procedure 17.0 Innovation Rig Diverter Schematic 3118' U 13-% Teono4y Page 28 ;ontrol Technology 358' 5M Contra ethnology Double Ram -118' Choke Line 16' Diverler Line 18.0 Innovation Rig BOP Schematic _13-5/8" 5M Control Technology Annular BOP ■N—I 7Technology Double Ram� 0 ® -------13-5/8" 5M Control Technology Single Ram 13-5/8" x 5M —11" x 5M 9-5/8" DBL D Seal t2O" 2-1/16"x 5M Casing Hanger13-5/8" x 5M S-22 13-518" NOM 9-518"BTC Btm x2-1/16" x 5M 10.5"-4 SA Pin Top W/ Primary Seal ng ing Page 29 Milne Point Unit E -42L1 SB Producer Hilcox E� � Drilling Procedure 18.0 Innovation Rig BOP Schematic _13-5/8" 5M Control Technology Annular BOP ■N—I 7Technology Double Ram� 0 ® -------13-5/8" 5M Control Technology Single Ram 13-5/8" x 5M —11" x 5M 9-5/8" DBL D Seal t2O" 2-1/16"x 5M Casing Hanger13-5/8" x 5M S-22 13-518" NOM 9-518"BTC Btm x2-1/16" x 5M 10.5"-4 SA Pin Top W/ Primary Seal ng ing Page 29 H Hilcorp 19.0 Wellhead Schematic 9:. �e c slip P t 11 L _ 1 I :9 .r 9:. �e c slip t 11 L _ 1 I 5; Y Y P Milne Point Unit E-421-1 SB Producer Drilling Procedure i ''FII Pi HOLZ 're Cxil•'�iTI LL� ' FF SE all( �Lr IEl ITIS rt r n IIRFA ° HLLLH AI Lor'III--- .m .0 - L 9 Cf 'pC f IFnM1L r w r16,t_ wu t o n....•A La. 10_>S � RR pc 4tIPtYF.A �_ I a IY'S`. HA - (Pi 270 )I Page 30 t 11 L _ 1 5; Y Y P ITV �Irl V r-x11r ac z cis _ t r p; Ei 4) hf' 11 hax i ''FII Pi HOLZ 're Cxil•'�iTI LL� ' FF SE all( �Lr IEl ITIS rt r n IIRFA ° HLLLH AI Lor'III--- .m .0 - L 9 Cf 'pC f IFnM1L r w r16,t_ wu t o n....•A La. 10_>S � RR pc 4tIPtYF.A �_ I a IY'S`. HA - (Pi 270 )I Page 30 H HilcoT E� � Milne Point Unit E-421-1 SB Producer Drilling Procedure 20.0 Days Vs Depth MPU E -42L1 5B Dual Lat OA/OB Producer Days vs Depth 1000 —MPU E -42L1 SB Dual Lat OA/OB Producer ME 5000 x 11000 13000 15000 0 5 10 15 Days Page 31 20 21.0 Formation Tops & Information MPU E -42L1 Formations (wp04) MD (ft) NDss (ft) ND (ft) Formation Pressure (psi) EMW (PPg) Milne Point Unit 2115 -1707 1755 E-421-1 SB Producer 8.46 Hilcorp Evagy Cmoryvy Drilling Procedure 21.0 Formation Tops & Information MPU E -42L1 Formations (wp04) MD (ft) NDss (ft) ND (ft) Formation Pressure (psi) EMW (PPg) Base Permafrost 2115 -1707 1755 772.2 8.46 LA3 5861 -3628 3676 1617.44 8.46 Schrader Bluff NB 6945 -4128 4176 1837.44 8.46 Schrader Bluff OA (Target) 7750 -4239 4286 1885.84 8.46 Page 32 H HilcoTp Milne Point Unit E-421.1 SB Producer Drilling Procedure GENERALIZED GEOLOGICAL FORECAST SS GEOLOGICAL TVD FM LITH DESCRIPTION At Garol. • ap� Grbl Unconsolidated coarse to medium sand and small gravel with «.tom. 5OO minor siltstone. Heavy gravel conglomerate to 1400'- Wood fragments 1,000 8 , • + ; throughout permafrost zone- Abundant pyrite at 1500 fl. o 4 Base �� RUNNING GRAVELS 1700' permafrost 2,000' Be prepared for HYDRATE gas cut HYDRATES9 C raid 2000 to 25CO' as (E -land E41 Sagai anicktok L -11--12&-2"). (E-14,30, (plus F-10 -11. HYDRATES. -33 a -210 GAS CUT MUD A Predominangy clay to .f- 3000' with Interbeds of sand, clays and slltstones with occasional shows of coal. Y 3,000 Continued Inwitieds of sand, clays and s8tsiones with occasional shows of coal- Clay, sihstone and sand interbeds between 3D00 and 6000'. Llgnl2e34DO-350011 SVirtenelsnarerarty("muddier")than waaaaw C those In the Prudhoe Bay area. asoo• I:,- t ucaN15 Ugnu: Thick SWABBINGfSTICKY -200 to 300 In some areas, water -tilled at E -pad- _A a o on. filled i ctIonmostly some zones are filled with hydrocarbon. The Ugnu section (Imerbeddtd fluvial 58ndatanP sandstone A 3 and stare) represents use in:bst progradation of the Ugnu dela is system over the underlying CLAYIGUMBO: E -20a. -28. C D C x shallow roanne Schrader Bluff section. Fluvial nature Carl make 11 difficult to doermhe top Y a and base of Individual units. Bohan bounding surface of the entire Ugnu package Is picked D A at the regional unconlonnity M7DS isee the 14sands bAcw)- GAS CUT MUD E-24 AT 3906 p M -Sands: Fluvial, deltaic chamxt sandstones prograded over the underlying shallow TVD; E -13B @ 3618 tvd. 4,000 , marine sandstones of the Schrader Stuff- The M -Sands are subdivided into three TIGHTIPACKING OFF, E -25A, A t a'- Iithostraligraprac units flea. Mb. Pole butt top to bottom) tat can be difficult to correlate due �+ to their guvialdeitaic nature. The M70S marks the lower most boundary. M-awtd intervals Surface casing seat a are typically coamening upward packages of varying thicknesses. raniii gfrom 50-80 thick All zones are highly unconsolidated sandstones ith in the 30311%and for Schrader Bluff C �- Cat<a witporosities range pereabibries reaching upwards of 20OD-SOOD mit. Each M- srid interval acts as a completion. eyer L hydraulically separate reservoir based on current understanding. C v. N -Sands: The N+aaritls are composed of slacked. marine shoreface sandstones tlai 71GHTILEDGES (COAL) RUNNING SURFACE C A a a coarsen upwards ham thin, silty mudslones into thin, low nef.gross very Ilne to rre6um CASING, E-24, -33 8 -25. grained sandstones. The NO. NC & ND -Sands are the pest quality reservoir rack ol dean, D yU - high rieLgross line to media u grained sandstone. ll poroshy ranges from 12-36i6 and d 3 Z pennesblimm range from 100-3000 mod. The NC & ND-aands we the primary target With E, secondary targets in theNB-sand. The more unconsolidated Units pypicaty the NO, NC A J m NO) tend to washuuL aid the liver grained silty mudslorws can cause slow ROP. Each N -sand acts as a hydraulically isolated separate reservoir. A O•Band3: The O -sands consist of slacked lower shorclace marine sands that clean upwards tram silty mudstones pmervirriing shares) to thin bedded, very Pone to Pone grained sandstones- These OA and OS sandstones are 25.30'thick. andthe OA -sand is the primary y'y rp s D Larget for horizontal wells at E -pad. Oland poros,bes range from 12-36% and penneabdilies in 4 in the OBsand reach upwards of Boo ltd, whereas perrneaalleti s In the OA -sand reach only y t 350 ltd. There are underlying OB sands {OBtrOBt) final correlate over the reglon- N f C May contain tight nodules and lenses that cause directional detleclion (especially when 0 horizootalf aid slow ROP- Each 0 -sand trio l acts as a hydraulically Isolated reservoir. e The numerous sub-selsmlc `5-30 n taunts and the lateral diseontinu yob the NBA ds make n S 0,3p O essential for clear pick Identification down through the Ugnu and N -sands. as well as careful geosteering In horizontal wells. Page 33 n Hilcorp E, Cmnpoy 22.0 Anticipated Drilling Hazards Milne Point Unit E -42L1 SB Producer Drilling Procedure 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: J 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 H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event 1-12S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. 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 34 H Hilcorp ^ ZTJ 23.0 Innovation Rig Layout Milne Point Unit E-42LI SB Producer Drilling Procedure Page 35 / H Hilcorp Em C22 24.0 FIT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: Milne Point Unit E-42LI SB Producer Drilling Procedure 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. PIU 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 36 H Hilcorp I wgy CZT 25.0 Innovation Rig Choke Manifold Schematic Milne Point Unit E-421.1 SB Producer Drilling Procedure Page 37 Milne Point Unit E -42L1 SB Producer Hilcr Drilling Procedure 26.0 Casing Design 11 Calculation & Casing Design Factors DATE: 6/14/2019 WELL: MPU E -42L1 DESIGN BY: Joe Engel n Criteria: Hole Size 12-1/4" Mud Density: 9.2 ppg Hole Size 8-1/2" Mud Density: 9.2 ppg Hole Size Mud Density: Drilling Mode M/8" MASP: 1458 psi (see attached MASP determination & calculation) MASP: 7,626 Production Mode MASP: 1458 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.494 psi/ft) and the casing evacuated for the internal stress Page 38 Casing Section Calculation/Specification 1 2 3 4 Casing OD M/8" 4-1/2" Top (MD) 0 7,626 Top (TVD) 0 4,287 Bottom (MD) 7,776 11,948 Bottom (TVD) 4,287 4,157 Length 7,776 4,322 Weight (ppf) 40 13.5 Grade L-80 L-80 Connection TV H1125 Weight w/o Bouyancy Factor Obs) 311,040 58,347 Tension at Top of Section (ibs) 311,040 56,347 Min strength Tension (1000 lbs) 916 279 Worst Case Safety Factor (Tension) —1-94- 4.78, Collapse Pressure at bottom (Psi) 2,118 2,054 Collapse Resistance w/o tension Psi) 3,090 6,540 Worst Case Safety Factor (Collapse) 1.46 - 4.16 ' MASP (psi) 1,458 1,458 Minimum Yield (psi) 5,750 9,020 Worst case satety factor Burst 3.84 Page 38 R H_lolco�rp 27.0 8-1/2" Hole Section MASP 11 Maximum Anticipated Surface Pressure Calculation corp 8-1/2" Hole Section HilMPU E -42L1 Milne Point Unit MD TVD Planned Top: 7776 4287 Planned TD: 11948 4157 Milne Point Unit E -42L1 SB Producer Drilling Procedure Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff OA Sandi 4,287 1959 1 Oil 8.79 0.440 Offset Well Mud Densities Well MW range Top (TVD) 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: 4,287 (ft) x 0.78(psi/ft)= 3343.8 3343(psi) - [0.1(psi/ft)*4287(ft))= 2915 si MASP from pore pressure (complete evacuation of wellbore togas from Schrader Bluff OA sand) 4287 (ft) x 0.44(psi/ft)= 1886 psi \ ' 1886(psi)-0.1(psi/ft)*4287(ft) 1458 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 39 H HilczT 28.0 Spider Plot (NAD 27) (Governmental Sections) Milne Point Unit E-421-1 SB Producer Drilling Procedure Milne Pant Unit MPE 42L1 Well 0 1.000 2,000 nz EEEENNEEEC====== Feet Page 40 29.0 Surface Plat (As Built) (NAD 27) I �■ ■1 I Nwlo ■ 32 ■ 2 T 3 n■ dS t0 ■ 0 u I N7M9 PRO.ECr n 21 ■ i p 22 ■ d I 9sl ■ 12 1110 ° NCINITY MAP I 24 ■ ■ >o I N.TS 9 ■ ■ 4 —N— I E-42} ■ 21 I n ■ ■ 7 1N ■ ■ 14 Mia "AD I 20 ■ ■ m 2° ■ ■19 f4■ 11,22 I LEGEND m ■ ys ■ ■ 32 AS-stANm CCNDUDTOR TR ■ ■ 36 I ■ ENSnNG W DUDTDR 41 ■ ■ JS I 4 ■ l GRAPHIC SCALE NOTES, D 1DD 2110 TDO Milne Point Unit ( N VSEf) E -42L1 SB Producer Hilcorp Drilling Procedure 06.22 A 4EDDEDD PDAMNS NIE TV. 29.0 Surface Plat (As Built) (NAD 27) I �■ ■1 I Nwlo ■ 32 ■ 2 T 3 n■ dS t0 ■ 0 u I N7M9 PRO.ECr n 21 ■ i p 22 ■ d I 9sl ■ 12 1110 ° NCINITY MAP I 24 ■ ■ >o I N.TS 9 ■ ■ 4 —N— I E-42} ■ 21 I n ■ ■ 7 1N ■ ■ 14 Mia "AD I 20 ■ ■ m 2° ■ ■19 f4■ 11,22 I LEGEND m ■ ys ■ ■ 32 AS-stANm CCNDUDTOR TR ■ ■ 36 I ■ ENSnNG W DUDTDR 41 ■ ■ JS I 4 ■ l GRAPHIC SCALE NOTES, D 1DD 2110 TDO 1. A1A9N STAT: ft DOD®INATES APE 20NE 4 W27. ( N VSEf) 2 OASIS of ICCAT■ Is N2R n OP-] AND E-1. 111 - 200 N. ] WSS of MA11011 TARE PDNT DA" T4. COORDINATES A 4EDDEDD PDAMNS NIE TV. POSITION(DMS) S PAD IEA11 EDAIE FWKR IS 0.21119061 PAD ELEY. 6. SURVEY WTI NAY 4 MS. IIPLANT E-42 7. IETEIE)tLE fE9D BOOP: 11011-01 F8. M LOCATED MITHIN PROTRACTED SEC. 25. T. 13 N. R 10 F IINIAT NFRINAN Al Aar♦ WILL A.S.P. GEODETIC GEODETIC GRA�fi. SEC110N NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) PAD ELEY. OFFSETS IIPLANT E-42 Y-6016.240.99' N-$094.95• 70'27'17.031' 70.4547308' 20.8' 3,704'FSL X=569137.33' E= 1,292.01' 149'26'0&899' 149.4358053' 2006' FEL 11ARwARr Hilcorp Alaska S %° m MPU E -PAD AS -STAKED CONDUCTOR WELL E-42 Page 41 1.1 b 30.0 Milne Point Unit E -42L1 SB Producer Drilling Procedure Schrader Bluff OA Sand Offset MW vs TVD Chart Page 42 Schrader Bluff OA Sand Offset MW vs TVD MW, ppg 8.5 8.7 8.9 9.1 9.3 9.5 9.7 99 10.110310.5 0 1 nny m 1000 i Ti 2000 O 2500 90 +I I 4000 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-42 MPU E -42L1 Plan: MPU E -42L1 wp04 Standard Proposal Report 14 May, 2019 HALLIBURTON Sperry Drilling Services HALLIBURTON =Per'ry ONlling Sec MD Inc TVD -N/-S +El -W Dleg TFace Vs.. Target Anno.6on 1 ]]75008300 1,-,,0 428702 -569354 -1839.10 DOD 0.00 5871 54 KOP: Start Dir41)1C0':MTMD,42B].02T D:O@•RTTF 2 800796 92.32 193.90 4296.53 -6919.24 -109496 400 002 6104.05 End Dir: W07aV MD, 4296.53' TVD 3 9998.69 9232 193.90 421600 -775007 -237289 0.00 0.00 8093.15 MPU E42L1 up03 CPI Start DU r110P: 9NB.69'MD, 4216WO 4 10029.02 91.71 193.90 421493 -77n,50 -2380.17 200 17997 8123.47 End 01r: 19029.02' MD, 421493' TVD 5 11948.55 91.71 19390 4157.60 -9641.95 -2841.19 0.00 O.W 10042.14 MPU E-0211 wp03 CA Toe Total Depth: 1194855' MD. 4157,6 WD -BOD 0 600 1200 REFERENCE INFORMATION WELL DETAILS: Man. MPU E42 Copdrale (NIE) ReMmrrs Wel Rom MPU E42, Two Noel Vad I(NO)D"A"W": MPU E42 ACS1aked RKB®42.30.1, Ground Level 2080 A4uwrtd Col RMeIermI MPU E42 As caked RKB ®4730w11 8143 �M-W NOMillp 9 LatlWde LonplWe CahllaLNn AMWE: Mllimum Cwanpe 0.00 OW 6316240.99 569137.33 70. 2T 17MION 149'26$4.5 FORMATgN TW OETAHb Project: Milne Point Site: MPIEPad Well: Plan: MPU E42 Wellbore: MPU E -42L1 Design: MPU E42L1 wpO. Sec MD Inc TVD -N/-S +El -W Dleg TFace Vs.. Target Anno.6on 1 ]]75008300 1,-,,0 428702 -569354 -1839.10 DOD 0.00 5871 54 KOP: Start Dir41)1C0':MTMD,42B].02T D:O@•RTTF 2 800796 92.32 193.90 4296.53 -6919.24 -109496 400 002 6104.05 End Dir: W07aV MD, 4296.53' TVD 3 9998.69 9232 193.90 421600 -775007 -237289 0.00 0.00 8093.15 MPU E42L1 up03 CPI Start DU r110P: 9NB.69'MD, 4216WO 4 10029.02 91.71 193.90 421493 -77n,50 -2380.17 200 17997 8123.47 End 01r: 19029.02' MD, 421493' TVD 5 11948.55 91.71 19390 4157.60 -9641.95 -2841.19 0.00 O.W 10042.14 MPU E-0211 wp03 CA Toe Total Depth: 1194855' MD. 4157,6 WD -BOD 0 600 1200 REFERENCE INFORMATION WELL DETAILS: Man. MPU E42 Copdrale (NIE) ReMmrrs Wel Rom MPU E42, Two Noel Vad I(NO)D"A"W": MPU E42 ACS1aked RKB®42.30.1, Ground Level 2080 A4uwrtd Col RMeIermI MPU E42 As caked RKB ®4730w11 8143 �M-W NOMillp 9 LatlWde LonplWe CahllaLNn AMWE: Mllimum Cwanpe 0.00 OW 6316240.99 569137.33 70. 2T 17MION 149'26$4.5 FORMATgN TW OETAHb CASING DETAILS "'Ido "'o""9WNa M'. m184s02TW'.W m wWkn.W Intim. ETVDss +4 4239.44 loa, Fmm con" 'le SmwFMn Ono 3B .. �z. WFU aar) ]cl o+¢ric_0.0 Wr mim McI E4x 0.V.. lWa11. a4x1 xMNp.IFRz.Ns.s.x 7113. MPII E4X1 WI 511 _- OInWpAtl.5t9 don. 6115-0] 069.55 MPY EJ]L11µUa 1MiV E4S11 M6.6a0 .,M 41 06• p 41 K 4, Ck w� g 41 ag a t S $ e WE42 adO5- LI CA Hael $ MPU E42L1 uTO3 CPI Ap moo: 4111 017 E MPU ElIL1 vy0a MPU E42 up06 NPU E4211 AdM GA Tee 1600 240 3000 3600 4200 480D 5400 600 6600 7200 7800 8400 9000 9fi00 10200 10800 11400 Vertical Section at 193.90° (1200 usttlin) CASING DETAILS MG Size Name ETVDss +4 4239.44 7776.ao 65m 9WTGW Ono 3B ++946 ss anrz a1n•..lu- Hkow Alxka, LLC ColdOW M.OWJ A,ilrvm Cu-.. ERM Spee. 1..SA Scan MMME: coned An.. 30 ERw, SUM.: M.&I Cava Warring MCMM: E- Ram $ MPU E42L1 uTO3 CPI Ap moo: 4111 017 E MPU ElIL1 vy0a MPU E42 up06 NPU E4211 AdM GA Tee 1600 240 3000 3600 4200 480D 5400 600 6600 7200 7800 8400 9000 9fi00 10200 10800 11400 Vertical Section at 193.90° (1200 usttlin) REFERENCE INFORMATION Go -ordinals (NIE) Reference: Well Plan: MPU E42. Taff, None Vetlbal (ND) Releren¢: MPU E.42 ASSgked RKB @ 4).3Wa11 Meagured Depth Reference: MPU E-42As 31akad RKB @ 4].30usfi CalwlaWn Wheal Minimum Curvature WELL DETAILS: Plan: MPU E>2 Grepnd Leal: 2B.eD +N/ -S +&-W NoMmg Fns[mg Letittudc longitude 0.00 0.00 6016240.99 5691}].}3 ]0°2]'R0310N 149°26'8.8985W Project: Milne Point r. Site: M Pt E Pad Well: Plan: MPU E-42 Wellbore: MPU E -42L1 a5oo Plan: MPU E42L1 wp04 d>SO MALUBURTON BPeery Oellting 3250 2000 ' ]250 -5600 4800 -4000 -3200 -2400 -1600 -800 0 800 1600 2400 West( -)/East(+) (1200 mft/in) 1 CASING .._FAILS TVD WDSS MD Size Name 4287.14 4239.84 7776.00 9-518 9 5/8" TOW 415T.60 4110,30 11948.55 4-1/2 4 112" x 8 112' REFERENCE INFORMATION Go -ordinals (NIE) Reference: Well Plan: MPU E42. Taff, None Vetlbal (ND) Releren¢: MPU E.42 ASSgked RKB @ 4).3Wa11 Meagured Depth Reference: MPU E-42As 31akad RKB @ 4].30usfi CalwlaWn Wheal Minimum Curvature WELL DETAILS: Plan: MPU E>2 Grepnd Leal: 2B.eD +N/ -S +&-W NoMmg Fns[mg Letittudc longitude 0.00 0.00 6016240.99 5691}].}3 ]0°2]'R0310N 149°26'8.8985W Project: Milne Point r. Site: M Pt E Pad Well: Plan: MPU E-42 Wellbore: MPU E -42L1 a5oo Plan: MPU E42L1 wp04 d>SO MALUBURTON BPeery Oellting 3250 2000 ' ]250 -5600 4800 -4000 -3200 -2400 -1600 -800 0 800 1600 2400 West( -)/East(+) (1200 mft/in) HALLIBURTON Database: NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Plan: MPU E-42 Wellbore: MPU E-421_1 Design: MPU E-421_1 wp04 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU E-42 TVD Reference: MPU E-42 As -Staked RKB @ 47.30usft MD Reference: MPU E-42 As -Staked RKB @ 47.30usft North Reference: True Survey Calculation Method: Minimum Curvature Project Milne Point, ACT, MILNE POINT Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) , Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site M Pt E Pad, TR -13-10 Site Position: Northing: From: Map Easting: Position Uncertainly: 0.00 usft Slot Radius: 6,013,798.68 usft Latitude: 569,440.72usft Longitude: 0" Grid Convergence: 70° 26'52.9824 N 149° 26'0.6546 W 0.53' Well Plan: MPU E-42, Dual Lat Well Position +N/ -S 0.00 usft Northing: 6,016,240.99 usft Latitude: 70° 27' 17.0310 N +EI -W 0.00 usft Easting: 569,137.33 usft Longitude: 149° 26' 8.8985 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usfl Ground Level: 20.80 usft Wellbore MPU E-421_1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2018 7/15/2019 16.62 80.96 57,423.37746817 Design MPU E-421_1 wpO4 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,775.00 Vertical Section: Depth From (TVD) +N/S +EI -W Direction (usft) (usft) (usft) (I 26.50 0.00 0.00 193.90 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/ -S +E/•W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 7,775.00 83.00 193.90 4,287.02 4,239.72 -5,593.54 -1,839.10 0.00 0.00 0.00 0.00 6,007.96 92.32 193.90 4,296.53 4,249.23 -5,819.24 -1,894.96 4.00 4.00 0.00 0.02 9,998.69 92.32 193.90 4,216.00 4,168.70 -7,750.07 -2,372.89 0.00 0.00 0.00 0.00 10,029.02 91.71 193.90 4,214.93 4,167.63 -7,779.50 -2,380.17 2.00 -2.00 0.00 179.97 11,948.55 91.71 193.90 4,157.60 4,110.30 -9,641.95 -2,841.19 0.00 0.00 0.00 0.00 5/142019 3:52:44PM Page 2 COMPASS 5000.15 Build 91 Planned Survey Measured Halliburton H A LL I B U R TO N Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU E-42 Company: Hilcorp Alaska, LLC TVD Reference: MPU E-42 As -Staked RKB @ 47.30usft Project: Milne Point MD Reference: MPU E-42 As -Staked RKB @ 47.30usft Site: M Pt E Pad North Reference: True Well: Plan: MPU E-42 Survey Calculation Method: Minimum Curvature Wellbore: MPU E-421_1 (usft) (1) Design: MPU E -42L1 wp04 (usft) usft Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (1) (1) (usft) usft (usft) (usft) (usft) (usft) -20.80 26.50 0.00 0.00 26.50 -20.80 0.00 0.00 6,016,240.99 569,137.33 0.00 0.00 100.00 0.00 0.00 100.00 52.70 0.00 0.00 6,016,240.99 569,137.33 0.00 0.00 200.00 0.00 0.00 200.00 152.70 0.00 0.00 6,016,240.99 569,137.33 0.00 0.00 300.00 0.00 0.00 300.00 252.70 0.00 0.00 6,016,240.99 569,137.33 0.00 0.00 350.00 0.00 0.00 350.00 302.70 0.00 0.00 6,016,240.99 569,137.33 0.00 0.00 400.00 1.50 220.00 399.99 352.69 -0.50 -0.42 6,016,240.48 569,136.91 3.00 0.59 500.00 4.50 220.00 499.85 452.55 -4.51 -3.78 6,016,236.45 569,133.59 3.00 5.29 550.00 6.00 220.00 549.63 502.33 -8.01 -6.73 6,016,232.91 569,130.68 3.00 9.40 600.00 7.88 214.33 599.27 551.97 -12.85 -10.34 6,016,228.05 569,127.11 4.00 14.96 700.00 11.76 208.52 697.78 650.48 -27.47 -19.07 6,016,213.35 569,118.51 4.00 31.25 800.00 15.70 205.58 794.91 747.61 -48.64 -29.79 6,016,192.08 569,108.00 4.00 54.37 900.00 19.67 203.80 890.17 842.87 -76.25 -42.42 6,016,164.35 569,095.62 4.00 84.21 1,000.00 23.64 202.59 983.09 935.79 -110.17 -56.92 6,016,130.30 569,081.44 4.00 120.62 1,100.00 27.62 201.72 1,073.23 1,025.93 -150.24 -73.21 6,016,090.10 569,065.52 4.00 163.42 1,200.00 31.61 201.05 1,160.15 1,112.85 -196.25 -91.21 6,016,043.92 569,047.95 4.00 212.41 1,300.00 35.60 200.52 1,243.42 1,196.12 -247.98 -110.84 6,015,992.01 569,028.81 4.00 267.35 1,400.00 39.59 200.09 1,322.64 1,275.34 -305.19 -132.00 6,015,934.62 569,008.18 4.00 327.96 1,500.00 43.58 199.72 1,397.42 1,350.12 -367.59 -154.58 6,015,872.02 568,986.18 4.00 393.96 1,600.00 47.58 199.40 1,467.40 1,420.10 -434.88 -178.48 6,015,804.51 568,962.91 4.00 465.02 1,700.00 51.57 199.12 1,532.24 1,484.94 -506.73 -203.57 6,015,732.44 568,938.49 4.00 540.80 1,800.00 55.56 198.87 1,591.61 1,544.31 -582.79 -229.75 6,015,656.15 568,913.02 4.00 620.92 1,890.71 59.19 198.66 1,640.51 1,593.21 -655.12 -254.31 6,015,583.60 568,889.13 4.00 697.03 1,900.00 59.19 198.66 1,645.26 1,597.96 -662.68 -256.87 6,015,576.02 568,886.65 0.00 704.98 2,000.00 59.19 198.66 1,696.48 1,649.18 -744.05 -284.35 6,015,494.40 568,859.93 0.00 790.57 2,100.00 59.19 198.66 1,747.71 1,700.41 -825.42 -311.82 6,015,412.79 568,833.21 0.00 876.16 2,200.00 59.19 198.66 1,798.93 1,751.63 -906.80 -339.30 6,015,331.17 568,806.49 0.00 961.75 2,300.00 59.19 198.66 1,850.15 1,802.85 -988.17 -366.78 6,015,249.56 568,779.77 0.00 1,047.34 2,400.00 59.19 198.66 1,901.37 1,854.07 -1,069.54 -394.26 6,015,167.94 568,753.05 0.00 1,132.93 2,500.00 59.19 198.66 1,952.59 1,905.29 -1,150.91 -421.74 6,015,086.32 568,726.33 0.00 1,218.52 2,600.00 59.19 198.66 2,003.81 1,956.51 -1,232.28 -449.22 6,015,004.71 568,699.61 0.00 1,304.11 2,700.00 59.19 198.66 2,055.03 2,007.73 -1,313.65 -476.70 6,014,923.09 568,672.89 0.00 1,389.70 2,800.00 59,19 198.66 2,106.25 2,058.95 -1,395.03 -504.17 6,014,841.48 568,646.17 0.00 1,475.29 2,900.00 59.19 198.66 2,157.47 2,110.17 -1,476.40 -531.65 6,014,759.86 568,619.45 0.00 1,560.88 3,000.00 59.19 198.66 2,208.69 2,161.39 -1,557.77 -559.13 6,014,678.25 568,592.73 0.00 1,646.47 3,100.00 59.19 198.66 2,259.91 2,212.61 -1,639.14 -586.61 6,014,596.63 568,566.01 0.00 1,732.06 3,200.00 59.19 198.66 2,311.13 2,263.83 -1,720.51 -614.09 6,014,515.01 568,539.29 0.00 1,817.65 3,300.00 59.19 198.66 2,362.35 2,315.05 -1,801.89 -641.57 6,014,433.40 568,512.57 0.00 1,903.24 3,400.00 59.19 198.66 2,413.57 2,366.27 -1,883.26 -669.05 6,014,351.78 568,485.85 0.00 1,988.83 3,500.00 59.19 198.66 2,464.79 2,417.49 -1,964.63 -696.52 6,014,270.17 568,459.13 0.00 2,074.42 3,600.00 59.19 198.66 2,516.01 2,468.71 -2,046.00 -724.00 6,014,188.55 568,432.41 0.00 2,160.01 3,700.00 59.19 198.66 2,567.23 2,519.93 -2,127.37 -751.48 6,014,106.94 568,405.69 0.00 2,245.60 3,800.00 59.19 198.66 2,618.46 2,571.16 -2,208.75 -778.96 6,014,025.32 568,378.97 0.00 2,331.19 3,900.00 59.19 198.66 2,669.68 2,622.38 -2,290.12 -806.44 6,013,943.71 568,352.25 0.00 2,416.78 4,000.00 59.19 198.66 2,720.90 2,673.60 -2,371.49 -833.92 6,013,862.09 568,325.53 0.00 2,502.37 4,100.00 59.19 198.66 2,772.12 2,724.82 -2,452.86 -861.39 6,013,780.47 568,298.81 0.00 2,587.96 511412019 3:52:44PM Page 3 COMPASS 5000.15 Build 91 HALLIBURTON Halliburton Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU E-42 Company: Hilcorp Alaska, LLC TVD Reference: MPU E-42 As -Staked RKB @ 47.30usft Project: Milne Point MD Reference: MPU E-42 As -Staked RKB @ 47.30usft Site: M Pt E Pad North Reference: True Well: Plan: MPU E-42 Survey Calculation Method: Minimum Curvature Wellbore: MPU E-421_1 Design: MPU E -42L1 wp04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting OLS Vert Section (usft) (1) (1) (usft) usft (usft) (usft) (usft) (usft) 2,776.04 4,200.00 59.19 198.66 2,823.34 2,776.04 -2,534.23 -888.87 6,013,698.86 568,272.09 0.00 2,673.55 4,300.00 59.19 198.66 2,874.56 2,827.26 -2,615.60 -916.35 6,013,617.24 568,245.37 0.00 2,759.14 4,400.00 59.19 198.66 2,925.78 2,878.48 -2,696.98 -943.83 6,013,535.63 568,218.65 0.00 2,844.73 4,500.00 59.19 198.66 2,977.00 2,929.70 -2,778.35 -971.31 6,013,454.01 568,191.93 0.00 2,930.32 4,600.00 59.19 198.66 3,028.22 2,980.92 -2,859.72 -998.79 6,013,372.40 568,165.21 0.00 3,015.91 4,700.00 59.19 198.66 3,079.44 3,032.14 -2,941.09 -1,026.27 6,013,290.78 568,138.50 0.00 3,101.50 4,800.00 59.19 198.66 3,130.66 3,083.36 -3,022.46 -1,053.74 6,013,209.16 568,111.78 0.00 3,187.09 4,900.00 59.19 198.66 3,181.88 3,134.58 -3,103.84 -1,081.22 6,013,127.55 568,085.06 0.00 3,272.68 5,000.00 59.19 198.66 3,233.10 3,185.80 -3,185.21 -1,108.70 6,013,045.93 568,058.34 0.00 3,358.28 5,100.00 59.19 198.66 3,284.32 3,237.02 -3,266.58 -1,136.18 6,012,964.32 568,031.62 0.00 3,443.87 5,200.00 59.19 198.66 3,335.54 3,288.24 -3,347.95 -1,163.66 6,012,882.70 568,004.90 0.00 3,529.46 5,300.00 59.19 198.66 3,386.76 3,339.46 -3,429.32 -1,191.14 6,012,801.09 567,978.18 0.00 3,615.05 5,400.00 59.19 198.66 3,437.99 3,390.69 -3,510.70 -1,218.62 6,012,719.47 567,951.46 0.00 3,700.64 5,500.00 59.19 198.66 3,489.21 3,441.91 -3,592.07 -1,246.09 6,012,637.85 567,924.74 0.00 3,786.23 5,600.00 59.19 198.66 3,540.43 3,493.13 -3,673.44 -1,273.57 6,012,556.24 567,898.02 0.00 3,871.82 5,700.00 59.19 198.66 3,591.65 3,544.35 -3,754.81 -1,301.05 6,012,474.62 567,871.30 0.00 3,957.41 5,800.00 59.19 198.66 3,642.87 3,595.57 -3,836.18 -1,328.53 6,012,393.01 567,844.58 0.00 4,043.00 5,900.00 59.19 198.66 3,694.09 3,646.79 -3,917.55 -1,356.01 6,012,311.39 567,817.86 0.00 4,128.59 6,000.00 59.19 198.66 3,745.31 3,698.01 -3,998.93 -1,383.49 6,012,229.78 567,791.14 0.00 4,214.18 6,100.00 59.19 198.66 3,796.53 3,749.23 -4,080.30 -1,410.97 6,012,148.16 567,764.42 0.00 4,299.77 6,200.00 59.19 198.66 3,847.75 3,800.45 -4,161.67 -1,438.44 6,012,066.55 567,737.70 0.00 4,385.36 6,300.00 59.19 198.66 3,898.97 3,851.67 -4,243.04 -1,465.92 6,011,984.93 567,710.98 0.00 4,470.95 6,400.00 59.19 198.66 3,950.19 3,902.89 -4,324.41 -1,493.40 6,011,903.31 567,684.26 0.00 4,556.54 6,500.00 59.19 198.66 4,001.41 3,954.11 -4,405.79 -1,520.88 6,011,821.70 567,657.54 0.00 4,642.13 6,523.36 59.19 198.66 4,013.38 3,966.08 -4,424.79 -1,527.30 6,011,802.63 567,651.30 0.00 4,662.12 6,600.00 62.19 197.96 4,050.89 4,003.59 -4,488.23 -1,548.29 6,011,739.01 567,630.90 4.00 4,728.74 6,700.00 66.12 197.11 4,094.47 4,047.17 4,574.04 -1,575.39 6,011,652.97 567,604.60 4.00 4,818.54 6,800.00 70.05 196.31 4,131.79 4,084.49 -4,662.88 -1,602.05 6,011,563,89 567,578.76 4.00 4,911.19 6,900.00 73.98 195.55 4,162.65 4,115.35 -4,754.32 -1,628.15 6,011,472.22 567,553.52 4.00 5,006.22 7,000.00 77.92 194.82 4,186.92 4,139.62 -4,847.93 -1,653.54 6,011,378.39 567,529.00 4.00 5,103.19 7,100.00 81.86 194.10 4,204.47 4,157.17 4,943.24 -1,678.11 6,011,282.86 567,505.31 4.00 5,201.61 7,128.97 83.00 193.90 4,208.29 4,160.99 4,971.11 -1,685.06 6,011,254.93 567,498.63 4.00 5,230.33 7,200.00 83.00 193.90 4,216.95 4,169.65 -5,039.54 -1,702.00 6,011,186.35 567,482.33 0.00 5,300.83 7,300.00 83.00 193.90 4,229.13 4,181.83 -5,135.89 -1,725.84 6,011,089.80 567,459.38 0.00 5,400.08 7,400.00 83.00 193.90 4,241.32 4,194.02 -5,232.23 -1,749.69 6,010,993.24 567,436.43 0.00 5,499.34 7,500.00 83.00 193.90 4,253.51 4,206.21 -5,328.58 -1,773.53 6,010,896.68 567,413.49 0.00 5,598.59 7,600.00 83.00 193.90 4,265.70 4,218.40 -5,424.93 -1,797.37 6,010,800.13 567,390.54 0.00 5,697.85 7,700.00 83.00 193.90 4,277.88 4,230.58 -5,521.28 -1,821.22 6,010,703.57 567,367.60 0.00 5,797.10 7,775.00 • 83.00 193.90 4,287.02 4,239.72 -5,593.54 -1,839.10 6,010,631.16 567,350.39 0.00 5,871.54 KOP : Start Dir 4-1100': 7775' MD, 4287.02'TVD : 0.02' RT TF 7,776.00 83.04 193.90 4,287.14 4,239.84 -5,594.50 -1,839.34 6,010,630.19 567,350.16 4.00 5,872.54 9 518" TOW 7,800.00 84.00 193.90 4,289.85 4,242.55 -5,617.65 -1,845.07 6,010,606.99 567,344.64 4.00 5,896.38 7,900.00 88.00 193.90 4,296.83 4,249.53 -5,714.47 -1,869.03 6,010,509.97 567,321.58 4.00 5,996.12 5/14/2019 3:52:44PM Page 4 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Pian: MPU E-42 Wellbore: MPU E-421_1 Design: MPU E-421_1 wp04 Planned Survey Measured Vertical Depth Inclination Azimuth Depth (usft) (1) (1) (usft) 8,007.96 92.32 193.90 4,296.53 End Dir : 8007.96' MD, 4296.53' TVD 8,100.00 92.32 193.90 4,292.80 8,200.00 92.32 193.90 4,288.76 8,300.00 92.32 193.90 4,284.71 8,400.00 92.32 193.90 4,280.67 8,500.00 92.32 193.90 4,276.62 8,600.00 92.32 193.90 4,272.58 8,700.00 92.32 193.90 4,268.53 8,800.00 92.32 193.90 4,264.49 8,900.00 92.32 193.90 4,260.44 9,000.00 92.32 193.90 4,256.40 9,100.00 92.32 193.90 4,252.35 9,200.00 92.32 193.90 4,248.31 9,300.00 92.32 193.90 4,244.26 9,400.00 92.32 193.90 4,240.22 9,500.00 92.32 193.90 4,236.17 9,600.00 92.32 193.90 4,232.13 9,700.00 92.32 193.90 4,228.08 9,800.00 92.32 193.90 4,224.04 9,900.00 92.32 193.90 4,219.99 9,998.69 92.32 193.90 4,216.00 Start Dir 2-1100': 9998.69' MD, 4216'TVD 10,000.00 92.29 193.90 4,215.95 10,029.02 91.71 193.90 4,214.93 End Dir : 10029.02' MD, 4214.93' TVD 10,100.00 91.71 193.90 4,212.81 10,200.00 91.71 193.90 4,209.83 10,300.00 91.71 193.90 4,206.84 10,400.00 91.71 193.90 4,203.85 10,500.00 91.71 193.90 4,200.87 10,600.00 91.71 193.90 4,197.88 10,700.00 91.71 193.90 4,194.89 10,800.00 91.71 193.90 4,191.91 10,900.00 91.71 193.90 4,188.92 11,000.00 91.71 193.90 4,185.93 11,100.00 91.71 193.90 4,182.94 11,200.00 91.71 193.90 4,179.96 11,300.00 91.71 193.90 4,176.97 11,400.00 91.71 193.90 4,173.98 11,500.00 91.71 193.90 4,171.00 11,600.00 91.71 193.90 4,168.01 11,700.00 91,71 193.90 4,165.02 11,800.00 91.71 193.90 4,162.04 11,900.00 91.71 193.90 4,159.05 Halliburton Standard Proposal Report 4,165.51 Local Co-ordinate Reference: Well Plan: MPU E-42 -2,397.22 6,008,371.46 TVD Reference: MPU E-42 As -Staked RKB @ 47.30usft 4,162.53 MD Reference: MPU E-42 As -Staked RKB @ 47.30usft 566,790.15 North Reference: True -8,042.42 -2,445.25 6,008,176.99 566,767.04 Survey Calculation Method: Minimum Curvature 4,156.55 -8,139.44 -2,469.27 6,008,079.76 566,743.92 Map Map 4,153.57 -8,236.47 TVDss +N/S +E/ -W Northing Easting DLS Vert Section usft (usft) (usft) (usft) (usft) 4,249.23 -8,430.52 4,249.23 -5,819.24 -1,894.96 6,010,404.97 567,296.63 4.00 6,104.05 4,245.50 -5,908.51 -1,917.06 6,010,315.51 567,275.36 0.00 6,196.02 4,241.46 -6,005.50 -1,941.06 6,010,218.31 567,252.26 0.00 6,295.94 4,237.41 -6,102.49 -1,965.07 6,010,121.10 567,229.15 0.00 6,395.85 4,233.37 -6,199.48 -1,989.08 6,010,023.90 567,206.05 0.00 6,495.77 4,229.32 -6,296.47 -2,013.09 6,009,926.70 567,182.94 0.00 6,595.69 4,225.28 -6,393.46 -2,037.10 6,009,829.50 567,159.84 0.00 6,695.61 4,221.23 -6,490.46 -2,061.10 6,009,732.30 567,136.73 0.00 6,795.53 4,217.19 -6,587.45 -2,085.11 6,009,635.10 567,113.63 0.00 6,895.45 4,213.14 -6,684.44 -2,109.12 6,009,537.90 567,090.53 0.00 6,995.36 4,209.10 -6,781.43 -2,133.13 6,009,440.70 567,067.42 0.00 7,095.28 4,205.05 -6,878.42 -2,157.13 6,009,343.50 567,044.32 0.00 7,195.20 4,201.01 -6,975.41 -2,181.14 6,009,246.30 567,021.21 0.00 7,295.12 4,196.96 -7,072.40 -2,205.15 6,009,149.10 566,998.11 0.00 7,395.04 4,192.92 -7,169.39 -2,229.16 6,009,051.90 566,975.00 0.00 7,494.95 4,188.87 -7,266.38 -2,253.16 6,008,954.70 566,951.90 0.00 7,594.87 4,184.83 -7,363.38 -2,277.17 6,008,857.50 566,928.80 0.00 7,694.79 4,180.78 -7,460.37 -2,301.18 6,008,760.30 566,905.69 0.00 7,794.71 4,176.74 -7,557.36 -2,325.19 6,008,663.10 566,882.59 0.00 7,894.63 4,172.69 -7,654.35 -2,349.19 6,008,565.90 566,859.48 0.00 7,994.54 4,168.70 -7,750.07 -2,372.89 6,008,469.97 566,836.68 0.00 8,093.15 4,168.65 -7,751.34 -2,373.20 6,008,468.70 566,836.38 2.00 8,094.46 4,167.63 -7,779.49 -2,380.17 6,008,440.48 566,829.67 2.00 8,123.47 4,165.51 -7,848.36 -2,397.22 6,008,371.46 566,813.26 0.00 8,194.41 4,162.53 -7,945.39 -2,421.24 6,008,274.23 566,790.15 0.00 8,294.37 4,159.54 -8,042.42 -2,445.25 6,008,176.99 566,767.04 0.00 8,394.32 4,156.55 -8,139.44 -2,469.27 6,008,079.76 566,743.92 0.00 8,494.28 4,153.57 -8,236.47 -2,493.29 6,007,982.52 566,720.81 0.00 8,594.23 4,150.58 -8,333.50 -2,517.30 6,007,885.28 566,697.70 0.00 8,694.19 4,147.59 -8,430.52 -2,541.32 6,007,788.05 566,674.58 0.00 8,794.15 4,144.61 -8,527.55 -2,565.34 6,007,690.81 566,651.47 0.00 8,894.10 4,141.62 5,624.58 -2,589.36 6,007,593.57 566,628.36 0.00 8,994.06 4,138.63 -8,721.61 -2,613.37 6,007,496.34 566,605.24 0.00 9,094.01 4,135.64 -8,818.63 -2,637.39 6,007,399.10 566,582.13 0.00 9,193.97 4,132.66 -8,915.66 -2,661.41 6,007,301.86 566,559.02 0.00 9,293.92 4,129.67 -9,012.69 -2,685.42 6,007,204.63 566,535.90 0.00 9,393.88 4,126.68 -9,109.71 -2,709.44 6,007,107.39 566,512.79 0.00 9,493.83 4,123.70 -9,206.74 -2,733.46 6,007,010.15 566,489.68 0.00 9,593.79 4,120.71 -9,303.77 -2,757.48 6,006,912.92 566,466.56 0.00 9,693.74 4,117.72 -9,400.80 -2,781.49 6,006,815.68 566,443.45 0.00 9,793.70 4,114.74 -9,497.82 -2,805.51 6,006,718.44 566,420.33 0.00 9,893.65 4,111.75 -9,594.85 -2,829.53 6,006,621.21 566,397.22 0.00 9,993.61 5142019 3:52:44PM Page 5 COMPASS 5000.15 Build 91 HALLIBURTON Halliburton Standard Proposal Report Database: NORTH US+CANADA Local Co-ordinate Reference: Well Plan: MPU E-42 Company: Hilcorp Alaska, LLC TVD Reference: -5,593.54 MPU E-42 As -Staked RKB @ 47.30usft Project: Milne Point MD Reference: TVD MPU E-42 As -Staked RKB @ 47.30usft Site: M Pt E Pad North Reference: (usft) True Well: Plan: MPU E-42 Survey Calculation Method: Minimum Curvature Wellbore: MPU E-421_1 1.02usft at 7828.93usft MD (4292.59 TVD, -5645.61 N, -1851.99 E) - Circle (radius 50.00) Design: MPU E-421_1 wp04 MPU E-421_1 wp03 OA Toe Planned Survey 4,157.60 -9,641.95 -2,841.19 Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (") (1) (usft) usft (usft) (usft) (usft) (usft) 4,110.30 11,948.55 . 91.71 193.90 4,157.60 ' 4,110.30 -9,641.95 -2,841.19 6,006,574.00 ' 566,386.00 0.00 10,042.14 Total Depth: 11948.55' MD, 4157.6' TVD - Circle (radius 50.00) Targets (usft) (usft) (usft) Comment Target Name 4,287.02 -5,593.54 -1,839.10 KOP : Start Dir 4°/100' : 7775' MD, 4287.02'TVD : 0.02" RTTF - hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W - Shape (") (") (usft) (usft) (usft) MPE-42 wp05-L1 OA Heel 0.00 0.00 4,293.60 -5,645.54 -1,851.97 - plan misses target center by 1.02usft at 7828.93usft MD (4292.59 TVD, -5645.61 N, -1851.99 E) - Circle (radius 50.00) Total Depth : 11948.55' MD, 4157.6' TVD MPU E-421_1 wp03 OA Toe 0.00 0.00 4,157.60 -9,641.95 -2,841.19 - plan hits target center - Circle (radius 50.00) MPU E -42L1 wp03 CP1 0.00 0.00 4,216.00 -7,750.07 -2,372.89 - plan hits target center - Circle (radius 50.00) 11,948.55 4,157.60 41/2"x81/2" 7,776.00 4,287.14 95/8"TOW Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W Northing Easting (usft) (usft) 6,010,579.04 567,338.00 6,006,574.00 566,386.00 6,008,469.97 566,836.68 4-1/2 8-1/2 9-5/8 12-1/4 (usft) (usft) (usft) (usft) Comment 7,775.00 4,287.02 -5,593.54 -1,839.10 KOP : Start Dir 4°/100' : 7775' MD, 4287.02'TVD : 0.02" RTTF 8,007.96 4,296.53 -5,819.24 -1,894.96 End Dir : 8007.96' MD, 4296.53' TVD 9,998.69 4,216.00 -7,750.07 -2,372.89 Start Dir 2°/100' : 9998.69' MD, 42167VD 10,029.02 4,214.93 -7,779.49 -2,380.17 End Dir : 10029.02' MD, 4214.93' TVD 11,948.55 4,157.60 -9,641.95 -2,841.19 Total Depth : 11948.55' MD, 4157.6' TVD 5/1412019 3.52:44PM Page 6 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt E Pad Plan: MPU E-42 MPU E-421_1 MPU E -42L1 wp04 Sperry Drilling Services Clearance Summary Anticollision Report 14 May, 2019 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad -Plan; MPU E42 - MPU E -42L1 -MPU E421_1 wp04 Well Coordinates: 6,016,240,99 N, 569,137.33 E (]0° 27' 1T 03" N, 149° 26' 08.90" W) Datum Height: MPU E42 As -Staked IRKS @ 47.30usft Scan Range: 7,775.00 to 11,948.55 ush. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft Geodetic Scale Factor Applied Version: 5000.15 Build: 91 Scan Type: Scan Type: 25.00 HALLIBURTON Sperry Orilling Services HALLIBURTON Anticollision Report for Plan: MPU E-42 - MPU E -42L1 wp04 Hilcorp Alaska, LLC Milne Point Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) 453.81 8,987.49 Reference Design: M Pt E Pad - Plan: MPU E42 - MPU E42L1 - MPU E4211 wpp4 10,550.DO 1.656 Scan Range: 7,775.00 to 11,948.55 uaft. Measured Depth. Pass - 9,000.00 Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft 9,000.00 Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellhore Name - Design (usft) (usft) (usft) (usft) Usft EX KAVEAR32.25 5.975 Centre Distance M Pt E Pad MPE-25 - MPE-25 - MPE-25 MPE-25 - MPE-25 - MPE-25 MPE-25 - MPE25PB2 - MPE-25PB2 MPE-25 - MPE-25PM - MPE-25PB2 MPE-25 - MPE25PB2 - MPE-25PB2 Plan: MPU E42 - MPU E42 - MPU E42 wp06 Plan: MPU E42 - MPU E42 - MPU E42 wpO6 Prelim DualLatPlan: MPU E -39 -MPU E -39i- MPU E-: M Pt S Pad MPS -19 - MPS -19 - MPS -19 MPS -19 - MPS -19A- MPS -19A MPS -19 - MPS-19AL1 - MPS-19AL1 MPS -19 - MPS-19APB1 - MPS-19APB1 8,987.49 453.81 8,987.49 179.80 10,550.DO 1.656 Centre Distance Pass - 9,000.00 453.98 9,000.00 178.67 10,550.00 1.655 Clearance Factor Pass - 7,775.00 1,454.48 7,775.00 1,211.05 8,809.62 5.975 Centre Distance Pass - 7,875.00 1,462.35 7,875.00 1,205.85 8,905.00 5.701 Ellipse Separation Pass - 7,950.00 1,471.08 7,950.00 1,212.18 8,905.00 5.682 Clearance Factor Pass - 8,075.00 23.14 8,075.00 20.89 8,074.01 10.275 Ellipse Separation Pass - 11,948.55 65.00 11,948.55 52.78 11,949.71 5.321 Clearance Factor Pass - 11,948.55 993.94 11,948.55 744.68 11,787.85 3.988 Clearance Factor Pass - 11,948.55 849.89 11,948.55 734.67 8,123.00 7.363 Clearance Factor Pass - 11,948.55 729.49 11,948.55 519.36 8,460.31 3.472 Clearance Factor Pass - 11,948.55 978.63 11,948.55 895.96 7,961.64 11.838 Clearance Factor Pass - 11,948.55 729.49 11,948.55 519.48 8,460.31 3.474 Clearance Factor Pass - From To (usft( (usft) 26.50 900.00 900.00 7,775.00 7,775.00 8,175.00 MPU E-4211 wp04 8,175.00 11,948.55 MPU E4211 wp04 Survey/Plan Survey Tool 2_Gym-NS-GC_Drll collar 2 MWD+IFR2+MS+Sag 2_MWD_MterpA i+Sag 2_MWD+IFR2+MS+Sag 14 May, 2019 - 15,53 Page 2 of 5 COMPASS HALLIBURTON Anticollision Report for Plan: MPU E-42 - MPU E -42L1 wp04 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance beMreen wellbore centres. Clearance Factor= Distance Between Profiles/(Distance Between prelims - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Hileorp Alaska, LLC Milne Point 14 May, 2019 - 1553 Page 3 of 5 COMPASS MALLIBURTON Project Milne Point REFERENCE INFORMATgN uDErAas:NmeMW EJxNAD 19x)(NACEON mNus) AbYa vera ".:=INal a✓mcve: w. 1P wu EJx. Tmaxom Site: M Pt E Pad P.�ry Gr1111ng Well: Plan: MPU E-02 Mrlo wl9eroivv: MWEdxb&vkel Fltaggl]90wa Relertnm. YW Hx NSUYm PNB®a]]Waaµmfiin Dmw41�vA: xoao Wellbore: MPU E4211 U'aafen"°"0°i AN°"'°"c�m�aNR Eain6 Ini:N4e W"yiN@ 990 a.m 9o15xa9.9� w9u]33 w•u t]a19N 1m•ue 99esw Plan: MPU E-02L1 My04 SURVEY..:W PROGRAM NO GL08AL FILTER: Using 0ae=BefineO sebceon 8 Rlervl9 c1 W1 pale: tp19o5axim:OpUO vali0ama: ves versio": ® ]])500 To 1194855 Ladder / S.F. Plots CASMG DETAILS pe>N From DepN Ta surveylPlan x O [ pnllcdbr W NDSB ND Nme PH 29.50 9M.Op MPU EJxuy361MPU EJ21-1^a"•9GL 90000 ]]]SM MPUH2 µH IMPU EJ21 MWD IFR2+MS+sag T]500 81]5.00 MPU EJ2L1 xpOd (MPp EJ2L11 pMWp M1=ry Ai+Saq 42,# 4x)984 ]]]600 9-59 95/B'TOW 81]500 11948.55 MPU E42Li xyp4lM>II EJ2L1) 3 MWp+IFR2+M5+Sa9 dl>).bp 4110.30 1INUS 4-I%x 411-.3iR" VI50.00 o I S120,00 o' ,Lgow N MPU E42 06j U 60.0 } 0 mmira m ! c 30.00 � v ' I 1 DOD I I ! 8100 8325 8550 8]]5 9D00 9225 9450 9675 9900 IG125 10350 10575 10800 11025 11250 11475 11700 11925 12150 12375 Measured Depth (450 usft(in) I I w LL 4AA�Idaoc. `3.00 o $ res Re m son q. t0D No-Go Zone -Stop Drilling NDERROR 0.00 81D0 8325 8550 8]]5 9000 9225 9450 9675 9900 10125 10350 10575 10800 11025 11250 11475 41700 11925 12150 12375 Measured Depth (450 USfUin) TRANSMITTAL LETTER CHECKLIST /'// WELL NAME: l pa E: / PTD: 2-1 ( `&W/ Development _Service _Exploratory _ Stratigraphic Test Non -Conventional FIELD: / " (` ! POOL:�c {ice ,cep Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CFIECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit / LATERAL No. API No. 5N� - V/ (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- -_) from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements 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 da s after completion, suspension or abandonment of this well. Revised 2/2015 IWELL PERMIT CHECKLIST Field & Pool MILNE POINT, SCHRADER BUFF OIL - 525140 Well Name MILNE PT UNIT E-421_1 Program DEV Well bore seg © I PTD#:2190910 Company Hilcorp. Alaska LLC _.. _ Initial Class/Type _DEV/PEND. GeoArea 890 — _Unit 11328 On/Off Shore On__. Annular Disposal F-1 Appr Date SFD 6/14/2019 Engineering Appr Date GLS 6/17/2019 Geology Appr Date SFD 6/14/2019 2 Lease number appropriate _ Yes _ Surf Loc & Top Prod Int lie in ADL0025518; TO lies. in ADL0380110. 3 Unique well name and number Yes Date Commissioner Date 4 Well located ina. defined pool, Yes Milne Point Schrader Bluff Oil Pool (525140), governed by. CO 477, amended by CO 47T05. 5 Well located proper distance from drilling unit. boundary Yes CO 477.05 specifies: "There are no restrictions as to well spacing except that no pay shall 6 Well located proper distance from other wells Yes be opened. in a well closer than. 500 feet from the exterior boundary of the affected area." 7 Sufficient acreage. available in drilling unit. Yes As planned, well conforms to spacing requirements .... _ 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 12 Permit can be issued without administrative. approval _ _ Yes 13 Can permit be approved before 15 -day wait..... _ _ _ Yes 14 Well located within area and strata authorized by Injection Order # (put_ 10# in, comments) (For, Yes 15 All wells within 1/4, mile area of review identified (For service well only) ..... NA 16 Pre -produced injector duration of pre -production less than 3 months. (For service well only) NA 17 Nonconven, gas conforms to AS31.05.030Q.1.A),6.2.A-D) _ _ _ ... NA 18 Conductor string. provided ——� _ - _ ......... NA.. _ _ NA 19 Surface casing. protects all known USDWs _ _ _ _ _ _ _ _ _ _ NA 20 CMT.vol adequate to circulate on conductor & surf.csg ... _ _ _ NA 21 CMT vol_ adequate to tie-in long string to surf csg.. _ _ _ .. NA . . 22 CMT will coverall known productive horizons _ _ ...... _ _ _ _ _ Yes _ _ _ _ Lateral will. have slotted liner and. swell packers.... 23 Casing designs adequate for C, T, B&.permafrost . _ _ _ _ Yes _ BTC supplied 24 Adequate tankage. or reserve pit _ _ _ _ _ _ _ Yes ..... _ 25 1f_a re -drill, has.a 10-403 for abandonment been approved _ _ _ _ _ NA _ _ Lateral will be sidetracked with whipstock. in the 9 5/8" casing 26 Adequate wellbore separation proposed.. _ _ _ Yes L1 will target OA sand 50 ft TVD above the mainbore in the OB. sand.. . 27 If diverter required, does it meet regulations.. _ _ _ _ _ _ NA.. wellhead in place.. Using BOPE. 28 Drilling fluid program schematic & equip list adequate. _ Yes _ Drilling with 8.9-. 9.5 pgp. mud, 29 BOPEs, do they meet regulation _ _ _ _ _ _ _ _ _ Yes _ _ _ _ Innovation has 11" BOPE 5000 psi WP 30 BOPE press rating appropriate; test to (put psig in comments) _ _ _ _ Yes _ _ _ MASP = 1458 psi will test BOPE to 3000 psi 31 Choke. manifold complies w/API. RP -53 (May 84).. _ _ _ _ _ Yes 32 Work will occur without operation shutdown _ _ _ _ Yes 33 Is presenceof H2S gas probable .............. ......... _ _ _ _ No 34 Mechanical condition of wells within AOR verified (For. service well only), _ _ _ _ _ _ _ _ _ _ _ NA_ 35 Permit. can be issued w/o hydrogen sulfide measures _ _ _ _ _ _ _ _ _ _ Yes _ .. H2S not anticipated from drilling of offset wells; however, rig will have H2S sensors and alarms. 36 Data presented on potential overpressure zones _ _ .......... Yes ... Planned mud program. appears adequate. to control_ operator's forecast formation pressures.. 37 Seismic analysis. of shallow gas zones _ _ _ _ _ _ ... _ NA Managed Pressure. Drilling will be used to monitor and mitigate any abnormal pressure encountered. 38 Seabed condition survey (if off -shore) _ _ _ _ _ _ _ ... ...NA 39 Contact name/phone for weekly_ progress reports [exploratory only] _ NA Geologic Engineering Public Planned lateral in the Schrader OA sand 50 ft TVD above the motherbore... OB sand . GIs Commissioner: Date: Commissioner: Date Commissioner Date its !l s7 JAC 6/101
