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220-027
Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 09/24/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU K-44B (220-027) PLUG SET RECORD (REVISED) 04/29-30/2020 Please include current contact information if different from above. Received by the AOGCC 09/25/2020 PTD: 2200270 E-Set: 33985 Abby Bell 09/25/2020 Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 09/24/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU K-44B (220-027) PERFORATING RECORD 04/29-30/2020 Please include current contact information if different from above. Received by the AOGCC 09/25/2020 PTD: 2200270 E-Set: 33984 09/25/2020 Abby Bell David Douglas Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchrage, AK 99503 Tele: 907 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 8/20/2020 To: AOGCC Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL MPU K-44B (PTD 220-027) Halliburton RCBL 29-April-2020 Please include current contact information if different from above. Received by the AOGCC 09/02/2020 PTD: 2200270 E-Set: 33748 Abby Bell 09/02/2020 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23567-02-00Well Name/No. MILNE PT UNIT K-44BCompletion Status1-OILCompletion Date5/1/2020Permit to Drill2200270Operator Hilcorp Alaska, LLCMD7983TVD7140Current Status1-OIL8/14/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalList of Logs Obtained:ROP, DGR, AGR, ABG, ADR, EWR MD & TVD / CBL 4-30-20NoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF7/20/20205400 7983 Electronic Data Set, Filename: MPU K-44B LWD Final.las33573EDDigital DataDF7/20/2020 Electronic File: MPU K-44B LWD Final MD.cgm33573EDDigital DataDF7/20/2020 Electronic File: MPU K-44B LWD Final TVD.cgm33573EDDigital DataDF7/20/2020 Electronic File: MPU K-44B_Definitive Survey Report.pdf33573EDDigital DataDF7/20/2020 Electronic File: MPU K-44B_Definitive survey Report.txt33573EDDigital DataDF7/20/2020 Electronic File: MPU K-44B_GIS.txt33573EDDigital DataDF7/20/2020 Electronic File: MPU K-44B LWD Final MD.emf33573EDDigital DataDF7/20/2020 Electronic File: MPU K-44B LWD Final TVD.emf33573EDDigital DataDF7/20/2020 Electronic File: MPU K-44B LWD Final MD.pdf33573EDDigital DataDF7/20/2020 Electronic File: MPU K-44B LWD Final TVD.pdf33573EDDigital DataDF7/20/2020 Electronic File: MPU K-44B LWD Final MD.tif33573EDDigital DataDF7/20/2020 Electronic File: MPU K-44B LWD Final TVD.tif33573EDDigital Data0 0 2200270 MILNE PT UNIT K-44B LOG HEADERS33573LogLog Header ScansC8/14/20207980 6800 Electronic Data Set, Filename: MAIN PASS.las33655EDDigital DataC8/14/2020 Electronic File: MAIN PASS.dlis33655EDDigital DataC8/14/2020 Electronic File: MPU K-44 RBT 29APRIL20.pdf33655EDDigital DataFriday, August 14, 2020AOGCCPage 1 of 2MPU K-44B LWDFinal.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23567-02-00Well Name/No. MILNE PT UNIT K-44BCompletion Status1-OILCompletion Date5/1/2020Permit to Drill2200270Operator Hilcorp Alaska, LLCMD7983TVD7140Current Status1-OIL8/14/2020UICNoINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:5/1/2020Release Date:3/23/2020Friday, August 14, 2020AOGCCPage 2 of 2M. Guhl8/14/2020 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 7/09/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU K-44B (220-027) DGR ABG ADR Halliburton LWD FINAL 07 MAY 2020 Received by the AOGCC 07/20/2020 PTD: 2200270 E-Set: 33573 Abby Bell 07/20/2020 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 29.3' BF:29.3' Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22. Logs Obtained: 23. BOTTOM 7" L-80 7,138' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 7,850'2-7/8" SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 9-7/8" 208 sx STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 5/1/2020 3744' FSL, 2020' FEL, Sec 3, T12N, R11E, UM, AK 721' FNL, 1098' FWL, Sec 2, T12N, R11E, UM, AK 220-027 / 320-147 Milne Point Field / Kuparuk River Oil Pool 56.5' 7,983' MD / 7,140' TVD HOLE SIZE AMOUNT PULLED 50-029-23567-02-00 MPU K-44B 584535 6005880 724' FNL, 1066' FWL, Sec 2, T12N, R11E, UM, AK CEMENTING RECORD 6006726 SETTING DEPTH TVD 6006730 BOTTOM TOP Surface CASING WT. PER FT.GRADE 587609 587641 TOP SETTING DEPTH MD Surface Per 20 AAC 25.283 (i)(2) attach electronic information DEPTH SET (MD) N/A PACKER SET (MD/TVD) 26# 7,973 Gas-Oil Ratio:Choke Size:Water-Bbl: PRODUCTION TEST 5/7/2020 Date of Test: 80 5/19/2020 24 Flow Tubing 938 0.5 Oil-Bbl: suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 72.50.5 ESP 7,918' - 7,939' MD / 7,080' - 7,099' TVD 7,933' - 7,976' MD / 7,094' - 7,133' TVD 4/30/20 5SPF 4-5/8" 6.7 ROP, DGR, AGR, ABG, ADR, EWR MD & TVD / CBL 4-30-20 Sr Res EngSr Pet GeoSr Pet Eng N/A 23 Oil-Bbl: Water-Bbl: 6.7 938195 April 25, 2020 April 20, 2020 ADL375133 / ADL375132 N/A 1,994' MD / 1,940' TVD 5,431' MD / 4,813' TVDN/A N/A 7,983' MD / 7,140' TVD WINJ SPLUG Other Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 11:04 am, May 27, 2020 RBDMS HEW 5/29/2020 Completion Date 5/1/2020 HEW DSR-5/29/2020DLB 05/29/2020 5,431' MD / 4,813' TVD SFD 6/10/2020 Oil gls 6/26/20 G Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD 1,994' 1,940' Top of Productive Interval Kup C 7,918' 7,080' 5,734' 5,072' 7,489' 6,677' 7,578' 6,761' 7,624' 6,805' 7,735' 6,909' 7,918' 7,080' 7,978' 7,134' LCU 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Contact Email:cdinger@hilcorp.com Authorized Contact Phone: 777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: FORMATION TESTS Permafrost - Top Colville This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inc lination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Kuparuk C LCU Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Kuparuk D HRZ Kalubik Formation at total depth: Kalubik GR Marker Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Report. Signature w/Date: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. INSTRUCTIONS Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2020.05.27 09:37:01 -08'00' Monty M Myers _____________________________________________________________________________________ Revised By: CJD 5/26/2020 SCHEMATIC Milne Point Unit Well: MPU K-44B Last Completed: 5/1/2020 PTD: 220-027 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 78.6 / A-53 / Weld - Surface 80' 10-3/4" Surface 45.5 / L-80 / BTC 9.950 Surface 5,431’ 7" Production 26 / L-80 / TXP 6.276 Surface 7,983’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 7,850’ GENERAL WELL INFO API: 50-029-23567-02-00 Drilled and Completed By Innovation 5/1/2020 TREE & WELLHEAD Tree Seaboard 3-1/8”, 5K Wellhead Seaboard 16 3/4" 3M x 11" 5M Multibowl w/11" x 2-7/8" Tbg Hgr. Tubing Hanger Hanger - 2-7/8" EUE - Dual penetrations for ESP and dummy HT. 2.5" "H" BPV. 2ea 1/2" NPT control line ports. OPEN HOLE / CEMENT DETAIL 20" Driven 10-3/4” Stg 1 L – 680 sx / T – 310 sx: Stg 2 L – 265 sx / T – 315 sx 7” Cmt w/ 208 sks Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 5,431’ Max Hole Angle = 34° @ 4,083’ Hole Angle through perforations = 20° WINDOW DETAIL 10-3/4” Window: Top @ 5,431 / Bottom @ 5,451 JEWELRY DETAIL No Depth Item 1 191’ Sta.2 GLM: 2.875" CAMCO w/ DPSOV 2 7,687’ Sta.1 GLM: 2.875" CAMCO w/ 1" Dummy Valve 3 7,745’ 2-7/8” XN-Nipple : Min ID = 2.31” 4 7,797’ Discharge Head: Bolt on - 2.875 FPDIS 400 5 7,797.5’ Ported Sub: Zenith HEAD S/A B/O PRESS PORT 400P 6 7,798’ Pump: PMP 400PMSXD 119 FLEX10 H6 FER STD 7 7,821’ Gas Separator: GASSEP 400GSEV MT H6 8 7,824’ Gas Avoider: GAS AVOIDER 400 GRAVITY CUP LS H6 9 7,826’ Upper Tandem Seal: GSBDB H6 SB/AB PFSA 10 7,833’ Lower Tandem Seal: GSBDB H6 SB/AB PFSA 11 7,840’ Motor: 562XP 50Hp / 1,265V / 24A 12 7,845’ Zenith Motor Gauge & Centralizer: Bottom @ 7,850’ PERFORATION DETAIL KUP Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk C 7,918’7,939’7,080’7,099’21 4/30/2020 Open 7,933’ 7,976’ 7,094’ 7,133’ 43 4/30/2020 Open window 5431 ft Perfs 7918-7976 ft KUP C Note: double shot zone 7933-3939' CIBP set at 7980' md Activity DateO Ops Summary 4/20/2020 PJSM Cont C/O HT38 to NC50 Saver Sub on Top Drive. C/O Grabber dies and bell guide. Clean and clear rig floor.,PJSM Service rig. Grease Crown, Top Drive, Blocks, Drawworks, Spinners, Cobra Heads and Iron Roughneck. Check oil in Top Drive. Swap to High Line power@ 07:30.,PJSM Drain Stack and install long wear ring. (Lgth 26" 10" ID) as per NOS onsite. RILDS.,PJSM P/U M/U Baker N-1 CIBP assy 12.25' Single in hole W/ 5" HWDP to 510' MD at 90 ft/min. No losses. P/U 57K SLK 57K.,Cont RIH W/ singles 5" NC50 D.P. F/ 510' to 5,455' MD at 90 ft/min. P/U 155K SLK 127K. Putting 1 turn to left every 1,000' as per Baker Rep. No losses.,PJSM Set CIBP as per Baker Rep on site. Top of plug @ 5,455' MD. P/U 155K SLK 127K ROT 139K.,PJSM Displace fresh water to 9.5 ppg LSND Mud. Pump 50 bbls 175 Vis sweep and 489 bbld 9.5 ppg LSND at 12 bpm ICP 250 PSI FCP 575 PSI. Shut down and rack back 1 stand to 5,400' MD.,PJSM R/U Head Pin and HP hose. Flood Choke and Kill lines. Test 10 3/4" Csg to 2,700 PSI for 30 min on chart, good. Pumped and bled back 5 bbls. Blow down lines and R/D test Equip.,PJSM Pump dry job and blow down Top Drive. POOH racking back 5" D.P & 5" HWDP F/ 5,400' to K-1 running tool. L/D running assy as per Baker rep.,PJSM P/U M/U 9.75" Window Mill, 9.5" Lower Mill, 5.813" Flex Joint, 9.875" Upper Mill, 2 ea 5.813" Pup Jnt. Scribe 180° off bolt hole (high side) on 9.75" Window Mill carry scribe to top of pup Jnt. Verified by MWD, DD, Baker Rep and CO Rep. Leave hanging in Derrick. P/U 9.563" Bottom Trip Anchor ( 3 pin 19.8K shear) & 10.75" Gen II Whipstock and set in rotary table. M/U Whipstock to Window MIll W/ 45K shear Bolt.,M/U 6.75" DM Collar, 6.75" TM Collar and 6.75" Float Sub (Port Float). Perform RFO F/ Scribe to DM Collar checked by Baker, DD, MWD and Co Rep onsite. RFO 6.12" / 6.74" = 326.88°.,PJSM P/U M/U 1 jnt 5" HWDP, 2 ea 6.5" Extreme Magnets RIH W/ 5" HWDP to 620' MD. Perform shallow hole test 500 GPM, 830 PSI, good.,PJSM RIH Whipstock BHA W/ 5" D.P. F/ 620' to 5,422' MD. Filled at 3,300' MD. Run speed 90 ft/min.,PJSM Break Circ. at 450 GPM 850 PSI. MWD Inc reads in 6° increments. P/U 162K, SLK 130. Orientate to 23° R. Slack down and set at 5,456' MD. Set down 30K anchor set. P/U 10K over good set. Slack down 48K and shear bolt. TOW 5,431' BOW 5,451' MD. L/D Single and kelly up on full stand. Start milling at 5,451' MD 450 GPM 860 PSI 60 RPM TRQ 6K.,Daily fluid hauled to G&I 859 bbls total = 1,492 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 0 bbls total = 1,440 bbls Daily Fluid lost 0 bbls total production = 0 bbls Contractor AFE #: AFE $: Job Name: Spud Date: Well Name: Field: County/State: MP K-44A Milne Point Hilcorp Energy Company Composite Report , AK n (LAT/LONG): evation (RKB): API #: Activity Date Ops Summary 4/21/2020 Mill 9-7/8" window in 10-3/4" casing F/ 5431' - T/ 5451' MD as per BOT rep. TOW @ 5431, BOW @ 5451'. 3-4 fph, 2-4k wob, 60-80 rpm, 11-15k tq. 162k up, 128k dn, 140k rot.;Continue milling window in 10-3/4" casing F/ 5451' - T/ 5477' MD (4850' TVD) putting full gauge upper string mill @ btm of window. Stage up from 10 to 15k wob, increase rpms 110, 9k tq, 455 gpm, 1070 psi, 57% flow. Trip thru window 3x clean without pumps/rot. 155# metal recovered.;Circulate 40 bbls hi-vis sweep STS with 10% increase in cuttings (shale/clay).;B/D TDS. R/U and perform 12.5 FIT. Pump 1.6 bbls @ 1/2 bpm, 760 psi final/ 4850' TVD w/ 9.5 MW. Chart and record same. 1 bbl bled back. R/D test equipment.;PJSM Cut & slip. Hang Blocks. cut 95' drilling line. (15 Wraps) Accum TM 32,525. 988' left on spool. Check brake gap. Calibrate Block height. Monitor well, static.;PJSM Grease Crown, Blocks, Spinners EAM sheave wobble on Blocks and Crown.;PJSM Pump dry job. POOH 5" D.P. F/ 5,390' to 617' MD. Rack back 8 stands HWDP to 137' MD. P/U 165K SLK 127K. Lost 4 bbls for trip.;PJSM Remove metal F/ Extreme magnets. 125# metal recovered F/ magnets. Total metal recovered F/ milling 280 #.;PJSM L/D 2 ea Extreme Magnets, 1 jnt 5" HWDP, leave Float Sub, TM Collar and DM Collar together and L/D. Cont L/D 2 ea Pup Jnts, Upper Mill, Flex Jnt, Lower Mill and W indow Mill. Mills showed no sign of excessive wear and in gauge. Baker rep onsite.;PJSM Clean and clear rig floor. L/D Baker Milling BHA and tools. Stage on rig floor Bit, X/O and subs.;PJSM P/U M/U Separation BHA #2 9.875" Hughes GT-C1 Tricone Bit, 6.625" X/O Bit Sub, 6.75" TerraForce Motor Lobe 6:7-6 stg, 6.75" DM Collar, 6.75" TM Collar, 6.75" Float Sub (Ported), 6 jnts 5" HWDP, 6.5" Hydra Jar and 11 jnts 5" HWDP total length 616.71' MD.;Perform RFO 0.18"/6.75"=9.6° witnessed by DD, MWD, Driller and Co Rep on site.;PJSM Single in hole 94 jnts of 5" D.P. F/ 616' to 2,525' MD. (Drift 3.125" OD) P/U 85K SLK 76K. No losses.;Daily fluid hauled to G&I 859 bbls total = 1,492 bbls Daily metal recovered 285 lbs, total = 285 lbs Daily water hauled from L Pad Lake 0 bbls total = 1,440 bbls Daily Fluid lost 0 bbls total production = 0 bbls 4/22/2020 Continue trip w/ 9.875" mtr assy singling in w/ 5" NC50, S-135, 19.5# drill pipe from shed F/ 2525' - T/ 3606' MD (3.125" drift). 101k up, 90k dn. Calc disp.;Continue trip in from derrick F/ 3606' - T/ 5354' MD. 156k up, 128k dn. Calc displacement for trip. Went on Gen Pwr @ 07:30 hrs due to turbine issues.;Fill pipe, orient mtr to 30° RHS @ 5354' MD. Trip in with no pump/rot F/ 5354' to 5461' (TOW @ 5431', BOW @ 5451'). Establish parameters @ 5461' washing down to 5477' MB. Drill 9-7/8" hole F/ 5477' - T/ 5617' MD (4967' TVD). Distance to WP #3 0.31', 0.27 high, 0.15 left.;550 gpm, 1900 psi, 60 rpm, 9.5k tq, 400 units gas. Control drill w/ 65-75 ROP, 16k max WOB.;Circulate STS 30 bbl hi-vis sweep, 9.5 ppg, 135 vis, 550 gpm, 1900 psi, 60 rpm, 9.5k tq. Max gas @ btms up 659 units. 10% inc in cuttings. Obtain SPR's @ 5617' MD (4967' TVD , 9.5 MW) 32/48 spm - #1 MP 180/232 psi, #2 MP 182/230 psi. Orient HS. Monitor well (static).;POOH F/ 5617' - T/ BHA. 162k up, 128k dn. Pulled into casing clean (no pump/rot). Pump dry job, B/D TDS and continue trip out.;L/D BHA. Drain and flush MWD/MTR assy. B/O and L/D MWD, Mtr and Bit. Bit grade - 1,1,WT,A,E,I,BT,BHA. 2.5 bbl loss over calculated for trip out.;PJSM Hang Blocks and adjust Drawwork Brake air gaps.;PJSM Johnny Whack Stack to get any metal out of cavities.;PJSM P/U M/U Production BHA 3 as per Sperry DD & MWD.P/U 9.875" HDBS GTD54WM PDC, 7.625" 7600 Geo Pilot Dirigo Hybrid, 6.75" DM Collar, 6.75" ADR Collar, 9.875 ILS, 6.75" DGR Collar, 6.75" PWD Collar, 6.75" TM HOC, 6.75" Float Sub (Plunger Solid), 2 ea 6.75" Flex Collars,;6.75" Float Sub (Plunger, Solid, Crows ft), 6 jnts 5" HWDP, 6.5" SLB Hydra Jars and 11 jnts 5" HWDP total lgth 711.64'. MWD uploaded tools SIMOPS tested Beyond hard lines to 250 PSI & 1,250 PSI for 5 min ea. Shallow hole test tools at 500' 500 GPM, 1,050 PSI, good. Cycle pumps for survey, good.;PJSM RIH BHA W/ 5" D.P. F/ 711' to 5,485' MD. P/U 155K SLK 125K. No losses. Break in Gep Pilot at 3,200' MD Stage up F/ 5 RPM to 60 RPM while filling pipe as per MWD. Pass through window (TOW 5,431', BOW 54,51') on elevators with out issue. No losses.;PJSM Fill pipe and obtain SPR at 5485' MD. Perform MAD pass F/ 5,488' to 5,617' MD 4.5 ft/min 500 GPM, 1,370 PSI, 60 RPM, TRQ 9K, Max Gas 243U. ECD 10.0. P/U 165K, SLK 129K, ROT 145K.;SPR at 5485' MD (4,851' TVD) MW 9.6. MP #1 32-170, 48-225. MP #2 32-160, 48-210.;PJSM Attempt to Drill 9.875" Production Hole adjusting all parameters F/ 5,617' to 5,649' MD (4,981' TVD) total 32' (AROP 16') 500-600 GPM, 1,350-1,800 PSI, 60-120 RPM, TRQ 9-11K, WOB 2-23K. P/U 165K, SLK 129K, ROT 145K. Max Gas 138U. ECD 10.1.ppg.;Daily fluid hauled to G&I 57 bbls total = 1,606 bbls Daily metal recovered 23 lbs, total = 308 lbs Daily water hauled from L Pad Lake 130 bbls total = 1,700 bbls Daily Fluid lost 0 bbls total production = 0 bbls 4/23/2020 Drill 9.875" Production Hole adjusting all parameters F/ 5,649' to 5,705' MD (5,041' TVD) total 56' (AROP 22') 585 GPM, 1765 PSI, 60-120 RPM, TRQ 9.2K, WOB 2-23K. P/U 165K, SLK 129K, ROT 147K. Max Gas 138U. ECD 9.8.ppg. MP #2 leak on #2 pod weep hole.;CBU while troubleshooting #2 MP. 585 gpm, 1810 psi, 140 rpm, 10k tq. 9.86 ECD w/ 9.5 MW. Found #2 MP needed tore down to repair. Pulled up into shoe from 5705' to 5402' MD. Pulled into window without issue.;PJSM, C/O liner, liner nut and wear plate on MP#2 - Pod #2. Grease traveling equipment. Function test MP #2 (test good).;TIH F/ 5402' - T/ 5705' MD. Exited window without issue.;Drill 9.875" Production Hole F/ 5,705' to 5,715' MD (5050' TVD) total 32' (AROP 16') 585 GPM, 1765 PSI, 60-160 RPM, TRQ 9.2K, WOB 25K. P/U 165K, SLK 129K, ROT 147K. ECD 9.8.ppg.;Drill 9.875" Production Hole F/ 5,715' to 5926' MD, total 210' (AROP 35') 580 GPM, 1770 PSI, 125 RPM, TRQ 11.2K, WOB 25-35K. P/U 190K, SLK 125K, ROT 153K. 105u BGG, Max Gas 204u. ECD 9.8.ppg. Drilled hard formation @ 5770' MD (5098' TVD). Saw oil @ shakers w/ 204u gas @ btms up.;Saw 20k overpull and 20k set down during connection @ 5793' MD (jars @ window). Worked thru with minimal effort and continued drilling ahead with no other issues.;Drill 9.875" Production Hole adjusting param eters as needed F/ 5,926' to 6,180' MD (5,472' TVD) total 254' (AROP 42.3') 580 GPM, 1,825 PSI, 90-125 RPM, TRQ on 11.3K, TRQ off 11.9K, WOB 15-35K. P/U 195K, SLK 125K, ROT 155K. Max Gas 159U. BGG 130U. ECD 9.95 ppg.;SPR at 5,988' (5,297' TVD) MW 9.4. MP #1 32-160, 48-209. MP #2 32-162, 48-211.;PJSM Cont to drill 9.875" Production Hole adjusting parameters F/ 6,180' to 6,431' MD (5,701' TVD) total 251' (AROP 41.8') 530 GPM, 1,685 PSI, 90-120 RPM, TRQ on 11K, TRQ off 11.9K, WOB 20-35K. P/U 203K, SLK 131K, ROT 157K. Max Gas 159U. BGG 131U. ECD 10.12 ppg.;MP #1 Pod 4 liner has movement, reduced efficiency on MP #1.;Distance to WP#03: 1.29', 0.45' Low 1.21 Right;Daily fluid hauled to G&I 228 bbls total = 1,834 bbls Daily metal recovered 80 lbs, total = 388 lbs Daily water hauled from L Pad Lake 520 bbls total = 2,220 bbls Daily Fluid lost 0 bbls total production = 0 bbls 27.21 n (LAT/LONG): evation (RKB): 50-029-23567-02-00API #: Well Name: Field: County/State: MP K-44B Milne Point Hilcorp Energy Company Composite Report , AK Contractor AFE #: AFE $: 2011326D $2,141,972 Job Name:2011326D MPU K-44B Drilling Spud Date: Mill Window in 10 3/4" @ 5431' md Mill 9-7/8" window in 10-3/4" casing F/ 5431'- T/ 5451' MD as per BOT rep. TOW @ 5431, BOW p R/U and perform 12.5 FIT. 4/24/2020 Cont to drill 9.875" Production Hole F/ 6431' - T/ 6686' MD (total 255' / AROP 43') 25-35k WOB, 530 GPM, 1685 PSI, 80-120 RPM, 12K tq on, 11.5k tq off, 60% F/O. 100u BGG, 143u Max Gas. 10 ECD w/ 9.5 MW. 204k up, 139k dn, 162k rot.;Cont to drill 9.875" Production Hole F/ 6686' - T/ 7120' MD / 6343' TVD (total 434' / AROP 72') 25-35k WOB, 530 GPM, 1685 PSI, 80-150 RPM, 13K tq on, 13.5k tq off, 60% F/O. 130u BGG, 170u Max Gas. 10.2 ECD w/ 9.5 MW. 213k up, 142k dn, 172k rot.;Cont to drill 9.875" Production Hole F/ 7,120' to 7,194' MD (6,401' TVD) total 74' (AROP 74') 530 GPM, 1,840 PSI, 80-150 RPM, TRQ on 13K, TRQ off 13.5K, WOB 25-35K. P/U 221K, SLK 138K, ROT 173K. Max Gas 171U. BGG 129U. ECD 10.32 ppg. No losses.;PJSM Obtain survey at 7,194' MD. Send Geo Pilot to home. Rot & Rec F/ 7,194' to 7,124' MD Pump 40 bbl 300+ Vis sweep returned 40 bbls early as Calc. W/ 50% increase Clay W/ slight shale. 530 GPM, 1,820 PSI, 180 RPM, TRQ 12.5K, ROT 173K, ECD 10.18 ppg. Max Gas 197U. No losses.;Increased black product up to 8 ppb for HRZ. SPR at 7,194' MD (6,401' TVD) MW 9.55. MP #1 32-193, 48-252. MP #2 32-190, 48-250.;PJSM POOH on elevators 3 stand F/ 7,194' to 7,000' MD Pulled 20K over 2X. Start BROOH F/ 7,000' to 5,799' MD 490 GPM, 1,550 PSI, 100 RPM, TRQ 13K, P/U 216K, SLK 151K,, ROT 169K. BROOH showed no signs of over pull or erratic TRQ. Jars pulled through window clean.;At 5,887 to 5,997' CBU over 2 stands 490 GPM 1,520 PSI, 100 RPM, TRQ 11.2K, Max Gas 304U, ROT 147K ECD fell F/ 10.12 to 10.02 ppg. Shakers unloaded at BU same clay W/ slight shale. No losses.;PJSM Cont BROOH F/ 5,799’ to 5,670’ MD 30 ft/min 490 GPM, 1,480 PSI, 100 RPM, TRQ 11.7K, ROT 147K, Max Gas 83U. Attempted to pull on elevators pulled 10K over, Kelly up and pump out 5" D.P. W/ last stand 5” HWDP across Window F/ 5,670’ to 5,611’ MD 490 GPM, 1,480 PSI saw 5K;over string weight drag (P/U 184K) Cont to POOH 5” D.P. on elevators F/ 5,611’ to 5,404’ MD BHA going through window saw 5-7K drag. No losses.;PJSM Install RCD Bearing as per Beyond Rep onsite. Drain stack remove trip nipple. M/U RCD Bearing on single jnt F/ string. Install RCD Bearing. M/U Clamp divert flow to MPD choke. SIMOPS MP #1 Pod 4 Start replacing Liner & Wear Plate.;PJSM Service rig. Grease Blocks, Top Drive, Wash Pipe and Iron Roughneck. Check oil in Top Drive. Check welds on cradle. Finish MP #2.Flooded and tested MPD lines and Equip at 500 GPM, MPD 500 GPM, 1,540 PSI 39 PSI line restriction.;PJSM RIH W/ 5" D.P. on elevators F/ 5,404' to 7,134' MD. P/U 210K SLK 135K. Seeing about 3K consistent drag for the whole trip in. No losses.;Wash down last stand F/ 7,134 to 7,194' MD. 530 GPM MPD 530 GPM, 1,840 PSI 80 RPM, TRQ 13.5K, Max GAs 334U. ECD 10.26, MWD send down link. P/U 212K SLK 141K ROT 168K.;Distance to WP#3: 2.01', 1.73' Low 1.03' Left.;Daily fluid hauled to G&I 342 bbls total = 2,176 bbls Daily metal recovered 42 lbs, total = 430 lbs Daily water hauled from L Pad Lake 390 bbls total = 2,610 bbls Daily Fluid lost 0 bbls total production = 0 bbls 4/25/2020 Cont to drill 9.875" Production Hole F/ 7,194' to 7,576' MD . Total 382' (AROP 64') 590 GPM, 2570 PSI, 140 RPM, TRQ on 14K, TRQ off 13K, WOB 35-40K. P/U 217K, S/O 141K, ROT 170K. Max Gas 211u. Hold 11.1-11.3 EMW w/ MPD (360 psi drlg /475 psi connections).;TOP of HRZ @ 7490' MD / 6678' TVD.;Cont to drill 9.875" Production Hole F/ 7,576' to 7,976' MD . Total 420' (AROP 70') 590 GPM, 2660 PSI, 140 RPM, TRQ on 15K, TRQ off 14K, WOB 35-40K. P/U 220K, S/O 148K, ROT 176K. Max Gas 876u, 110u BGG. Hold 11.1-11.3 EMW w/ MPD (360 psi drlg /475 psi connections).;Cont 9.875" Production Hole F/ 7,976' to TD 7,983' MD ( 7,140' TVD) total 7' 590 GPM/ MPD 584, 2,660 PSI, 140 RPM, TRQ on 14-16.5K, TRQ off 15K, WOB 35-40K. P/U 220K, SLK 148K, ROT 148K. Max Gas 876U. MPD 360 PSI pumps on,pumps off 475 PSI 11.1-11.3 ppg EMW W/ 9.55.ppg MW. TD called By Geologist.;At 7,978' MD setting down 40K WOB unable to drill. Adjusting all parameters. Sent Geo Pilot back to 17% deflection and was able to drill to TD 7,983 ' MD. Obtain survey on bottom, set Geo Pilot to home position.;PJSM Rot & Red F/ 7,983' to 7,922' MD CBU 4X 600 GPM/ MPD 589, 2,775 PSI, 130 RPM, TRQ 15K, Max Gas 340U. Pumped 35 bbl 9.1 ppg 35 Vis Sweep/ 35 bbl 11.5 ppg 307 vis Sweep returned as Calc. 25% increase of fines.;PJSM Blow down Top Drive and line up circ through MPD choke line at 4 bpm,. POOH on elevators F/ 7,983' to 7,731' MD P/U 231K SLK 145K at 30 ft/min MPD schedule. Pulled tight at 7,747', 7,742, 7,738' & 7,731' MD wiping each time. Pulling 35K over 6X at 7,731' MD.;Started BROOH F/ 7,790' to 7,484' MD. 500 GPM/ MPD 490, 2,100 PSI, 100 RPM, TRQ 15-18.5K, Max Gas 60U, ECD 11.2 ppg, 15-20 ft/min. MPD holding 320 PSI dynamic & 530 PSI static. ECD 11.1 to 11.2 ppg. Erratic TRQ seen but no over pulls or Press spikes.;PJSM Cont BROOH F/ 7,484' to 7,194' MD. 500 GPM/ MPD 488, 2,030 PSI, 100 RPM, TRQ 13-15K, Max Gas 318U, ECD 11.2 ppg, P/U 212K SLK 133K ROT 169K 15-20 ft/min. MPD 320 PSI dynamic & 530 PSI static. ECD 11.1 to 11.2 ppg. No over pulls or Press spikes.;PJSM Blow down Top Drive and line up circ through MPD choke line at 4 bpm. RIH on elevators F/ 7,194' to 7,928' MD P/U 236K SLK 146K. 30 ft/min as per Beyond schedule. MPD 480 PSI dynamic & 530 PSI static. ECD 11.1 to 11.2 ppg;PJSM Fill string and obtain parameters. Wash down F/ 7,928' to 7,983' MD. Rot & Rec F/ 7,983' to 7,928' MD 590 GPM/ MPD 580, 2,600 PSI, 100 RPM, TRQ 14-16K, Max Gas 303U P/U 236 SLK 146K ROT 177K.;Begin weight up W/ spike fluid 11.5 ppg into active system in 0.3 ppg increments F/ 9.6 ppg to ~10.5 ppg.. Beyond walking down press F/ 330 PSi to 125 PSI maintaining 11.2 PPG ECD.;SPR at 7,983' (7,140' TVD) MW 9.55 MPD Back Press 375 PSI. MP #1 32-555, 48-620. MP #2 48-550, 48-615.;Distance to WP#3: 5.05', 2.18' High, 4.56' Left;Daily fluid hauled to G&I 342 bbls total = 2,518 bbls Daily metal recovered 71 lbs, total = 501 lbs Daily water hauled from L Pad Lake 390 bbls total = 3,000 bbls Daily Fluid lost 0 bbls total production = 0 bbls 4/26/2020 Monitor well w/ 0 psi back pressure on MPD (static w/ 10.5 MW). 100 rpm, 15k tq, stage pumps up 580 gpm, 2600 psi w/ 11.3 EMW (125 psi MPD). Spot 50 bbl liner running pill on btm (7983' to estimated top @ ~7455' ) w/ 12 ppb black product and 4% lube. B/D TDS.;POOH F/ 7983' - T/ 6550' @ 30 fpm, Increase pulling to 45-60 fpm from 6550' to 5418' MD. Hole took calculated displacement. On btm wts - 235k up, 153k dn, 182k rot. Saw 5-10k drag pulling last 50' of BHA into window with minimal overpull. Hold 11.1-11.3 EMW during trip w/ MPD.;CBU 2x @ 5418' MD. Pumped 40 bbl hi-vis sweep w/ no increase in cuttings. 580 gpm, 2275 psi, 40 rpm, 8.7k tq w/ 11.24 EMW. B/D TDS and lineup MPD for tripping operations. 168k up, 118k dn.;POOH racking back F/ 5418' - T/ 3935' MD @ 60 fpm holding 280 dynamic, 220 static w/ Beyond MPD system (11.1-11.3 EMW).;Continue trip out laying down excess 5" dp to allow enough room in derrick for upcoming casing run. POOH F/ 3935' - T/ 711' (BHA) holding 11.3 EMW w/ MPD. 280 dynamic / 220 static. Trip took calculated displacement.;Stage psi down F/ 220 psi to zero and monitor well (static). PJSM, Pull MPD bearing and install trip nipple. Blow down MPD lines, clean RCD and L/D same from floor. Begin rigging out MPD lines, equipment.;PJSM L/D 5" HWDP & Jars to pipe shed 711' to 160' MD.. Recover crows foot and corrosion ring. Down load MWD. P/U 70K SLK 70K SIMOPS blow down Geo Span, grease blocks, spinners, crown, iron roughneck. L/D remaining BHA. Bit Grade 2-4- CT-G-X-1-LT-TD.;2 chipped inner row, 2nd row severe chipping and missing cutters. Stabs in gauge W/ minimal wear.;PJSM P/U 5" working single M/U wear ring puller. BOLDS & pull wear ring.;PJSM L/D BHA components F/ rig floor. Bit, TM, DM, & FS.;PJSM P/U Weatherford 7" slips, elevators, Volant CRT and handling Equip. 19 7" Centralizers to rig floor. M/U Volant CRT to Top Drive and chain off swivel. Install Bail ext and elevators.;PJSM P/U M/U & Innovex 7" Float Ported Shoe, slick jnt and Innovex FC (BakLoc) 2 ea solid body Centralizers. Test Float, good. Cont RIH 7" L-80 26# TXP F/ 164' to 2,031' MD. Follow Beyond trip schedule 90-120 ft/min. P/U 76K SLK 71K. 1 ea centralizer to jnt 22. Weatherford TRQ to 14,750 ft/lb.;Filling every 5 jnts and topping off every 10 jnts.;Daily fluid hauled to G&I 92 bbls total = 2,610 bbls Daily metal recovered 0 lbs, total = 501 lbs Daily water hauled from L Pad Lake 130 bbls total = 3,130 bbls Daily Fluid lost 0 bbls total production = 0 bbls gp @ B/D TDS and lineup MPD for tripping operations Cont RIH 7" L-80 26# TXP F/ 164' to 2,031' MD. RIH with 7" casing ;Cont 9.875" Production Hole F/ 7,976' to TD 7,983' MD ( 7,140' TVD) Cont to drill 9.875" Production Hole F/ 6431' - T/ 6686' TD at 7983 ft md Cont to drill 9.875" Production Hole F/ 7,194' to 7,576' M 4/27/2020 Continue running 7" TXP, 26#, L-80 production casing F/ 2031' - T/ 5399' MD @ 90-120 fpm. tq connections 14,750 ft/lbs. fill every 5 jts, top off every 10 for displacement. Hole gave calculated displacement.;Rot and reciprocate pipe @ 5399' - 5358' MD. Staged up to 8 bpm, 290 psi, 50% flow out w/ no losses. Rot @ 10 rpm, 8k tq.;Continue running 7" TXP, 26#, L-80 production casing F/ 5399' - T/ 7250' MD @ 90 fpm. tq connections 14,750 ft/lbs, 202k up, 130k dn. fill every 5 jts, top off every 10 for displacement. Hole gave calculated displacement.;Rot and reciprocate pipe @ 7250' - 7210' MD. Circulate btms up staging up to 8 bpm, 380 psi, 50% flow, 10 rpm, 9-12k tq. Did have 300 psi held with no circulation but free pipe (up/dn/rot). Worked pipe to establish initial circulation with no further problems. 205k up, 140k dn.;Continue running 7" TXP, 26#, L-80 production casing F/ 7250' - T/ 7965' MD @ 80 fpm. tq connections 14,750 ft/lbs, 235k up, 142k dn. fill every 5 jts, top off every 10 for displacement. Hole gave calculated displacement.;P/U jt #199 and wash dn F/ 7965' to tag depth of 7975' MD, 4 bpm, 290 psi, 34% flow. Set dn 2x @ 7975' w/ 25k solid tag. 220k up, 142k dn. No increase in pump psi due to eccentric shoe design and competent formation. Spaced out for setting 7"-1.31' off btm once landed.;L/D 3 Jnts of 7" Csg. Add 2 space out jnts 11.86' & 9.75". Run Jnt 197 and M/U Hanger/ Landing Jnt. Break circ @ 2 bpm 120 PSI. Land Hanger at 7,973.36' MD.;PJSM Recip F/ 7,973' to 7,960' MD 7 bpm, 400 PSI, RF 44%. P/U 220K, SLK 140K. Condition mud for cement job ~20 YP. YP in and out 21, shut down. No losses. Blow down Top Drive. SIMOPS L/D Weatherford tongs, air slips and Equip.;PJSM R/U swing, 2 low trqs and cement line to Volant. Hal pump 5 bbls H2O PT low kick out 1200 pSI, high 4,036 PSI 5 min. Back out Volant drop By Pass Plug, Hal pump 40 bbl 11.0 ppg Tuned Spacer 4 bpm 500 PSI, 45 bbls 15.8 ppg Intermediate Cement 4 bpm ICP 640 PSI FCP 240 PSI.;Drop top plug. Hal pump 20 bbl H2O 5.5 BPM FCP 320 PSI, turn over to rig. Rig pumped 285 bbls Calc 282.36 bbls pump rate 6 bpm 360 PSI for 235 bbls away, 3 bpm 271 PSI 20 bbls away and 2 bpm FCP 460 PSI. Plug did not pump. Checked floats appeared floats not holding bled back 0.75 bbls.;Pumped 1 bbl at 3 bpm 600 PSI, opened bleeder and bled back 0.75 bbls floats held. CIP at 23:30. Recip pipe during entire job P/U 225K SLK 135K. Set 100K on Hanger. No losses entire job. Calc TOC 7,035' MD.;PJSM R/D cement lines. Blow down to Hal and rig them down.;PJSM Pull landing jnt. M/U Pack Off on jnt. Run in and set Pack Off as per NOS Rep onsite. RILDS. Fill void W/ graphite grease. Test void to 250 PSI low 5 min and 4,000 PSI high 10 min. Pull and L/D running jnt.;PJSM R/D Volant CRT and bail ext. C/O elevators to 5" Hydraulic. Clean and clear rig floor.;PJSM L/D 5" D.P. F/ Derrick via mouse hole. (18 stands) Monitor well W/ trip tank, static. SIMOPS Empty pits and begin cleaning.;Daily fluid hauled to G&I 425 bbls total = 3,035 bbls Daily metal recovered 0 lbs, total = 501 lbs Daily water hauled from L Pad Lake 130 bbls total = 3,260 bbls Daily Fluid lost 0 bbls total production = 0 bbls cmt 7" csg qp pp(p) ;Continue running 7" TXP, 26#, L-80 production casing F/ 7250' - T/ 7965' MD gpj Land Hanger at 7,973.36' MD.;PJSM Recip F/ 7,973' to 7,960' MD 7 bpm, gq pp pg py Hal pump 40 bbl 11.0 ppg Tuned Spacer 4 bpm 500 PSI, 45 bbls 15.8 ppg Intermediate Cement 4 bpm ICP 640 PSI FCP 240 PSI.;Drop top plug. g p p ppg p p ppg p pppg Hal pump 20 bbl H2O 5.5 BPM FCP 320 PSI, turn over to rig. Rig pumped 285 bbls Calc 282.36 bbls pump rate 6 bpm 360 PSI for 235 bbls away, 3 bpm 271 pp ggpp pp p PSI 20 bbls away and 2 bpm FCP 460 PSI. Plug did not pump. Checked floats appeared floats not holding bled back 0.75 bbls.;Pumped 1 Activity DateO Ops Summary 4/28/2020 Continue L/D 5" dp from derrick using mousehole (74 stds total). Sym ops - LRS freeze protect 10-3/4" x 7" annulus w/ 120 bbls diesel, 2 BPM, 713 ICP, 950 FCP.,C/O lower pipe rams to 2-7/8" x 5-1/2" VBR's. R/U and test same w/ 2-7/8" test jt. 250/3500 psi w/ 5 min hold on each. Chart and record same. Failed 2nd test (uppers) due to failed "Seals" on test plug. Pull, redress and set test plug. Retested without issue. B/D and R/D test equipment. Pump plug on seat, pull test plug w/ 10k.,Install 10" ID wear bushing, RILDS. Mob BHA tools to floor and stage same. C/O and prep 4" handling equipment.,PJSM, M/U 6.125" Milltooth, bit sub (ported flapper float installed), 10x jts 4" HWDP (307' total length). Single in hole F/ 307' to 2631' w/ 4" HT38 drill pipe out of shed. Drift 2.375".,Cont to RIH with 4" HT38 drill pipe from derrick from 2631' to 7769'. Wash down to 7860' at 2 bpm 480 psi. Calculated displacement observed. PUW 141K, SOW 104K.,CBU x 2 at 7 bpm, 1500 psi, 60 rpms, 5.5Kft-lbs, reciprocating pipe.,Rig up to test casing, flood lines and purge air, shut UPR's. PT casing to 3000 psi for 30 minutes - good test. 2.9 bbls pumped, 2.9 bbs returned.,Conduct choke drill with rig crews, bringing pumps up to simulated ICP while holding pressure. Crew change - conduct choke drill with oncoming rig crew.,Rig down casing test equipment: high pressure hose, head pin. Blow down c hoke and kill lines.,Drill out cement and shoe track down to shoe from 7831' to 7983'; tag plug at 7866', float collar at 7901', shoe at 7983'. WOB 1-7K, 295 gpm, 1475psi, 120 rpms,7.1Kft- lbs. Ream through float x 2. CBU.,Displace to 10.5 ppg NaBr brine. Pump 40 bbls high vis spacer followed by brine until clean at shakers at 295 gpm, 1530 psi, 80 rpms, 6.5Kft-lbs.,Daily fluid hauled to G&I 461 bbls total = 3,496 bbls Daily metal recovered 0 lbs, total = 501 lbs Daily water hauled from L Pad Lake 130 bbls total = 3,390 bbls Daily Fluid lost 0 bbls total production = 0 bbls 4/29/2020 POOH laying down 6 jtns 4" drill pipe from 7983' to 7760' - no indication of swabbing. RIH 2 stands from derrick to 7850'. Pump dry job. Cont. POOH laying down drill pipe from 7850' to 3031'. Calc hole fill observe. PUW 76K, SOW 73K.,Cut and slip 88' of drilling line. check air gaps on brake - within spec. Calibrate block height.,Service rig: grease crown, blocks, top drive, spinners, drawworks. Check oil and welds on top drive - good.,Cont. POOH laying down drill pipe from 3031' to 307'. L/D BHA: 10 jnts HWDP, XO, Bit sub, Bit. Calculated hole fill observed.,Clean and clear rig floor. Send down air slips.,Rig up E-line: spot E-line truck, Bring lubricator to rig floor. rig up sheave. Build tool string.,RIH with CBL, GR, CCL on E-line to 7983' and log up to 6800'. POOH. Build tool string #2 3-1/8" GR/CCL un-centralized to obtain better GR data. RIH and log from 7983' to 7100'.,Build tool string #3: 31.5" CIBP, GR/CCL. RIH; set down on float collar at 30 fpm. Pick up and RIH at 50 fpm tag bottom, perform correlation pass. RIH and set CIBP, bottom at 7983' top at 7980.4'. POOH.,R/D lubricator. Shut blinds, flood and purge choke lines. PT CIBP to 1500 psi for 10 minutes. R/U to test lubricator.,Daily fluid hauled to G&I 914 bbls total = 4,410 bbls Daily metal recovered 0 lbs, total = 501 lbs Daily water hauled from L Pad Lake 0 bbls total = 3,390 bbls Daily Fluid lost 0 bbls total production = 0 bbls 4/30/2020 M/U HES 4-5/8" VANN (Scallop) TCP's (43.5' effective length of shot). 5 spf, 60° F 105 per gun(2x guns). RIH on HES E-line to 200'. Close annular on 7" extension M/U with pickoff head. Test same 250/1000 psi (good test). Continue RIH tagging up on depth @ 7977' MD. Set depth @ tag and log up F/ 7977.55' - T/ 7700' MD. Correlate top float collar @ 7897.5' from drilled logs GR. RIH and verify tag depth (same tag).,1500# dn, 2600# up line tension on btm. P/U to 2500# line tension. Putting guns on depth. Fire same. Good indication of guns fired (line jump). Well static. BTM perfs @ 7976.3', Top perfs @ 7932.8'. POOH and redress guns w/ 20.5' of perfs (1x gun), 5 spf, 60F, 105 shots. RIH w/ TCP's (150 fpm in/50 fpm up logging). Tag @ 7976' (adjust and correlate as per drilled logs/CCL).,1200# dn, 2090# up line tension on btm. P/U and log 2x from 7977' up to 7680' CCL/GR. Verify logs w/ drilled logs (TOP of Kup "C" 7917'). Tag @ 7977', pick up putting top shot @ 7918' as per completion engineer/geo. Fire same w/ good indication of guns fired (line jump). Well static. Top perfs @ 7918', btm perfs @ 7938.83' (6.03' overlap on perfs from previous run). 100% shots fired from both runs. POOH.,Rig down E-Line, L/D lubricator. Remove sheave from elevators.,Remove wear bushing. R/U Centrilift: bring up job box. 160 cannon clamps. R/U ESP sheave in derrick. Power up ESP spooler. Pull ESP cable through sheave in derrick and secure on rig floor.,Pick up 562 XP motor and service with oil. M/U upper and lower seals to motor and service with oil. M/U Gas avoider, separator, pump, Zenith ported sub. Pick up and install centralizer on bottom of motor zenith gauge. Install ESP cable motor lead. Install CAP line. Install protecterlizer on top of motor, lower tandem seal, gas separator; Flat guard on seals, SS band on top gas separator.,RIH with ESP completion on 2-7/8", 6.5#, L-80, EUE tubing from 62' to 947' as per detail, installing cannon clamps every joint to joint 15 then every other joint. TQ connections to 2250 ft-lbs. PUW 40K, SOW 40K. Calculated displacement observed.,Cont. to RIH with ESP completion on 2-7/8", 6.5#, L-80, EUE tubing from 947' to 5035' as per detail, installing cannon clamps every other joint. TQ connections to 2250 ft-lbs. Test ESP cable every 1000'. PUW 68K, SOW 61K. Calculated displacement observed.,Daily fluid hauled to G&I 57 bbls total = 4,467 bbls Daily metal recovered 0 lbs, total = 501 lbs Daily water hauled from L Pad Lake 0 bbls total = 3,390 bbls Daily Fluid lost 0 bbls total production = 0 bbls n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: MP K-44B Milne Point Hilcorp Energy Company Composite Report , AK Contractor AFE #: AFE $: Job Name:2011326C MPU K-44B Completion Spud Date: g ,RIH with CBL, GR, CCL on E-line to 7983' and log up to 6800'. g RIH and set CIBP, bottom at 7983' top at 7980.4'. gggp GR/CCL un-centralized to obtain better GR data. Set CIBP at 7983' pp Build tool string #2 3-1/8" freeze protect OA with 120 bbls diesel pp p pipe.,Rig up to test casing, flood lines and purge air, shut UPR's. Sym ops - LRS freeze protect 10-3/4" x 7" annulus w/ 120 bbls diesel, M/U HES 4-5/8" VANN (Scallop) TCP's (43.5' effective length of shot) Perforate Kup C Note; double shot zone 7933-7938' p . BTM perfs @ 7976.3', Top perfs @ 7932.8'. cement and shoe track down to shoe from 7831' to 7983'; tag plug at 7866', float collar at 7901', shoe at 7983'. WOB 1-7K, 295 gpm, 1475psi, 120 rpms,7.1Kft- lbs. Ream through float x 2. CBU. p)g@ Top perfs @ 7918', pppgp @ p p g g g g (jp) btm perfs @ 7938.83' (6.03' overlap on perfs from previous run). 100% shots fired from both runs. POOH.,Rig down E-Line, L/D Crewgpp gggppp gp change - conduct choke drill with oncoming rig crew.,Rig down casing test equipment: high pressure hose, head pin. Blow down choke and kill lines.,Dgggggqpgpp drill shoe track and float collar 5/1/2020 Continue RIH w/ ESP completion on 2-7/8" EUE, 6.5#, L-80 tubing F/ 5035' - T/ 7823' MD. 2250 ft/lb tq on connection. 93k up, 72k dn. Calc displacement for trip. Test cable every 1000' (all test good).,M/U tbg hanger, landing jt and terminate ESP cable to penetrator on hanger (test penetrator - Good). Drain stack and landout hanger w/ 37k string wt. Final set depth 7849.78' MD. Clamps on mtr assy protectolizers 3x, flat guards 2x, SS band 1x, Cannon Clamps 137ea. Sym Ops - R/D running equipment and stage on floor. Spool excess ESP cable back to unit and prep for demob.,Set BPV.,Flush fresh water through both mud pumps, mud line, kill line, choke line, choke manifold. Blow down lines.,Remove mouse hole, riser. Disconnect choke and kill lines. Suspend MPD head. Rack back BOP stack on pedestal. Set DSA aside. Set MPD head down. Secure stack. Sim Ops: clean pits, begin disconnecting interconnects. Take apart mud pumps for inspection.,N/U tubing adapter and tree: prep hanger face. Install CTS on BPV. Dress tubing adapter. Change out dummy penetrator due to slight bend. N/U dry hole tree. Test tubing hanger void 500/5 min, 5000/10 min. - good. Make final ESP cable, Zenith gauge test through penetrator - good. Test Tree 500/5000 psi - good. Sim Ops Continue working on mud pumps, interconnects. Bridle up.,Final Report for K-44B.,Daily fluid hauled to G&I 114 bbls total = 4,561 bbls Saved 165 bbls of 10.5 ppg brine to D14. Daily metal recovered 0 lbs, total = 501 lbs Daily water hauled from L Pad Lake 0 bbls total = 3,390 bbls Daily Fluid lost 0 bbls total production = 0 bbls Continue RIH w/ ESP completion on 2-7/8" EUE, 6.5#, L-80 tubing F/ 5035' - T/ 7823' MD. 2250 ft/lb tq on connection. 93k up, 72k dn. Calc displacement for pg trip. Test cable every 1000' (all test good).,M/U tbg hanger, landing jt and terminate ESP cable Run ESP (no packer) p ,N/U tubing adapter and tree: prep hanger face. 30 April, 2020 Milne Point M Pt K Pad MPU K-44B 500292356702 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt K Pad Halliburton Definitive Survey Report Well: Wellbore: MPU K-44 MPU K-44B Survey Calculation Method:Minimum Curvature MPU K-44B Actual RKB @ 56.51usft Design:MPU K-44B Database:NORTH US + CANADA MD Reference:MPU K-44B Actual RKB @ 56.51usft North Reference: Well MPU K-44 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Milne Point, ACT, MILNE POINT Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: MPU K-44 usft usft 0.00 0.00 6,005,880.17 584,535.02 29.30Wellhead Elevation:0.00 usft0.00 70° 25' 33.570 N 149° 18' 40.034 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU K-44B Model NameMagnetics IFR 4/5/2020 16.02 80.86 57,373.00000000 Phase:Version: Audit Notes: Design MPU K-44B 1.0 ACTUAL Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:5,405.64 75.420.000.0027.21 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 4/30/2020 Survey Date 3_MWD_Interp Azi+Sag H003Mb: Interpolated azimuth + sag correction128.21 499.17 MPK-44 Interp (MPK-44)03/28/2016 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa594.55 5,405.64 MPK-44 MWD+IFR2+MS+sag (1) (MPK-03/29/2016 3_MWD A001Mb/ISC4: BGGM declination correction on5,431.00 5,577.79 MPU K-44B Interp Azi (MPU K-44B)03/30/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa5,640.39 5,703.71 MPU K-44B MWD+IFR2+MS+Sag (1) (M 04/24/2020 3_MWD A001Mb/ISC4: BGGM declination correction on5,766.59 5,766.59 MPU K-44B Interp Azi (2) (MPU K-44B)04/24/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa5,831.47 7,954.08 MPU K-44B MWD+IFR2+MS+Sag (2) (M 04/24/2020 MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 27.21 0.00 0.00 27.21 0.00 0.00-29.30 6,005,880.17 584,535.02 0.00 0.00 UNDEFINED 128.21 0.33 35.07 128.21 0.24 0.1771.70 6,005,880.41 584,535.18 0.33 0.22 3_MWD_Interp Azi+Sag (1) 218.46 0.14 35.07 218.46 0.54 0.38161.95 6,005,880.72 584,535.39 0.21 0.50 3_MWD_Interp Azi+Sag (1) 315.20 0.14 35.07 315.20 0.73 0.52258.69 6,005,880.91 584,535.53 0.00 0.68 3_MWD_Interp Azi+Sag (1) 403.61 0.09 35.07 403.61 0.88 0.62347.10 6,005,881.06 584,535.63 0.06 0.82 3_MWD_Interp Azi+Sag (1) 499.17 0.40 35.07 499.17 1.21 0.85442.66 6,005,881.39 584,535.86 0.32 1.13 3_MWD_Interp Azi+Sag (1) 594.55 0.41 35.07 594.54 1.77 1.24538.03 6,005,881.95 584,536.24 0.01 1.64 3_MWD+IFR2+MS+Sag (2) 688.52 0.33 59.69 688.51 2.18 1.67632.00 6,005,882.37 584,536.66 0.19 2.16 3_MWD+IFR2+MS+Sag (2) 782.62 3.51 62.00 782.55 3.67 4.44726.04 6,005,883.89 584,539.42 3.38 5.22 3_MWD+IFR2+MS+Sag (2) 874.20 3.72 59.90 873.95 6.47 9.49817.44 6,005,886.75 584,544.44 0.27 10.81 3_MWD+IFR2+MS+Sag (2) 4/30/2020 4:47:43PM COMPASS 5000.15 Build 91E Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt K Pad Halliburton Definitive Survey Report Well: Wellbore: MPU K-44 MPU K-44B Survey Calculation Method:Minimum Curvature MPU K-44B Actual RKB @ 56.51usft Design:MPU K-44B Database:NORTH US + CANADA MD Reference:MPU K-44B Actual RKB @ 56.51usft North Reference: Well MPU K-44 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 971.45 6.44 60.18 970.80 10.77 16.95914.29 6,005,891.13 584,551.85 2.80 19.12 3_MWD+IFR2+MS+Sag (2) 1,065.56 7.19 59.23 1,064.25 16.41 26.591,007.74 6,005,896.87 584,561.42 0.81 29.87 3_MWD+IFR2+MS+Sag (2) 1,159.81 9.92 54.29 1,157.44 24.16 38.251,100.93 6,005,904.76 584,572.99 3.00 43.11 3_MWD+IFR2+MS+Sag (2) 1,254.22 13.85 51.79 1,249.81 35.90 53.741,193.30 6,005,916.68 584,588.35 4.20 61.05 3_MWD+IFR2+MS+Sag (2) 1,347.10 14.07 47.45 1,339.95 50.42 70.801,283.44 6,005,931.38 584,605.23 1.15 81.21 3_MWD+IFR2+MS+Sag (2) 1,441.95 17.25 57.75 1,431.29 65.72 91.191,374.78 6,005,946.92 584,625.45 4.44 104.80 3_MWD+IFR2+MS+Sag (2) 1,537.16 19.82 56.51 1,521.55 82.17 116.601,465.04 6,005,963.64 584,650.67 2.73 133.53 3_MWD+IFR2+MS+Sag (2) 1,631.28 21.66 54.34 1,609.57 101.10 144.021,553.06 6,005,982.88 584,677.87 2.12 164.83 3_MWD+IFR2+MS+Sag (2) 1,725.19 23.28 53.85 1,696.35 122.15 173.091,639.84 6,006,004.26 584,706.70 1.74 198.26 3_MWD+IFR2+MS+Sag (2) 1,819.24 23.16 54.11 1,782.78 143.96 203.081,726.27 6,006,026.40 584,736.44 0.17 232.78 3_MWD+IFR2+MS+Sag (2) 1,914.26 27.58 60.21 1,868.63 165.85 237.331,812.12 6,006,048.69 584,770.43 5.40 271.44 3_MWD+IFR2+MS+Sag (2) 2,007.49 28.52 67.63 1,950.93 185.05 276.651,894.42 6,006,068.33 584,809.54 3.87 314.33 3_MWD+IFR2+MS+Sag (2) 2,101.79 30.13 74.89 2,033.17 199.80 320.341,976.66 6,006,083.56 584,853.05 4.14 360.32 3_MWD+IFR2+MS+Sag (2) 2,196.24 32.67 75.78 2,113.78 212.24 367.942,057.27 6,006,096.54 584,900.50 2.73 409.52 3_MWD+IFR2+MS+Sag (2) 2,290.89 34.98 74.94 2,192.41 225.57 418.912,135.90 6,006,110.45 584,951.31 2.49 462.21 3_MWD+IFR2+MS+Sag (2) 2,385.08 35.13 75.78 2,269.51 239.24 471.262,213.00 6,006,124.71 585,003.49 0.54 516.30 3_MWD+IFR2+MS+Sag (2) 2,479.68 35.02 75.73 2,346.93 252.62 523.952,290.42 6,006,138.68 585,056.02 0.12 570.66 3_MWD+IFR2+MS+Sag (2) 2,574.07 33.40 75.95 2,424.99 265.60 575.402,368.48 6,006,152.25 585,107.32 1.72 623.73 3_MWD+IFR2+MS+Sag (2) 2,668.28 33.35 76.18 2,503.66 278.08 625.702,447.15 6,006,165.29 585,157.47 0.14 675.55 3_MWD+IFR2+MS+Sag (2) 2,762.76 33.30 76.40 2,582.61 290.38 676.132,526.10 6,006,178.17 585,207.75 0.14 727.45 3_MWD+IFR2+MS+Sag (2) 2,857.50 33.14 76.15 2,661.86 302.70 726.552,605.35 6,006,191.05 585,258.03 0.22 779.35 3_MWD+IFR2+MS+Sag (2) 2,953.19 33.13 76.31 2,741.99 315.15 777.352,685.48 6,006,204.07 585,308.68 0.09 831.65 3_MWD+IFR2+MS+Sag (2) 3,045.48 32.98 76.91 2,819.35 326.80 826.322,762.84 6,006,216.28 585,357.51 0.39 881.98 3_MWD+IFR2+MS+Sag (2) 3,140.49 32.89 76.51 2,899.09 338.68 876.592,842.58 6,006,228.73 585,407.64 0.25 933.62 3_MWD+IFR2+MS+Sag (2) 3,234.99 32.30 76.66 2,978.70 350.49 926.112,922.19 6,006,241.10 585,457.02 0.63 984.52 3_MWD+IFR2+MS+Sag (2) 3,329.58 31.84 76.87 3,058.86 361.99 975.003,002.35 6,006,253.15 585,505.77 0.50 1,034.73 3_MWD+IFR2+MS+Sag (2) 3,423.82 32.11 75.94 3,138.80 373.72 1,023.503,082.29 6,006,265.43 585,554.13 0.60 1,084.62 3_MWD+IFR2+MS+Sag (2) 3,517.99 34.16 75.56 3,217.65 386.40 1,073.393,161.14 6,006,278.66 585,603.87 2.19 1,136.09 3_MWD+IFR2+MS+Sag (2) 3,612.95 34.31 76.28 3,296.16 399.39 1,125.213,239.65 6,006,292.24 585,655.53 0.45 1,189.51 3_MWD+IFR2+MS+Sag (2) 3,706.78 34.14 76.62 3,373.74 411.76 1,176.513,317.23 6,006,305.19 585,706.69 0.27 1,242.28 3_MWD+IFR2+MS+Sag (2) 3,797.80 33.88 77.33 3,449.19 423.23 1,226.113,392.68 6,006,317.22 585,756.15 0.52 1,293.17 3_MWD+IFR2+MS+Sag (2) 3,895.33 33.84 77.42 3,530.18 435.11 1,279.143,473.67 6,006,329.70 585,809.03 0.07 1,347.48 3_MWD+IFR2+MS+Sag (2) 3,989.15 34.21 76.67 3,607.94 446.88 1,330.303,551.43 6,006,342.05 585,860.05 0.60 1,399.95 3_MWD+IFR2+MS+Sag (2) 4,083.43 34.36 77.19 3,685.84 458.89 1,382.033,629.33 6,006,354.64 585,911.64 0.35 1,453.04 3_MWD+IFR2+MS+Sag (2) 4,178.11 32.99 75.74 3,764.63 471.16 1,433.073,708.12 6,006,367.49 585,962.53 1.68 1,505.53 3_MWD+IFR2+MS+Sag (2) 4,267.29 32.62 75.98 3,839.59 482.97 1,479.923,783.08 6,006,379.82 586,009.24 0.44 1,553.84 3_MWD+IFR2+MS+Sag (2) 4,368.17 31.79 76.90 3,924.95 495.58 1,532.193,868.44 6,006,393.02 586,061.35 0.96 1,607.60 3_MWD+IFR2+MS+Sag (2) 4,461.75 32.57 76.47 4,004.15 507.06 1,580.683,947.64 6,006,405.05 586,109.71 0.87 1,657.42 3_MWD+IFR2+MS+Sag (2) 4,556.56 33.60 75.78 4,083.59 519.47 1,630.934,027.08 6,006,418.03 586,159.81 1.16 1,709.17 3_MWD+IFR2+MS+Sag (2) 4,651.12 33.10 76.12 4,162.57 532.09 1,681.364,106.06 6,006,431.22 586,210.09 0.56 1,761.16 3_MWD+IFR2+MS+Sag (2) 4/30/2020 4:47:43PM COMPASS 5000.15 Build 91E Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt K Pad Halliburton Definitive Survey Report Well: Wellbore: MPU K-44 MPU K-44B Survey Calculation Method:Minimum Curvature MPU K-44B Actual RKB @ 56.51usft Design:MPU K-44B Database:NORTH US + CANADA MD Reference:MPU K-44B Actual RKB @ 56.51usft North Reference: Well MPU K-44 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 4,745.65 33.54 76.51 4,241.57 544.38 1,731.814,185.06 6,006,444.08 586,260.39 0.52 1,813.08 3_MWD+IFR2+MS+Sag (2) 4,839.64 34.23 76.88 4,319.59 556.43 1,782.804,263.08 6,006,456.71 586,311.24 0.77 1,865.46 3_MWD+IFR2+MS+Sag (2) 4,934.14 34.35 77.85 4,397.67 568.08 1,834.754,341.16 6,006,468.94 586,363.05 0.59 1,918.67 3_MWD+IFR2+MS+Sag (2) 5,028.26 33.76 76.44 4,475.65 579.80 1,886.134,419.14 6,006,481.24 586,414.29 1.05 1,971.35 3_MWD+IFR2+MS+Sag (2) 5,121.90 34.34 76.97 4,553.23 591.85 1,937.164,496.72 6,006,493.87 586,465.17 0.70 2,023.77 3_MWD+IFR2+MS+Sag (2) 5,213.04 32.72 76.12 4,629.20 603.56 1,986.124,572.69 6,006,506.13 586,513.99 1.85 2,074.10 3_MWD+IFR2+MS+Sag (2) 5,310.79 32.24 76.10 4,711.66 616.16 2,037.084,655.15 6,006,519.31 586,564.80 0.49 2,126.59 3_MWD+IFR2+MS+Sag (2) 5,405.64 33.16 75.79 4,791.48 628.61 2,086.784,734.97 6,006,532.32 586,614.36 0.99 2,177.82 3_MWD+IFR2+MS+Sag (2) 5,431.00 33.14 75.72 4,812.71 632.02 2,100.234,756.20 6,006,535.88 586,627.76 0.17 2,191.69 3_MWD (3) 5,453.20 34.06 76.78 4,831.20 634.94 2,112.164,774.69 6,006,538.93 586,639.66 4.91 2,203.98 3_MWD (3) 5,513.95 34.19 79.70 4,881.50 641.88 2,145.524,824.99 6,006,546.25 586,672.93 2.70 2,238.01 3_MWD (3) 5,577.79 34.19 82.77 4,934.31 647.35 2,180.964,877.80 6,006,552.12 586,708.31 2.70 2,273.69 3_MWD (3) 5,640.39 33.27 85.77 4,986.37 650.83 2,215.544,929.86 6,006,555.99 586,742.84 3.04 2,308.02 3_MWD+IFR2+MS+Sag (4) 5,703.71 30.52 83.36 5,040.13 653.97 2,248.844,983.62 6,006,559.51 586,776.10 4.79 2,341.04 3_MWD+IFR2+MS+Sag (4) 5,766.59 27.56 80.42 5,095.10 658.24 2,279.055,038.59 6,006,564.12 586,806.26 5.22 2,371.35 3_MWD (5) 5,831.47 24.31 76.68 5,153.44 663.81 2,306.855,096.93 6,006,570.01 586,833.99 5.61 2,399.67 3_MWD+IFR2+MS+Sag (6) 5,894.79 23.42 77.14 5,211.35 669.62 2,331.805,154.84 6,006,576.09 586,858.88 1.44 2,425.28 3_MWD+IFR2+MS+Sag (6) 5,957.82 23.31 77.29 5,269.21 675.15 2,356.185,212.70 6,006,581.90 586,883.19 0.20 2,450.26 3_MWD+IFR2+MS+Sag (6) 6,022.48 23.93 80.33 5,328.46 680.16 2,381.595,271.95 6,006,587.21 586,908.53 2.11 2,476.11 3_MWD+IFR2+MS+Sag (6) 6,085.10 24.23 82.58 5,385.63 683.96 2,406.855,329.12 6,006,591.28 586,933.75 1.54 2,501.52 3_MWD+IFR2+MS+Sag (6) 6,148.38 24.32 80.60 5,443.31 687.76 2,432.585,386.80 6,006,595.38 586,959.43 1.29 2,527.38 3_MWD+IFR2+MS+Sag (6) 6,212.18 24.10 79.66 5,501.50 692.25 2,458.365,444.99 6,006,600.16 586,985.15 0.70 2,553.45 3_MWD+IFR2+MS+Sag (6) 6,275.71 23.93 79.16 5,559.53 697.00 2,483.775,503.02 6,006,605.19 587,010.51 0.42 2,579.25 3_MWD+IFR2+MS+Sag (6) 6,339.39 23.78 79.15 5,617.77 701.84 2,509.075,561.26 6,006,610.32 587,035.75 0.24 2,604.94 3_MWD+IFR2+MS+Sag (6) 6,402.37 23.90 80.41 5,675.38 706.36 2,534.125,618.87 6,006,615.12 587,060.74 0.83 2,630.32 3_MWD+IFR2+MS+Sag (6) 6,466.22 24.10 80.48 5,733.71 710.67 2,559.735,677.20 6,006,619.72 587,086.30 0.32 2,656.19 3_MWD+IFR2+MS+Sag (6) 6,530.16 24.04 79.78 5,792.09 715.14 2,585.425,735.58 6,006,624.48 587,111.94 0.46 2,682.18 3_MWD+IFR2+MS+Sag (6) 6,593.40 24.12 79.42 5,849.83 719.80 2,610.805,793.32 6,006,629.43 587,137.26 0.26 2,707.92 3_MWD+IFR2+MS+Sag (6) 6,657.31 23.85 78.84 5,908.22 724.70 2,636.315,851.71 6,006,634.62 587,162.71 0.56 2,733.84 3_MWD+IFR2+MS+Sag (6) 6,719.78 23.68 78.36 5,965.39 729.67 2,660.995,908.88 6,006,639.87 587,187.33 0.41 2,758.98 3_MWD+IFR2+MS+Sag (6) 6,783.53 22.97 77.96 6,023.93 734.85 2,685.695,967.42 6,006,645.33 587,211.97 1.14 2,784.19 3_MWD+IFR2+MS+Sag (6) 6,847.73 23.09 78.56 6,083.01 739.96 2,710.286,026.50 6,006,650.71 587,236.50 0.41 2,809.28 3_MWD+IFR2+MS+Sag (6) 6,911.05 24.24 80.20 6,141.01 744.63 2,735.266,084.50 6,006,655.67 587,261.42 2.09 2,834.63 3_MWD+IFR2+MS+Sag (6) 6,975.03 23.74 79.75 6,199.46 749.16 2,760.886,142.95 6,006,660.49 587,286.98 0.83 2,860.56 3_MWD+IFR2+MS+Sag (6) 7,038.01 23.34 80.21 6,257.20 753.54 2,785.656,200.69 6,006,665.15 587,311.70 0.70 2,885.63 3_MWD+IFR2+MS+Sag (6) 7,101.72 23.46 79.94 6,315.67 757.90 2,810.576,259.16 6,006,669.79 587,336.57 0.25 2,910.85 3_MWD+IFR2+MS+Sag (6) 7,162.89 21.66 80.46 6,372.16 761.90 2,833.696,315.65 6,006,674.05 587,359.64 2.96 2,934.24 3_MWD+IFR2+MS+Sag (6) 7,228.44 20.56 78.79 6,433.31 766.14 2,856.926,376.80 6,006,678.55 587,382.81 1.91 2,957.78 3_MWD+IFR2+MS+Sag (6) 7,292.55 20.66 75.96 6,493.32 771.07 2,878.936,436.81 6,006,683.73 587,404.77 1.56 2,980.32 3_MWD+IFR2+MS+Sag (6) 7,356.00 20.64 72.77 6,552.69 777.10 2,900.476,496.18 6,006,690.01 587,426.24 1.77 3,002.69 3_MWD+IFR2+MS+Sag (6) 4/30/2020 4:47:43PM COMPASS 5000.15 Build 91E Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt K Pad Halliburton Definitive Survey Report Well: Wellbore: MPU K-44 MPU K-44B Survey Calculation Method:Minimum Curvature MPU K-44B Actual RKB @ 56.51usft Design:MPU K-44B Database:NORTH US + CANADA MD Reference:MPU K-44B Actual RKB @ 56.51usft North Reference: Well MPU K-44 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 7,417.44 21.33 70.87 6,610.06 783.97 2,921.376,553.55 6,006,697.11 587,447.06 1.58 3,024.65 3_MWD+IFR2+MS+Sag (6) 7,483.36 19.71 82.31 6,671.82 789.39 2,943.736,615.31 6,006,702.78 587,469.34 6.55 3,047.64 3_MWD+IFR2+MS+Sag (6) 7,546.77 19.43 84.73 6,731.57 791.79 2,964.826,675.06 6,006,705.42 587,490.41 1.35 3,068.67 3_MWD+IFR2+MS+Sag (6) 7,610.42 20.11 81.82 6,791.46 794.32 2,986.206,734.95 6,006,708.19 587,511.75 1.88 3,089.99 3_MWD+IFR2+MS+Sag (6) 7,674.04 20.64 79.92 6,851.10 797.84 3,008.066,794.59 6,006,711.96 587,533.58 1.33 3,112.04 3_MWD+IFR2+MS+Sag (6) 7,737.58 20.65 79.26 6,910.56 801.89 3,030.106,854.05 6,006,716.25 587,555.56 0.37 3,134.38 3_MWD+IFR2+MS+Sag (6) 7,801.24 20.34 79.76 6,970.20 805.94 3,052.016,913.69 6,006,720.56 587,577.43 0.56 3,156.61 3_MWD+IFR2+MS+Sag (6) 7,865.09 20.13 80.38 7,030.10 809.75 3,073.776,973.59 6,006,724.61 587,599.13 0.47 3,178.62 3_MWD+IFR2+MS+Sag (6) 7,896.72 20.52 81.25 7,059.77 811.51 3,084.617,003.26 6,006,726.49 587,609.96 1.56 3,189.56 3_MWD+IFR2+MS+Sag (6) 7,954.08 22.52 85.30 7,113.13 813.94 3,105.507,056.62 6,006,729.16 587,630.82 4.34 3,210.39 3_MWD+IFR2+MS+Sag (6) 7,983.00 22.52 85.30 7,139.84 814.84 3,116.547,083.33 6,006,730.19 587,641.84 0.00 3,221.30 PROJECTED to TD Approved By:Checked By:Date: 4/30/2020 4:47:43PM COMPASS 5000.15 Build 91E Page 5 Chelsea Wright Digitally signed by Chelsea Wright Date: 2020.04.30 13:52:04 -08'00'Benjamin Hand Digitally signed by Benjamin Hand Date: 2020.04.30 15:04:24 -08'00' TD Shoe Depth: PBTD: Jts. 2 196 197 Yes X No X Yes No 100 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes X No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg)Rate (bpm):Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: Yes X No Casing Rotated? Yes X No Reciprocated?X Yes No % Returns during job Cement returns to surface? Yes X No Spacer returns?Yes X No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: Casing (Or Liner) Detail Shoe 7 5/8 2626 Rotate Csg Recip Csg Ft. Min.PPG105 Shoe @ 7973 FC @ Top of Liner7,889.00 Floats Held 26 45 0 45 LSND CASING RECORD County State AK Supv.S Barber/ O Amend Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.MP K-44B Date Run 27-Apr-20 Setting Depths Component Size Wt.Grade THD Make Length Bottom Top TXP BTC Innovex 2.01 7,983.69 7,981.68 Csg Wt. On Hook:135,000 Type Float Collar:Conventional No. Hrs to Run:18 10.5 6 100 460FIRST STAGE11Tuned Spacer 40 285/282.36 285 2 Bump press Calc Bump Plug? 23:30 4/27/2020 7,035 7,973.007,983.00 CEMENTING REPORT Csg Wt. On Slips:100,000 LSND 15.8 45 Type of Shoe:Ported Casing Crew:Weatherford www.wellez.net WellEz Information Management LLC ver_04818br 2 ea 7" solid body centralizer on Shoe Jnt, Slick Jnt & FC Jnt 6 total. 1 ea for 19 jnts depth 7,075' MD 7" Csg 7 26.0 L-80 TXP BTC Tenaris 112.80 7,981.68 7,900.88 FC 7 5/8 TXP BTC Innovex 1.28 7,900.88 7,899.60 7" Csg 7 26.0 L-80 TXP BTC Tenaris 7,810.74 7,899.60 88.86 7" Csg Pup 7 26.0 L-80 TXP BTC Tenaris 21.61 88.86 67.25 7" Csg 7 26.0 L-80 TXP BTC Tenaris 39.53 67.25 27.72 7" Pup 7 26.0 L-80 TXP BTC Tenaris 2.20 27.73 25.52 Hanger 10 3/4 1.20 25.52 24.32 RKB 7 24.32 Intermediate Blend 208 1.21 3.75 CBL ran (TOC at 6900 ft) Good bond below 7150' md gls NOTE: Cement bond across Kup C interval looks poor but likely cement is impacted by the permeability of the reservoir. Drilled hard cement in the shoe track. gls 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 $33/,&$7,21)25681'5<$33529$/6 $$& )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO Digitally signed by Chad Helgeson DN: cn=Chad Helgeson, ou=Users Date: 2020.04.02 12:09:39 -05'00' Chad Helgeson By Samantha Carlisle at 9:17 am, Apr 02, 2020 320-147 DLB 04/02/20 (final well report) *3500 psi BOP test gls 4/2/20 10-407 *CBL required in 7" casing X X TCP DSR-4/2/2020 4/6/2020 dts 4/2/2020 JLC 4/6/2020 Kuparuk Producer Well: MPU K-44B Date: 03/26/2020 Well Name: MPU K-44B API Number: 50-029-23567-02-00 Current Status: Suspended Pad: MP K-Pad Estimated Start Date: April 8th, 2020 Rig: Innovation Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts PTD and P&A sundry #: 220-027 & 320-113 First Call Engineer: Ian Toomey (907) 777-8434 (O) (907) 909-3987 (M) Second Call Engineer: David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number: 2011326C Job Type: TCP & ESP completion Current Bottom Hole Pressure: Not perforated Maximum Predicted BHP: 3,137 psi at 7130’ TVD MPSP: 2,454 psi (0.10 psi/ft gas gradient) Brief Well Summary: The parent well, K-44 was drilled in 2016 and worked over in May 2019. In September 2019, the well was sidetracked as K-44A with the intent of drilling a lateral in the Kuparuk C-sand. The 7” casing was top set in the Kalubik. Two attempts were made to drill the 6-1/8” lateral, however due to hole conditions the well was plugged back in the 7”. The 7” was pressure tested to 1500 psi for 30 min, and operations were suspended. Hydrocarbon bearing zones were never penetrated. K-44A will be officially abandoned by the Innovation rig in April 2020 (sundry #320-113) then the well will be sidetrack to create K-44B (PTD 220-027). Objective: Complete the K-44B sidetrack by perforating the Kuparuk C-sand formation with TCP the run ESP in the upper completion. Procedural Note: This work will be performed by the Innovation as a continuation drilling of MPU K-44B. These steps will replace Section 14 & 15 of the approved PTD #220-027. Completion Procedure: 1. RU E-line. PU and MU GR/CCL tool string. RIH, tag TOC/PBTD and POOH logging GR/CCL to surface (use open hole MWD log for correlation). 2. PU, MU and RIH with CBL. Log from TOC/PBTD across the Kuparuk interval and determine the TOC (estimated TOC at ~6,500’ MD). RD E-line and put on standby for correlation. a. A CIBP may be set just above the TOC in the shoe track depending on the depth of the lowest perforation. 3. PU and MU 4-5/8”, 5 SPF TCP gun assembly (gun length will be determined by Geo after drilling the reservoir, C-sand estimated thickness is 68’). a. Depending on actual gun length, the perforation might be conveyed on E-line with full pressure gear. 4. TIH with the TCP and lightly tag TOC/PBTD. Space out to a good working height for E-line. 5. RU E-line. PU, MU and RIH with GR/CCL. Correlate the guns on depth. Confirm correlation with OE and Geo. 6. POOH and RD E-line. 7. PU and space out to place the guns on depth. 8. Close the annular or UPR. Drop the activation ball and allow the ball to gravitate to seat. Pressure up on the DP to 2,500 psi to fire the guns. ) 8.46 ppg EMW -forward CBL to AOGCC via email. (and proposed perf interval) - Packer waiver based on BHP < 8.55 ppf EMW ( per CO 390A then Kuparuk Producer Well: MPU K-44B Date: 03/26/2020 9. Check for pressure under the annular or UPR and bleed to 0 psi if needed. Open the annular or UPR and observe the well for flow. 10. Circulate bottoms up. 11. Tag bottom of well to determine if TCP debris is blocking perforations 12. A cleanout run may be needed before running upper completion. 13. Observe the well for flow to ensure it is static or on a slight vac. 14. POOH laying down DP and the spent TCP gun assembly. 15. RU to run 2-7/8” ESP completion. Pull the wear ring. 16. 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. 17. RIH with the following ESP completion equipment installing cross coupling clamps on every connection for the first 15 then every other after that: a. Centralizer b. Motor Gauge c. ESP motor d. Lower tandem seal e. Upper tandem seal f. Intake g. Pump h. Discharge Head, i. 1 joint, 2-7/8”, 6.5#, L-80, EUE 8rd j. Nipple, 2.313” XN Profile with 2.205” no-go, 10’ handling pups above and below. k. 1 joint, 2-7/8”, 6.5#, L-80, EUE 8rd l. GLM, 2-7/8” x 1” with DV install, 10’ handling pups above and below. 18. Continue to RIH with the ESP completion on 2-7/8” tubing as per tally installing cross coupling clamps on every connection for the first 15 then every other after that. Check the electric conductivity of the ESP cable every 1,500’. 19. At ~200’ MD run 2-7/8” x 1” GLM with 0.25” OV installed and 10’ handling pups above/below. 20. 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. 21. Land tubing with extreme care to minimize damaging the ESP penetrator, pigtail and alignment pin. Note PU and SO weights on tally along with band/clamp summary. 22. RILDS and LD landing joint. 23. Install TWC and ND BOP. 24. NU the tubing head adapter and PT the tubing hanger void to 500/5,000 psi. 25. NU the tree and PT the tree to 250/5000 psi. 26. Install gauges on the tree and secure the cellar. 27. Release and RDMO Innovation Rig. 28. Turn the well over to operations via handover form. Kuparuk Producer Well: MPU K-44B Date: 03/26/2020 Attachments: 1. Proposed Schematic 2. Blank MOC Form _____________________________________________________________________________________ Created By: TDF 3/24/2020 PROPOSED Milne Point Unit Well: MPU K-44B Last Completed: Future PTD: TBD JEWELRY DETAIL No.Top MD ItemID 1 TBD STA#1 2-7/8” x 1” GLM w/ 0.25” DPOV 2.441” 2 TBD STA#2 2-7/8” x 1” GLM, w/Dummy GLV 2.441” 3 TBD 2-7/8” XN Nipple - MIN ID 2.205” 2.205” 4 TBD Bolt on Discharge Head - 5 TBD Ported Discharge Head - 6 TBD Pump 3:- 7 TBD Pump 2:- 8 TBD Pump 1:- 9 TBD Gas Separator: - 10 TBD Upper Tandem Seal: 11 TBD Lower Tandem Seal: 12 TBD Motor: 13 TBD Sensor/ Centralizer: TD = 7,980 (MD) / TD = 7,139’(TVD) 20” Ori g. KB Elev.: 55.8’/ GL Elev.: 29.3’ 7”77 10-3/4” PBTD = 7,969’ (MD) / PBTD = 7,130’(TVD) ES Cementer @ 1,616’ 1 2 3 4 & 5 6, 7 & 8 9 10 & 11 12 13 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20"Conductor78.6 /A-53 /Weld -Surface 80' 10-3/4"Surface 45.5 /L-80 / BTC 9.794 Surface ±5,597’ 7"Intermediate 26 / L-80 / TXP 6.059 Surface ±,980’ TUBING DETAIL 2-7/8”Tubing 6.5 / L-80 / EUE 8rd 2.347 Surface ±7,400’ WELL INCLINATION DETAIL 7” Window @ ±5,540’ MD GENERAL WELL INFO API: 50-029-23567-02-00 TREE & WELLHEAD Tree Seaboard 3-1/8”, 5K Wellhead Seaboard SCU 14B-27 Changes to APD Nov 2012 Hilcorp Alaska, LLC Changes to Approved Permit to Drill Date: Subject: Changes to Approved 10-403 Sundry for MP K-44B File #:MP K-44B Completion Program Any modifications to MP K-44B Drilling & Completion Program will be documented and approved below. Changes to an approved APD will be communicated to the BLM and AOGCC. Sec Page Date Procedure Change Approved By Approved By Approval: Chad Helgeson 4/1/2020 Operations Manager Date Prepared: Ian Toomey 4/1/2020 Operations Engineer Engineer Date THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a c g c c. a l a s k a. g o v Re: Milne Point Field, Kuparuk River Oil Pool, MPU K -44B Hilcorp Alaska, LLC Permit to Drill Number: 220-027 Surface Location: 3744' FSL, 2020' FEL, SEC. 3, T12N, RI IE, UM, AK Bottomhole Location: 725' FNL, 1096' FWL, SEC. 2, T12N, RI IE, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to redrill the above referenced development 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, OV5� Daniel T. Seamount, Jr. Commissioner r� DATED this _day of March, 2020. RECEIVED STATE OF ALASKA MAR 11 2020 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL '%OGGG 20 AAC 25.005 1a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas Drill [I i❑ Stratigraphic Test 11Development -Oil Q Redrill 91 Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ 2. Operator Name: Hilcorp Alaska, LLC Service - WAG Service - Disp Service - Winj ❑ Single Zone Service - Supply ❑ Multiple Zone ❑ 5. Bond: Blanket❑Q Single Well ❑ Bond No. 022224484 1 c. Specify if well is proposed for: Coalbed Gas C1 Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 11- Well Name and Number: MPU K -44B 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 6. Proposed Depth: MD: 7,980' TVD: 7,139' 12. Field/i(s): Milne Point Field Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 3744' FSL, 2020' FEL, Set 3, T121 R11 E. UM, AK Top of Productive Horizon: 736'1 1033' FWL, Sec 2, T12N, R11 E, UM, AK Total Depth: 725' FNL, 1096' FWL, Sec 2, T12N, R11 E. UM, AK 7. Property Designation: ADL375133, ADL375132 8. DNR Approval Number, NIA 13. Approximate Spud Date: 4/2/2020 9. Acres in Property: 5120 14. Distance to Nearest Property: 725' to nearest unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 584535 y- 6005880 Zone -4 10. KB Elevation above MSL (ft): 55.8' GL / BF Elevation above MSL (ft): 29,3' 15. Distance to Nearest Well Open to Same Pool: 3200' to MPU K-1 BA 16. Deviated wells: Kickoff depth: 5540 feet Maximum Hole Angle: 34 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 110 Surface: 2927 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) 9-718" 7" 26# L-80 TXP-SR 7,980' Surface Surface 7,980' 7,139' 500 ft3 19, PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): 8,078' 6,949' 7,161' Effect. Depth MD (ft): Effeci. Depth TVD (ft): Junk (measured): 7,161' 6,388' 7,698' (TDF) Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 20" N/A 80' 80' Surface 5,597' 10-314" 580 sx 5,597' 4,952' Intermediate 7,725' 7" 176 sx 7,725' 6,787' Production Liner Perforation Depth MD (ft): NIA Perforation Depth TVD (ft): NIA Hydraulic Fracture planned? Yes ❑ No ❑Q 20. Attachments: Property Plat ❑Q BOP Sketch Diverter Sketch Drilling Program Seabed Report Time v. Depth Plot Drilling Fluid Program Shallow Hazard Analysis 20 AAG 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Joe Engel Authorized Name: Monty Myers Contact Email: ert el hllcor .Com Authorized Title: Drilling anager Contact Phone: 777-8395 Few- A-3-" `"Y ---I 17;A5 Authorized Signature: Date: �`ZQ Commission Use Only Permit to Drill LZ Number: Q — C)7,7150- API Number: ii — Q Permit —00 Approval Date: See cover letter for other requirements. Conditions of approval : If box is checked, /well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: 50� PSi 4, P e3 Samples req'd: Yes ❑ NOR Mud log req'd: Yes❑ HzS measures: Yes Wi Directional svy req'd: Yes [ No❑ - G %aL v `` C a ie r[�' k—�� • Spacing exception req'd: Yes ❑ i Inclination -only svy req' l: Yes[] Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BY 3 123 rZV Approved by: COMMISSIONER THE COMMISSION Date: 6 1 • ta f ppSubs i DuForplicate and Fora 10-401 Revised 512077 This permit is valid r 4 n rova! per 20 AAC 25.005(g} Attachments n Duplicate 3�7_ _/2o /� �,��Z:� cs-);t B 03%tz/-Aa Hilcorp Alaska, LLC Milne Point Unit (MPU) K -44B Sidetrack Drilling Program Version 1 March 5, 2020 U Ilileaq. Al.-ka, 1.1.1: 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 Current & Proposed Wellbore Schematic.................................................................................6 7.0 Drilling / Completion Summary................................................................................................9 8.0 Mandatory Regulatory Compliance / Notifications................................................................10 9.0 MIRU, K -44A Abandonment & Sidetrack Preparation.........................................................12 10.0 Mill 10-3/4" Window and Kick Off.........................................................................................14 11.0 Intermediate Hole Section Summary......................................................................................17 12.0 Drill 9-7/8" Intermediate Hole Section....................................................................................18 13.0 Run & Cement 7" Intermediate Casing.................................................................................. 22 13.0 Cleanout Run...........................................................................................................................27 14.0 TCP Guns.................................................................................................................................27 15.0 Run 3-1/2" ESP Completion....................................................................................................28 16.0 Innovation Rig BOP Schematic...............................................................................................30 17.0 Days vs Depth........................................................................................................................... 31 18.0 Formation Tops & Information............................................................................................... 32 19.0 Anticipated Drilling Hazards.................................................................................................. 33 20.0 Innovation Rig Layout.............................................................................................................34 21.0 FIT Procedure..........................................................................................................................35 22.0 Innovation Choke Manifold Schematic...................................................................................36 23.0 Casing Design Information...................................................................................................... 37 24.0 9-7/8" Hole Section MASP....................................................................................................... 38 25.0 Spider Plot (NAD 27) (Governmental Sections)...................................................................... 39 26.0 Surface Plat (As Built) (NAD 27)............................................................................................. 40 1.0 Well Summary Milne Point Unit K -44B Kuporuk Producer Drilling Procedure Well K -44B Pad Milne Point `K' Pad Planned Completion Type 7" Cemented Casing / 3-1/2" ESP Target Reservoir(s) Ku aruk C Planned Well TD, MD / TVD 7,979' MD / 7,139' TVD PBTD, MD / TVD ±7,969' MD / 7,130' TVD Surface Location Governmental 3744' FSL, 2020' FEL, Sec 3, T12N, RI IE, UM, AK Surface Location (NAD 27 — Zone 4) X=584535.02, Y=6005880.1 Top of Productive Horizon Governmental) 736' FNL, 1033' FWL, Sec 2, T12N, RI IE, UM, AK TPH Location AD 27 X= 587577.41, Y= 6006713.9 BHL (Governmental) 725' FNL, 1096' FWL, Sec 2, T12N, RI IE, UM, AK BHL (NAD 27) X=587640.1, Y=6006725 AFE Number AFE Pre -Drill 5 AFE Drilling Das 7 AFE Completion Das 4 AFE Pre -Drill Amount AFE Drilling Amount AFE Completion Amount AFE Facility Amount Maximum Anticipated Pressure (Surface) 2,927 psig Maximum Anticipated Pressure Downhole/Reservoir) 3,137 psig Work String 5" 19.5# NC50 KB Elevation above MSL: 26.5 + 29.3 ft = 55.8 ft AMSL GL Elevation above MSL: 29.3 ft AMSL BOP Equipment 13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams Page 2 H ffil— , .%1—k., a J: 2.0 Management of Change Information Milne Point Unit K -44B Kuparuk Producer Drilling Procedure 11 Hilcorp Alaska, LLC xilcorp Changes to Approved Permit to Drill Date: 3.10.2020 Subject: Changes to Approved Permit to Drill for MPU K -44B File #: MPU K -44B Drilling and Completion Program Any modifications to MPU K -44B Drilling & Completion Program will be documented and approved below. Changes to an approved APD will be approved in advance to the AQGCC. Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 H afl—p AI.A., LIA 3.0 Tubular Program: Milne Point Unit K -44B Kuparuk Producer Drilling Procedure All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). 4.0 Drill Pipe Information: Page 4 / OD (in) ID (in) Drift Corin' ` rg"- " Burst Collapse section in OD in(#/ft) (psi) (psi)k-1 Cond 20" 78.6 A-53 Weld 13.5" 10-3/4" 9.95 9.794 11.75 45.5 L-80 BTC 5210 2470 1040 9-7/8" 7" 6.276 6.151 7.656 26 L-80 YD 7240 5410 604 T) All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). 4.0 Drill Pipe Information: Page 4 / n Ililrwp:\lu.ku, L1,1: 5.0 Internal Reporting Requirements Milne Point Unit K -44B Kuparuk 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 Detailed Daily Plan Forwards • Distributed to ienp_el@hilcop.com and mmyers =.hilcop.com 5.3 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcorp.com, mm, ers e hilcorp.com. iengel@hilcorp.com and cdin2er@Mlcorp.com 5.4 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. 5.5 EHS Incident Reporting • Health and safety: Notify EHS field coordinator. • Environmental: Drilling Environmental coordinator • Notify Drilling Manager & Drilling Engineer • Submit Hilcorp Incident report to contacts above within 24 hrs 5.6 Casing Tally • Send final "As -Run" Casing tally to mmyers@hilcoro com, ieng_el@,hilcorp.com and cdinper@hilc=.com 5.7 Casing and Cmt report • Send casing and cement report for each string of casing to mm, ers e hilcorp.com, iengelnhilcorp.com and cdinger@hilc=.com 5.8 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmvers@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 ienggl@hilcorp.com Completion Engineer Ian Toomey 907.777.8434 907.903.3987 itoomev@hilcorp.com Geologist Radu Girbacea 907.777.8324 907.230.9490 rgirbacea(@hilcorp.com Reservoir Engineer Almas Aitkulov 907.777.8475 979.739.3133 aaitkulov(a)hilcorp.com Drlg Environmental Coord Keegan Fleming 907.777.8477 907.350.9439 kfleming@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 caiones(@hilcori).com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorp.com Page 5 H Ililmry Mask, 1.11: 6.0 Current & Proposed Wellbore Schematic Milne Point Unit K -44B Kuparuk Producer Drilling Procedure HLi Current Schematic Milne Paint Unit Well zA1PU K -44A Last Completed- Future Pi D: 2i9-116 Ot MEW: 6fj%I!W:2RY .. __ TREE & WELLHEAD L � Tree imtaara }UB". �( M We----- D0.51NG DETAL lp site rfm WIGraWmnn DNtlD Top I Btm m'CaMuctor T8b h53/WNa - Swhae 1 EO' 103)4" Surtete 45.5 1-00 BTC1 9T s:Mam I 5.W, T' IntermMiah Xf L-BOl TMP 1 6059 1 SUMary 1 7.725' TUBING DETAIL 3 UFT Tebm 9.3 LAO'QJCBrd I ISurt 3 _-------------------------- _-------------- _________.__....-_ ...__._. JEWELRY DETAIL toI T NO Rem 10 11 7.554• Cmvil Bcaiier OPEN HOlE J CENlENr DETAIL and WY 13U3" LW M343 LRb/LeaallmyOlSflailtCmt to surt,ce 9-T?B• 3860(s m:iae r' 35 WELL INCLINATION DETAIL Y WiMnx @T,6^A'-T,82Y MQ ._________________--------- __ _____...__.___-__-___ GENERAL WFJ11NFO ' AN�50024]356T-0ISO T0=8,Ifif(N )/ W0=4GITYDf ISTD=TJSN IBq! vsm=43rBlnq Page 6 Milne Point Unit ` K-448 Kuparuk Producer Ililmrp ,llw'ka, IA,1: � '� Lj L- N Drilling Procedure Frt *EL -c e.r/GLEW.:293 f 27 i 3 E'ur V f' 1 �3'JgSiS510 I ] 7g 55th %Q Proposed Schematic jd 1(liiii"✓ t9a m !2 Point un r Well: tAPU K -44A Last Completed: NIA PTD: 219-116 -------------------------------------- I -------------------------------------------------- TREE & WELLHEAD ee I Seaboard 3-1 ,5K wffm ea -41116 (g %/11 U NJ JEWELRY DETAIL 3 ------------------------------------------------------------ OPEN HOLE / CEMENT DETAIL mi Nxv su ce 6nU•'+-.'�/��__• 13-Sj2" C�3e2 hbls (IEaC(126 F.tls(Ttil)Cm[tCSulfXe j° 5 ` sae 3a Imsde7 13 TD= 9,077 (MD) / TD= e,94e'VM PSID=7,Sst' (MD)/PffrD-6-M" WELL INCLINATION DETAIL 7' V4i KR tY @ 7,W9' -7,M' MD -------------------------------------------------------------- i GENERALWELLINFO M1:50-0 23567 -MTD H 11 ii .p.\lush., LLA: Milne Point Unit K -44B Kuporuk Producer Drilling Procedure MilneII Unit Well MPI K -&4E Proposed Schematic La`,LCompleted. Future ., PTD: TED 04 MEeti 550/QE .:M -v TD=7;0jKVI jTD=7,1WITVCI P5TD=7,983' (hOj 1VD=7..13DIT1ol Page 8 _ ________________________________-.--_-________________T TRFE & WELWEAD Top NO Rem ID Tree I Seaboard 3 -VI". SK STMIC4NG12-JJI". 1" wJ a.25"DPDV 2.041" 2 Wellhead STM Cy 2-7JB"x 1"5bkou ^" w1D..V GLV 2.41" 3 TBD 3-172"%N Nipoe-MN O2.265' CASING oETaL 4 i� 2altun Disoiv elf m - 5 TBD P. m D.i p Hr d Size Type nVG2deJCAnn Drift to TDP 7 TIO F�2: PMPSWNt5%D93FLCV4711S B 20'C Mixw 72 61 A 5 Y wN m - Sarf=® 9 TBD ID3,14" S.H= 45.51 L-801 ii. M4 Sarts 5,597' LAJ T 1 MtermMmte 2b1L-B9JT2P 16.059 1 SM.. 7.580' •1 TUBING DETAIL Mttpr: •., 13 1 3-12' 1 T.bmv I g.3'L20'NC2rd 1 1867 1 Surf 1 =7.100' _, .------------- ..--------------------------- ____________________________ - JEWEIRY DETAIL W. Top NO Rem ID 1 TBD STMIC4NG12-JJI". 1" wJ a.25"DPDV 2.041" 2 TBD STM Cy 2-7JB"x 1"5bkou ^" w1D..V GLV 2.41" 3 TBD 3-172"%N Nipoe-MN O2.265' 2.705" 4 TBD 2altun Disoiv elf m - 5 TBD P. m D.i p Hr d 6 TBO Pu=pa: PMPS3VK1-1XD93RCR47115 7 TIO F�2: PMPSWNt5%D93FLCV4711S B TBD Pump\: PMPS3vKv;xD2DGINPSIIIIN6 9 TBD Ga Separator:SMG5NWMM1 CFEI t0 TO 0 wTmtlemS.LGS83DBIId5B1ABPTSI 11 TBD bxv Tandem Seol G58308116S8JAB PPSA 12 To Mttpr: 13 1 TBD ISenxpr/[er4rafaer: it WELL INCLINATION DETAIL Y W.M. 811;5.547 MD __________________________________________________________It GENERAL WELLINFO • API: SQ@423567-02-00 H Iilrwp Al.kq IAC 7.0 Drilling / Completion Summary MPU K -44B is to be a sidetracked producer with the Kuparuk C as the target. Milne Point Unit K -44B Kuparuk Producer Drilling Procedure The parent well, K-44 was drilled in 2016 and worked over in May 2019. In September 2019, the well was sidetracked as K -44A with the intent of drilling a lateral in the Kup C. 7" casing was top set in the Kalubik. Two attempts were made to drill the 6-1/8" lateral, however due to hole conditions the well was plugged back in the 7", 7" was pressure tested to 1500 psi for 30 min, and the well entered operational shutdown. Hydrocarbon bearing zones were never penetrated. K -44A will be officially abandoned by the Innovation rig in April 2020 (submitted on a separate sundry). a V 1 Current wellbore schematic is attached. 1 The Innovation Rig will be used to complete the abandonment of K -44A, sidetrack and complete the K -44B wellbore. Drilling operations are expected to commence approximately April 2, 2020. The existing 10-3/4" surface casing will be used and a pressure test conducted prior to drilling the sidetrack The directional plan for this sidetrack will have one hole section. A 9-7/8" hole will drilled to the base of the Kup C at 7,979' MD / 7,139' TVD, 7" casing will then be ran and cemented. The well completed with a 3-1/2" ESP completion. All waste & mud generated during drilling operations will be hauled to the Milne Point G&I facility on `B" pad A separate sundry notice has been submitted to cover reservoir abandonment and wellbore preparation for the sidetrack. The aforementioned sundry will cover the following operations: # ps A 32L n 1. MIRU the Innovation Rig. Test BOPE u 2. Circulate out freeze protect, pull 3-1/2" killstring 3. Set CIBP at -5570' MD, PT, cut and pull 7" casing 4. RIH set whipstock for sidetrack, PT 10-3/4" Casing t/ 2500 psi General sequence of operations pertaining to this approved drilling procedure: 1. Mill window in 10-3/4" 2. RIH & Kick off well with motor T 3. MU 9-7/8"BHA and drill t/ TD, 7,979' MD 4. Run 7" and cement 5. Run 3-1/2" ESP Completion 6. N/D BOP, N/U tree, RDMO Reservoir Evaluation Plan Intermediate: No Mud Logging, LWD: GR & Res Page 9 Milne Point Unit K -44B Kuparuk Producer Drilling Procedure 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with all AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2) week intervals during the drilling and completion of K -44B. Ensure to provide AOGCC 24 Ins notice prior to testing BOPS. • The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 10/10 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BDP 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". • Ensure both AOGCC approved drilling permit is posted on the rig floor and in Co Man office. Variance Requests: • There are no variance requests at this time. l Page 10 K nikwp AL• ku, 11A: Summary of BOP Equipment and Test Requirements Milne Point Unit K -44B Kuparuk Producer Drilling Procedure Hole Section Equipment Test Pressure(psi) • 13-5/8" x 5M Control Technology Inc Annular BOP • 13-5/8" x 5M Control Technology Inc Double Gate Initial Test: 250/3500 o Blind ram in bottom cavity (Annular 2500 psi) • Mud cross w/ 3" x 5M side outlets 9-7/8" 13-5/8" x 5M Control Technology Single ram • 3-1/8" x 5M Choke Line Subsequent Tests: • 3.1/8" x 5M Kill line 250/3500 • 3-1/8" x 5M Choke manifold (Annular 2500 psi) • 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 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. Additional requirements may be stipulated on 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: guy.schwartz@alaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: Victoria.loepp@a alaska.gov Mel Rixse / Petroleum Engineer / (0): 907-793-1231 / (C): 907-907-223-3605 / Email: melvin.rixse(_@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors @ alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/ Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 11 Milne Point Unit K -44B Kuporuk Producer Drilling Procedure 9.0 MIRU, K -44A Abandonment & Sidetrack Preparation Note: All following operations will be under the sundry to abandon K -44A 9.1 MIRU Innovation Rig 9.2 Rig Orientation on K-44: *Not to Scale 1I I I o o I 0 I � I I I o I I � I II z i 5. s• K-44 u. Ie • z; . n 35 S0 33• .n 9• 3P a3• K -PAD A separate sundry 9.3 K -44A abandonment will be completed with Innovation. p y was submitted to the AOGCC (Sundry #XXX -XXX). 'tt" 32v_ir3 y1- ?-/"/Z- In September 2019, K-44 sidetracked as K -44A with the intent of drilling a lateral in the Kup C. 7" casing was top set in the Kalubik. Two attempts were made to drill the 6-1/8" lateral, however due to hole conditions the well was plugged back in the 7", 7" was then pressure tested to 1500 psi for 30 min, and the well entered operational shutdown. Hydrocarbon bearing zones were never penetrated. 9.4 Sundry operations is below: 1. MIRU the Innovation Rig. Test BOPE (3-1/2" & 5" Test Joints) 2. Circulate out freeze protect, pull 3-1/2" killstring 3. RIH & Cut 7" casing at -- 5560' MD, pull and lay down cut 7" casing Page 12 H Illboq, Alaska, LIX Milne Point Unit K -44B Kuparuk Producer Drilling Procedure a. Company Man & Baker Rep to review cut depth for whipstock placement to ensure window is not across 10-3/4" casing connection 4. RIH set 10-3/4" CIBP. Test 10-3/4" Casing t/ 2700 psi for 30 min. Ensure to record pressure and plot on FIT graph. AOGCC regulation is 50% of burst = 5210 / 2 = 2605 psi, test pressure is 2700 psi. 5. This will conclude operations covered by the sundry. 9.5 Abandonment and sidetrack preparations under the sundry are to be performed on a 1 week BOPE test cycle. Once operations are covered by PTD, the BOPE test cycle is 2 weeks, from the most recent test. • Ensure 5" test joint was used on previous test Page 13 Milne Point Unit K -44B Kuporuk Producer Drilling Procedure 10.0 Mill 10-3/4" Window and Kick Off Note: All following operations will be covered under by the PTD for K -44B 10.1 Whipstock Set Depth Information: • Planned TOW:5,540'MD 0 • Deepest hydrocarbon bearing sand in 10-3/4" hole section: Schrader Bluff Ne, • 5,272' MD, 4,617' MD, 4,680' TVD • —268' between planned TOW and base of deepest hydrocarbon bearing sand 10.1 MU 10-3/4" Mill Assembly as per Baker tally 10.2 If needed, perform cleanout run with mill BHA • This may not be necessary as a 10-3/4" CIBP was previous ran to set depth • RIH tag top of CIBP at — 5555' MD • Displace well to 9.5 ppg LSND milling fluid • Confirm depth with casing tally and tag depth that placement of whipstock and window will not be across a collar • CBU & circ min 1 hi-visc sweep to remove any debris caused by the cleanout run. Anything left in the wellbore could affect setting of the whipstock & anchor • Obtain PU/SO/ROT and document. This will be used to set up shear pins, bolt and compare after whipstock is set • POOH, endure no changes to DP tally 10.3 PU remaining parts of milling/whipstock BHA • Make up HWDP, storing magnets, and float sub • Ensure magnets are in trough, under shakers and flow area to capture metal shavings circulated 10.4 Install MWD and UBHO, and orient. Rack back mill assembly. • Ensure a dedicated MWD is available for orientation of the whipstock 10.5 Pick up whipstock as per Baker rep, using whipstock handling system. • Inspect whipstock and anchor and shear screws 10.6 Attach mills to whipstock with shear bolt. • Ensure shear bolt is undamaged and correct shear value 10.7 Verify offset between MWD and whipstock tray, witnessed by Drilling Supervisor, MWD/DD and Baker Rep. Document and record offset in well file 10.8 Slowly run in the hole as per Baker Rep. Run extremely slow through the BOP & wear bushing to prevent damaging the shear bo It. Page 14 N I lik'rp Manka, I.IA: Milne Point Unit K -44B Kuparuk Producer Drilling Procedure 10.9 Run in hole at 1 % to 2 minutes per stand. Ensure work string is stationary prior to setting the slips, and removed slowly as well. These precautions are to avoid weakening the shear bolt and prematurely setting the anchor. 10.10 Shallow Test MWD 10.11 Stop atleast 30-45' above tagged CIBP depth, obtain survey with MWD. Consider having gyro personnel on standby in event MWD surveys are not reliable. 10.12 Milling fluid will be 9.5 ppg LSND 10.13 With the bottom of the Whipstock 30 — 45' above the cement base, work torque out of string, measure and record P/U and S/O weights. Obtain good survey to orient Whipstock face. 10.14 Orient Whipstock to desired direction by turning DP in 1/4 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° ROHS. 10.15 Whipstock Orientation Diagram: 45R Desired orientation of the Whipstock face is 15R to 45R, target is 30 ROHS Confirm with Baker Rep Hole Angle at window interval (5,555 MD) is —33 deg, target Azimuth 75-80. 10.16 Once Whipstock is in desired orientation, slack off and tag anchor to set Bottom Trip Anchor. 10.17 Set down 15-20K on anchor (based upon number of shear pins) to trip, P/U 5-7K maximum overpull to verify anchor is set. The window mill can then be sheared off by slacking off weight on the Whipstock shear bolt. (35k shear value, verify after whipstock is picked up). 10.18 P/U 5-10' above top of Whipstock. 10.19 CBU and confirm 9.5 ppg MW in/out • Ensure Mud properties are sufficient for transporting metal cuttings • Visc: 40-60, YP: 18-20 Page 15 I/ H llih. 'p Alaska, LLC Milne Point Unit K -44B Kuparuk Producer Drilling Procedure 10.20 Record P/U, S/O weights, and free rotation. Slack off to top of Whipstock and with light weight and low torque. Mill window as per Baker Rep. Utilize 4 ditch magnets on the surface to catch metal cuttings. Pump high visc sweeps as necessary. 10.21 If possible, install catch trays in shaker underflow chute to help catch metal cuttings. 10.22 Clean catch trays and ditch magnets frequently while milling window 10.23 Mill window until the uppermost mill has passed across the entire tray. Dress and polish window as needed. 10.24 With upper mill at the end of the tray, this will drill — 20' of new hole. 10.25 After window is milled and before POOH, shut down pumps and work milling assembly through window watching for drag. Dress and polish window as needed. After reaming, shut off pumps and rotary (if hole conditions allow) and pass through window checking for drag. 10.26 Circulate Bottoms Up until even MW in,{out and hole is clean of metal shavings. Reduce mud properties for drilling. (1734 g K� 10.27 Pull back into 9- casing and perform FIT t/ 12.5 ppg EMW. Chart Test. 10.28 POOH & LD Milling BHA. Gauge Mills for wear. 10.29 If upper mill is under gauge, pickup second mill BHA with same assembly (to ensure same cut pattern) and perform dress off run to ensure window is correct diameter. 10.30 PU stack washer and wash BOPE stack. Function all rams to clear any potential milling debris. Page 16 K W1.1, Alawka. LLC 11.0 Intermediate Hole Section Summary Milne Point Unit K-448 Kuparuk Producer Drilling Procedure Depths of Interest MD/ND Directional BHA Drilling Notes Casing &Cement 10/3/4" Window K-44Bwp1 Bit ✓ MW Casing 5,540/ 4,4903 9-7/8" HDBS MM65 9.5 ppg LSND 7" 26# TXP to Surface NO BITSLEEVE Inc 300' Above Drop to 20' at 7,230 HRZ, add black Colville Top Hold to TD RSS products Centralizers 5,732/ 5,5069 GeoPi lot 7600 7" x 8-1/2" Centeks Azi IncreaseMWt/ 1/jt to TOC Turn to 80a by 5,755 10.5 at TD Hold to TD MWD/LWD HRZ Gamma / Res / PWD 7480/ 6742 J MPD Have Gyro On Standby if Mag. KuparukC Interference is seen Drillpipe InstallRCD300' 7,911/7075 outside window 5" NC50 Above HRZ Cement TD CBHP Target: 1 Stage 11.3 PPG EMW 7979/ 7139 Drilling Parameters: 4 89 bbl 15.8ppg Class G Flow Rate:600gpm @Top HRZ (Super CBL & Microbond) 120+ rpm TOOH: Offset TOC Req: 500' Above Kup swab to 11.3 C ppg EMW Note: Managed Pressure Drilling will be used on the intermediate hole section. Prior to drilling, verify all rig crew member are familiar with operation. If needed, install RCD bearing element and perform practice connections to familiarize crews with its operations. Page 17 K nil,—p Al.k., LLC 12.0 Drill 9-7/8" Int 'a a ole Section Milne Point Unit K -44B Kuparuk Producer Drilling Procedure 12.1 Pick up 9-7/8" Motor BHA • Motor BHA will be used ensure kick off and drill enough full gauge OH for the RSS BHA • Motor and MWD 12.2 RIH with Motor BHA to 3 stands above whipstock 12.3 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 12.4 Orient motor and continue lowering assembly through window with no flow or rotation �/ • Ensure BHA and DP tally are verified ,C • Circulating can cause the rotating bit to catch the whipstock and result in rotating it or becoming mechanically stuck 12.5 Once through the window and tagged up on bottom, drill ahead to confirm kick off, build to tangent angle and ensure clearance for RSS BHA. • Drill — 150' to 200' of new hole • Confirm kick off with MWD Surveys, have gyro ready if magnetic interference is present • Ensure enough new hole is drilled to bury RSS BHA 12.6 Orient motor and pull through the window with no flow or rotary 12.7 CBU xl-2, OWFF 12.8 POOH LD BHA 12.9 MU 9-7/8" 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. • RSS to have at bit Gamma for calling TD • Ensure MWD is R/U and operational. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. • Drill pipe will be 5" 19.5# S-135, NC50 • Run x2 Solid Plunger Floats for MPD Page 18 ff 11ilrorp Alaska, 1.1.1: 12.13 Intermediate hole section mud program summary: Milne Point Unit K -44B Kuparuk Producer Drilling Procedure • Density: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. • 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: Ensure 6 rpm is >9.875 (hole diameter) for sufficient hole cleaning, YP as low as possible • Inhibition: 3% KCl will be used for handling clay cuttings. Watch MBT levels, dilute as necessary to maintain. Increase KCI % if needed • Run the centrifuge continuously while drilling the production hole, this will help with solids removal and minimize sand content and LGS to maintain fluid properties and quality of the mud system. • PVT will be used throughout the drilling phase. Remote monitoring stations will be available at the driller's console, Co Man office, & Toolpusher office. System Type: 9.5 - 10.8 ppg 3% KCI Inhibited LSND WBM Properties: Section Density Plastic Yield Point LGS MBT HPHT pH Viscosity Intermediate 9.5-10.5 15-25 12.14 RIH w/ 9-7/8" directional assembly on 5" DP from the derrick. • Shallow test MWD to confirm tool communication 12.15 Once on bottom, ensure wellbore has 9.5ppg 3% KCL LSND 12.16 Drill 9-7/8" Hole to - 300' MD above HRZ, 7,180' MD • RPM: 120+ • Flow Rate: 600 GPM (200 ft/min Annular Velocity) Page 19 J Milne Point Unit K -44B Kuparuk Producer Drilling Procedure Ensure shaker screens are set up to handle this flow rate, shakers running slightly wet to maximize solids removal efficiency. Check for holes on screens on every connection. • WOB as needed • Pump tandem high vise high weight / low vise low weight sweeps to aid in hole cleaning • Take MWD surveys every stand • Monitor hole cleaning indicators: PUW, pump pressure and ECD. Make wiper trips or backream connections if necessary 12,17 CBU x2, perform short trip to window if necessary • RPM: 120+ • Flow Rate: 600 GPM (200 ft/min Annular Velocity) • Alternate reciprocation depths to avoid troughing/ledging 12.18 Increase black productions for Shale stability. MW will remain at 9.5 ppg unless otherwise noted with drilling ECDs • If needed, increase MW with pre sheared spike fluid, in .3 ppg per circulation, this is to ensure no barite sag or uneven density 12.19 Install MPD Element Ensure rig crew is familiar with MPD connection operations Ensure max pressure relief settings are set correction to ensure no wellbore damage is created 12.20 Drill 9-7/8" hole section to section TD per Geologist and Drilling Engineer in Kuparuk C sand (To mitigate drilling in to wet Kup B7 sand), 7,979' MD l RPM: 120+ ��o Ff • Flow Rate: 600 GPM (200 ft/min Annular Velocity) • WOB as needed • Target ECD: 11.3 ppg EMW (Range +/- 5%) • Utilize MPD to maintain CBHP (constant bottom hole pressure) at the HRZ on connections, following Annular pressure ramp schedule • This will reduce the pumps on/ pumps off pressure cycles on shales • Slow ramp pumps on/offon each connection • Smooth connections are more important that connection time • Monitor losses on connetions, reduce annular pressure if needed. • Pump tandem high vise high weight / low vise low weight sweeps to aid in hole cleaning, monitor ECD effect of sweeps • Take MWD surveys every stand • Monitor hole cleaning indicators: PUW, pump pressure and ECD. Backream connections if 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. Page 20 I/ H Ilikorp Alwkv, LIX Milne Point Unit K-449 Kuporuk Producer Drilling Procedure Ensure good communication with Geologist to call TD, it is a orimary objective of this well that we do not drill in to the wet B7 sand. 12.21 At TD; CBU at full rate and RPM least 4-5 times at maximum circulation and rotation. Alternate reciprocation depths while CBU to reduce risk of troughing and dropping inclination. 12.22 Perform wiper trip t/ above the HRZ, offsetting swab with MPD maintaining 11.3 CBHP. 12.23 RIH to bottom • Slow string speed to limit surge on shales 12.24 Weight up at TD for shale stability, ±10.5 ppg, maintaining CHBP of 11.3 nog EMW • Perform weight up with pre -sheared spike fluid, weighting up with .3 ppg increments 12.25 Observe well for flow 12.26 Spot Casing Running Pill t/ above HRZ 12ppb black product, graphite, 4% lube 12.27 TOOH with the drilling assembly t/ 10-3/4" Shoe, Offsetting Swab with MPD • Follow tripping schedule, matching string speed and annular pressure • Rack back DP while TOOH, Do not lay down drill pipe. This is to minimize open hole time before casing is on bottom. 12.28 Ifbackreaming is necessary: • Circulate at max rate while maintaining drilling ECD's (flow will be less due to 10.5 ppg MW) • Perform CBHP connections • 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 and circ at least a b/u once at the shoe. 12.29 CBU x2 at 10-3/4" Window 12.30 Continue TOOH to HWDP/ BHA, offsetting swab with MPD 12.31 Pull RCD Bearing element 12.32 LD BHA Page 21 H llik,q, Alaska, LLA: Milne Point Unit K -44B Kuparuk Producer Drilling Procedure 13.0 Run & Cement 7" Intermediate Casin 13.1 Change pipe rams to 7" solid body and testsame L/, -� ? �'14'i y �-- 3-7,o z� 13.2 Dummy run 7" Hanger and check packoffto verify fitment PSA% 13.3 R/U 7" casing running equipment. • Ensure 7" TXP (BTC Compatible) x NC50 crossover is on rig floor and M/U to FOSV. • Ensure all casing has been drifted prior to running. • Be sure to count the total # of joints 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. • R/U CRT w/ cement swivel. 13.4 M/U & threadlock shoe track assy consisting of: • (1) Float shoe joint w/ float shoe bucked on. Install (2) solid body centralizers over a stop ring at 10' from each end. • (1) Baker locked joint. Install (1) solid body centralizer mid joint over a stop ring • (]) Float collar joint w/ float collar bucked on pin end. Install(]) solid body centralizer mid tube over a stop ring. • Ensure proper operation of float shoe and float collar. 13.5 Run 7" 26# L-80 TXP casing. • Fill casing while running using CRT or fill up line. • Use "BOL 2000" thread compound. Dope pin end only w/ paint brush. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Install centralizers on every ioint to planned TOC, 6,575' NW • Install 3 centralizers across 10-3/4" window 13.5 RIH following casing running schedule, keeping surge below max drilling ECD EMW • Circulate BU at 10-3/4" shoe & — 300' above HRZ (7,180' MD) to ensure mud is conditioned prior to RIH Model circulation rates, do not exceed 11.3 one EMW ECD, for both losses at the Colville and shale stability Do not circulate in the middle of the HRZ, can increase possibility ofpackoffs Past 7" casing runs through HRZ have had success with very slow running speeds, do not stack weight or push casing down. Let the hole dictate running speeds. 13.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. Slow in and out of slips. 13.7 Lower string to depth. MU hanger and landing joint. Casing will be set on depth with hanger. Page 22 H H &'.P Al. k.. I.11C Milne Point Unit K -44B Kuparuk Producer Drilling Procedure 13.8 Circulation and condition mud for cement job through CRT. Reduce YP to < 20 to help ensure success of cement job. Slowly stage up pump rates, if possible, in 15 min increments .25-.5 bpm at a time. 13.9 After circulating, set string at setting depth. 7" Casing Torque Values Connection MUT (Min) MUT (Opt) MUT (Max) Max Operating ft -lb ft -lb ft -lb Torque, ft -lb TXP 13,280 14,750 16,230 20,000 Page 23 H I lilrorp klu.ke. 1.1.1: Milne Point Unit K -44B Kuparuk Producer Drilling Procedure TXP® BTC —, 05x09,•2018 Outside Diameter 7.000 in. Min. Wall 87.5% GEOB6EM Thickness (') Grade LAO WIN,Type Connection OD TOM in Co:{Jing Lergm ID.200 tr I 6264 n Wall Thickness 0.362 in. Connec8on OD REGULAR REGULAR PERFORMANCE Option COUPLING PIPE BODY 604000x1070 7240AOD psi Bndy. Red 1st Band: Red Grade LBO Type 11' Drift AN Standard 1st Band: Brown 2nd Sand. bs Edema! Pie>wre Capa:iy 5410.000 si 2nd Band: - Brown i MAKE4OPTORQUE3 Type Casing 3rd Band - 3rd Bando - Minimum 13280 Mbs Cptm..m 1475Mbe Naw i_ 162306-1xs eh Bsnd. - I PIPE B( r--:. - Operating Toque 20006 h-Ihs Yed Tcr 23400 h -lbs Notes GEOMETRY This connection is fully interchangeable with: Narnnal 00 7.000 m Nnmlra! 11k:ght 26 best Oih &151 n Normal D 6276 in a.11 1,rass 0.362;,, Plain End Weigh! 25.69[sE OD Tdemn-e API PERFORMANCE Bxy Yield StrengN 604 xt0001b=_ Imemai Veld 7240 ;zi Bh1Y5 60000 psi Ccll-rinse 5410 psi Page 24 CIONNECTION DATA GEOB6EM — - Connection OD TOM in Co:{Jing Lergm ID.200 tr Ccnneceon ID 6264 n Make-up Lr-- 4.579 in Threads per rn 5 Ccnne-_6on OD Oprsn REGULAR PERFORMANCE Tenon E6cie^, 100.0% JON Yeld Stre.90, 604000x1070 7240AOD psi lbs Corrpressien EFie.-cy 100% Cwnpresso,. Street& 604.001 Max.Arcwable Serairg 52 '100h bs Edema! Pie>wre Capa:iy 5410.000 si i MAKE4OPTORQUE3 ___ Minimum 13280 Mbs Cptm..m 1475Mbe Naw i_ 162306-1xs i OPERATK7N LMR TORQUES - Operating Toque 20006 h-Ihs Yed Tcr 23400 h -lbs Notes This connection is fully interchangeable with: TXPE BTC - 7 in. - 23129 J 32/35/38 Ibs4t Page 24 ff 164orp AI.A., LIX Milne Point Unit K -44B Kuparuk Producer Drilling Procedure 13.10 Hold a pre -job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. • How to handle cement returns at surface, regardless of how unlikely it • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cement operation. • Extra hands in the pits to strap during the cement jab to identify any losses • Document efficiency of all possible displacement pumps prior to cement job. 13.11 7" cement job will be a single stage, single slurry job. 13.12 RU Cement lines to cement swivel on CRT. Plugs will be dropped manually. 13.13 Pump 5 bbls fresh water. Pressure test surface cement lines to 4000 psi. o S'r- 5° 13.14 Pump remaining 40 bbls 10.5 ppg tuned spacer. L e To 13.15 Drop bottom plug, Mix and pump slurry per below calculations, 30% OH excess volume Section: Calculation: Vol lVol (ft3) 9.875' OH x 7" Casing: (7,979'— 6,575') x 0.0471 bpfx 1.3 = 86 482.8 7" Shoe Track: 80' x.038 bpf= 3 16.8 Total Volume: 89 500 Slurry Information 4-131sIt 13.16 After pumping cement, drop top plug and displace cement with drilling mud. Use rig pumps for displacement. Ensure to have a good baseline measurement for pump displacement ahead of time. Displacement talcs: • Once cement turns the corner, slow displacement rates to 2 bpm. This is to ensure we do not exceed ECD limits and have circumferential cement • 7,899' x.038 bpf= 300.2 bbls Page 25 Cement Slurry System ExpandaCem Density 15.8 lb/gal Yield 1.16 ft3/sk Mixed Water 4.972 gal/sk 4-131sIt 13.16 After pumping cement, drop top plug and displace cement with drilling mud. Use rig pumps for displacement. Ensure to have a good baseline measurement for pump displacement ahead of time. Displacement talcs: • Once cement turns the corner, slow displacement rates to 2 bpm. This is to ensure we do not exceed ECD limits and have circumferential cement • 7,899' x.038 bpf= 300.2 bbls Page 25 H npcorp M.A., U,C Milne Point Unit K -44B Kuparuk Producer Drilling Procedure 13.17 Reciprocate casing during cement job. If at anytime pipe movement gets sticky, land casing hanger. 13.18 Monitor returns closely while displacing cement. Ensure pits are strapped every 10 bbls of displacement and communicated with Co Rep. If losses are seen, let DSM know and possibly reduce pump rate. 13.19 Do not over displace by more than %z shoe track volume. Total volume in shoe track is 3.5 bbls 13.20 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. • If this is the case, monitor the pressure on the casing and do not let it exceed 500 psi over the final pump pressure. Ensure to report the following on wellez. • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration • Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping ofjob. Final circulating pressure • Note if pre flush or cement returns at surface & volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job and 13.20 R/D cementing equipment. Flush out wellhead with FW. 13.21 Test void to 250/4000 psi for 10 min. 13.22 Freeze protect 10-3/4" x 7" Annulus 13.23 Lay down 5" DP Page 26 H Ilikorp Alv k.. LII: 13.0 Cleanout Run Milne Point Unit K -44B Kuparuk Producer Drilling Procedure 13.1 Ensure rams have been tested on 4" & 3-1/2" test joint prior to cleanout run 13.2 PU and MU 6-1/8" milltooth bit cleanout assembly. 13.3 TIH to the baffle adapter. Note the depth of TOC tagged in morning report. �5`�.,� 00 13.4 RU and PT the 7" casing tn.r.vv ps for 30 minutes charted. IT C">y 13.5 Drill out the shoe track to that will accommodate the TCP guns. That depth will be determined byte E and Geo. ._ 1 13.6 Circulate the well clean. Displace the well with a hi -vis pill followed by clean brine.) 13.7 TOOH with cleanout assembly 14.0 TCP Guns `/ CAL - 14.1 RU E -line. PU and MU GR/CCL tool string. RIH, tag TOC/PBTD and POOH logging GR/CCL (use open hole MWD log for correlation). 14.2 PU and MU 4-5/8", 5 SPF TCP gun assembly (gun length will be determined by Geo after drilling the reservoir). 14.3 TIH with the TCP and lightly tag TOC/PBTD. Space out to a good working height for E -line. 14.4 RU E -line. PU, MU and RIH with GR/CCL. Correlate the guns on depth. Confirm correlation with OE and Geo. 14.5 POOH and RD E -line. 14.6 PU and space out to place the guns on depth. 14.7 Close the annular or UPR. Drop the activation ball and allow the ball to gravitate to seat. Pressure up on the DP to 2,500 psi to fire the guns. 14.8 Check for pressure under the annular or UPR and bleed to 0 psi if needed. Open the annular or UPR and observe the well for flow. 14.9 Circulate bottoms up. 14.10 Tag bottom of well to determine if TCP debris is blocking perforations L A cleanout run may be needed before running upper completion. 14.11 Observe the well for flow to ensure it is static or on a slight vac. 14.12 POOH laying down DP and the spent TCP gun assembly. Page 27 H Hit., ANA., U.I. 15.0 Run 3-1/2" ESP Completion 15.1 RU spooler with ESP power cable. Milne Point Unit K -44B Kuporuk Producer Drilling Procedure 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 3-1/2" ESP Completion as per tally 15.5 MU ESP assembly and RIH to setting depth. • Ensure appropriate well control crossovers on rig floor and ready. • Monitor displacement from wellbore while RIH. • Check the conductivity of electric cable every 2,000' and every new splice while running in hole. a QUA' I ubing Specification Shoot TOOL 3-1/219.30#1 L80, EUE 8RD, R2 00: 3.500 In Corm mtbn: 3UY EUE BRD t0: 1992 In coupling OD. 4.508 in Might 9.30 barn . —_ . Tool Joint ID. .Drift'. _ _ 2.992 In Grade: l80 2.997 In Tube Well: 0.254 in Tubag length: R2 Thread Compound Friction FacW, 1.0 Maximum MUT: 4,000 ft4bs RBW: 0203. In Optimal MUT _— — 3,200 ft4b$ Tube Tamale 163,178 8m Minimum MUT: 2,400 INba Tube Collapse: 7,399 psi Tube tnlemal Bmsl'. 9,289 pat OrsplacemenlEmunate: 0.00339 bbWft Capacity Estimate: 0.00870 bbWfl 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. Page 28 H Ilik.p Al.kn, LLC Milne Point Unit K -44B Kuparuk Producer Drilling Procedure 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 N/U 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 3-1/2" x 7" 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. 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. 15.16 RDMO Innovation Rig Page 29 16.0 Innovation Rig BOP Schematic 13.518' 5M C Annular BOF -13.518' 5M C Technology[ 3-118' Kill 13-518' 5M C Technology: Page 30 Milne Point Unit K -44B Kuparuk Producer Drilling Procedure 2-7/8" x 5-1/2" VBR Blind Rams �-- 3-118' Choke line 2-7/8" x 5-1/2" VBR !'x 5M x5M 17.0 Days vs Depth 0 1000 2000 3000 = 4000 L d N a 5000 d J N T 6000 7000 8000 9000 10000 0 2 4 6 8 Days Milne Point Unit K -44B Kuporuk Producer Drilling Procedure MPU K -44B Kuparuk C Slant Producer Days vs Depth Page 31 10 12 14 16 n Iliho", I.Lr. 18.0 Formation Tops & Information Milne Point Unit K -44B Kuparuk Producer Drilling Procedure MPU K -44B Formations (w ol) MD (ft) TVDss (ft) ND (ft) Formation Pressure (psi) EMW (PPE) Colville 5732 5014 5069 2230.36 8.46 HRZ 7480 6615 6670 2934.8 8.46 Kalubik 7557 6687 6742 2966.48 8.46 KalII Gamma Marker(KGM) 7617 6744 6799 2991.56 8.46 Kup D 7736 6856 6911 3040.84 8.46 Kup C 7911 7020 7075 3113 8.46 Ku p C Base 7970 7075 7130 3137.2 8.46 4400- Na:aada HRZ: Highly Radloactive2one. Very daMILUUMrtype POSSIBLE SHALLOW GAS +1- 4500 4lOD' (,,uLC_d. 6560' are HR2 (CASCADE#1) possible at top of HRL E.n o-Sarma Schrader Bluff Sands: Conunued layered alubik (SBR Gradually diminishing ROP. coarsening upward sands as above except more 4000- D"I 1-100' Shale condensed. Possible ny6tocarhon bear Ing. 4800' Top of aetre "Cap Fack". SANDS Seabee C SANDS: Sandstone, shales upward. GIt bearing LCUtarget 5,000 7000' LCU: Lauver Cretaceous Unconfarmity -14a0'B (LZ) Seabee (Colville) Interval: Predominantly SANDS below LCU- Fine to medium grain sands becoming more Interbeh dded Oilstone Intl clay with bead of sand. shaend sharer with depth. Hytltaaarbon bearing. Pinches out to occasional seams of coal. The Seabee is generally the north and sickens to the soulheeaL Top sand, 6-7, m 12" uneventful unll reaching the HRZ_ Expect good Penetration H-100' rates (.1-100 Rh). _r, 1W,lIt- ! 6350- Top HRZ HRZ: Highly Radloactive2one. Very daMILUUMrtype .f-100 shale. organic, good source rack. Tuft (bentonite) zone 6560' are HR2 possible at top of HRL N-100' Kalubik Shale: Market MK19 good log marker. alubik Gradually diminishing ROP. 6750' V. Kuparuk Interval: 1-100' Shale The V' Shale is the top Kuparuk sediment and la known 6960' -ol a! -fog' f aetre "Cap Fack". SANDS C SANDS: Sandstone, shales upward. GIt bearing LCUtarget 7000' LCU: Lauver Cretaceous Unconfarmity -14a0'B (LZ) a Sands: Also known as the laminated Tana, begins SANDS below LCU- Fine to medium grain sands becoming more sharer with depth. Hytltaaarbon bearing. Pinches out to the north and sickens to the soulheeaL Top sand, 6-7, m 12" target Use controlled drilling rate In Kuparuk for LWO. H-100' A A: Fine grain sandstone. Potential hydrocarbon AND bearing. Secondary Kupamk target at K+sad 7300' .1 -loo' _. ' I I Miluveach shales: oredominanW alter shale. Page 32 N C f 9.7 Dim I 10.1110.2 1113139 9.9 dog E&I RESERVVOO R RESEIR --PRESSURE-=- fill PRESSVRE-=- till Kuparuk reservoir ure of 1600 psi dQ ad (9.9 ppg). Average mature +167 deg F at tb Currant 2004 reservoir uses are 7.6 to 4,0 ppg VA Eater Kuparuk / cautiously. ALTHOUGH NO WELLS ON K -PAD HAVE STUCK PIPE IN THIS INTERVAL- THIS NTERVALTHIS IS A STUCK PIPE INTERVAL OR S. E F and easing seat for normal Kuparuk Completion. K Ililooq, M.A., IAA: 19.0 Anticipated Drilling Hazards Milne Point Unit K -44B Kuporuk Producer Drilling Procedure 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 with AV of 200 ft/min. Lost Circulation: Lost circulation has been seen in the Colville formation at EMW exceeding — 12.0 ppg. Monitor ECDs during production section to ensure ECDs stay below 12.0. 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. Abnormal Pressures and Temperatures: Kuparuk reservoir pressure is predicted to be normal (.45 psi/ft TVD). The last penetration in this fault block, K- 44 (2016), confirms this. Wellbore Stability: This well will drill through historically trouble shales, HRZ & Kalubik. Maintain sufficient MW for stability and utilize MPD to maintain constant bottom hole pressure to mitigate on/off pressure cycles. Use MPD to offset swab effect while TOOK Follow tripping in hole schedule to manage surge pressures on shales. Anti -Collision: The only close approaches with this wellbore are with the abandoned sections of K-44 and K -44A. K-44APB 1 & P132 are open hole abandonments. Faulting: There are no known faults in either hole section. H2S: Treat every hole section as though it has the potential for 1-12S. No H2S events have been documented on drill wells on "K" pad. • The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. • The rig will have fully functioning automatic 1-12S detection equipment meeting the requirements of 20 AAC 25.066. • In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 33 20.0 Innovation Rig Layout Milne Point Unit K -44B Kuparuk Producer Drilling Procedure Page 34 N na..,.p Al.kn, u.c 21.0 FIT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: Milne Point Unit K -44B Kuparuk 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. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in I -minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre -determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre -determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 35 H 22.0 Innovation Choke Manifold Schematic Milne Point Unit K -44B Kuparuk Producer Drilling Procedure Page 36 ./ ff nil �,.j„wwm.. ia.c 23.0 Casing Design Information Calculation & Casing Design Factors nMilne Point Unit Hitcoxp DATE: 3.11.2020 WELL: MPU K44B DESIGN BY: Joe Engel n Criteria: Hole Size 9.875 Mud Density: 9.5 Hole Size Mud Density: Drilling Mode MASP(9.875"): 2927 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation ' 1, 2, 3 Max MW gradient external stress and the casing evacuated for the internal stress Milne Point Unit K -44B Kuparuk Producer Drilling Procedure CasinC Section 1 2 3 Cal cu latio n/Specification Casing OD 7" Top (MD) 0 Top (TVD) 0 Bottom (MD) 7,979 Bottom (TVD) 7,139 Length 7,979 Weight (ppl) 26 Grade L-80 Connection TXP Weight w/o Bouyancy Factor(Ibs) 207,454 Tension at Top of Section Obs) 207,454 Min strength Tension (1000 lbs) 604 Worst Case Safety Factor (Tension) 2.9 1 Collapse Pressure at bottom (Psi) 3,570 Collapse Resistance w/o tension (Psi) 5,410 Worst Case Safety Factor (Collapse) 1.52 MASP (psi) 2,927 Minimum Yield (psi) 7,240 Worst case safety factor (Burst) 2.47 Page 37 N Ililcorp Aln ku, LIX Milne Point Unit K -44B Kuparuk Producer Drilling Procedure 24.0 9-7/8" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 9-7/8" Intermediate Hole Section HIcor MPU K -44B Milne Point MD TVD Planned Top: 5540 4903 Planned TD: 7979 7139 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad KupC 7,037 3057 1 Oil 8.4 0.434 Offset Well Mud Densities Well MW ranee Too (TVD) Bottom (TVD) Date K-44 10.20 4,903 7,376 2016 L-43 9.3-9.8 439 6,745 2004 L-41 9.5-10.8 4,850 6,889 2018 L-55 9.5-10.5 4,563 6,890 2018 *MW for5hale Stability Assumptions: 1. Fracture gradient at shoe is estimated at 0.7 psi / ft based on field test data. 2. Maximum planned mud density for the 9.875" hole section is 10.5 ppg. 3. Calculations assume Kuparuk reservior contains 100% gas (worst case). 4. Calculations assume worst case event is complete evacuation of wellbore to gas. Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface: 103/4"Window 5540'MD/4903'TVD 4903 (ft) x 0.7(psi/ft)= 3432 3432 (psi) - [0.1(psi/ft)*4903(ft)]= 2942 psi Drilling Mode MASP MASP from pore pressure (wellbore completely evacuated togas) 7139(ft) x 0.51(psi/ft)= 3640 psi 3640(psi)-[0.1(psi/ft)*7139(ft)]= 2927 si Summary: 1. MASP while drilling 9-7/8" Intermediate hole isgoverned bythewellborecompleteyevacuatedtogasfrom the Kuparuk Reservior Page 38 25.0 Spider Plot (NAD 27) (Governmental Sections) Milne Point Unit K -44B Kuporuk Producer Drilling Procedure Legend e MPU K-448 SHL X MPU K-4411TPH t MPU K44B BHL - Other Surface Holes (SHL) Other BotNm Holes (BHL) - - Other Well Paths [:3Oil and Gas U.d Bwndery U013NU1E._.�. Pad Fmtprid , I PH `]IPC K44B BHL _ scc`vE r< MILNE+POINT UNIT \IPL: K-iaB SHL ' •�, oa 31 1 Se1.2 Sec.1 Sec _s Se; ADL375133 U012N011E• iZl SEC.'] SEC1L I Sec.11 Milne Point Unit MPK-44B Well 0 1.000 2,000 sao ow. xn.om Wool EEEEEEKzz== Feet Page 39 H IHI , 11.-k., LIA 26.0 Surface Plat (As Builti (NAD 27) Milne Point Unit K -44B Kuporuk Producer I Drilling Procedure I M� f TM PROJECT K-44 VICINITY MAP IT K -PAD RENAMED CONDUCTOR REVISION NOTE i MELL MP K-4 + AS -BUNT CNOUCTIAt Thothy Saffibat T,S S -BUILT A KISIL10200 y. Ii A9 -WILT ORAV%6 FOR CCTIO&TOR 111 ,-10 K.AMED COMLU=R IS AS NOLLOAS Ot 0 CONIC, NAME NEW COND NAME IIRIC(51ICQ4 - MP K-10 MP K-44 SURVEYOR'S CERTIFICATE I XCftw COT FrNAT I AM PROPERLY MEGISTEND �M) Ui NOTES 10 pi tAM S15NKnNG E, 1. STATE OF MAGA AMAT 1996 NS AS -BUILT KPi A SCTUi MADE By 2 IIF IWUD Bi Vi (13-21) SUPOMSiM AMU NAT ALL 3 Ai.ASKA SSE LAW COXFtDOMIES AA ZONE 4, AAASi MIMI MAD 27 (XfIFTEXT AS AMND ONO MARCDETAILS AMC H 24 1996. 4 Mi K -Pe SCIILE FACTO IS OM99012 Dr.IL7. SINN.L DAVID 'A Li MDi 'iOM' AHL V� Wi, c-1 SCALE A I'VIAWLS or BIT MPU OA`LM (MSL) p I "T'i "T' �.N 5MAS , M DUDE. QW I KI 75 1. C -I. - T E1EF%XTOi - I., LET.Ii 0' WAOID1 A, ASE000T55TEST I . ISO N. LOCATED WITHIN PROTRACTED SEC_ 3, 1, 12 N, R. 11 E.. UMAT MUERIO AN. &ASKA 'HELL A.S.P. PLANT GEODETIC IPOSITION Ii TIC CELLAR ETON ON NO COORDINATES COORDINATESIPOSIT.M(CIMS) 0 D.DD) BOX ELEV. OFFSETS K-44 7 259917'1 2R�3 31744* FS_ I<9319206' 2,020' TEL THikorp AlaskaNT K -PAD MILNE POI bell RENAMED CONDUCTOR WELL 9-44 Page 40 Y=6,005,8801] N 9,939.93 70'2833.570" Hilcorp Alaska, LLC Milne Point M Pt K Pad MPU K-44 MPU K -44B Plan: MPU K -44B wp01 Standard Proposal Report 10 March, 2020 HALLIBURTON Sperry Drilling Services SECTION DETAILS Sec MD Inc Azi 1 5540.00 33.16 75.60 2 556000 33.21 79.07 3 5580.00 33.18 79.03 4 5755.03 24.46 80.61 5 7081.54 24.46 80.61 6 7230.44 20.00 80.00 7 739oAPt 20.00 80.00 8 7894.13 20.00 80.00 9 7979.74 23.42 80.00 TVD +N/ -S 4903,89 646.94 4920.63 64934 4937.36 651.42 5090.57 666.47 6298.01 756.06 6435.81 765.51 6588.16 775.01 705947 804.93 7139.00 81043 +E/ -W 215&28 2168.96 2179.71 2282.65 2804.56 2860.08 2913.97 3083.63 3114.81 Oleg TFace VSect 0.00 0.00 2251 64 9.50 90.00 2262.58 0.18 -145.06 2273.51 5.00 175.69 2357.56 0.00 0.00 2904.57 3.00 -1T/ 31 2960.68 0.00 0.00 301523 0.00 0.00 318695 4.00 0.00 3218.52 Target Annotation KOP : Start Dir 9.5-11001: 5540' MD, 4903SWTVD: 90° RT Start Dir0.18°/109: 5560'MD, 4920.63T/D Start Dir5-/100:5580' MD, 4937.36TVD End Dir :575503' MD, 5090.57' TVD Start Dir 3-110D: 7081.54MD, 6298.017VD End Dir :7230.44' MD, 6435 81' TVD MPU K-0RD wP05 CP1 Stan Du 4°/100': 7894.13 MD, 70594TND Total Depth: 797974' MD, 7139'TVD ® MALLIBUQTON 6298.01'TVD SURVEY PROGRAM Date :2020.03-10700:00:00 Validated: Vas Version: ePa..r o.nu, Depth From Depth To Survey/Plan Tool 127.50 498.46 MPW941ntelp(MPK-44) 3_MWD IMerp Aa+Sag WELL DETAILS: MPU KJ 593.84 5540.00 MPK44 MWD+IFR2+MS+sag(1)(MPK-44) 3_MWD+IFR2+MS+Sag Ground Level: 2930 5540.00 5940.00 MPU K44B wp01(MPU K44B) 3MWD Azi+Sag +N/ -B +E/ -W Northing Easti, Latittude Longitude 5840.00 7979.74 _Inter, MPU K-0 Bwp01 (MPU K44B) 3 MWD+FR2+MS+Sag 0.00 0.00 0005880.17 58453502 70. 25' 33.575 N 149° 18'40.034 W REFERENCE INFORMATION CASING DETAILS project: Milne Point Co-oNinate (NSE) Reference: Well MPU Kot, True North Verticel (ND) Reference: MPV K44B Planned RKB @55 BOusB (Innovation) TVD TVDSS MD $ize Name M Pt K Pad Site: 4903.89 4648.09 5540.00 10-3/4 10 N r' TOW Measure) Depth Reference: MPU K -44B Planned RKB ®55.6ousn (Innovation) 7139.00 7083.20 7979.74 7 T' x 9 7/8" Well; MPU K-44 Calculation Method: MNimum Curvature MPU K -44B Hilcorp Alaska, LLC FORMATION TOP DETAILS Wellbore: Design: MPU K -44B wp01 TVDPath TVDssPath MDPaIh Formation Calculation Method: Minimum Curvature 506980 5014.00 5732,11 SB BASE Error System: ISCWSA 667a80 661500 7480.51 HRZ Scan Method: Closest Approach 3D 6742,80 61 7557,13 KLB Error Surface: Pedal Curve 6799.60 874000 7817,79 KLGM Warning Method: E. Ratio 6911 w 6856.00 7736.90 )075.00 702000 791154 KUP D KUP C 1125 1350 1575 1800 2025 KOP : Start Dir 9.5.1100' : 5540' MD, 4903.89'TVD : 90` RT TF Start Dir 0.18-/100': 5560' MD, 4920.637VD - _ _ - - - - - - - Start Dir 5-1100': 5580' MD, 4937.36 -TVD _ _ End Dir : 5755.03' MD, 5090.57' TVD 6500 650 6500 ,/ G 000 1 Top Of Cement r NN 1p00 1000 Start Dir 3-/100': 7081.54' MD, 6298.01'TVD U K-44RD wpO5 ClDt End Dir : 7230.44' MD, 6435.81' TVD 7" x 9 7/8" MPU K-448 wp01 TOF (387' LIH) TOF (12.22' Geopilot + Bit) oo_ p MPU KO4AP82 m --'__--8077 gOliB-7___ 8178 _ MPU K-44APB1 Start Dir 4'/100': 7894.13' MD, 7059.47'TVD Total Depth : 7979.74' MD, 7139' TVD MPK-44- 16370 2250 2475 2700 2925 3150 3375 3600 3825 4050 4275 Vertical Section at 75.42' (450 usft/in) IS 1,L FVV K-unPB2 6M9 7x9]? A@II KJAAP111 - NF(1i22'GydNa&Q r lL£(98]L01) FW KAia xy'll 103N"IOW � ' MFU K-0JRO x145 CP1 -- � $ Tap Of Cams TOW fIyIM1: ]9ry ]9'MD, ]139 NO $ N FifM '. 515503'M1m, 509J5TM3 Sm IAW $°ll[O:558]'MD, 49PM'IVO SW UrnIBY1gY SSMMn.i9206)TID KW:SM P✓95°/I%'. SSia h0,JAll.B9'IVp; W RFTF CASING DETA Project: Milne Point TVD mss MD Sim Nm Site: M Pt K Pad +90389 46480 SAa.W 10-34 Ia 314. TOW Well: MPU K-44 713900 7W3 20 79]9>4 7 ]^x979^ Wellbore: MPU K -44B Plan: MPU K -44B WPO NALLI®UFTON REFERENCE INFORM4TIIXJ Nanem lNrtl aN«a.�c WHI MPUBNrvuC a[a@llA9xn lmmrNml Mel (NU) Palennu. ® VMuuM w%nP PU Kaa�BPYmM Nrc!@ll.fYan llmarellenl WEIL CtTALLS: AffUKdd GrtuN level: i9.3a •N/Sa0 F •lp IstivWe �9 �IB'JO0Ww 00000 5W W 045080.I] 58!5]503 ]4°2a'33.SNN .0 2475 2550 2625 2M 2]]5 2650 08 300 3075 3150 3225 3300 3375 3450 3525 WM(-YBel1(+) (150 usWin) HALLIBURTON Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt K Pad Well: MPU K44 Wellbore: MPU K44B Design: MPU K -44B wp01 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well MPU K-44 TVD Reference: MPU K44B Planned RKB @ 55.80usft (Innovati MD Reference: MPU K44B Planned IRKS @ 55.80usft (Innovati North Reference: True Survey Calculation Method: Minimum Curvature project Milne Point, ACT, MILNE POINT flap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point dap Zone: Alaska Zone 04 Using geode0c scale factor Site M Pt K Pad, TR -12-11 Site Position: From: Map Position Uncertainty: Well MPU K-44 Well Position +NIS +El -W Position Uncertainty Wellbore MPU K -44B Northing: 5,994,744.31 usft Latitude: 70° 23'44.152 N Easting: 583,595.36usft Longitude: 149° 19'11.252 W 0.00 usft Slot Radius: 0" Grid Convergence: 0.64 ° Magnetics Model Name 0.00 usft Northing: 6,005,880.17 usft 0.00 usft Easting: 584,535.02 usft 0.00 usft Wellhead Elevation: 0.00 usfl Sample Date Declination (1) BGGM2019 3/10/2020 16.10 Design MPU K44B wp01 Dogleg Audit Notes: Turn Measured Version: Phase: PLAN Vertical Section: Depth From (TVD) +W -S Depth (usft) (usft) (1) 26.50 0.00 Plan Sections Dogleg Build Turn Measured +NIS +FJ -W Vertical TVD Depth Inclination Azimuth Depth System (usft) (1) (1) (usft) usft 5,540.00 33.16 75.60 4,903.89 4,848.09 5,560.00 33.21 79.07 4,920.63 4,864.83 5,580.00 33.18 79.03 4,937.36 4,881.56 5,755.03 24.46 80.61 5,090.57 5,034.77 7,081.54 24.46 80.61 6,298.01 6,242.21 7,230.44 20.00 80.00 6,435.81 6,380.01 7,390.44 20.00 80.00 6,586.16 6,530.36 7,894.13 20.00 80.00 7,059.47 7,003.67 7,979.74 23.42 80.00 7,139.00 7,083.20 Latitude: 70° 25' 33.570 N Longitude: 149° 18'40.034 W Ground Level: 29.30 usft Dip Angle PI Tie On Depth: +El -W (usft) 0.00 Field Strength (nT) 80.85 57,377.41862881 5,540.00 Direction (°I 75.42 3/102020 3:38:53PM Page 2 COMPASS 5000.15 Build 91E Dogleg Build Turn +NIS +FJ -W Rate Rate Rate Tool Face (usft) (usft) (°/100usft) ('/100usft) (*1100usft) V) 646.94 2,158.28 0.00 0.00 0.00 0.00 649.34 2,168.96 9.50 0.24 17.35 90.00 651.42 2,179.71 0.18 -0.15 -0.19 -145.06 666.47 2,262.65 5.00 -4.98 0.90 175.69 756.06 2,804.56 0.00 0.00 0.00 0.00 765.51 2,860.08 3.00 -3.00 -0.41 -177.31 775.01 2,913.97 0.00 0.00 0.00 0.00 804.93 3,083.63 0.00 0.00 0.00 0.00 810.43 3,114.81 4.00 4.00 0.00 0.00 3/102020 3:38:53PM Page 2 COMPASS 5000.15 Build 91E HALLIBURTON Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt K Pad Well: MPU K-44 Wellbore: MPU K -44B Design: MPU K -44B wp01 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well MPU K-44 ND Reference: MPU K -44B Planned RKB @ 55.80usft (Innovati MD Reference: MPU K -44B Planned RKB @ 55.80usft (Innovati North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +Nl-S +EI -W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -29.30 26.50 0.00 0.00 26.50 -29.30 0.00 0.00 6,005,880.17 584,535.02 0.00 0.00 127.50 0.33 35.07 127.50 71.70 0.24 0.17 6,005,880.41 584,535.18 0.33 0.22 217.75 0.14 35.07 217.75 161.95 0.54 0.38 6,005,880.72 584,535.39 0.21 0.50 314.49 0.14 35.07 314.49 258.69 0.73 0.52 6,005,880.91 584,535.53 0.00 0.68 402.90 0.09 35.07 402.90 347.10 0.88 0.62 6,005,881.06 584,535.63 0.06 0.82 498.46 0.40 35.07 498.46 442.66 1.21 0.85 6,005,881.39 584,535.86 0.32 1.13 593.84 0.41 35.07 593.83 538.03 1.77 1.24 6,005,881.95 584,536.24 0.01 1.64 687.81 0.33 59.69 687.80 632.00 2.18 1.67 6,005,882.37 584,536.66 0.19 2.16 781.91 3.51 62.00 781.84 726.04 3.67 4.44 6,005,883.89 584,539.42 3.38 5.22 873.49 3.72 59.90 873.24 817.44 6.47 9.49 6,005,886.75 584,544.44 0.27 10.81 970.74 6.44 60.18 970.09 914.29 10.77 16.95 6,005,891.13 584,551.85 2.80 19.12 1,064.85 7.19 59.23 1,063.54 1,007.74 16.41 26.59 6,005,896.87 584,561.42 0.81 29.87 1,159.10 9.92 54.29 1,156.73 1,100.93 24.16 38.25 6,005,904.76 584,572.99 3.00 43.11 1,253.51 13.85 51.79 1,249.10 1,193.30 35.90 53.74 6,005,916.68 584,588.35 4.20 61.05 1,346.39 14.07 47.45 1,339.24 1,283.44 50.42 70.80 6,005,931.38 584,605.23 1.15 81.21 1,441.24 17.25 57.75 1,430.58 1,374.78 65.72 91.19 6,005,946.92 584,625.45 4.44 104.80 1,536.45 19.82 56.51 1,520.84 1,465.04 82.17 116.60 6,005,963.64 584,650.67 2.73 133.53 1,630.57 21.66 54.34 1,608.86 1,553.06 101.10 144.02 6,005,982.88 584,677.87 2.12 164.84 1,724.48 23.28 53.85 1,695.64 1,639.84 122.15 173.09 6,006,004.26 584,706.70 1.74 198.27 1,818.53 23.16 54.11 1,782.07 1,726.27 143.96 203.08 6,006,026.40 584,736.44 0.17 232.78 1,913.55 27.58 60.21 1,867.92 1,812.12 165.85 237.33 6,006,048.69 584,770.43 5.40 271.44 2,006.78 28.52 67.63 1,950.22 1,894.42 185.05 276.65 6,006,068.33 584,809.54 3.87 314.34 2,101.08 30.13 74.89 2,032.46 1,976.66 199.80 320.34 6,006,083.56 584,853.05 4.14 360.33 2,195.53 32.67 75.78 2,113.07 2,057.27 212.24 367.94 6,006,096.54 584,900.50 2.73 409.53 2,290.18 34.98 74.94 2,191.70 2,135.90 225.57 418.91 6,006,110.45 584,951.31 2.49 462.21 2,384.37 35.13 75.78 2,268.80 2,213.00 239.24 471.26 6,006,124.71 585,003.49 0.54 516.31 2,478.97 35.02 75.73 2,346.22 2,290.42 252.62 523.95 6,006,138.68 585,056.02 0.12 570.67 2,573.36 33.40 75.95 2,424.28 2,368.48 265.60 575.40 6,006,152.25 585,107.32 1.72 623.74 2,667.57 33.35 76.18 2,502.95 2,447.15 278.08 625.70 6,006,165.29 585,157.47 0.14 675.56 2,762.05 33.30 76.40 2,581.90 2,526.10 290.38 676.13 6,006,178.17 585,207.75 0.14 727.46 2,856.79 33.14 76.15 2,661.15 2,605.35 302.70 726.55 6,006,191.05 585,258.03 0.22 779.36 2,952.48 33.13 76.31 2,741.28 2,685.48 315.15 777.35 6,006,204.07 585,308.68 0.09 831.66 3,044.77 32.98 76.91 2,818.64 2,762.84 326.80 826.32 6,006,216.28 585,357.51 0.39 881.99 3,139.78 32.89 76.51 2,898.38 2,842.58 338.68 876.59 6,006,228.73 585,407.64 0.25 933.63 3,234.28 32.30 76.66 2,977.99 2,922.19 350.49 926.11 6,006,241.10 585,457.02 0.63 984.52 3,328.87 31.84 76.87 3,058.15 3,002.35 361.99 975.00 6,006,253.15 585,505.77 0.50 1,034.73 3,423.11 32.11 75.94 3,138.09 3,082.29 373.72 1,023.50 6,006,265.43 585,554.13 0.60 1,084.63 3,517.28 34.16 75.56 3,216.94 3,161.14 386.40 1,073.39 6,006,278.66 585,603.87 2.19 1,136.10 3,612.24 34.31 76.28 3,295.45 3,239.65 399.39 1,125.21 6,006,292.24 585,655.53 0.45 1,189.52 3,706.07 34.14 76.62 3,373.03 3,317.23 411.76 1,176.51 6,006,305.19 585,706.69 0.27 1,242.29 3,797.09 33.88 77.33 3,448.48 3,392.68 423.23 1,226.11 6,006,317.22 585,756.15 0.52 1,293.18 3,894.62 33.84 77.42 3,529.47 3,473.67 435.11 1,279.14 6,006,329.70 585,809.03 0.07 1,347.49 3,988.44 34.21 76.67 3,607.23 3,551.43 446.88 1,330.30 6,006,342.05 585,860.05 0.60 1,399.96 4,082.72 34.36 77.19 3,685.13 3,629.33 458.89 1,382.03 6,006,354.64 585,911.64 0.35 1,453.05 4,177.40 32.99 75.74 3,763.92 3,708.12 471.16 1,433.07 6,006,367.49 585,962.53 1.68 1,505.54 3/10/2020 3:38:53PM Page 3 COMPASS 5000.15 Build 91E HALLIBURTON Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt K Pad Well: MPU K-44 Wellbore: MPU K -44B Design: MPU K -44B wp01 Planned Survey Halliburton Standard Proposal Report Local Co-ordinate Reference: Well MPU K-44 TVD Reference: MPU K -44B Planned RKB @ 55.80usft (Innovati MD Reference: MPU K -44B Planned RKB @ 55.80usft (Innovati North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Depth Inclination Azimuth Depth TVDss +W -S +EI -W (usft) (^) (_) (usft) usft (usft) (usft) 4,266.58 32.62 75.98 3,838.88 3,783.08 482.97 1,479.92 4,367.46 31.79 76.90 3,924.24 3,868.44 495.58 1,532.19 4,461.04 32.57 76.47 4,003.44 3,947.64 507.06 1,580.68 4,555.85 33.60 75.78 4,082.88 4,027.08 519.47 1,630.93 4,650.41 33.10 76.12 4,161.86 4,106.06 532.09 1,681.36 4,744.94 33.54 76.51 4,240.86 4,185.06 544.38 1,731.81 4,838.93 34.23 76.88 4,318.88 4,263.08 556.43 1,782.80 4,933.43 34.35 77.85 4,396.96 4,341.16 568.08 1,834.75 5,027.55 33.76 76.44 4,474.94 4,419.14 579.80 1,886.13 5,121.19 34.34 76.97 4,552.52 4,496.72 591.85 1,937.16 5,212.33 32.72 76.12 4,628.49 4,572.69 603.56 1,986.12 5,310.08 32.24 76.10 4,710.95 4,655.15 616.16 2,037.08 5,404.93 33.16 75.79 4,790.77 4,734.97 628.61 2,086.78 5,499.61 33.09 75.51 4,870.06 4,814.26 641.43 2,136.91 5,540.00 33.16 75.60 4,903.89 4,848.09 646.94 2,158.28 KOP : Start Dir 9.5-1100': 5640' MD, 4903.89'TVD : 90° RT TF -10 3/4" TOW 5,550.00 33.17 77.33 4,912.26 4,856.46 648.22 2,163.60 5,560.00 33.21 79.07 4,920.63 4,864.83 649.34 2,168.96 Start Dir 0.18°1100' : 5560' MD, 4920.63'TVD 5,580.00 33.18 79.03 4,937.36 4,881.56 651.42 2,179.71 Start Dir 5°/100' : 5580' MD, 4937.36'TVD 5,600.00 32.18 79.17 4,954.20 4,898.40 653.46 2,190.32 5,700.00 27.20 80.02 5,041.04 4,985.24 662.43 2,239.01 5,732.11 25.60 80.35 5,069.80 5,014.00 664.87 2,253.08 SB BASE 5,755.03 24.46 80.61 5,090.57 5,034.77 666.47 2,262.64 End Dir : 5755.03' MD, 5090.57' TVD 5,800.00 24.46 80.61 5,131.50 5,075.70 669.51 2,281.02 5,900.00 24.46 80.61 5,222.53 5,166.73 676.26 2,321.87 6,000.00 24.46 80.61 5,313.55 5,257.75 683.01 2,362.72 6,100.00 24.46 80.61 5,404.57 5,348.77 689.77 2,403.58 6,200.00 24.46 80.61 5,495.60 5,439.80 696.52 2,444.43 6,300.00 24.46 80.61 5,586.62 5,530.82 703.27 2,485.28 6,400.00 24.46 80.61 5,677.65 5,621.85 710.03 2,526.13 6,500.00 24.46 80.61 5,768.67 5,712.87 716.78 2,566.99 6,600.00 24.46 80.61 5,859.70 5,803.90 723.54 2,607.84 6,700.00 24.46 80.61 5,950.72 5,894.92 730.29 2,648.69 6,800.00 24.46 80.61 6,041.74 5,985.94 737.04 2,689.55 6,900.00 24.46 80.61 6,132.77 6,076.97 743.80 2,730.40 7,000.00 24.46 80.61 6,223.79 6,167.99 750.55 2,771.25 7,081.54 24.46 80.61 6,298.01 6,242.21 756.06 2,804.56 Start Dir 3°/100' : 7081.54' MD, 6298.01'TVD 7,100.00 23.91 80.55 6,314.85 6,259.05 757.29 2,812.02 7,200.00 20.91 80.15 6,407.29 6,351.49 763.68 2,849.60 Map Map Northing Easting DLS Vert Section (usft) (usft) 3,783.08 6,006,379.82 586,009.24 0.44 1,553.85 6,006,393.02 586,061.35 0.96 1,607.60 6,006,405.05 586,109.71 0.87 1,657.43 6,006,418.03 586,159.81 1.16 1,709.18 6,006,431.22 586,210.09 0.56 1,761.16 6,006,444.08 586,260.39 0.52 1,813.08 6,006,456.71 586,311.24 0.77 1,865.47 6,006,468.94 586,363.05 0.59 1,918.68 6,006,481.24 586,414.29 1.05 1,971.36 6,006,493.87 586,465.17 0.70 2,023.77 6,006,506.13 586,513.99 1.85 2,074.10 6,006,519.31 586,564.80 0.49 2,126.59 6,006,532.32 586,614.36 0.99 2,177.83 6,006,545.71 586,664.33 0.18 2,229.57 6,006,551.45 586,685.64 0.21 2,251.64 6,006,552.79 586,690.94 9.50 2,257.11 6,006,553.97 586,696.29 9.50 2,262.58 6,006,556.17 586,707.01 0.18 2,273.51 6,006,558.34 586,717.59 5.00 2,284.28 6,006,567.86 586,766.18 5.00 2,333.67 6,006,570.45 586,780.22 5.00 2,347.90 6,006,572.17 586,789.76 5.00 2,357.56 6,006,575.41 586,808.10 0.00 2,376.10 6,006,582.63 586,848.87 0.00 2,417.34 6,006,589.84 586,889.64 0.00 2,458.58 6,006,597.06 586,930.41 0.00 2,499.81 6,006,604.27 586,971.18 0.00 2,541.05 6,006,611.49 587,011.95 0.00 2,582.29 6,006,618.70 587,052.72 0.00 2,623.53 6,006,625.92 587,093.49 0.00 2,664.76 6,006,633.13 587,134.26 0.00 2,706.00 6,006,640.35 587,175.03 0.00 2,747.24 6,006,647.56 587,215.80 0.00 2,788.47 6,006,654.78 587,256.57 0.00 2,829.71 6,006,661.99 587,297.34 0.00 2,870.95 6,006,667.88 587,330.58 0.00 2,904.57 6,006,669.20 587,338.03 3.00 2,912.11 6,006,676.01 587,375.53 3.00 2,950.08 3/102020 3:38.'53PM Page 4 COMPASS 5000.15 Build 91E HALLIBURTON Database: Company: Project: Site: Well: Wellbore: Design: NORTH US+CANADA Hilcorp Alaska, LLC Milne Point M Pt K Pad MPU K-44 MPU K -44B MPU K -44B wp01 TVD Reference: Planned Survey MD Reference: MPU K -44B Planned RKB @ 55.80usft (Innova6 North Reference: True Measured Minimum Curvature (usft) Vertical 765.51 Depth Inclination Azimuth Depth TVDss (usft) (') (1) (usft) usft 7,230.44 20.00 80.00 6,435.81 6,380.01 End Dir : 7230.44' MD, 6435.81' TVD 2,944.31 7,300.00 20.00 80.00 6,501.18 6,445.38 7,390.44 20.00 80.00 6,586.16 6,530.36 7,400.00 20.00 80.00 6,595.15 6,539.35 7,480.51 20.00 80.00 6,670.80 6,615.00 HRZ 587,543.80 795.59 3,030.70 6,006,709.97 7,500.00 20.00 80.00 6,689.12 6,633.32 7,557.13 20.00 80.00 6,742.80 6,687.00 KUB 6,006,720.28 587,611.03 805.98 3,089.59 7,600.00 20.00 80.00 6,783.08 6,727.28 7,617.79 20.00 80.00 6,799.80 6,744.00 KLGM 7,700.00 20.00 80.00 6,877.05 6,821.25 7,736.98 20.00 80.00 6,911.80 6,856.00 KUP_D 7,800.00 20.00 80.00 6,971.02 6,915.22 7,894.13 20.00 80.00 7,059.48 7,003.68 Start Dir 4°/100' : 7894.13' MD, 7059.47'TVD 7,900.00 20.23 80.00 7,064.99 7,009.19 7,911.54 20.70 80.00 7,075.80 7,020.00 KUP_C 7,970.81 23.07 80.00 7,130.80 7,075.00 LCU 7,979.74 23.42 80.00 7,139.00 7,083.20 Total Depth : 7979.74' MD, 7139' TVD Targets Target Name - hit/miss target - Shape MPU K-44RD wp05 CP1 - plan hits target center - Point Casing Points Halliburton Standard Proposal Report Local Co-ordinate Reference: Well MPU K-44 TVD Reference: MPU K -44B Planned RKB @ 55.80usft (Innovati MD Reference: MPU K -44B Planned RKB @ 55.80usft (Innova6 North Reference: True Survey Calculation Method: Minimum Curvature Dip Angle Dip Dir. TVD +N/ -S (°) (°) (usft) (usft) 0.00 0.00 6,586.16 775.01 DLS Vert Section Map Map +N/ -S +E/ -W Northing Easting (usft) (usft) (usft) (usft) 765.51 2,860.08 6,006,677.96 587,385.99 769.64 2,883.51 6,006,682.35 587,409.36 775.01 2,913.97 6,006,688.07 587,439.76 775.58 2,917.19 6,006,688.67 587,442.97 780.36 2,944.31 6,006,693.76 587,470.03 781.52 2,950.88 6,006,694.99 587,476.58 784.91 2,970.12 6,006,698.60 587,495.79 787.46 2,984.56 6,006,701.31 587,510.19 788.52 2,990.55 6,006,702.44 587,516.17 793.40 3,018.24 6,006,707.63 587,543.80 795.59 3,030.70 6,006,709.97 587,556.23 799.34 3,051.92 6,006,713.95 587,577.41 804.93 3,083.63 6,006,719.90 587,609.05 805.28 3,085.62 6,006,720.28 587,611.03 805.98 3,089.59 6,006,721.02 587,615.00 809.82 3,111.35 6,006,725.10 587,636.71 810.43 3,114.81 6,006,725.75 587,640.17 Dip Angle Dip Dir. TVD +N/ -S (°) (°) (usft) (usft) 0.00 0.00 6,586.16 775.01 DLS Vert Section 6,380.01 Hole 3.00 2,960.68 0.00 2,984.40 0.00 3,015.23 0.00 3,018.49 0.00 3,045.94 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 4.00 4.00 4.00 4.00 +E/ -W Northing (usft) (usft) 2,913.97 6,006,688.07 3,052.58 3,072.06 3,086.68 3,092.74 3,120.77 3,133.38 3,154.86 3,186.95 3,188.97 3,192.99 3,215.01 3,218.52 Easting (usft) 587,439.76 Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 5,540.00 4,903.89 103/4"TOW 10-3/4 14-112 7,979.74 7,139.00 7" x 9 7/8" 7 9-7/8 3/10/2020 3:38:53PM Page 5 COMPASS 5000.15 Build 91E HALLIBURTON Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt K Pad Well: MPU K44 Wellbore: MPU K44B Design: MPU K -44B wp01 Formations Measured Vertical Vertical TVD Reference: Depth Depth Depth SS MPU K -44B Planned RKB @ 55.80usft (Innovati (usft) (usft) Survey Calculation Method: 7,911.54 7,075.80 KUP_C 7,557.13 6,742.80 KLB 7,970.81 7,130.80 LCU 7,480.51 6,670.80 HRZ 7,617.79 6,799.80 KLGM 5,732.11 51069.80 SB—BASE 7,736.98 6,911.80 KUP_D Plan Annotations Halliburton Standard Proposal Report Local Co-ordinate Reference: Well MPU K-44 TVD Reference: MPU K -44B Planned RKB @ 55.80usft (Innovati MD Reference: MPU K -44B Planned RKB @ 55.80usft (Innovati North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) 5,540.00 4,903.89 646.94 2,158.28 5,560.00 4,920.63 649.34 2,168.96 5,580.00 4,937.36 651.42 2,179.71 5,755.03 5,090.57 666.47 2,262.64 7,081.54 6,298.01 756.06 2,804.56 7,230.44 6,435.81 765.51 2,860.08 7,894.13 7,059.48 804.93 3,083.63 7,979.74 7,139.00 810.43 3,114.81 Dip Dip Direction Name Lithology (1 (') Comment KOP : Start Dir 9.5°/100' : 5540' MD, 4903.89'TVD : 90° RT TF Start Dir 0.18°/100' : 5560' MD, 4920.639VD Start Dir 5-1100': 5580' MD, 4937.36'TVD End Dir : 5755.03' MD, 5090.57' TVD Start Dir 3-/100': 7081.54' MD, 6298.01'TVD End Dir : 7230.44' MD, 6435.81' TVD StartDir 4°/100' : 7894.13' MD, 7059.47'TVD Total Depth: 7979.74' MD, 7139' TVD 3/102020 3:38:53PM Page 6 COMPASS 5000.15 Build 91E Hilcorp Alaska, LLC Milne Point M Pt K Pad MPU K-44 MPU K -44B MPU K -44B wp01 Sperry Drilling Services Clearance Summary Anticollision Report 10 March, 2020 Closest Approach 3D Proximity Scan on Current Survey Data (I ighsi0e Reference) Reference Design: MPt KPad - MPU K -44 -MPU K-0 B - MPD K -44B W01 Well Coordinates: 6,005,880.17 N, 584,535.02 E (70.25' 33.57 N, 149° 18' 40.03" W) Datum Height: MPU K-0 B Planned RKB @ 55.80usft (innovation) Scan Range: 5,540.00 to 7,979.74 usR. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usf Geotletic Scale Factor Applied Version: 5000.15 Build: 91E Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 207+ 100110000freference Scan Type: 2500 HALL18URTON Sperry Drilling Services HALLIBURTON Anticollision Report for MPU K-44 - MPU K -44B wp01 Hileorp Alaska, LLC Milne Point Closest Approach 31) Proximity Scan on Current Survey Data (Nighslde Reference) Reference Design: M Pt K Pad - MPU Kd - MPU Kd B - MPU KL B wp01 Scan Range: 6,640.00 to 7,979.74 oak Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is 1,500.00 usa Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name- Wellbore Name- Design (usa) (..ft) (usa) (usa) usa M Pt Cascade M Pt K Pad MPK-I8-MPK-I8-MPK-18 Survey Tool 554000 990.31 5.540.00 936.34 5,356.53 18.349 Clearance Factor Pass - MPK-I8-MPK-I8A-MPK-18A 5,940.00 7,979.74 MPU K -44B wp01 5,540.00 990.31 5,540.00 936.34 5,356.53 18.349 Clearance Factor Pass - MPU K44 - MPK44 - MPK44 5,840.00 26.16 5,840.00 2374 5,845.82 10792 Clearance Factor Pass - MPU K44 -MPU K-0 APB1 -MPU K44APB1 5,840.00 4.04 5,840.00 0.35 5,839.85 1.094 Centre Distance Pass - MPU K-0 -MPU K-44APB1 -MPU K44APBI = MPU K-44-MPUK-44APB2-10PUK-0APIK 5,840.00 4.04 $840.00 0.19 5,839.85 1.049 Centre Distance Pass - MPUK44-MPU K44APM-MPU K-0APB2 ✓- _ From To Survey/Plan Survey Tool (usa) (uaR) 127.50 498.46 3MWD _InterpA i+Sag 593.84 5,540.00 3_W _MD+IFR2+MS+Seg 5,540.00 5,940.00 MPU K -44B wp01 3MWD_Interp Av+Sag 5,940.00 7,979.74 MPU K -44B wp01 3__MWD+IFR2+MS+Sag Ellipse error tens 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 between wellbore centres. Clearance Factor= Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 10 March, 2020 - 14:48 Page 2 o/4 COMPASS MALLIBURTON PmjeG: Milne Polnl REFERENCE IWMMXTNM' µEyL D9rpp5pApD Kdf NADI9]]WAIX.'nNCCNU3) ANGo] W m (x(q aneienea: weemau wm, ]rve xwn sire: MRK Pod ae r •x^q q(I NW111. MPU Kdd µpllbore: MPU Ki46 nan(]vo)nerr..m mw nuec�u^mWenne�55tlua Wmva0.nl M°° neNremn e: mw Ass.mo 11^mwme) O'°'°'d�rt 1930 +0w OMW NOMmg Fainp 1131 a IonOiwde Plan: MPU K-44a wP31 Gw ^ ° ,MlMum curvaWry 6'JOSg0911 S8i51i 03 'N'iP 315]ON IJ9. 18JO.ON GLOBAL FILTER APPLIED: All .11 IPTRew8Nn 200'a 100IfOW or rele2nce gown. zozoag)z]w:m. onm m roueae: v e w 5540 To 7070,70 EM ]e.l o.pn nrcm n.m ro CASMG D127 ETAILS em sO a a.. Mni Ms 3i eoeo �irnz ma se°e u (1)WPww) 3 ND TVgSS MD Si. N. eke rn�(.1J Ki I, iNWO p ' w000 ywIlnyWnt n. 493.69 4848.09 55W 10-314 10314"OW 7139W ]08130 ]919.]4 7 7'.97M' 0 150GO- .'120.00- m120.00 I u I W d fi0 W 0 m 30.00 I I _ — 000 5550 5700 5850 5000 6150 6300 6450 6800 6750 6900 7050 ]200 ]350 7500 7650 7800 7950 8100 8250 8100 Measured Depth (300 usfi/in) MPK�4 T—�---- - T a.pD K.y44 P81 I �.._Fi �— _ 3.00 m M . I - T-- — 'MPPU —--- _-_ I r— I o 2.00 -'-- o. - -'Co q. Ilision Risk Procedures Re j W 1.0) Collision Avoidance Re,- fN.-fG. Zane -Stop Drilling 000 5550 5700 5850 60M 6150 6300 8450 8600 6750 6900 7050 7200 7350 7500 7650 7110 7950 810D 8250 8400 Measured Depth (300 usH/in) TRANSMITTAL LETTER CHECKLIST WELL NAME: h FG( K -4-+B PTD: a a © - O 'o -Z 4- /Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: M t I h e Pa t k:t POOL: Ku patru K K I vein t J l I Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- -_ (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50— from from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Spacing Approval to produce/inject is contingent upon issuance of a Exception conservation 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 fust caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non- production or production testing of coal bed methane is not allowed for 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 \II/ within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool PTD#:2200270 Com Administration I 1 Appr Date DLB 3/12/2020 Engineering 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Appr Date - GLS 3/20/2020 29 Well -located in a_ defined _pool _ - - - _ Yes 30 Yes Well located proper distance from other wells - - - - - - - - - - - - - - - - X31 Sufficient acreage -available in -drilling unit_ _ - - - - _ - - - - - Yes 32 Yes . - Directional plan view _& wellbore profile included. Operator only affected party_ - -- ---- ---- 33 Operator has appropriate_ bond in force -- - - -- Yes 34 Yes --- 35 Geology Yes 36 Appr Date 37 DLB 3/12/2020 38 NA_ - - - _ - - - Yes 39 INT, KUPARUK RIVER OIL - 525100 Well Name: MILNE PT UNIT K -44B Program DEV-_ Initial Class/Type DEV/PEND GeoArea 890 Unit 11328 _ On/Off Shore On Permit fee attached NA - Lease number appropriate -------- Yes _ - -Unique well name and number - _ _ ----------------------- ----------------- Yes Well -located in a_ defined _pool _ - - - _ Yes Well.located proper distance from drilling unit_boundary_ - _ - - Yes Well located proper distance from other wells - - - - - - - - - - - - - - - - Yes Sufficient acreage -available in -drilling unit_ _ - - - - _ - - - - - Yes -If-deviated, is -wellbore plat -included -- - - - _ - - - Yes . - Directional plan view _& wellbore profile included. Operator only affected party_ - -- ---- ---- Yes -- - - - - Operator has appropriate_ bond in force -- - - -- Yes Permit_ can be issued without conservation order_ Yes Permit_ can be issued without administrative -approval _ _ _ -- Yes . Can permit be approved before 15-day_wait_ Yes Well -located within area and strata authorized by Injection Order# (put 10# in.comments)-(For_ _N_A_ - - . All wells _within 1/4, mile _area _of review identified (For service well only) - - - - - - _ NA_ Pre -produced injector: duration -of pre -production less than 3 months -(For -service well only) - N_A_ N_onconven. gas conforms to AS31.05.030Q.1_.A),Q.2.A-D) - - - - - - - - - - - - - - - - - - - NA_ Conductor string -provided - - - - _ NA_ Sidetrack from existing well _K -44A_ - - - - - - - - - Su face -casing- protects all -known_ USDWs - - _ - - - - _ - - - - - - - NA_ CMT_vol_ adequate to circulate -on conductor & surf _csg - - - - - NA_ - - - - CMT vol_ adequate. to tie-in long string to surf csg--- - - - - - - N_A_ - - - - - - - - - . CMT -will coverall known -productive horizons_ - - - - - - - - Yes - - - - - - 7" will_be_cemented 500 ft_above Kup C_ Casing designs adequate for CJ, B &_permafrost_ - - - - Yes Adequate tankage_or reserve pit Yes Rig has steel pits. Innovation Rig - - - - - If_a_re-drill, has -a- 1.0-403 for abandonment been approved Yes . 320-113 P &_A sundry for K -44A- - - - - - - - - - - - - - - - - _ _ _ _ _ Ade uate wellbore separation q P proposed Yes If diver -ter required, does -it -meet regu_la_tions_ - - - - _ - - - - - - - - - - - - _ NA_ Will -use BOPE ..._ wellhead -in place. Drilling fluid_ program schematic-&- equip list adequate_ - - - - Yes Max form_ press -=-364Q psi (9.8_ ppg _E_WM)_ will drill -with 9.5_- 10.5 ppg mud BOPEs,_do they meet_ regulation - -- - - - _ - - - Yes - - - 13 5/8"5000 psi WP_BOPE.. - _ -BOPE-press rating appropriate; test to (put psig in comments). - - - - - _ - - - - - - Yes - - - MASP = 2927 -psi -Will test BOPE to 3500 psi - - - - Choke_manifold complies w/API_RP-53 (May 84)- - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - Work will occur without operation shutdown - - - - . - _ - Yes Sundry -required - und y -required_ to Perf and_complete_wellbore. _Kup C_ ESP completion. Is presence of H2S gas probable - Yes - - - H2S on. pad., Rig_has sensors and_alarms._ Mechanical -condition of wells within AOR verified (For -service well only) - - - - NA_ Permit- can be issued w/o hydrogen_ sulfide measures - - - - - - No_ H2S measures required._ Potential exists to encounter H2S in this mature reservoir. _ - Data -presented on potential overpressure zones - - - - - Yes Seismic_analys_is_ of shallow gas -zones - - - NA - -Seabed Seabed condition survey -(if off_ -shore) - - NA Contact name/phone for weekly progress reports_ [exploratory only] NA Well bore seg ❑ Annular Disposal n Geologic Engineering Public ESP completion in Kup C sand ... Will need to verify BHP prior to running ESP (packer requirement per C0390A ) gls Commissioner: Date: Commissioner: Date Commissioner Date S3Z SSL( 3/z3
