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220-013
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 8/27/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU S-57 (220-013) Halliburton GEOSTEERING/STRATASTEER 7 MAR 2020 MPU S-57 PTD: 2200130 E-Set: 33717 Received by the AOGCC 08/31/2020 Abby Bell 08/31/2020 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23666-00-00Well Name/No. MILNE PT UNIT S-57Completion Status1-OILCompletion Date3/10/2020Permit to Drill2200130Operator Hilcorp Alaska, LLCMD13680TVD4101Current Status1-OIL4/8/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:ROP/ABG/DGR/EWR/ADR 2"/5" MD…ABG/DGR/EWR/ADR 2"/5" TVDNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC3/25/2020105 13680 Electronic Data Set, Filename: MPU S-57 LWD Final.las32255EDDigital DataC3/25/20205190 13642 Electronic Data Set, Filename: MPU S-57 ADR Quadrants All Curves.las32255EDDigital DataC3/25/2020 Electronic File: MPU S-57 LWD Final MD.cgm32255EDDigital DataC3/25/2020 Electronic File: MPU S-57 LWD Final TVD.cgm32255EDDigital DataC3/25/2020 Electronic File: MPU S-57.xlsx32255EDDigital DataC3/25/2020 Electronic File: MPU S-57_Definitive Survey Report.pdf32255EDDigital DataC3/25/2020 Electronic File: MPU S-57_definitive survey report.txt32255EDDigital DataC3/25/2020 Electronic File: MPU S-57_GIS.txt32255EDDigital DataC3/25/2020 Electronic File: MPU S-57_Plan.pdf32255EDDigital DataC3/25/2020 Electronic File: MPU S-57_VSec.pdf32255EDDigital DataC3/25/2020 Electronic File: MPU S-57 LWD Final MD.emf32255EDDigital DataC3/25/2020 Electronic File: MPU S-57 LWD Final TVD.emf32255EDDigital DataC3/25/2020 Electronic File: MPU_S-57_Geosteering.dlis32255EDDigital DataC3/25/2020 Electronic File: MPU_S-57_Geosteering.ver32255EDDigital DataC3/25/2020 Electronic File: MPU S-57 LWD Final MD.pdf32255EDDigital DataC3/25/2020 Electronic File: MPU S-57 LWD Final TVD.pdf32255EDDigital DataC3/25/2020 Electronic File: MPU S-57 LWD Final MD.tif32255EDDigital DataC3/25/2020 Electronic File: MPU S-57 LWD Final TVD.tif32255EDDigital DataWednesday, April 8, 2020AOGCCPage 1 of 2MPU S-57 LWDFinal.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23666-00-00Well Name/No. MILNE PT UNIT S-57Completion Status1-OILCompletion Date3/10/2020Permit to Drill2200130Operator Hilcorp Alaska, LLCMD13680TVD4101Current Status1-OIL4/8/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION 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:3/10/2020Release Date:2/4/2020C3/25/2020 Electronic File: EMFView3_1.zip32255EDDigital DataC3/25/2020 Electronic File: Readme.txt32255EDDigital Data0 0 2200130 MILNE PT UNIT S-57 LOG HEADERS2200130 MILNE PT UNIT S-57 LOG HEADERS32255LogLog Header ScansWednesday, April 8, 2020AOGCCPage 2 of 2M. Guhl4/8/2020 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: __________________ 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: BF: 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- TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 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 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 Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 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 Date of Test: Flow Tubing Gas-Oil Ratio:Choke Size:Water-Bbl: PRODUCTION TEST Per 20 AAC 25.283 (i)(2) attach electronic information CASING WT. PER FT.GRADE TOP SETTING DEPTH MD TOP CEMENTING RECORDSETTING DEPTH TVD HOLE SIZE AMOUNT PULLED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG WAG Gas BOTTOM SIZE DEPTH SET (MD) PACKER SET (MD/TVD) TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 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, to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion?YesNo PACKER SET (MD/TVD)SIZE DEPTH SET (MD) TUBING RECORD t each interval open (MD/TVD of Top and Bottom; Perforation Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. Status:OilSPLUG OtherAbandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory WINJ WDSPLNo. of Completions: ____________________ Service Stratigraphic Test or Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: ss: 7. Date Spudded: 15. API Number: ion of Well (Governmental Section): 8.Date TD Reached: 16.Well Name and Number: oductive Interval: 9.Ref Elevations: KB: 17. Field / Pool(s): GL: BF: pth: 10.Plug Back Depth MD/TVD: 18. Property Designation: ion of Well (State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: x- y-Zone- x- y- Zone- 12.SSSV Depth MD/TVD:20. Thickness of Permafrost MD/TVD: pth: x- y- Zone- onal or Inclination Survey: Yes (attached) No 13.Water Depth, if Offshore:21.Re-drill/Lateral Top Window MD/TVD: it electronic information per 20 AAC 25.050 (ft MSL) Obtained: BOTTOM on, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, esistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation Acronyms may be used. Attach a separate page if necessary WT. PER FT.GRADE TOP SETTING DEPTH MD TOP CEMENTING RECORDSETTING DEPTH TVD HOLE SIZE AMOUNT PULLED G BOTTOM 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, Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 24 1 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 3244' FSL, 443' FEL, Sec 12, T12N, R10E, UM, AK 2612' FSL, 1292' FEL, Sec 12, T12N, R10E, UM, AK 87' FSL, 1720' FWL, Sec 35, T13N, R10E, UM, AK 565567 564724 562390 5999908 5999270 6007284 4 4 4 03/10/2020 02/19/2020 03/04/2020 63.50 36.30 36.30 13,680' MD / 4,101' TVD 13,680' MD / 4,101' TVD N/A N/A 220-013 50-029-23666-00-00 MPU S-57 Milne Point Field / Schrader Bluff Oil Pool ADL380109 / ADL025518 LONS 01-001 2,015' MD / 1,834' TVD N/A ROP/ABG/DGR/EWR/ADR 2"/5" MD ABG/DGR/EWR/ADR 2"/5" TVD 20" 215# X-42 Surface 107' Surface 107' Conductor ±270 ft3 9-5/8" 40# L-80 Surface 5,208' Surface 4,119' 12-1/4" Stg 1 L - 375 sx / T - 398 sx Stg 2 L - 875 sx / T - 264 sx 7" 26# L-80 Surface 4,877' Surface 4,078' Tieback Tieback 6-5/8" 20# L-80 4,877' 13,658' 4,078' 4,100' 8-1/2" Cementless Liner w/ Screens **Please see attached schematic for detail** Liner run on 03/03/2020 3-1/2" 4,978' 4,721' MD / 4,028' TVD 03/22/2020 Jet Pump 03/25/2020 587 133 0 N/A 226.7 240 3495 587 133 0 TBD - Waiting on Test Results ✔ ✔ ✔ ✔ ✔ By Samantha Carlisle at 10:44 am, Apr 01, 2020 Completion Date 3/10/2020 HEW gls 4/7/20 RBDMS HEW 4/2/2020 DSR-4/1/2020 G SFD 4/1/2020 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Contact Phone: 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: 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). 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. 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. 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. This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). INSTRUCTIONS Authorized Name: Authorized Title: Authorized SignatureZ'DWH: 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at 7': 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. 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 Permafrost - Top Permafrost - Base No Sidewall Cores: 30. TVD countered):FORMATION TESTS d summarize lithology and presence of oil, gas or water (subm and all subsequent laboratory analytical results per 20 AAC 2 Yes No Well tested? Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment SB NE cdinger@hilcorp.com 2015 1834 SB NE 5150 4116 SV5 1537 1466 SV1 2530 2298 Ugnu LA3 4006 3594 SB NA 4802 4056 SB NE 5112 4112 Drilling Manager Monty Myers Cody Dinger 777-8389 Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg & Cmt Report ✔✔ ✔ Digitally signed by Monty Mack Myers DN: cn=Monty Mack Myers, ou=Users Reason: I am approving this document Date: 2020.04.01 10:13:12 -08'00' Monty Mack Myers _____________________________________________________________________________________ Revised By: STP 03/14/2020 Schematic Milne Point Unit Well: MPU S-57 Last Completed: 3/10/2020 PTD: 220-013 GENERAL WELL INFO API: 50-029-23666-00-00 Drilled, Cased & Completed by Innovation – 3/10/2020 TREE & WELLHEAD Tree Cameron 3-1/8" 5M Wellhead FMC 11" 5M TC-1A w/11" x 3 1/2" TC-II Top & Bottom Tubing Hanger with 3" CIW "H" BPV profile. 2ea 3/8" NPT control lines. OPEN HOLE / CEMENT DETAIL 20” x 34” 270 ft3 Cement to surface in a 42” hole 9-5/8” 1st stage L – 732 ft3 / T – 458 ft3 in a 12-1/4” hole 9-5/8” 2nd stage L – 1937 ft3 / T – 314 ft3 in a 12-1/4” hole 6-5/8” Cementless Slotted Liner in 8-1/2” hole CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20"x34” Conductor (Insulated) 215.5 / A-53B / Weld 19.250” Surface 107’ N/A 9-5/8" Surface 40 / L-80 / TXP 8.835” Surface 5,208' 0.0758 7” Tieback 26/ L-80 / TXP 6.276” Surface 4,877’ 0.0383 6-5/8” Liner (Slotted) 20 / L-80 / Hydril 563 6.049” 4,877’ 13,658’ 0.0355 TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 2.867” Surface 4,978’ 0.0087 WELL INCLINATION DETAIL KOP @ 250’ Max Hole Angle = 93.8° @ 6,021’ Hole Angle @ Sliding Sleeve = 62° @ 4,622’ Hole Angle @ XN Profile = 67° @ 4,747’ JEWELRY DETAIL No. Top MD Item ID Upper Completion 1 22’ Tubing Hanger: 3-1/2" FMC, TC 1A (3-1/2” TC-II Top x Btm) w/ Blast Jt 2.992” 2 4,601’ 3-1/2” Baker Hughes Discharge Gauge (Tubing Read) 2.875” 3 4,622’ 3-1/2" HES XD Sliding Sleeve, 2.813” Min ID (7C Jet Pump Set 3/11/20) 2.813” 4 4,647’ 3-1/2" Baker Hughes Suction Gauge (Tubing Read) 2.875” 5 4,668’ 3-1/2” HES X-Nipple, 2.813” Min ID 2.813” 6 4,721’ 7" x 3-1/2" HES PHL Retrievable Packer (50.5k shear release) 2.885” 7 4,747’ 3-1/2” HES XN Nipple MIN ID = 2.750” 2.750” 8 4,977’ 3-1/2” WLEG – Btm @ 4,978’ 2.867” Lower Completion 9 4,866’ Locator Sub w/ 10’ Bullet Seals (8.25” OD No-Go; Spaced out 1.41’) 6.151” 10 4,877’ SLZXP Liner Top Packer with DG slips (11.28' Tieback Sleeve) 6.190” 11 4,898’ Crossover, 7" Hydril 563 Box x 6-5/8" Hydril 563 Pin 5.950” 12 13,656’ Eccentric Clear Shoe – Btm @ 13,658’ - SLOTTED LINER DETAIL Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Status 4,877’ 5,150’ 4,078’ 4,116’ 273’ Liner Top/Blank Jts 5,150’ 11,987’ 4,116’ 4,074’ 6,837’ Slotted Liner 11,987’ 12,476’ 4,074’ 4,078’ 489’ Blank Joints 12,476’ 13,656’ 4,078’ 4,100’ 1,180’ Slotted Liner Activity Date Ops Summary 2/15/2020 Prep Cellar for Move. Swap to Gen Power @ 1300 hrs. disconnect Hi Line Power. B/D H20 and steam. Stage spil response material on each module. M/U Diverter T on S-57. Flip up roof caps. Continue to C/O Pods on #2 MP. Peak on location at 14:00.;PJSM W/ Peak. Spot Break Shack and Enviro Vac. Move Cutting Box and warm shack to S Pad. Jack up Gen Mod and install jeep. Pull ahead and set up hooch and heater to warm tires. Jack up and spot Pit Mod W/ heaters for tires. Spot Pipe Shed. -44° F Peak used cold weather variance to proceed.;Convoy Pipe Shed and Catwalk to S Pad. Install tow bar on Sub. Open cellar beams for clearing Tree.;PJSM Continually check tires and cold starts on Gen, Mud and Sub Mods. Moved Cattle Chute and Pipe Shed to S-Pad at 2 mph due cold Temp. Stop at MP Y and checked all Equip before moving to S-Pad. Load rig Matts and trailers as weather allows. 2/16/2020 PJSM Flat tires observed , unhook Gen Mod jeep and set down. Build hooch and set up heaters on tires. Prep for Peak tire truck to make repairs. Jack up Sub Mod and leave M Pad to S Pad. Use Cat to assist as needed. Spot Matts around S-57 and RCD W/ Tree components behind conductor.;Pull Sub Mod on Matts, install tow bar and remove mounting pins F/ Sub. Rotate Sub 90°. Assist Peak W/ tire repair. Replace O-ring on Mud jeep. Remove stairs F/ koomey landing. Turn stompers and walk Sub to well. Lower pole on well house. Spot Sub and shim level over S-57. Checking tires hourly.;Filled two tires before moving Gen & Mud. Hook up Jeep and turn Gen Mod around. Move Gen & Mud Mod to S-Pad. Merry up Cattle Chute to Sub.;Daily hauled 290 bbls to G&I total = 0 bbls Daily water hauled 0 bbls from L Pad total = 0 bbls Daily metal 0 lbs, total metal 0 lbs Daily Fluid lost 0 bbls total = 0 bbls 2/17/2020 PJSM Cont spotting and shimming Cattle Chute. Spot and shim Pipe Shed, Mud and Gen Mods. Hook up inner connects. Set Stairs around rig. Go to F Pad and move Shop to S Pad. Spot and R/U Break Shack and Enviro Vac. Set up containment and spot cutting box. Work on rig acceptance.;Cont. working on MP #2. Start H2O, Air and Steam around rig. Move Office F/ M Pad to S Pad. Scope up Derrick. Work on rig acceptance check list. Go to M Pad and P/U Herculite and clean up around pad. Cont hauling misc trailers F/ M Pad to S Pad. C/O Wash Pipe. Spot Hot Shack & Beyond Choke house.;Load 5" D.P. in Pipe Shed. Install Hydraulic Elevators and test new solenoid vlave. Install cellar grating and prep for N/U NOPE. 2/18/2020 Rig settled out. Decision made to re level rig. Re tract back cattle chute. Disconnect Mezzanine lines. Jack up rig and shim. Jack down and set out riggers. Hook up Mezz and scope cattle chute into place. Run hi line cable as per Milne Point Electricians and swap to Hi lIne Power @ 11:30.;Continue to load and process 5" DP. Continue putting #2 MP back together. Rig Accepted at 06:00.;PJSM, Hook up Bridge cranes to stack and remove chain Binders. Set stack on Diverter T. Begin installing Knife Valve.;Continue to N/U Diverter System. Re-align knife valve. M/U diverter sections and tighten flange bolts. Install 4" conductor valves. Center up stack and adjust chains. Wellhead rep tighten slip lock head screws. SimOps: Continue working on mud pumps. Load and process 5" drill pipe.;Continue N/U diverter system. Install extension saddle and diverter section with crane. Grease crown, service skate. Full derrick Inspection. PT mud pump #2 to 2500 psi - good. Install bell nipple and riser.;Finish tightening diverter clamp bolts. Install drain hoses on drip pan. Install T-bars on conductor valves. Install 1502 flange and cap on Kill line. Get RKB's. Install short mouseholes.;Drift (3.125") pick up and rack back 58 stands of 5" drill pipe. SimOps: Bring on spud mud to pits, move fluid around and check lines. C/O mechanical seal on mix pump 2. 2/19/2020 Continue to P/U and rack back 190 jts 5" NC50 drill pipe. Rack back 9 stds 5" HWDP w/ SLB jars. Hook up Knife Valve.;Service Rig. Open Coffin on TD and inspect junction box for oil residue. Close and secure Coffin.;Test Diverter System on 5" DP Test: Knife valve = 3 seconds and Annular = 9 seconds. 6 N2 bottle avg = 2333 psi. Test gas alarms. Drawdown - 2950 start, 2200 drawdown, 11 sec for 200 psi, 50 sec full charge. Check PVT, flow paddle. Witness Waived by Matt Herrera.;Pre-Spud meeting. PJSM on P/U BHA #1. Bring BHA components to rig floor. M/U 12.25" Kymera 3 cone bit to mud motor and XO.;Flood conductor and surface lines. Test 3000 psi (good). Check diverter lines for leaks. Tag ice @ 35' MD. Wash down at 350 gpm, 230 psi to 107'. Spud well, displace to spud mud. Drill 12-1/4" hole from 106' to 254' at 400 gpm, 414 psi, 30 rpms, 1.2Kft-lbs.;CBU x 2 at 400 gpm, 400 psi, racking one stand back. POOH on elevators. B/D top drive. Pick up and inspect bit - good.;M/U BHA as per Sperry: M/U DGR collar, EWR-P4, DM. Measure RFO MW to MTR =5.9"/8.11" = 261.9, M/U PWD, HCIM, TM, UBHO. Plug in and download, hang E-line sheave while downloading. Oreintate UBHO. M/U (3) flex collars, 1 stnd HWDP to 242'. Obtain TF and survey with Gyro. Wash down to 254'.;Drill 12-1/4" Surface Hole F/ 254' to 585' MD (331' total = 66 fph AROP) 400 GPM, 1050 PSI, 40 RPM, TRQ 2K, WOB 2-4K, ECD 9.68 ppg w/ 8.9 ppg MW. P/U 67K, S/O 64K, ROT 64K. Sliding as needed to maintain WP03 with 3°/100 build. KOP 254'. Collecting gyro surveys on E-Line every stand.;Daily hauled 171 bbls to G&I total = 461 bbls Daily water hauled 130 bbls from L Pad total = 810 bbls Daily Fluid lost 0 bbls total = 0 bbls Distance to WP03: 1.66', 1.65' high, 0.09' left. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: MP S-57 Milne Point Unit Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Innovation Job Name:2010572D MPU S-57 Drilling Spud Date: j p gp ;Test Diverter System on 5" DP Test: Knife valve = 3 seconds and Annular = 9 seconds. 2/20/2020 Drill 12-1/4" Surface Hole F/ 585' to 984' MD (399' total = 66 fph AROP) 450 GPM, 1215 PSI, 40 RPM, TRQ 4-5K, WOB 8-15K, ECD 9.57 ppg w/ 8.9 ppg MW. P/U 76K, S/O 74K, ROT 75K. Sliding as needed to maintain WP03 with 3°/100 build. Collecting gyro surveys on E-Line every stand .;Drill 12-1/4" Surface Hole F/ 984' to 1376' MD (392' total = 65 fph AROP) 450 GPM, 1450 PSI, 50 RPM, TRQ 5K, WOB 10-15K, ECD 10.19 ppg w/ 9.0 ppg MW. P/U 80K, S/O 75K, ROT 79K. Max Gas 187U Sliding as needed to maintain WP03 with 3°/100 build. Collecting gyro surveys on E-Line every stand.;Drill 12-1/4" Surface Hole F/ 1376' to 1946' MD (570' total =95fph AROP) 500 GPM, 1615 PSI, 60 RPM, TRQ 6K, WOB 12-20, ECD 10.18 ppg w/ 9.0 ppg MW. P/U 100K, S/O 82K, ROT 90K. Max Gas 257U Sliding as needed to maintain WP03 with 3°/100 build. Start tangent section with maintenance slides at 1521'.;Collecting gyro surveys on E-Line every stand; last gyro survey 1405'. Release Gyro at 1880'.;Drill 12-1/4" Surface Hole F/ 1946' to 2773' MD (827' total =138fph AROP) 530 GPM, 1720 PSI, 80 RPM, TRQ 8.5K, WOB 12-20, ECD 10.17 ppg w/ 9.2 ppg MW. P/U 112K, S/O 90K, ROT 100K. Max Gas 2072U at 2440', possible gas hydrate in SV-2. Maintenance slides as needed to maintain WP03.;Base of permafrost logged at 2020'MD/ 1875'TVD.;Daily hauled 969 bbls to G&I total = 1430 bbls Daily water hauled 1170 bbls from L Pad total = 1980 bbls Daily Fluid lost 0 bbls total = 0 bbls Distance to WP03: 4.54', 4.05' low, 2.06' right. 2/21/2020 Drill 12-1/4" Surface Hole F/ 2773' to 3222' MD (449' total = 75fph AROP) 550 GPM, 1940 PSI, 80 RPM, TRQ 6K, WOB 1-4, ECD 9.89 ppg w/ 9.0 ppg MW. P/U 121K, S/O 95K, ROT 102K. Max Gas 60U. End of tangent at 2808', start 5°/100 turn. Backream full stands.;Drill 12-1/4" Surface Hole F/ 3222' to 3603' MD (381' total = 64fph AROP) 550 GPM, 2060 PSI, 80 RPM, TRQ 9K, WOB 3-6, ECD 9.62 ppg w/ 9.0 ppg MW. P/U 135K, S/O 103K, ROT 113K. Max Gas 233U. Continue 5°/100 turn. Backream full stands.;Drill 12-1/4" Surface Hole F/ 3603' to 4016' MD (413' total = 69fph AROP) 550 GPM, 2150 PSI, 80 RPM, TRQ 9- 10K, WOB 14-17, ECD 9.69 ppg w/ 9.0 ppg MW. P/U 148K, S/O 105K, ROT 115K. Max Gas 1088U. Continue 5°/100 turn & build. Backream full stands.;Drill 12-1/4" Surface Hole F/ 4016' to 4366' MD (350' total = 58fph AROP) 550 GPM, 1900 PSI, 80 RPM, TRQ 10-12K, WOB 12-20, ECD 9.6 ppg w/ 8.9 ppg MW. P/U 159K, S/O 105K, ROT 124K. Max Gas 818U. Continue 5°/100 turn & build. Backream full stands.;Daily hauled 1311 bbls to G&I total = 2741 bbls Daily water hauled 1430 bbls from L Pad total = 3410 bbls Daily Fluid lost 0 bbls total = 0 bbls Distance to WP03: 11.02', 9.66' high, 5.31' left 2/22/2020 Drill 12-1/4" Surface Hole F/ 4366' to 4811' MD (445' total = 74fph AROP) 550 GPM, 2100 PSI, 80 RPM, TRQ 10-12K, WOB 12-20, ECD 9.6 ppg w/ 8.9 ppg MW. P/U 168K, S/O 101K, ROT 123K. Max Gas 531U. Continue 5°/100 turn & build. Backream full stands.;Drill 12-1/4" Surface Hole F/ 4811' to 5129' MD (318' total= 45fph AROP) 550 GPM, 2140 PSI, 80 RPM, TRQ 11-13K, WOB 16-18, ECD 9.66 ppg w/ 9.0 ppg MW. P/U 160K, S/O 95K, ROT 115K. Max Gas 652U. Continue 5°/100 turn & build. Backream full stands. Pump high vis sweep at 4,950' with minimal increase.;Multiple issues throughout the day with I/O comms shutting down pumps and or drawworks. At 5129' drillers console shut down for several minutes. CBU reciprocating pipe, 550 gpm,1900psi, 60 rpms, 11Kft-lbs. Rack back one stand. Blow down top drive. Hilcorp IT and electrician troubleshoot issue.;Continue trouble shooting PLC. Reboot main CPU's, clean fiber optics cable and test. No issues detected. Continue circulating after reboot - no issues with PLC. Grease washpipe, service and inspect iron roughneck.;Drill 12-1/4" Surface Hole F/ 5129' to 5217' MD; casing point (88' total= 59fph AROP) 550 GPM, 2175 PSI, WOB 4-9, ECD 9.64 ppg w/ 9.0 ppg MW. P/U 155K, S/O 95K, ROT 115K. Max Gas 405U. Backream full stands. NE sands logged at 5155'.;BROOH from 5,127' to 5,110'. CBU x 2 racking one stand back every bottoms up 550 gpm, 1900 psi, 80 rpms, 12.5Kft-lbs. Max gas 252U, ECD 9.43 ppg. PUW 168K, SOW 98K, ROT 115K. Lowering viscosity for a 23 YP. Monitor well, static. Wash and ream from 5,002' to 5,217'.;BROOH from 5,217' to 3,667' at 550 gpm, 2000 psi, 80 rpms, 10Kft-lbs TQ. Pulling speeds 25- 30 fpm. Max gas 388U. PUW 138K, SOW 101K, ROT 121K. Continue having issues with I/O comms errors shutting down drawworks, mud pumps.;Daily hauled 1487 bbls to G&I total = 4228 bbls Daily water hauled 1560 bbls from L Pad total = 4970 bbls Daily Fluid lost 0 bbls total = 0 bbls Distance to WP03: 8.74', 8.39' low, 2.43' left 2/23/2020 Cont. to BROOH from 3667' to 2776' at 550 gpm, 1800 psi, 80 rpms, 8Kft-lbs. Pulling speeds from 25-30 fpm. PUW 120K, SOW 89K, ROT 99K. Max gas 150U. Issues with I/O comms/PLC system continues to shut down drawworks and mud pumps.;CBU prior to entering tangent section at 550 gpm, 1750 psi, 80 rpms, 7Kft-lbs, reciprocating pipe. Max gas 131U, ECD's 9.87 ppg with 9.05 ppg MW.;BROOH from 2776' to 2585' at 550 gpm, 1750 psi, 80 rpms, 8Kft-lbs. Pulling speeds from 25-30 fpm. PUW 120K, SOW 89K, ROT 99K, Max gas 35U.;Service rig. Reboot I/O switch and router.;Replaced Moxa Ethernet switch for I/O comms/ PLC.;BROOH from 2585' to 867' at 550 gpm, 1500 psi, 80 rpms, 3-8Kft-lbs. Pulling speeds from 25-30 fpm. PUW 96K, SOW 48K, ROT 83K, Max gas 155U. At 1500' slow pulling speed and obtain bottoms up while pulling stand, hole unloaded cleaning up after BU.;BROOH from 867' to 430', 450gpm, 900 psi, 60 rpms, 2000ft-lbs. Pulling speeds from 10-15 fpm as hole dictates. TD stalled (limiter set at 10K) at 860', slack off and obtain rotary. Max gas 155U.;POOH on elevators from 430', rack back HWDP/Jars. L/D (3) DC. Plug in and download MWD. Continue to L/D BHA. Bit grade 1-1-BT-A-E-1-NO- TD.;Clean and clear rig floor of BHA components.;Rig up to RIH with 9-5/8" casing. Bring centralizers to rig floor. M/U Volant CRT tool, bail extensions, elevators, double stack power tongs.;Service rig: grease crown and blocks.;PJSM. RIH with 9-5/8", 40#, L-80 TXP casing. M/U shoe track, baker lock and Install bypass baffle on top of float collar. Check floats - good. PUW 48K SOW 48K. Continue to RIH with 9-5/8" casing to 277'.;Daily hauled 684 bbls to G&I total = 4876 bbls Daily water hauled 650 bbls from L Pad total = 5620 bbls Daily Fluid lost 0 bbls total = 0 bbls 2/24/2020 Cont. to RIH with 9-5/8", 40#, L-80 TXP casing from 277' to 1485'. Make up TQ 21Kft-lbs. PUW 89K, SOW 70K. Work through tight spot from 987' to 1100', washing and reaming periodically at 3.5 bpm, 8 rpms. Fill pipe ever 3-5 joints to prevent freezing up, breaking circulation every 10 joints.;Cont. to RIH with 9- 5/8", 40#, L-80 TXP casing from 1485' to 2189'. Make up TQ 21Kft-lbs. PUW 115K, SOW 70K. Fill pipe ever 3-5 joints to prevent freezing up, breaking circulation every 10 joints.;Circulate bottoms up staging up to 5 bpm, 145 psi, reciprocating pipe. Max gas 12U.;Cont. to RIH with 9-5/8", 40#, L-80 TXP casing from 2189' to 3171' as per tally. Make up TQ 21Kft-lbs. PUW 140K, SOW 83K. Fill pipe ever 3-5 joints to prevent freezing up, breaking circulation every 10 joints. M?U ES cementer as per tally and Bakerloc connections.;Circulate bottoms up at base of tangent reciprocating pipe. Stage pumps up to 5 bpm, 135 psi. PUW 162, SOW 95. Max Gas 25U.;Cont. to RIH with 9-5/8", 40#, L-80 TXP casing from 3171' to 5207'. Make up TQ 21Kft-lbs. PUW 255K, SOW 125K. Fill pipe ever 3-5 joints to prevent freezing up, breaking circulation every 10 joints. Wash last stand down at 3 bpm, 170 psi. Losses while running casing =14.1 bbls.;Circulate 2 x bottoms up. Stage pumps up to 7 bpm in upstroke, 225 psi reciprocating pipe, rotate pipe 1-2 rpms, 15Kft-lbs. Max Gas 89U. PUW 225K, SOW 125K. Blow down top drive.;Monitor well for 30 minutes - static.;Cont. circulating staging pumps up to 7.5 bpm in upstroke, 190 psi. PUW 230K, SOW 130K. Break 20' vent line section and stage cement trucks. Re-install vent line. Maintain constant communication with hands working on vent line. Stage cement trucks. Rig up HES cementers. Blow air to;cementers to ensure line clear. Blow down top drive. Rig up cement hoses to Volant, and break circulation staging up to 7 bpm, 470 psi through the cement line. Pre-Job safety meeting.;Daily hauled 228 bbls to G&I total = 5104 bbls Daily water hauled5250 bbls from L Pad total = 6140 bbls Daily Fluid lost 38 bbls total = 38 bbls Drill 12-1/4" Surface Hole F/ 585' to 984' MD gg RIH with 9-5/8", 40#, L-80 TXP casing. 2/25/2020 1st stage cement: fill lines with 5 bbls H20 and PT 1000/4000 psi -good. HES mixed and pumped: 55 bbls of 10.0 ppg Tuned spacer with Polyflake and red dye 3.5 bpm, 175 psi Drop Bypass plug 157 bbls 12.0 ppg Type I/II lead cementer at 5 bpm, 420 psi 82 bbls 15.8 Class G Tail cement at 5 bpm, 422 psi.;Drop shut off plug, and displace with: 20 bbls water at 3.5 bpm, 150 psi (HES). Swap to rig pumps for 192 bbls 9.2 ppg drilling mud at 6.5 bpm, 338 psi. Swap to cementers for 75 bbls 9.4 ppg tuned spacer (10 below ES cementer, 65 above) at 5 bpm, 315 psi.;Swap to rig pumps for 103 bbls 9.2 ppg drilling mud slow rate to 2 bpm with 10 bbls to go, FCP 680 psi; bumped plug (4 bbls over). Pressure up to 1200 psi and hold for five minutes. Check floats - not holding. Attempt to get floats to hold by pressure up to 1200-1300 psi and rapidly dumping.;Pressure with no success. Pressure up to 1300 psi and hold. Full returns during cement job. CIP at 10:06.;Continue holding psi while WOC. Final psi 1059. SimOps: C/O pressure switch on top drive.;Bleed off csg 1059 psi to 0. 1.5 bbls bled back to static. PSI up on ES cementer and observe tool shift open at 2760 psi. Circ hole clean staging up to 6 bpm, 845 psi. Polyflake observed on shakers at 33 bbls pumped. Observe spacer and slight trace of cement returned @ btms up. Pump 4x btms up.;Overboard a total of 140 bbls contaminated mud, spacer and cmt. Cmt returns confirmed w/ 12.2 PH and .6 ppg inc in MW. Blow down cement line. Flush stack x 2: disconnect Knife valve from accumulator. Drain stack. Fill stack with black water, function annular x3. Reconnect knife valve.;Cont. circulating through ES cementer at 6 bpm, 620 psi while prepping pits for second stage and WOC.;2nd stage cement: fill lines with 5 bbls H20 and PT 1000/4000 psi -good. HES mixed and pumped: 60 bbls of 10.0 ppg Tuned spacer with Polyflake and red dye 4 bpm, 278 psi. Cement wet at 21:56 459 bbls 10.7 ppg Type I/II lead cementer at 5 bpm, 540 psi. Observe contaminated cement at shakers at 339;bbls into lead. Swap to tail once good green cement observed at shakers. 55 bbls 15.8 Class G Tail cement at 4 bpm, 570 psi. Drop closing plug. Displace with HES pumping 20 bbls water at 4.5 bpm, 200 psi. Swap over to rig pumps for 147 bbls of 9.2 ppg mud at 6 bpm, slow to 2 bpm with 15;bbls to go. FCP 500 psi, bump plug 3 bbls over calculated. Pressure up to 1700 psi and observe ES cementer close. Hold pressure for 5 minutes, bleed back 1 bbls and confirm tool closed. CIP at 00:26. No losses during cement job.;120 bbls contaminated cement/mud and 220 bbls green cement returned to surface. Flush cement lines and valve with black water. Blow down and rig down cement line. Flush stack x 2 Drain stack, and fill with black water. Disconnect Knife valve and function bag x 3. Rig down Volant tools.;Install elevators. Remove mouse hole. Hook up bridge crane to stack and remove chains. Remove diverter section in cellar. Unbolt from speed head and deflate air boot. Flush stack.;Lift stack and center casing. Install 'E' slips, set 110K on slips. Prep casing for cut.;Daily hauled 1,202 bbls to G&I total = 6,306 bbls Daily water hauled 910 bbls from L Pad total = 7,050 bbls Daily Fluid lost 0 bbls total = 38 bbls 2/26/2020 PJSM, make final cut on 9-5/8" casing. L/D cut joint (29.32' length). R/D 9-5/8" casing equipment and R/U 5" handling equipment. Hot bolt stack to speed head. M/U Johnny whacker and flush stack w/ black water. B/D TDS. L/D single and johnny whacker. Cont clean pits. Clean pits.;Pull masters and P/U split masters. N/D knife valve, diverter "T", starter head and DSA. Dress 9-5/8" casing stump. L/D surface riser and p/u MPD riser (trip nipple). Mob wear ring, test plug and combo tool to rig floor. SimOps: continue cleaning pits.;Clean and clear cellar. Remove 4" conductor valves and install caps. Install FMC slip lock casing spool. Test slip lock void 2450 psi (80% casing collapse) for 10 minutes - good. Set test plug. SimOps: assist Cat mechanic with Gen #2. Assist Peak welder.;Install DSA. Remove bell nipple from top of annular. Install MPD RCD on top of annular. Tighten all flanges, hook up choke and kill lines. Take on Baradril-N mud.;Cont. to torque all flange bolts. Tighten choke and kill line flange. Install drip pan. R/U beyond 2" and 4" lines. SimOps: service rig floor tuggers. Load BHA in pipe shed.;Flood BOP and MPD lines, purge air. Test MPD system 300 psi/ 5 minutes, 1000 psi/ 15 minutes - good. Blow down lines. Remove test cap and install riser. Flood stack and check for leaks.;Daily hauled 633 bbls to G&I total = 6,939 bbls Daily water hauled 260 bbls from L Pad total = 7,310 bbls Daily Fluid lost 0 bbls total = 38 bbls 2/27/2020 PJSM, R/U BOP test equip.Flood lines, purge air from BOP, choke system. Test BOP's w/ 3.5"& 5" test jts to 250/3000 psi w/ 5 min hold on each. Chart & Record same. LPR (F/P after functioning) w/ 5" test jt. No other test failures. Test gas alarms 10/20 ppm H2S, 20/40% LEL. Test PVT's (good).;Perform Koomey Drawdown - Initial 3000 psi, drawdown 1600 psi, 200 psi increase @ 29 secs, full charge @ 95 secs. 2358 psi 6 bottle avg NO2. Test witnessed by AOGCC rep Brian Bixby. R/D test equipment. Test time F/ 07:00 to 12:30 hrs (5.5 hrs).;Install 9" ID wear bushing (38" length). RIULDS. L/D test joint. Blow down choke, kill lines and choke manifold. Install hydraulic elevators (5"). Service Iron Roughneck.;PJSM, M/U 8.5" Smith Milltooth tricone (used 1,1 in gauge), 6.75" TerraForce mtr w/ 1.5° bend, 6x jts 5" HWDP (NC50), SLB jars (38 hrs), 11x jts 5" HWDP (NC50). Total BHA #2 length = 592.51'.;Pick up, drift and single in the hole with 5" NC50 DP, 19.5# from 592' to 1,991'. Wash down to 2,158', 400 gpm, 660 psi. Calc displacement. PUW 91K, SOW 76K, ROT 86K. Tag cement at 2,158'.;Drill cement, plug and ES cement from 2158' to 2,175'. 400 gpm, 600 psi, 40 rpms, 4.5Kft-lbs. Tag ES cementer on depth. Work through ES cementers with pumps/rotary and no pumps/rotary - clean.;Cont. to pick up, drift and single in hole with 5" drill pipe from 2,178' to 4,088'. PUW 148K, SOW 90K. Calculated displacement observed. Fill pipe and blow down top drive.;Continue to RIH with stands from 4,088' to 4,915. Wash a nd ream through soft cement from 4,915' to 4,987', observe cement firming up at 4,987'. 400 gpm, 661 psi, 40 rpms, 10-14Kft-lbs, WOB 3K. PUW 171K, SOW 94K, ROT 120K.;Circulate bottoms up at 400 gpm, 660 psi, 40 rpms, 14Kft-lbs, reciprocating pipe. Observe cement over shakers firming up at bottoms up.;Blow down top drive, choke and kill lines. Rig up to PT casing, purge air. PT casing to 2500 psi for 30 minutes - good; 3.4 bbls pumped 3.3 bbls returned. Rig down and blow down.;Drill cement from 4987' to 5084' (tag baffle adapter on depth) at 450 gpm, 974 psi, 40 rpms, 10-14Kft-lbs. WOB 6-8K. PUW 165, SOW 94K, ROT 119K.;Daily hauled 82 bbls to G&I total = 7,021 bbls Daily water hauled 130 bbls from L Pad total = 7,440 bbls Daily Fluid lost 0 bbls total = 38 bbls Daily Metal collected 7 lbs total = 7 lbs 2/28/2020 Continue drill shoe track F/ 5084' - T/ 5217' MD (shoe @ 5208'). Drill 20' new formation F/ 5217' - T/ 5237' MD / 4122' TVD. 450 gpm, 975 psi, 40 rpm, 13k, 10- 15 wob. 165k up, 94k dn, 119k rot. Tagged jewelry on depth. Tripped thru clean.;Pump 40 bbls hi/vis sweep. Displace 9.4 ppg spud mud w/ 8.9 ppg Baradril "N". Sweep returned on time. Dump all spud mud/spacer and 30 bbls innerface. 450 gpm, 975 psi, 40 rpm, 10k tq. 8.95 MW In/Out. Thaw mud manifold on rig floor, continue troubleshoot boiler feed pumps.;POOH to 5165' MD. B/D TDS. R/U test equipment. Flood lines and purge air. Perform 12 ppg EMW FIT w/ upper pipe rams. Pump @ 3/4 bpm, 655 psi w/ 8.95 MW, 4122' TVD. 1.2 bbls pumped 1 bbl bled back (test good). R/D and blow down lines.;Monitor well (static). Pump dry job and blowdown lines. POOH on elevators F/ 5165' - T/ 592' (BHA).;L/D excess HWDP. Stand back 1 stand HWDP and Jar stand. L/D motor a bit. Bit grade 1-1-NO-1-E-I-NO-BHA.;Stage tools in shed. Bring TM, DM, float subs to rig floor. Grind bit break down to fit in rotary table breaker. Monitor hole on trip tank - static.;M/U BHA to 307': PDC bit, NRP, Geo-Pilot, ADR/HCIM, ILS, DGR, PWD, DM, TM, float sub. Plug in and download MWD. M/U (3) flex collars, float sub, (2) HWDP, Jars, HWDP. Shallow pulse test - good.;Pick up, drift and single in the hole from 307' to 4567'. Fill pipe and break in Geo- Pilot at 2500'. Cont. to RIH with stand from derrick from 4567' to 5203'. PUW 155, SOW 93K.;Daily hauled 644 bbls to G&I total = 7,665 bbls Daily water hauled 130 bbls from L Pad total = 7,570 bbls Daily Fluid lost 0 bbls total = 38 bbls Daily Metal collected 0 lbs total = 7 lbs Test BOP's w/ 3.5"& 5" test jts to 250/3000 psi w/ 5 min hold on each. Chart 1st stage cement: fill lines with 5 bbls H20 and PT 1000/4000 psi -good. HES mixed and pumped: 55 bbls of 10.0 ppg Tuned spacer with Polyflake and red dye rgpgp p ppg p yy 3.5 bpm, 175 psi Drop Bypass plug 157 bbls 12.0 ppg Type I/II lead cementer at 5 bpm, 420 psi 82 bbls 15.8 Class G Tail cement at 5 bpm, 422 psi.;Drop shut p p ;120 bbls contaminated cement/mud and 220 bbls green cement returned to surface. gg p p pppgp g ;2nd stage cement: fill lines with 5 bbls H20 and PT 1000/4000 psi -good. HES mixed and pumped: 60 bbls of 10.0 ppg Tuned spacer with Polyflakegpg pp ppg py and red dye 4 bpm, 278 psi. Cement wet at 21:56 459 bbls 10.7 ppg Type I/II lead cementer at 5 bpm, 540 psi. Observe contaminated cement at shakers Perform 12 ppg EMW FIT w/ g upper pipe rams. P cement 95/8" p gpp PT casing to 2500 psi for 30 minutes - good; 2/29/2020 PJSM, Cut and slip drilling line (62'). Inspect remaining line on drum (good). Check brakes (brakes). 1436' left on spool.;Grease crown, blocks and drawworks. C/O DS tugger.;Remove trip nipple from RCD head and install bearing. Verify seal w/ 2 bpm via MPD choke (test good).;Kelly up and wash down F/ 5203' - T/ 5237' MD. 450 gpm, 1050 psi, Baseline clean hole ECD's - 500 gpm, 1300 psi, 10.0 ECD / 550 gpm, 1565 psi, 10.06 ECD. 148k up, 90k dn, 114k rot.;Drill 8.5" production lateral F/ 5237' - T/ 6075' (838' total, 140 fph AROP). WOB 8K, 502 gpm, 1500 psi, 100% returns, 120 rpm, 13k tq on, 10.9k tq off, 10.3 ECD's. P/U 168K, S/O 62K, ROT 106K. B/R 15' @ connections. Drilled with MPD bypassed first 200 of lateral to clear leftover debris;from drilling out shoe track. Shakers screened up to 140's all.;Drill 8.5" production lateral F/ 6075' - T/ 6245' (170' total, 113 fph AROP). WOB 9K, 540 gpm, 1720 psi, 100% returns, 120 rpm, 14k tq on, 14k tq off, 10.44 ECD's. Max Gas = 735U. P/U 173K, S/O 63K, ROT 106K. B/R 15' @ connections. Observe surface vibration/pipe chatter. Adjust parameters to;attempt and mitigate with little success.;Observe MPD bearing leaking at 6245'. Attempt to CBU but unable to due to leak. Blow down top drive and beyond. POOH to 6130'. Pull MPD bearing, observe bearing and element apart with (8) 5/8" bolts 2" long missing - suspect down-hole. Install new bearing. Add lubes to active mud pits.;Flood lines, establish circulation at 1.5 bpm and check for leaks, good. Wash down from 6190' to 6245' at 550 gpm, 1650 psi, 80 rpms, 12Kft-lbs. Continue bringing lube concentrations up to 2.5%, appears to mitigate surface vibration/chatter.;Drill 8.5" production lateral F/ 6245' - T/ 6409' (164' total, 82 fph AROP). WOB 13K, 540 gpm, 1765 psi, 120 rpm, 10k tq on, 9.5k tq off, 10.4 ECD's with 9.0 ppg MW. Max Gas = 1050U. P/U 142K, S/O 83K, ROT 108K. B/R 15' @ connections. Pump lube sweep at 6355' to assist in surface vibration.;Drill 8.5" production lateral F/ 6409' T/ 7109' (700' total, 117fph AROP). WOB 18K, 550 gpm, 1890 psi, 140 rpm, 11k tq on, 10k tq off, 10.7 ECD's with 9.0 ppg MW. Max Gas = 1077U, P/U 134K, S/O 82K, ROT 107K. Start planned 4°/100 turn at 6100',;only able to get 2.8°-3.6°/100 DLS . Adjust parameters flow/rotary to increase turn rate. Higher flow/rotary with 20K WOB appears to give best Geo-Pilot output. Start backreaming full stands.;No faults have been crossed so far this lateral. No plugbacks have been drilled. 7 concretions have been drilled so far, for a total footage of 26' (1.5% of the lateral). Total footage in NE sand = 1772' Distance to WP03 = 58.31', 10.54' Low, 57.35' Left;Daily hauled 315 bbls to G&I total = 7,980 bbls Daily water hauled 470 bbls from L Pad total = 8,040 bbls Daily Metal collected 0 lbs total = 7 lbs Total fluid lost surface hole = 38 bbls Daily Fluid lost production 0 bbls total = 0 bbls 3/1/2020 Continue Drlg 8.5" lateral as per geo F/ 7109' - T/ 7872' MD (763' Total. 127 fph AROP).550 gpm, 2015 psi, 15k wob, 140 rpm, 12k tq on, 11k tq off. 818u Max gas. 11.2 ECD's. 146k up, 78k dn, 106k rot. B/R 15-30' between connections. 20L toolface to hold azimuth and Inc w/ 60-70% def. MW 9.3.;Drill 8.5" production lateral F/ 7872'' - T/ 8700' (828' total, 138 fph AROP). WOB 15K, 550 gpm, 2230 psi, 140 rpm, 18k tq on, 15-17k tq off, 11.42 ECD's with 9.3 ppg MW. Max Gas = 1030U. P/U 167K, S/O 57K, ROT 100K. B/R 30' @ connections.;Drill 8.5" production lateral F/ 8700' - T/ 9526' (826' total, 138 fph AROP). WOB 12K, 550 gpm, 2280 psi, 120 rpm, 16k tq on, 185k tq off, 11.76 ECD's with 9.3 ppg MW. Max Gas = 967U. P/U 175K, S/O 70K, ROT 101K. B/R 61' @ connections.;Drill 8.5" production lateral F/ 9526' - T/ 9544' while trouble shooting MWD pulser. Pulser intermittently not pulsing. Contact Halliburton ROC - attempt to reset tools both with downlink and manual, switch modes. Pulser increasingly gets worse and stops pulsing. Rack one stand back.;Pump high vis sweep (on time 20%) and circulate hole clean at 550 gpm, 2120 psi, 120 rpms, 16Kft-lbs recip. pipe. Obtain SPR's 32/48 spm: MP1 327/390, MP2 325/393Blow down top drive. Monitor well through MPD for 15 minutes 3 x buildup with less build up. Third buildup 16 psi in 5 minutes.;BROOH from 9463' to 8699' at 550 gpm, 2060 psi, 120 rpms, 16K ft-lbs. PUW 182K, SOW 70K, ROT 105K. Pulling speed 15-25 fpm as hole dictates.;No faults have been drilled so far this lateral. No plugbacks have been drilled so far. 15 concretions have been drilled so far this lateral for a total footage of 62' (1.4% of the lateral). 4336' drilled in NE sands Distance to WP03 29.54', 28.06' low, 9.21' Right;Daily hauled 1039 bbls to G&I total = 9,019 bbls Daily water hauled 1300 bbls from L Pad total = 9,340 bbls Daily Metal collected 0 lbs total = 7 lbs Total fluid lost surface hole = 38 bbls Daily Fluid lost production 0 bbls total = 0 bbls 3/2/2020 Continue BROOH due to MWD failure F/ 8699' - T/ 6792' MD. 550 gpm, 70 rpm, 14k tq, 171k up, 72k dn, 109k rot. 25-45 fpm as hole allows. Saw slight overpulls w/ slight psi increase at 9° DLS in lateral. Slowed pulling speed to 10 fpm @ 6792' and circulated 2x btms up at speed.;Pumped 40 bbl hi/vis sweep surface to surface at reduced pulling speed (5-10 fpm) w/ minimum increase in cuttings and on time.;Attempt to pull on elevators. Break over @ 210k up then pulled ratty at 170k. Continue BROOH F/ 6792' - T/ 5266'. 550 gpm, 1870 psi, 120 rpm, 14k tq, Pulling 15-40 fpm as hole dictates. Slow pulling speed last 2 stands before shoe and circulate 2 x BU. Max Gas 388U, 175u bgg.;Pull through shoe to 5203' with 125 gpm, 25 rpms. P/U 178K, S/O 78K, ROT 112K. Blow down top drive.;Monitor well - static. Remove MPD bearing and install trip riser. Leak check good. Blow down MPD lines.;POOH from 5203' to 4809'; calc displacement, no indication of swabbing. Pump dry job, blow down TD. Cont. to POOH from 4809' to 307' - calculated displacement.;Rack back Jar stand, HWDP, DC's. Break off float. Nothing noted on top of pulser. Download MWD. L/D BHA. Bit grade 1-1-NO-A-X-I-NO-DTF. Drain stack and inspect for bolts in BOP stack - none found.;Clean and clear rig floor of BHA components. Bring new BHA components to rig floor.;M/U BHA; re-run NOV Bit. M/U Geo-pilot, ADR/HCIM, ILS, DGR, PWD, DM, TM, and float sub. Plug in and upload. RIH with flex collars, HWDP and Jars from derrick. Shallow pulse test MWD tools.;No faults have been drilled so far this lateral. No plugbacks have been drilled so far. 15 concretions have been drilled so far this lateral for a total footage of 62' (1.4% of the lateral). 4336' drilled in NE sands Distance to WP03 29.54', 28.06' low, 9.21' Right;Daily hauled 635 bbls to G&I total = 9,654 bbls Daily water hauled 650 bbls from L Pad total = 9,990 bbls Daily Metal collected 0 lbs total = 7 lbs Total fluid lost surface hole = 38 bbls Daily Fluid lost production 0 bbls total = 0 bbls 3/3/2020 Continue trip in w/ new 8.5" RSS assy F/ 307' - T/ 2533' MD. 86k up, 71k dn.;Fill pipe, break circulation 550 gpm, 988 psi and break in Geo-Pilot as per DD staging up 5,10,20,40,60 rpms w/ 2-3 hold on each while slowly reciprocating pipe. Verify MWD working properly (test good). 105k up, 83k dn.;PJSM, Continue trip in F/ 2533' - T/ 5139' MD. Fill pipe and B/D TDS.;Svc Rig - Grease crown, spinners and TDS.;PJSM, Remove trip nipple and install MPD bearing as per Beyond MPD rep. Verify no leaks (test good).;PJSM Establish hole fill thru kill line and MPD Choke. RIH on elevators F/ 5,139' to 9,544' MD. Filled pipe at 8,100' MD, wiped thru a couple areas while RIH. No issues. Calc Disp. P/U 170K, SLK 90K.;PJSM Drill 8.5" Production Hole F/ 9,544' to 9,800' MD ( 4,089' TVD) total 256' (AROP 102') 550 GPM, 2,170 PSI, 140 RPM, TRQ ON 16-21K, TRQ OFF 16-19K, WOB 9-12K. ECD 11.0. P/U 181K, SLK 59K, ROT 104K. Max Gas 695U. MPD 543 GPM 100% open. Running H2O 40 bph. Both Centrifuges.;Dumped dilute 290 bbls. Pump Lube Pill W/ minimal change in TRQ. No issue with close approach S-20 F/ 9200’-9700’ MD.;PJSM Drill 8.5" Production Hole F/ 9,800' to 10,544' MD ( 4,065' TVD) total 744' (AROP 124') 450-550 GPM, 2,170 PSI, 100-150 RPM, TRQ ON 19.5-25K, TRQ OFF 21-23K, WOB 3-18K. ECD 10.86. P/U 215K, SLK 55K, ROT 103K. Max Gas 930U. MPD 488 GPM 100% open. Back ream 10' ea stand.;Increased Lubes F/ 2% to 2.75% to control TRQ F/ 24K to 20K average. Adjusting parameters for concretion, at 10,154' MD 8°/100 DLS putting us 40' left. INC good.;SPR @ 10,033' MD (4,079' TVD) MW 9.25 MP #1 32-265, 48-335 MP #2 32-270, 48-343.;PJSM Drill 8.5" Production Hole F/ 10,544' to 11,243' MD ( 4,073' TVD) total 699' (AROP 116') 550 GPM, 2,265 PSI, 150 RPM, TRQ ON 16-19K, TRQ OFF 15-17K, WOB 8- 14K. ECD 11.25. P/U 192K, SLK 48K, ROT 104K. Max Gas 1,263U. MPD 537 GPM 100% open. Back ream 10' ea stand.;SPR @ 11,050' MD (4,067' TVD) MW 9.15 MP #1 32-300, 48-366 MP #2 32-298, 48-360.;No faults have been drilled so far this lateral. No plugbacks have been drilled so far. 20 concretions have been drilled so far this lateral for a total footage of 105' (1.8% of the lateral). 5,952' drilled in NE sands Max Gas 24 hrs 1,263U. Distance to WP03 32.43', 7.52' High, 25.76' Left;Daily hauled 519 bbls to G&I total = 10,173 bbls Daily water hauled 520 bbls from L Pad total = 10,510 bbls Daily Metal collected 5 lbs total = 12 lbs Total fluid lost surface hole = 38 bbls Daily Fluid lost production 0 bbls total = 0 bbls 3/4/2020 PJSM Drill 8.5" Production Hole F/ 11,243' to 12,134' MD ( 4,069' TVD) total 891' (AROP 148.5') 550 GPM, 2,400 PSI, 150 RPM, TRQ ON 16-20K, TRQ OFF 19K, WOB 8-16K. ECD 11.56. P/U 188K, SLK 35K, ROT 104K. Max Gas 1,269U. MPD 535 GPM 100% open. Back ream 30' ea stand.;Went out of top of NE Sand at 12,006' back into NE Sand at 12,488' MD. Started 4°/100 to left at 12,000' MD due to close approach. SPR @ 11,622' MD (4,087' TVD) MW 9.2. MP #1 32-315, 48-385. MP #2 32-318, 48-390.;PJSM Drill 8.5" Production Hole F/ 12,134' to 12,768' MD ( 4,088' TVD) total 634' (AROP 105.6') 515 GPM, 2,380 PSI, 120-150 RPM, TRQ ON 16-20K, TRQ OFF 17K, WOB 10-17K. ECD 11.59. P/U 168K, SLK 54K, ROT 96K. Max Gas 793U. MPD 504 GPM 100% open. Back ream 60' ea stand. Max ROP 280 ft/hr.;SPR @ 12,705' MD (4,085' TVD) MW 9.25. MP #1 32-312, 48-386. MP #2 32-310, 48-387.;PJSM Drill 8.5" Production Hole F/ 12,768' to 13,533' MD ( 4,096' TVD) total 765' (AROP 127.5') 500 GPM, 2,300 PSI, 150 RPM, TRQ ON 18K, TRQ OFF 20K, WOB 7-10K. ECD 11.64. P/U 177K, SLK 35K, ROT 100K. Max Gas 1,350U. MPD 493 GPM 100% open. Back ream 60' ea stand. Max ROP 250 ft/hr.;AT 13,016' MD close approach to H- 08 80' CC. At 13,461' MD close approach to S-29 67' CC. SPR @ 13,210' MD (4,090' TVD) MW 9.25. MP #1 32-317, 48-399. MP #2 32-316, 48-393.;PJSM Drill 8.5" Production Hole F/ 13,533' to 13,680' MD (TD) ( 4,101' TVD) total 147' (AROP 98') 500 GPM, 2,390 PSI, 150 RPM, TRQ ON 19.5K, TRQ OFF 20K, WOB 10-15K. ECD 11.84. P/U 178K, SLK 35K, ROT 98K. Max Gas 957U. MPD 492 GPM 100% open. Back ream 60' ea stand. Max ROP 250 ft/hr.;PJSM Pump Tandem 30 bbl 9.15 ppg 35 Vis and 30 bbl 9.3 ppg 182 Vis sweeps. BROOH F/ 13,690' to 13,470' MD (3 stands) 4 BU 525 GPM, MPD 502 GPM, 2,360 PSI, 160 RPM, TRQ 19K, Max Gas 764U, BGG 180U, ECD 11.8, P/U 186K, SLK 35K, ROT 98K. Sweep back 2,000 Stks early minimal cuttings at Shakers.;SIMOPS Build SAPP Pills, Off load mud F/ Pits and prep for displacement. Stage and hook up Vac Trucks. Bring centralizers to rig floor.;Wash down F/ 13,470' to 13,680' MD. 525 GPM, MPD 515 GPM, 2,350 PSI, 160 RPM, TRQ 17K, P/U 186K, SLK 35K, ROT 98K. Cont prepping Pits for displacement.;No faults have been drilled so far this lateral. 27 concretions have been drilled so far this lateral for a total footage of 152' (1.8% of the lateral). 7990' drilled in NE sands, 482' drilled out of NE Sand Max Gas 24 hrs 1,350U. Distance to WP03 53.32', 17.91' Low, 50.22' Left.;Daily hauled 1,074 bbls to G&I total = 11,247 bbls Daily water hauled 1,300 bbls from L Pad total = 11,810 bbls Daily Metal collected 0 lbs total = 12 lbs Total fluid lost surface hole = 38 bbls Daily Fluid lost production 0 bbls total = 0 bbls 3/5/2020 PJSM, Displace 9.25 Baradril "N" w/ 9.2 "Quick Dril" lubricated brine (2%). Prior to disp - 8 bpm, 1350 psi, 160 rpm, 22k tq. 186k up, No Dn, 98k rot. Pump 3x 35 bbl Sapp pills with 25 bbl spacers between. Follow Sapp pill with Quik Dril. Post disp - 8 bpm, 895 psi, 160 rpm, 24-26k tq.;Max gas 211u. 10.5 ECD's, 215k up, No Dn, 106k rot. Monitor well after brine displacement. 14 gpm initial flow, trended down to 6.9 gpm over 10 min. L/D single, Drop 2.38" metal drift (no wire).;BROOH F/ 13,680' - T/ 12,898' MD. 20 fpm first 500' then increase to 30-40 fpm. 515 gpm, 1775 psi, 120 rpm, 17k tq, 120u BGG. 10.76 ECD's. 190k up, No Dn, 113k rot.;Continue BROOH F/ 12898' - T/ 10,770' MD. Max pulling speed 35 fpm as hole allows. 515 gpm, 1775 psi, 120 rpm, 18k tq. 10.8 ECD's. 12040' shakers blinded off. Reduce pulling speed and pump rate allowing time for shakers to clean up (1x btms up over 1 std). Then cont at previous pull speed.;PJSM Cont. BROOH F/ 10,770' to 8,762' MD 515 GPM, 1,520 PSI, MPD 478 GPM, 130 RPM, TRQ 16.5K, ECD 10.22, P/U 185K, SLK 75K, ROT 113K. BGG 180U. Pulling speed 35 ft/min as hole dictates. At 9,560' pulled at 3 ft/min for 2 stands CBU 1.5X hole unloaded at Shakers reduced flow to 330 GPM, 840 PSI.;W/ Max Gas 1,100U. MPD density out climbed to 10.11 ppg.;PJSM Cont. BROOH F/ 8,762' to 6,539' MD 535 GPM, 1,650 PSI, MPD 495 GPM, 130 RPM, TRQ 16K, ECD 10.02, P/U 172K, SLK 82K, ROT 114K. BGG 130U. Pulling speed 35-40 ft/min as hole dictates.;At 7,600' & 6,570' MD pulled at 3-5 ft/min for 2 stands CBU 1.5X hole unloaded at Shakers reduced flow to 400 GPM, 1,030 PSI W/ Max Gas 896U. MPD density out climbed to 9.9 ppg.;Daily hauled 2,292 bbls to G&I total = 13,539 bbls Daily water hauled 910 bbls from L Pad total = 12,720 bbls Daily Metal collected 0 lbs total = 12 lbs Total fluid lost surface hole = 38 bbls Daily Fluid lost production 0 bbls total = 0 bbls 3/6/2020 Continue BROOH F/ 6539' - T/ 5390' MD. 25-35 fpm, 550 gpm, 1620 psi, 120 rpm, 10k, 348u max gas, 110u bgg, 162k up, 81k dn, 110k rot.;Pump 35 bbl hi vis 9.2 ppg sweep @ 5390' MD pulling at reduced speed (5-10 fpm), 120 rpm, 10k, 550 gpm, 1650 psi. Circulated a total of 2x btms up while racking back 2 stands. 20% inc in cuttings from sweep then cleaned up.;Attempt to straight pull with no rotary F/ 5390' up into shoe. Pulled tight @ 5330' w/ 30k over (160k up clean). Rot/pump backream up thru tight spot @ 5330' to 5303' before stalling w/ 16k, 80 rpm, 420 gpm. Saw no pump psi increase working thru tight spots. S/O and work thru on 3rd attempt.;Continue backream up slowly with erratic tq and frequent 10-20k overpulls F/ 5303' - T/ 5280' MD. Pulled tight @ 5280' w/ 16k stall and 30k overpull. S/O and adjust tq limit to 18k. Backream up @ 80rpm, 420 gpm, 890 psi, 10k tq. Stalled @ 5280' w/ 18k tq, 40k overpull.;Bumped dn 5x before free pipe. Again there was no psi change only erratic tq and overpull (DM/TM collar at shoe). Slowly backream up thru tight spot @ 5280' with max pulling speed 2 fpm. Saw erratic 8k tq swings with 10k bobbles but worked past 5280' into 9-5/8" shoe.;Tq and overpulls cleaned up once 5' inside shoe. CBU inside shoe rot/recip F/ 5203' -T/ 5140' MD. 550 gpm, 1620 psi, 60 rpm, 7k tq, 145k up, 92k dn, 114k rot. No inc in cuttings @ btms up. Shut down and monitor well (static). Spot 40 bbl lube pill outside BHA displacing with dry job. B/D TDS.;Rig Svc - Grease crown, blocks, TDS, and spinners. Inspect top drive and check oil (good).;Well (static). Remove MPD bearing and install trip nipple. Check for leaks on stack (no leaks). B/D MPD lines.;POOH laying down 5" NC50 dp F/ 5203' - T/ 307' MD. Trip showed 21 bbl loss to hole. No overpull or obstructions on trip out from shoe.;PJSM L/D BHA - 5" HWDP, Jars, NM Flex (pulled corrosion ring from flex DC's), F/S (found 2.38" drift on top float sub). Clean floor and download MWD. B/O and L/D smart tools, Geo Pilot and Bit. BHA had no excessive wear. Bit Grade 1-1-NO-A-X-I-NO-TD.;PJSM Clean and clear rig floor of BHA components. Bring up 9 5/8" Scrapper BHA to rig floor.;PJSM Scope out top drive and inspect cradle, frame extend, welds, pins and hinges. Good. Grease Blocks.;PJSM M/U Mule Shoe, 9 5/8" Scrapper and bit sub to 5" D.P. as per Baker Rep onsite. RIH W/ 5" D.P. F/ 8' to 5,190' MD. L/D working Jnt. No issues RIH. Fill pipe at 2,500' MD. P/U 118K, SLK 90K. Lost 13 bbls for trip.;PJSM Hang Blocks, cut 69' 11 wraps. 1,367' on spool. Accum TM 27,817. Check Brakes. Perform EAM for Crown and Block sheaves wobble. Unhang Blocks. Set Top Drive and Drawwork limits. SIMOPS Remove 2 links F/ drag chain. Blow down Geo Span. Static loss 1.5 BPH.;PJSM POOH L/D 5" D.P. F/ 5,160' to 3,294' MD. P/U 95K, SLK 84K. Flag CATV D.P. in pipe shed. Calc Disp 32bbls, actual 35 bbls, Lost 3 bbls.;Daily hauled 500 bbls to G&I total = 14,039 bbls Daily water hauled 520 bbls from L Pad total = 13,240 bbls Daily Metal collected 0 lbs total = 12 lbs Daily Fluid lost production 32 bbls total = 32 bbls Total fluid lost surface hole = 38 bbls 3/7/2020 PJSM POOH L/D 5" D.P. F/ 3,294' to surface.. B/O and L/D scraper assy. Flag CATV D.P. in pipe shed. 9 total bbl loss for trip out.;PJSM, M/U 5" safety jt. Prep pipeshed for running liner. R/U 250T YC 6-5/8" casing elevators, Double stack power tongs and slips.;PJSM, M/U ported eccentric shoe (open profile / no float). Run 6-5/8" 563 Wedge, 20#, L-80 slotted liner as per detail F/ surface to 8750' MD. 7.1k opt M/U tq. Install 215 total 7-5/8" OD solid straight blade centralizers as per tally. Lost 12 bbls while running 6-5/8".;PJSM P/U M/U 5.29' 2 3/8" Shear out ball Assy to SLZXP. M/U SLZXP to 6 5/8" Liner. Setting tool shear 8 screws 2,648 PSI, Neutralizer 14 screws 4,186 PSI. RIH W/ 1 stand 5" D.P. to 8,855' MD. Circ thru SLZXP 1 bpm, 60 PSI, 3 bpm, 130 PSI, 5 bpm, 335 PSI. P/U 149K, SLK 69K. Blow down TD.;PJSM Convey 6 5/8" Liner W/ 5" D.P. F/ Derrick F/ 8,855' to 10,636' MD. Work tight hole at 10,100', 10,480' & 10,650' MD. P/U 149K, SLK 69K. SIMOPS Process 80 Jnts Yellow Jacket 5" HWDP in Pipe Shed. AVG 60-90 ft/min.;PJSM Convey 6 5/8" Liner W/ 20 jnts 5" HWDP single in hole F/ 10,636' to 11,258' MD. (Rabbit OD 2.75") P/U 205K, SLK 67K. AVG 60-90 ft/min.;PJSM Convey 6 5/8" Liner W/ Yellow Jacket 5" HWDP single in hole F/ 11,258' to 12,367' MD. P/U 265K, SLK 75K. (Rabbit OD 2.75"). Break in threads, M/U Break out 2X. Work tight spots 11,838', 11,880', F/ 12,160' to 12,366' MD Max P/U 300K.;PJSM Convey 6 5/8" Liner W/ Yellow Jacket 5" HWDP single in hole F/ 12,367' to 13,658' MD. P/U 285K, SLK 90K (Rabbit OD 2.75"). Break in threads, M/U Break out 2X. Work tight spots 12,693 & 12,860' MD W/ minor areas after that. D Max P/U 315K. Lost 22 bbl for RIH W/ D.P. and HWDP.;After making up last Jnt at 13,658' MD lost string weight. Started working string up to 350K W/ no slack weight F/ 13,658 to 13,645'. Worked 6K TRQ in String W/ little success. L/D working single. M/U 5" HWDP stand and kelly up. Break Circ at 3 bpm, 250 PSI, F/O 27%.;Working string up to 450K W/ no SLK WT. Increase pump rate to 4 bpm, 390 PSI F/O 32%. Discussed W/ town to set Liner at current depth 13,658' MD. L/D 5" HWDP 2 jnts to Pipe Shed. P/U M/U 5' pup, Head Pin and HP Lines.;Daily hauled 299 bbls to G&I total = 14,338 bbls Daily water hauled 130 bbls from L Pad total = 13,370 bbls Daily Metal collected 0 lbs total = 12 lbs Daily Fluid lost production 63 bbls total = 99 bbls Total fluid lost surface hole = 38 bbls 3/8/2020 Circulate 2.5x dp vol @ 4877' (TOL). 3 bpm, 260 psi. Last clean wts 27k up, 90k dn. Drop 29/32" phenolic ball. Pump dn @ 3 bpm reducing rate to 2 bpm, 150 psi @ 500 stks (928 calc to bump). Put ball on seat @ 632 stks, psi up to 600 psi. Walk psi up to 3000 psi. Saw setting tool shift @ 2900.;Hold 3000 psi 5 min, S/O to 84k. Walk psi up to 3600 psi w/ MP #1, shut in mud pumps and continue walk psi up with test pump to 4300 psi to neutralize pusher tool. Observed psi fall off @ 4300 psi to 60 psi. P/U 8' w/ free up wt 198k. Park and R/U to test annulus.;R/U test equipment. Purge air from kill, choke line and manifold. Shut in and pump 1/2 bpm, psi up to 1500 psi on 7" x 9-5/8" annulus w/ 10 min hold. 1.8 bbls pumped, 1.7 bled back. Test good. Chart and record same. R/D test equipment and B/D same.;Clear packoff from liner top and establish circulation staging up to 10 bpm, 875 psi, 10 rpm, 6.2k tq. Rot/Recip slowly and displace wellbore to 9.2 filtered brine. 360 bbls pumped.;Monitor well (slight flow) after 10 min. B/D TDS. Work pipe and continue to monitor (appears well is slightly out of balance). Pull 5 stds wet and monitor (Took proper displacement, Well static). Pull 5 more stand wet (proper displacement). Pump dry job W/ Corrosion Inhibitor, B/D TDS.;Continue trip out laying down 5" NC50 HWDP (Yellow Jacket pipe) POOH F/ 4785' - T/ 3895' MD. Hole took proper displacement.;Svc Rig - Grease blocks, TD and Iron Roughneck.;Continue POOH laying down 5" NC50 HWDP F/ 3895' - T/ 2509' MD. Hole took proper displacement.;TIH F/ 2509' - T/ 4372' MD with excess 5" DP out of derrick. Hole took proper displacement. POOH Laying down 5" NC50, 19.5#, S-135 drill pipe F/ 4,172' - T/ surface. B/O and L/D LRT. Tool showed indicators of good set. Activity Date Ops Summary 3/8/2020 Circulate 2.5x dp vol @ 4877' (TOL). 3 bpm, 260 psi. Last clean wts 27k up, 90k dn. Drop 29/32" phenolic ball. Pump dn @ 3 bpm reducing rate to 2 bpm, 150 psi @ 500 stks (928 calc to bump). Put ball on seat @ 632 stks, psi up to 600 psi. Walk psi up to 3000 psi. Saw setting tool shift @ 2900.,• Hold 3000 psi 5 min, S/O to 84k. Walk psi up to 3600 psi w/ MP #1, shut in mud pumps and continue walk psi up with test pump to 4300 psi to neutralize pusher tool. Observed psi fall off @ 4300 psi to 60 psi. P/U 8' w/ free up wt 198k. Park and R/U to test annulus,,R/U test equipment. Purge air from kill, choke line and manifold. Shut in and pump 1/2 bpm, psi up to 1500 psi on 7" x 9-5/8" annulus w/ 10 min hold. 1.8 bbls pumped, 1.7 bled back. Test good. Chart and record same. R/D test equipment and B/D same.,Clear packoff from liner top and establish circulation staging up to 10 bpm, 875 psi, 10 rpm, 6.2k tq. Rot/Recip slowly and displace wellbore to 9.2 filtered brine. 360 bbls pumped.,1130 Monitor well (slight flow) after 10 min. B/D TDS. Work pipe and continue to monitor (appears well is slightly out of balance). Pull 5 stds wet and monitor (Took proper displacement, Well static). Pull 5 more stand wet (proper displacement). Pump dry job W/ Corrosion Inhibitor, B/D TDS.,Continue trip out laying down 5" NC50 HWDP (Yellow Jacket pipe) POOH F/ 4785' - T/ 3895' MD. Hole took proper displacement.,Rig Svc - Grease blocks, TDS and Iron Roughneck.,Continue POOH laying down 5" NC50 HWDP F/ 3895' - T/ 2509' MD.,TIH F/ 2509' - T/ 4372' MD with excess 5" DP out of derrick. POOH Laying down 5" NC50, 19.5#, S-135 drill pipe F/ 4,172' - T/ surface. B/O and L/D LRT. Tool showed indicators of good set. Lost 9 bbls tripping and L/D pipe.,PJSM Drain Stack. P/U Safety Jnt and break off 6 5/8" XO. M/U Wear Ring puller. ROLDS. Pull Wear Ring. M/U 7" TCP XO to Safety Jnt. Set down in Pipe Shed.,PJSM Dummy run Hanger/ Landing Jnt 24.83' RKB to top of Hanger.,PJSM R/U Weatherford Power Tongs, C/O Elevators and install air slips. SIMOPS Load Pups in Pipe Shed. Work on drag chain. Static loss rate 1.5 bph.,PJSM P/U Seal Assy and inspect seals and ports. 15.40' Lngt, 7.375" OD, 6.19" ID,, 1.86' to 4 ea 1.0" Ports, 9.59' to No/Go. Start threads by hand to Jnt 1 of 7" 26# L-80 TXP. RIH to 1,990' MD. TRQ connection 14,750 ft/lb. P/U 80K, SLK 76K. Lost 4 bbls.,PJSM RIH 7"26# L-80 TXP. RIH F/ 1,990' to 4,878' MD. Set down 10K 3x. Perform space out, L/D 3 Jnts P/U M/U Pups (14.83', 2.60', 1.84') M/U Jnt 119 and Hanger W/ Landing Jnt. P/U 141K, SLK 106K. TRQ connection 14,750 ft/lb. Lost 3 bbls.,PJSM Land Hanger TOL 4,868.58' 1.41' off No/Go. 8.18' seals swallowed. M/U 7 " TXP X/O to FOSV. M/U to 7" Landing Jnt. Kelly up. Close Annular and Press up to 500 PSI, good. Bleed down to 250 PSI and strip up. Press. dropped and Line up to reverse Circ.,Daily hauled 647 bbls to G&I total = 14,985 bbls Daily water hauled 130 bbls from L Pad total = 13,500 bbls Daily Metal collected 0 lbs total = 12 lbs Daily Fluid lost production 12 bbls total = 111 bbls Total fluid lost surface hole = 38 bbls 3/9/2020 PJSM Reverse Circ. 7" X 9 5/8" annulus 60 bbls 9.2 ppg Corrosion Inhibited Brine at 6 bpm, 450 PSI. Shut Down. PT LRS to 1,500 PSI. LRS reverse Circ. 75 bbls Diesel at 2 BPM ICP 20 PSI, FCP 303 PSI. SIMOPS: Cont process 3.5" Tubing in Pipe Shed.,PJSM Strip thru Annular and land Hanger. SLK 71K. R/D lines and L/D Landing Jnt. P/U 5" Jnt and set Pack Off. RILDS. 2 LDS had bad Junk Rings, replaced. Test Pack Off 5 min 500 PSI, 15 Min 5,000 PSI, good. Test 7" X 9 5/8" annulus to 1,000 PSI for 30 min. R/D test Equip.,SIMOPS: Process 3.5" Tubing in Pipe Shed. Bring in all jewelry. R/U Weatherford 3.5" tools.,PJSM Break down 7" Safety Jnt. Clean and clear rig floor. SIMOPS Clean Pits.,PJSM Bring up 38 Tech Clamps & 59 Cross Collar Clamps. R/U Baker Centrilift tools. R/U Tech wire spool and hang sheave. 160 Jnts 3.5" in shed.,PJSM P/U M/U 3.5" WLEG, 3.5" EUE 9.3# L-80 Tubing, 2.75" XN, Halliburton 7" PHL Hydraulic-Set Perma-Latch Retrievable Packer, 1 Jnt 3.5" Tubing, 2.813" X , Centrilift Suction Gauge 331' MD. TRQ connections 3.2K.,Baker Centrilift Suction Gauge line fitting was incorrect. Baker went to shop and made correct fitting . Brought back another Discharge Gauge to C/O on in tally due to wrong threads for SS line.,RIH 3.5" HES Durasleeve (2.813" ID), C/O Discharge Gauge. Galled 10' handling pup. Put Discharge Gauge on bottom of full joint.,PJSM Cont RIH 3.5" Tubing F/ 377' to 4,978' MD. P/U 71K, SLK 61K. Lost 11 bbls. Test Tech line every 1,000'. Ran clamps every other jnt. Removed GLM as per engineer. Ran 155 Jnts, 38 Tech Clamps, 40 Cross Collar Clamps.,PJSM M/U X/O to Landing Jnt 3.5" EUE X TCII. P/U M/U Hanger. Terminate Tech Wire and test. PSI 1,932.92, Temp 78.8, Vz o, Volt 20.7. Land Hanger 4,978' MD. Set 42K on Hanger. RILDS.,PJSM M/U Head Pin to 3.5" Landing Jnt and HP Hoses. R/U IA for returns. Drop 1 9/16 OD Ball and Roller Rod. Wait 15 Min to land. SIMOPS R/D Baker tools and Equip. Start pumping at 1/4 bpm and ball seated in 15 Stks. Cont Press up to 1,700 PSI for 2 Min, Cont Press up to 3,000 PSI and hold for 5 min. Cont to Press up to 3,500 PSI for 30 min (good) all on chart. Pumped 1.67 bbls, bled 1.6 bbls.,Swap HP hoses to IA 3.5" X 7" Annulus. Pump 3/4 BPM Press up to 3,500 PSI for 30 Min (good) on chart. Pumped 1.86 bbls, bled 1.8 bbls. R/D test Equip and HP hoses. L/D Landing Jnt. R/D Weatherford.,Daily hauled 114 bbls to G&I total = 15,099 bbls Daily water hauled 0 bbls from L Pad total = 13,500 bbls Daily Metal collected 0 lbs total = 12 lbs Daily Fluid lost production 10 bbls total = 121 bbls Total fluid lost surface hole = 38 bbls n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: MP S-57 Milne Point Unit Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:2010572C MPU S-57 Completion Spud Date: pp pp pp p pp Park and R/U to test annulus,,R/U test equipment. Purge air from kill, choke line and manifold. Shut in and @p p p qp g pump 1/2 bpm, psi up to 1500 psi on 7" x 9-5/8" annulus w/ 10 min hold. 1.8 bbls pumped, 1.7 bled back. Test good. 3/10/2020 PJSM Set BPV. Johnny Wack Stack. Flush thru all surface Equip. Drain Stack.,PJSM Remove Koomey lines. Unbolt MPD. Pull Riser. R/D 4" MPD lines. Remove Choke and Kill. Remove drip pan. Install MPD plug and boty up clamp. Hook slings and shackles F/ Top Drive to MPD plug. SIMOPS R/D rig tongs. Install Matt Boards around S-56. Load and process 5" D.P. in Pipe Shed. Begin cleaning Pits.,PJSM Lift MPD and rack back BOP on pedestal and secure. Pull DSA off Well Head. Lower MPD and set in cellar. SIMOPS Process 5" D.P., clean Pits & MP inspection.,PJSM Install CTS on BPV. Prep Tech line and clean ring groove. Terminate Tech wire thru Well Head. Trq Dry Hole Tree to Spec. Install 3.125" valve on top of Tree. Test void and Tree 500 PSI low 5 min & 5,000 PSI 15 min. Pull BPV and shut in Master. SIMOPS Cont processing 5" D.P. & MP inspection.,PJSM Bridal up and scope down Derrick. Cont cleaning Pits. Finish processing 5" D.P. Get stair landings ready. Prep Equip for move. Swap to cold start power @ 22:30.,PJSM Disconnect service lines. Peak on location at 00:00. Stage Pipe Shed, Gen Mod, Mud Mod and Cattle Schute. Put heaters & hooch's on all Mods. Walk Sub off S-57 and begin walking to S-56. SIMOPS install Slip Lock Head and Diverter Tee on S-56. SIMOPS OPS put heater on S-56 Tree and R/U scaffolding.,Daily hauled 464 bbls to G&I total = 15,563 bbls Daily water hauled 120 bbls from L Pad total = 13,620 bbls Daily Metal collected 0 lbs total = 12 lbs Daily Fluid lost production 0 bbls total = 101 bbls Total fluid lost surface hole = 38 bbls 05 March, 2020 Milne Point M Pt S Pad MPU S-57 MPU S-57 500292366600 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Halliburton Definitive Survey Report Well: Wellbore: MPU S-57 MPU S-57 Survey Calculation Method:Minimum Curvature MPU S-57 Actual RKB @ 63.49usft Design:MPU S-57 Database:NORTH US + CANADA MD Reference:MPU S-57 Actual RKB @ 63.49usft North Reference: Well MPU S-57 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 S-57 usft usft 0.00 0.00 5,999,908.82 565,567.71 36.30Wellhead Elevation:usft0.50 70° 24' 36.716 N 149° 27' 57.973 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU S-57 Model NameMagnetics BGGM2019 2/7/2020 16.06 80.84 57,373.40541070 Phase:Version: Audit Notes: Design MPU S-57 1.0 ACTUAL Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:27.19 348.730.000.0027.19 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 3/5/2020 Survey Date 3_Gyro-GC_Csg H049Gb: North seeking on wireline in casing100.00 1,405.00 MPU S-57 Gyrodata E-Line Gyro (MPU S 02/06/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa1,443.52 5,158.47 MPU S-57 MWD+IFR2+MS+Sag (1) (MP 02/21/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa5,226.74 13,611.39 MPU S-57 MWD+IFR2+MS+Sag (2) (MP 03/02/2020 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 27.19 0.00 0.00 27.19 0.00 0.00-36.30 5,999,908.82 565,567.71 0.00 0.00 UNDEFINED 100.00 0.18 132.86 100.00 -0.08 0.0836.51 5,999,908.74 565,567.79 0.25 -0.09 3_Gyro-GC_Csg (1) 144.00 0.23 140.80 144.00 -0.19 0.1980.51 5,999,908.63 565,567.90 0.13 -0.23 3_Gyro-GC_Csg (1) 205.00 0.42 121.33 205.00 -0.40 0.46141.51 5,999,908.42 565,568.17 0.36 -0.49 3_Gyro-GC_Csg (1) 268.00 1.63 134.52 267.99 -1.15 1.29204.50 5,999,907.68 565,569.01 1.94 -1.38 3_Gyro-GC_Csg (1) 333.00 3.21 140.12 332.93 -3.20 3.12269.44 5,999,905.65 565,570.86 2.45 -3.75 3_Gyro-GC_Csg (1) 393.00 4.71 141.65 392.78 -6.42 5.73329.29 5,999,902.45 565,573.49 2.51 -7.41 3_Gyro-GC_Csg (1) 455.00 6.49 139.33 454.48 -11.07 9.59390.99 5,999,897.83 565,577.40 2.89 -12.73 3_Gyro-GC_Csg (1) 517.00 8.37 135.95 515.96 -16.97 15.01452.47 5,999,891.98 565,582.87 3.11 -19.58 3_Gyro-GC_Csg (1) 579.00 10.45 130.72 577.12 -23.89 22.41513.63 5,999,885.13 565,590.33 3.62 -27.81 3_Gyro-GC_Csg (1) 642.00 12.68 129.95 638.84 -32.05 32.04575.35 5,999,877.05 565,600.03 3.55 -37.70 3_Gyro-GC_Csg (1) 705.00 15.20 129.50 699.98 -41.75 43.72636.49 5,999,867.46 565,611.79 4.00 -49.49 3_Gyro-GC_Csg (1) 3/5/2020 1:14:49PM COMPASS 5000.15 Build 91E Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Halliburton Definitive Survey Report Well: Wellbore: MPU S-57 MPU S-57 Survey Calculation Method:Minimum Curvature MPU S-57 Actual RKB @ 63.49usft Design:MPU S-57 Database:NORTH US + CANADA MD Reference:MPU S-57 Actual RKB @ 63.49usft North Reference: Well MPU S-57 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 769.00 17.40 131.26 761.41 -53.40 57.39697.92 5,999,855.93 565,625.56 3.52 -63.58 3_Gyro-GC_Csg (1) 832.00 18.39 137.56 821.36 -66.95 71.18757.87 5,999,842.51 565,639.46 3.45 -79.57 3_Gyro-GC_Csg (1) 896.00 18.59 141.59 882.06 -82.39 84.33818.57 5,999,827.18 565,652.75 2.02 -97.28 3_Gyro-GC_Csg (1) 960.00 19.17 147.15 942.62 -99.21 96.37879.13 5,999,810.47 565,664.93 2.95 -116.13 3_Gyro-GC_Csg (1) 1,024.00 20.25 154.32 1,002.88 -118.03 106.87939.39 5,999,791.75 565,675.60 4.13 -136.64 3_Gyro-GC_Csg (1) 1,088.00 21.53 158.43 1,062.68 -138.93 115.99999.19 5,999,770.93 565,684.90 3.04 -158.92 3_Gyro-GC_Csg (1) 1,151.00 22.02 159.65 1,121.18 -160.76 124.341,057.69 5,999,749.18 565,693.45 1.06 -181.96 3_Gyro-GC_Csg (1) 1,215.00 24.22 163.39 1,180.04 -184.59 132.271,116.55 5,999,725.42 565,701.58 4.13 -206.88 3_Gyro-GC_Csg (1) 1,278.00 25.03 166.47 1,237.31 -209.93 139.081,173.82 5,999,700.14 565,708.62 2.41 -233.06 3_Gyro-GC_Csg (1) 1,342.00 25.79 169.24 1,295.12 -236.77 144.851,231.63 5,999,673.35 565,714.62 2.20 -260.52 3_Gyro-GC_Csg (1) 1,405.00 27.58 171.54 1,351.41 -264.67 149.551,287.92 5,999,645.50 565,719.57 3.28 -288.79 3_Gyro-GC_Csg (1) 1,443.52 28.97 172.77 1,385.34 -282.74 152.041,321.85 5,999,627.45 565,722.21 3.91 -307.00 3_MWD+IFR2+MS+Sag (2) 1,507.03 31.92 172.28 1,440.08 -314.64 156.231,376.59 5,999,595.59 565,726.68 4.66 -339.11 3_MWD+IFR2+MS+Sag (2) 1,570.77 31.68 172.55 1,494.25 -347.94 160.671,430.76 5,999,562.34 565,731.41 0.44 -372.63 3_MWD+IFR2+MS+Sag (2) 1,634.53 32.48 173.81 1,548.28 -381.56 164.681,484.79 5,999,528.76 565,735.72 1.64 -406.39 3_MWD+IFR2+MS+Sag (2) 1,698.09 31.60 174.92 1,602.16 -415.11 168.001,538.67 5,999,495.24 565,739.33 1.67 -439.94 3_MWD+IFR2+MS+Sag (2) 1,761.71 31.47 174.89 1,656.38 -448.26 170.951,592.89 5,999,462.12 565,742.57 0.21 -473.02 3_MWD+IFR2+MS+Sag (2) 1,825.53 31.92 176.05 1,710.68 -481.68 173.601,647.19 5,999,428.73 565,745.51 1.19 -506.32 3_MWD+IFR2+MS+Sag (2) 1,889.27 32.51 174.45 1,764.61 -515.54 176.421,701.12 5,999,394.90 565,748.63 1.63 -540.08 3_MWD+IFR2+MS+Sag (2) 1,953.05 32.47 173.62 1,818.41 -549.62 179.981,754.92 5,999,360.86 565,752.49 0.70 -574.19 3_MWD+IFR2+MS+Sag (2) 2,016.40 31.93 174.16 1,872.02 -583.18 183.571,808.53 5,999,327.33 565,756.37 0.97 -607.81 3_MWD+IFR2+MS+Sag (2) 2,080.26 32.73 171.58 1,925.98 -617.06 187.821,862.49 5,999,293.49 565,760.92 2.50 -641.87 3_MWD+IFR2+MS+Sag (2) 2,143.62 33.73 170.56 1,978.98 -651.36 193.211,915.49 5,999,259.24 565,766.61 1.81 -676.56 3_MWD+IFR2+MS+Sag (2) 2,207.74 33.28 170.39 2,032.44 -686.27 199.071,968.95 5,999,224.39 565,772.77 0.72 -711.94 3_MWD+IFR2+MS+Sag (2) 2,270.99 33.90 170.18 2,085.13 -720.76 204.972,021.64 5,999,189.96 565,778.98 1.00 -746.92 3_MWD+IFR2+MS+Sag (2) 2,334.55 34.32 170.51 2,137.76 -755.90 210.952,074.27 5,999,154.88 565,785.27 0.72 -782.55 3_MWD+IFR2+MS+Sag (2) 2,398.22 34.84 170.99 2,190.18 -791.56 216.762,126.69 5,999,119.27 565,791.39 0.92 -818.66 3_MWD+IFR2+MS+Sag (2) 2,461.88 34.99 171.29 2,242.38 -827.56 222.372,178.89 5,999,083.32 565,797.31 0.36 -855.06 3_MWD+IFR2+MS+Sag (2) 2,525.44 35.21 171.66 2,294.38 -863.71 227.792,230.89 5,999,047.23 565,803.05 0.48 -891.57 3_MWD+IFR2+MS+Sag (2) 2,588.70 35.62 170.96 2,345.94 -899.94 233.332,282.45 5,999,011.04 565,808.90 0.91 -928.19 3_MWD+IFR2+MS+Sag (2) 2,652.55 35.68 173.13 2,397.82 -936.79 238.482,334.33 5,998,974.24 565,814.38 1.98 -965.34 3_MWD+IFR2+MS+Sag (2) 2,716.37 34.41 174.47 2,450.07 -973.22 242.442,386.58 5,998,937.86 565,818.66 2.33 -1,001.84 3_MWD+IFR2+MS+Sag (2) 2,779.35 32.72 175.20 2,502.55 -1,007.90 245.582,439.06 5,998,903.21 565,822.10 2.76 -1,036.46 3_MWD+IFR2+MS+Sag (2) 2,843.69 30.64 178.74 2,557.30 -1,041.63 247.392,493.81 5,998,869.50 565,824.22 4.33 -1,069.89 3_MWD+IFR2+MS+Sag (2) 2,906.54 29.84 182.87 2,611.61 -1,073.26 246.962,548.12 5,998,837.87 565,824.06 3.55 -1,100.83 3_MWD+IFR2+MS+Sag (2) 2,970.67 28.44 187.52 2,667.63 -1,104.34 244.172,604.14 5,998,806.77 565,821.54 4.15 -1,130.76 3_MWD+IFR2+MS+Sag (2) 3,034.17 27.64 193.08 2,723.68 -1,133.68 238.852,660.19 5,998,777.39 565,816.48 4.30 -1,158.50 3_MWD+IFR2+MS+Sag (2) 3,094.79 26.76 196.54 2,777.60 -1,160.46 231.792,714.11 5,998,750.55 565,809.65 2.99 -1,183.38 3_MWD+IFR2+MS+Sag (2) 3,161.49 25.75 201.04 2,837.43 -1,188.38 222.312,773.94 5,998,722.55 565,800.42 3.35 -1,208.91 3_MWD+IFR2+MS+Sag (2) 3,224.81 22.89 207.21 2,895.13 -1,212.18 211.732,831.64 5,998,698.66 565,790.06 6.04 -1,230.19 3_MWD+IFR2+MS+Sag (2) 3/5/2020 1:14:49PM COMPASS 5000.15 Build 91E Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Halliburton Definitive Survey Report Well: Wellbore: MPU S-57 MPU S-57 Survey Calculation Method:Minimum Curvature MPU S-57 Actual RKB @ 63.49usft Design:MPU S-57 Database:NORTH US + CANADA MD Reference:MPU S-57 Actual RKB @ 63.49usft North Reference: Well MPU S-57 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 3,288.97 20.77 213.99 2,954.70 -1,232.72 199.672,891.21 5,998,678.02 565,778.17 5.13 -1,247.97 3_MWD+IFR2+MS+Sag (2) 3,352.28 20.47 223.42 3,013.97 -1,250.07 185.782,950.48 5,998,660.55 565,764.44 5.26 -1,262.27 3_MWD+IFR2+MS+Sag (2) 3,415.79 20.34 232.71 3,073.51 -1,264.83 169.363,010.02 5,998,645.65 565,748.15 5.10 -1,273.54 3_MWD+IFR2+MS+Sag (2) 3,479.14 21.88 241.10 3,132.62 -1,277.21 150.263,069.13 5,998,633.10 565,729.16 5.35 -1,281.94 3_MWD+IFR2+MS+Sag (2) 3,542.80 23.79 250.00 3,191.30 -1,287.33 127.803,127.81 5,998,622.78 565,706.79 6.19 -1,287.49 3_MWD+IFR2+MS+Sag (2) 3,606.49 25.41 259.42 3,249.23 -1,294.24 102.293,185.74 5,998,615.65 565,681.34 6.65 -1,289.27 3_MWD+IFR2+MS+Sag (2) 3,669.94 27.24 267.82 3,306.12 -1,297.29 74.383,242.63 5,998,612.35 565,653.47 6.53 -1,286.81 3_MWD+IFR2+MS+Sag (2) 3,733.25 28.13 275.74 3,362.20 -1,296.35 45.043,298.71 5,998,613.04 565,624.13 5.98 -1,280.16 3_MWD+IFR2+MS+Sag (2) 3,796.76 29.04 283.79 3,417.99 -1,291.18 15.163,354.50 5,998,617.95 565,594.21 6.23 -1,269.24 3_MWD+IFR2+MS+Sag (2) 3,861.07 30.66 290.05 3,473.78 -1,281.83 -15.413,410.29 5,998,627.02 565,563.56 5.46 -1,254.10 3_MWD+IFR2+MS+Sag (2) 3,924.08 33.40 293.51 3,527.20 -1,269.40 -46.413,463.71 5,998,639.18 565,532.45 5.23 -1,235.85 3_MWD+IFR2+MS+Sag (2) 3,988.25 36.06 294.95 3,579.93 -1,254.39 -79.743,516.44 5,998,653.90 565,498.99 4.34 -1,214.62 3_MWD+IFR2+MS+Sag (2) 4,051.79 39.21 295.54 3,630.24 -1,237.84 -114.823,566.75 5,998,670.14 565,463.77 4.99 -1,191.53 3_MWD+IFR2+MS+Sag (2) 4,115.60 42.85 296.94 3,678.37 -1,219.30 -152.383,614.88 5,998,688.34 565,426.05 5.88 -1,166.01 3_MWD+IFR2+MS+Sag (2) 4,179.17 46.09 298.66 3,723.73 -1,198.52 -191.763,660.24 5,998,708.78 565,386.50 5.44 -1,137.93 3_MWD+IFR2+MS+Sag (2) 4,242.42 47.96 300.06 3,766.85 -1,175.83 -232.083,703.36 5,998,731.11 565,345.98 3.37 -1,107.80 3_MWD+IFR2+MS+Sag (2) 4,306.47 50.71 301.88 3,808.58 -1,150.82 -273.723,745.09 5,998,755.76 565,304.13 4.80 -1,075.13 3_MWD+IFR2+MS+Sag (2) 4,369.84 54.07 303.76 3,847.25 -1,123.60 -315.893,783.76 5,998,782.60 565,261.72 5.80 -1,040.20 3_MWD+IFR2+MS+Sag (2) 4,433.17 55.32 305.95 3,883.86 -1,094.06 -358.293,820.37 5,998,811.76 565,219.07 3.44 -1,002.94 3_MWD+IFR2+MS+Sag (2) 4,496.98 57.43 308.86 3,919.19 -1,061.78 -400.483,855.70 5,998,843.67 565,176.60 5.03 -963.03 3_MWD+IFR2+MS+Sag (2) 4,560.59 59.03 311.03 3,952.69 -1,027.05 -441.933,889.20 5,998,878.03 565,134.86 3.84 -920.88 3_MWD+IFR2+MS+Sag (2) 4,624.46 62.28 312.84 3,983.99 -989.84 -483.333,920.50 5,998,914.87 565,093.14 5.66 -876.30 3_MWD+IFR2+MS+Sag (2) 4,686.42 64.50 312.97 4,011.74 -952.13 -523.903,948.25 5,998,952.22 565,052.24 3.59 -831.38 3_MWD+IFR2+MS+Sag (2) 4,751.54 67.18 313.28 4,038.39 -911.52 -567.263,974.90 5,998,992.45 565,008.52 4.14 -783.08 3_MWD+IFR2+MS+Sag (2) 4,812.10 71.56 314.14 4,059.72 -872.36 -608.223,996.23 5,999,031.24 564,967.23 7.35 -736.67 3_MWD+IFR2+MS+Sag (2) 4,878.72 75.47 314.44 4,078.62 -827.76 -653.934,015.13 5,999,075.43 564,921.13 5.88 -684.00 3_MWD+IFR2+MS+Sag (2) 4,942.68 79.88 314.59 4,092.27 -783.96 -698.484,028.78 5,999,118.83 564,876.21 6.90 -632.34 3_MWD+IFR2+MS+Sag (2) 5,005.57 83.63 314.93 4,101.29 -740.14 -742.664,037.80 5,999,162.26 564,831.64 5.99 -580.73 3_MWD+IFR2+MS+Sag (2) 5,068.79 84.50 315.72 4,107.82 -695.43 -786.874,044.33 5,999,206.58 564,787.05 1.85 -528.24 3_MWD+IFR2+MS+Sag (2) 5,132.42 83.88 315.79 4,114.27 -650.08 -831.044,050.78 5,999,251.53 564,742.49 0.98 -475.13 3_MWD+IFR2+MS+Sag (2) 5,158.47 84.56 316.10 4,116.89 -631.45 -849.064,053.40 5,999,270.00 564,724.30 2.87 -453.34 3_MWD+IFR2+MS+Sag (2) 5,226.74 87.17 316.10 4,121.81 -582.39 -896.284,058.32 5,999,318.64 564,676.67 3.82 -396.00 3_MWD+IFR2+MS+Sag (3) 5,259.53 87.97 316.28 4,123.20 -558.75 -918.954,059.71 5,999,342.08 564,653.78 2.50 -368.38 3_MWD+IFR2+MS+Sag (3) 5,322.86 89.82 317.27 4,124.42 -512.62 -962.324,060.93 5,999,387.82 564,610.02 3.31 -314.66 3_MWD+IFR2+MS+Sag (3) 5,385.69 91.37 318.28 4,123.77 -466.09 -1,004.544,060.28 5,999,433.97 564,567.40 2.94 -260.79 3_MWD+IFR2+MS+Sag (3) 5,449.58 93.09 318.80 4,121.28 -418.25 -1,046.804,057.79 5,999,481.43 564,524.72 2.81 -205.61 3_MWD+IFR2+MS+Sag (3) 5,513.07 93.52 318.72 4,117.62 -370.59 -1,088.594,054.13 5,999,528.72 564,482.52 0.69 -150.70 3_MWD+IFR2+MS+Sag (3) 5,576.63 93.27 319.07 4,113.86 -322.78 -1,130.304,050.37 5,999,576.16 564,440.39 0.68 -95.66 3_MWD+IFR2+MS+Sag (3) 5,640.31 93.03 318.85 4,110.36 -274.82 -1,172.054,046.87 5,999,623.74 564,398.23 0.51 -40.47 3_MWD+IFR2+MS+Sag (3) 5,703.66 92.78 319.19 4,107.15 -227.06 -1,213.544,043.66 5,999,671.14 564,356.32 0.67 14.48 3_MWD+IFR2+MS+Sag (3) 3/5/2020 1:14:49PM COMPASS 5000.15 Build 91E Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Halliburton Definitive Survey Report Well: Wellbore: MPU S-57 MPU S-57 Survey Calculation Method:Minimum Curvature MPU S-57 Actual RKB @ 63.49usft Design:MPU S-57 Database:NORTH US + CANADA MD Reference:MPU S-57 Actual RKB @ 63.49usft North Reference: Well MPU S-57 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 5,766.55 92.84 318.86 4,104.07 -179.64 -1,254.734,040.58 5,999,718.19 564,314.72 0.53 69.04 3_MWD+IFR2+MS+Sag (3) 5,830.26 92.97 317.76 4,100.84 -132.12 -1,297.054,037.35 5,999,765.33 564,271.99 1.74 123.91 3_MWD+IFR2+MS+Sag (3) 5,893.95 93.28 317.82 4,097.37 -85.02 -1,339.774,033.88 5,999,812.05 564,228.86 0.50 178.46 3_MWD+IFR2+MS+Sag (3) 5,957.68 93.34 316.22 4,093.69 -38.47 -1,383.154,030.20 5,999,858.21 564,185.08 2.51 232.58 3_MWD+IFR2+MS+Sag (3) 6,021.39 93.77 317.21 4,089.74 7.82 -1,426.754,026.25 5,999,904.11 564,141.09 1.69 286.50 3_MWD+IFR2+MS+Sag (3) 6,084.92 91.79 318.34 4,086.65 54.80 -1,469.394,023.16 5,999,950.72 564,098.04 3.59 340.91 3_MWD+IFR2+MS+Sag (3) 6,148.77 91.54 320.46 4,084.80 103.26 -1,510.924,021.31 5,999,998.80 564,056.09 3.34 396.55 3_MWD+IFR2+MS+Sag (3) 6,212.50 91.79 322.33 4,082.95 153.04 -1,550.664,019.46 6,000,048.23 564,015.91 2.96 453.14 3_MWD+IFR2+MS+Sag (3) 6,276.23 91.92 324.68 4,080.88 204.24 -1,588.554,017.39 6,000,099.09 563,977.58 3.69 510.76 3_MWD+IFR2+MS+Sag (3) 6,339.90 92.10 326.45 4,078.65 256.72 -1,624.534,015.16 6,000,151.24 563,941.15 2.79 569.25 3_MWD+IFR2+MS+Sag (3) 6,403.84 92.29 329.19 4,076.20 310.79 -1,658.554,012.71 6,000,205.01 563,906.65 4.29 628.93 3_MWD+IFR2+MS+Sag (3) 6,467.52 92.66 329.42 4,073.45 365.50 -1,691.034,009.96 6,000,259.43 563,873.70 0.68 688.93 3_MWD+IFR2+MS+Sag (3) 6,529.95 92.16 331.56 4,070.83 419.78 -1,721.754,007.34 6,000,313.43 563,842.51 3.52 748.17 3_MWD+IFR2+MS+Sag (3) 6,593.97 90.12 334.26 4,069.55 476.76 -1,750.894,006.06 6,000,370.14 563,812.87 5.29 809.74 3_MWD+IFR2+MS+Sag (3) 6,656.92 89.51 337.88 4,069.76 534.28 -1,776.424,006.27 6,000,427.44 563,786.84 5.83 871.15 3_MWD+IFR2+MS+Sag (3) 6,720.06 89.26 340.73 4,070.43 593.34 -1,798.734,006.94 6,000,486.29 563,764.01 4.53 933.43 3_MWD+IFR2+MS+Sag (3) 6,783.48 88.71 344.27 4,071.56 653.81 -1,817.804,008.07 6,000,546.58 563,744.42 5.65 996.46 3_MWD+IFR2+MS+Sag (3) 6,848.07 88.34 346.97 4,073.22 716.35 -1,833.834,009.73 6,000,608.97 563,727.84 4.22 1,060.92 3_MWD+IFR2+MS+Sag (3) 6,910.80 89.08 350.52 4,074.63 777.84 -1,846.074,011.14 6,000,670.35 563,715.06 5.78 1,123.63 3_MWD+IFR2+MS+Sag (3) 6,974.07 87.78 351.05 4,076.37 840.27 -1,856.204,012.88 6,000,732.69 563,704.39 2.22 1,186.83 3_MWD+IFR2+MS+Sag (3) 7,038.13 87.47 350.77 4,079.02 903.47 -1,866.314,015.53 6,000,795.79 563,693.72 0.65 1,250.79 3_MWD+IFR2+MS+Sag (3) 7,101.54 88.03 351.85 4,081.51 966.11 -1,875.884,018.02 6,000,858.33 563,683.60 1.92 1,314.08 3_MWD+IFR2+MS+Sag (3) 7,164.79 88.89 351.70 4,083.21 1,028.68 -1,884.934,019.72 6,000,920.82 563,674.01 1.38 1,377.22 3_MWD+IFR2+MS+Sag (3) 7,228.51 88.64 352.35 4,084.58 1,091.77 -1,893.764,021.09 6,000,983.82 563,664.61 1.09 1,440.82 3_MWD+IFR2+MS+Sag (3) 7,290.92 87.04 351.74 4,086.94 1,153.53 -1,902.404,023.45 6,001,045.50 563,655.44 2.74 1,503.08 3_MWD+IFR2+MS+Sag (3) 7,354.37 86.98 352.36 4,090.25 1,216.29 -1,911.164,026.76 6,001,108.17 563,646.13 0.98 1,566.34 3_MWD+IFR2+MS+Sag (3) 7,417.08 89.64 353.89 4,092.09 1,278.51 -1,918.664,028.60 6,001,170.32 563,638.08 4.89 1,628.83 3_MWD+IFR2+MS+Sag (3) 7,482.17 90.62 355.49 4,091.95 1,343.32 -1,924.684,028.46 6,001,235.07 563,631.49 2.88 1,693.56 3_MWD+IFR2+MS+Sag (3) 7,545.18 90.74 355.72 4,091.20 1,406.14 -1,929.514,027.71 6,001,297.83 563,626.11 0.41 1,756.12 3_MWD+IFR2+MS+Sag (3) 7,609.33 91.05 355.41 4,090.20 1,470.09 -1,934.474,026.71 6,001,361.73 563,620.59 0.68 1,819.80 3_MWD+IFR2+MS+Sag (3) 7,672.50 91.12 354.36 4,089.00 1,533.00 -1,940.104,025.51 6,001,424.58 563,614.41 1.67 1,882.60 3_MWD+IFR2+MS+Sag (3) 7,736.69 91.24 353.26 4,087.68 1,596.80 -1,947.024,024.19 6,001,488.31 563,606.93 1.72 1,946.52 3_MWD+IFR2+MS+Sag (3) 7,800.44 90.49 352.04 4,086.72 1,660.01 -1,955.184,023.23 6,001,551.45 563,598.22 2.25 2,010.11 3_MWD+IFR2+MS+Sag (3) 7,864.56 89.69 352.13 4,086.62 1,723.52 -1,964.014,023.13 6,001,614.87 563,588.84 1.26 2,074.12 3_MWD+IFR2+MS+Sag (3) 7,927.53 89.38 351.51 4,087.13 1,785.85 -1,972.974,023.64 6,001,677.11 563,579.33 1.10 2,137.00 3_MWD+IFR2+MS+Sag (3) 7,991.34 89.57 350.28 4,087.71 1,848.85 -1,983.064,024.22 6,001,740.02 563,568.68 1.95 2,200.76 3_MWD+IFR2+MS+Sag (3) 8,054.93 89.69 349.26 4,088.12 1,911.43 -1,994.364,024.63 6,001,802.49 563,556.84 1.62 2,264.33 3_MWD+IFR2+MS+Sag (3) 8,117.98 90.25 349.47 4,088.16 1,973.40 -2,005.994,024.67 6,001,864.34 563,544.66 0.95 2,327.38 3_MWD+IFR2+MS+Sag (3) 8,181.78 90.56 348.42 4,087.70 2,036.01 -2,018.234,024.21 6,001,926.84 563,531.88 1.72 2,391.18 3_MWD+IFR2+MS+Sag (3) 8,245.74 90.93 348.06 4,086.87 2,098.62 -2,031.264,023.38 6,001,989.33 563,518.30 0.81 2,455.13 3_MWD+IFR2+MS+Sag (3) 3/5/2020 1:14:49PM COMPASS 5000.15 Build 91E Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Halliburton Definitive Survey Report Well: Wellbore: MPU S-57 MPU S-57 Survey Calculation Method:Minimum Curvature MPU S-57 Actual RKB @ 63.49usft Design:MPU S-57 Database:NORTH US + CANADA MD Reference:MPU S-57 Actual RKB @ 63.49usft North Reference: Well MPU S-57 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 8,309.00 90.43 342.38 4,086.12 2,159.76 -2,047.394,022.63 6,002,050.32 563,501.63 9.01 2,518.24 3_MWD+IFR2+MS+Sag (3) 8,373.04 91.36 339.59 4,085.12 2,220.29 -2,068.254,021.63 6,002,110.66 563,480.25 4.59 2,581.68 3_MWD+IFR2+MS+Sag (3) 8,436.79 90.74 340.33 4,083.95 2,280.17 -2,090.094,020.46 6,002,170.34 563,457.88 1.51 2,644.67 3_MWD+IFR2+MS+Sag (3) 8,499.48 91.30 338.71 4,082.84 2,338.89 -2,112.024,019.35 6,002,228.85 563,435.44 2.73 2,706.54 3_MWD+IFR2+MS+Sag (3) 8,563.57 91.67 337.88 4,081.18 2,398.41 -2,135.724,017.69 6,002,288.16 563,411.23 1.42 2,769.55 3_MWD+IFR2+MS+Sag (3) 8,626.62 90.99 341.04 4,079.71 2,457.43 -2,157.834,016.22 6,002,346.98 563,388.60 5.13 2,831.75 3_MWD+IFR2+MS+Sag (3) 8,690.23 89.26 343.39 4,079.57 2,517.99 -2,177.264,016.08 6,002,407.36 563,368.64 4.59 2,894.95 3_MWD+IFR2+MS+Sag (3) 8,754.45 88.89 347.44 4,080.61 2,580.12 -2,193.424,017.12 6,002,469.34 563,351.93 6.33 2,959.04 3_MWD+IFR2+MS+Sag (3) 8,818.04 88.40 353.61 4,082.12 2,642.80 -2,203.884,018.63 6,002,531.92 563,340.92 9.73 3,022.55 3_MWD+IFR2+MS+Sag (3) 8,881.86 87.78 354.41 4,084.24 2,706.23 -2,210.544,020.75 6,002,595.29 563,333.71 1.59 3,086.06 3_MWD+IFR2+MS+Sag (3) 8,945.59 88.28 355.53 4,086.43 2,769.68 -2,216.124,022.94 6,002,658.67 563,327.57 1.92 3,149.37 3_MWD+IFR2+MS+Sag (3) 9,009.17 88.89 356.40 4,088.00 2,833.08 -2,220.604,024.51 6,002,722.03 563,322.54 1.67 3,212.43 3_MWD+IFR2+MS+Sag (3) 9,072.80 89.14 355.89 4,089.10 2,896.56 -2,224.874,025.61 6,002,785.46 563,317.71 0.89 3,275.52 3_MWD+IFR2+MS+Sag (3) 9,136.60 88.89 354.86 4,090.19 2,960.14 -2,230.024,026.70 6,002,848.99 563,312.01 1.66 3,338.88 3_MWD+IFR2+MS+Sag (3) 9,200.46 89.08 355.35 4,091.33 3,023.76 -2,235.474,027.84 6,002,912.55 563,306.00 0.82 3,402.33 3_MWD+IFR2+MS+Sag (3) 9,263.72 88.83 355.15 4,092.48 3,086.79 -2,240.704,028.99 6,002,975.53 563,300.21 0.51 3,465.17 3_MWD+IFR2+MS+Sag (3) 9,327.73 87.96 354.98 4,094.27 3,150.53 -2,246.214,030.78 6,003,039.22 563,294.15 1.38 3,528.77 3_MWD+IFR2+MS+Sag (3) 9,389.46 87.97 354.44 4,096.46 3,211.96 -2,251.894,032.97 6,003,100.59 563,287.92 0.87 3,590.12 3_MWD+IFR2+MS+Sag (3) 9,454.32 88.28 354.27 4,098.59 3,276.47 -2,258.274,035.10 6,003,165.03 563,280.98 0.55 3,654.63 3_MWD+IFR2+MS+Sag (3) 9,518.20 89.08 353.31 4,100.06 3,339.96 -2,265.184,036.57 6,003,228.45 563,273.51 1.96 3,718.25 3_MWD+IFR2+MS+Sag (3) 9,581.37 90.75 352.73 4,100.15 3,402.66 -2,272.864,036.66 6,003,291.07 563,265.29 2.80 3,781.24 3_MWD+IFR2+MS+Sag (3) 9,645.11 92.42 351.15 4,098.39 3,465.74 -2,281.794,034.90 6,003,354.07 563,255.80 3.61 3,844.85 3_MWD+IFR2+MS+Sag (3) 9,708.84 93.71 349.17 4,094.98 3,528.44 -2,292.664,031.49 6,003,416.66 563,244.38 3.70 3,908.46 3_MWD+IFR2+MS+Sag (3) 9,771.44 93.09 347.44 4,091.27 3,589.63 -2,305.334,027.78 6,003,477.73 563,231.18 2.93 3,970.95 3_MWD+IFR2+MS+Sag (3) 9,836.19 91.85 347.37 4,088.48 3,652.76 -2,319.434,024.99 6,003,540.73 563,216.52 1.92 4,035.62 3_MWD+IFR2+MS+Sag (3) 9,899.59 92.91 347.79 4,085.84 3,714.62 -2,333.064,022.35 6,003,602.47 563,202.36 1.80 4,098.95 3_MWD+IFR2+MS+Sag (3) 9,963.01 91.67 347.53 4,083.31 3,776.53 -2,346.604,019.82 6,003,664.24 563,188.27 2.00 4,162.31 3_MWD+IFR2+MS+Sag (3) 10,026.77 91.67 347.37 4,081.45 3,838.74 -2,360.454,017.96 6,003,726.32 563,173.88 0.25 4,226.02 3_MWD+IFR2+MS+Sag (3) 10,090.57 91.49 343.70 4,079.69 3,900.48 -2,376.384,016.20 6,003,787.92 563,157.41 5.76 4,289.69 3_MWD+IFR2+MS+Sag (3) 10,154.11 90.12 338.81 4,078.80 3,960.63 -2,396.794,015.31 6,003,847.88 563,136.47 7.99 4,352.66 3_MWD+IFR2+MS+Sag (3) 10,218.04 92.48 339.06 4,077.35 4,020.26 -2,419.764,013.86 6,003,907.31 563,112.98 3.71 4,415.64 3_MWD+IFR2+MS+Sag (3) 10,281.74 93.03 341.22 4,074.29 4,080.10 -2,441.374,010.80 6,003,966.95 563,090.85 3.50 4,478.55 3_MWD+IFR2+MS+Sag (3) 10,344.99 91.85 343.99 4,071.59 4,140.40 -2,460.264,008.10 6,004,027.07 563,071.43 4.76 4,541.37 3_MWD+IFR2+MS+Sag (3) 10,408.57 92.91 344.93 4,068.95 4,201.60 -2,477.284,005.46 6,004,088.11 563,053.88 2.23 4,604.72 3_MWD+IFR2+MS+Sag (3) 10,472.52 91.85 345.35 4,066.30 4,263.36 -2,493.674,002.81 6,004,149.72 563,036.95 1.78 4,668.49 3_MWD+IFR2+MS+Sag (3) 10,535.58 89.81 345.92 4,065.38 4,324.43 -2,509.314,001.89 6,004,210.65 563,020.78 3.36 4,731.45 3_MWD+IFR2+MS+Sag (3) 10,599.62 89.69 348.65 4,065.66 4,386.90 -2,523.404,002.17 6,004,272.98 563,006.13 4.27 4,795.46 3_MWD+IFR2+MS+Sag (3) 10,663.04 89.57 350.92 4,066.07 4,449.31 -2,534.654,002.58 6,004,335.28 562,994.34 3.58 4,858.86 3_MWD+IFR2+MS+Sag (3) 10,726.71 90.62 352.50 4,065.97 4,512.31 -2,543.834,002.48 6,004,398.20 562,984.61 2.98 4,922.45 3_MWD+IFR2+MS+Sag (3) 10,789.45 89.32 350.66 4,066.00 4,574.37 -2,553.024,002.51 6,004,460.17 562,974.88 3.59 4,985.10 3_MWD+IFR2+MS+Sag (3) 3/5/2020 1:14:49PM COMPASS 5000.15 Build 91E Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Halliburton Definitive Survey Report Well: Wellbore: MPU S-57 MPU S-57 Survey Calculation Method:Minimum Curvature MPU S-57 Actual RKB @ 63.49usft Design:MPU S-57 Database:NORTH US + CANADA MD Reference:MPU S-57 Actual RKB @ 63.49usft North Reference: Well MPU S-57 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 10,853.68 89.64 350.26 4,066.58 4,637.71 -2,563.664,003.09 6,004,523.40 562,963.68 0.80 5,049.30 3_MWD+IFR2+MS+Sag (3) 10,917.21 89.76 349.82 4,066.92 4,700.28 -2,574.654,003.43 6,004,585.87 562,952.15 0.72 5,112.81 3_MWD+IFR2+MS+Sag (3) 10,980.69 88.95 350.39 4,067.63 4,762.81 -2,585.564,004.14 6,004,648.30 562,940.69 1.56 5,176.27 3_MWD+IFR2+MS+Sag (3) 11,044.17 88.96 351.39 4,068.79 4,825.48 -2,595.614,005.30 6,004,710.87 562,930.09 1.58 5,239.69 3_MWD+IFR2+MS+Sag (3) 11,108.11 88.96 352.32 4,069.95 4,888.76 -2,604.664,006.46 6,004,774.06 562,920.48 1.45 5,303.53 3_MWD+IFR2+MS+Sag (3) 11,171.55 88.33 354.69 4,071.45 4,951.77 -2,611.844,007.96 6,004,837.00 562,912.76 3.86 5,366.73 3_MWD+IFR2+MS+Sag (3) 11,235.50 88.58 354.11 4,073.17 5,015.39 -2,618.074,009.68 6,004,900.56 562,905.96 0.99 5,430.34 3_MWD+IFR2+MS+Sag (3) 11,298.76 87.59 352.86 4,075.29 5,078.21 -2,625.254,011.80 6,004,963.30 562,898.24 2.52 5,493.34 3_MWD+IFR2+MS+Sag (3) 11,362.23 87.47 351.58 4,078.02 5,141.03 -2,633.834,014.53 6,005,026.05 562,889.10 2.02 5,556.64 3_MWD+IFR2+MS+Sag (3) 11,425.65 86.92 351.24 4,081.13 5,203.67 -2,643.294,017.64 6,005,088.59 562,879.09 1.02 5,619.91 3_MWD+IFR2+MS+Sag (3) 11,489.59 87.66 350.72 4,084.15 5,266.74 -2,653.314,020.66 6,005,151.57 562,868.53 1.41 5,683.73 3_MWD+IFR2+MS+Sag (3) 11,551.94 89.39 350.52 4,085.75 5,328.24 -2,663.464,022.26 6,005,212.97 562,857.83 2.79 5,746.02 3_MWD+IFR2+MS+Sag (3) 11,616.62 90.07 350.65 4,086.06 5,392.05 -2,674.044,022.57 6,005,276.67 562,846.69 1.07 5,810.67 3_MWD+IFR2+MS+Sag (3) 11,680.22 91.49 350.56 4,085.19 5,454.79 -2,684.434,021.70 6,005,339.31 562,835.76 2.24 5,874.23 3_MWD+IFR2+MS+Sag (3) 11,743.73 92.17 350.25 4,083.17 5,517.37 -2,695.014,019.68 6,005,401.80 562,824.63 1.18 5,937.68 3_MWD+IFR2+MS+Sag (3) 11,807.29 92.29 349.62 4,080.69 5,579.91 -2,706.114,017.20 6,005,464.23 562,812.98 1.01 6,001.17 3_MWD+IFR2+MS+Sag (3) 11,870.88 91.79 348.30 4,078.43 5,642.28 -2,718.274,014.94 6,005,526.49 562,800.27 2.22 6,064.72 3_MWD+IFR2+MS+Sag (3) 11,934.50 92.47 347.01 4,076.06 5,704.38 -2,731.874,012.57 6,005,588.46 562,786.13 2.29 6,128.28 3_MWD+IFR2+MS+Sag (3) 11,998.34 92.41 345.76 4,073.35 5,766.37 -2,746.884,009.86 6,005,650.31 562,770.58 1.96 6,192.01 3_MWD+IFR2+MS+Sag (3) 12,062.50 92.54 344.75 4,070.58 5,828.36 -2,763.194,007.09 6,005,712.15 562,753.72 1.59 6,255.99 3_MWD+IFR2+MS+Sag (3) 12,126.05 90.80 343.55 4,068.72 5,889.47 -2,780.544,005.23 6,005,773.09 562,735.84 3.33 6,319.31 3_MWD+IFR2+MS+Sag (3) 12,189.71 89.01 344.02 4,068.83 5,950.59 -2,798.324,005.34 6,005,834.05 562,717.53 2.91 6,382.73 3_MWD+IFR2+MS+Sag (3) 12,253.36 87.34 344.90 4,070.86 6,011.88 -2,815.364,007.37 6,005,895.18 562,699.95 2.97 6,446.17 3_MWD+IFR2+MS+Sag (3) 12,314.33 89.58 344.53 4,072.49 6,070.67 -2,831.434,009.00 6,005,953.82 562,683.37 3.72 6,506.96 3_MWD+IFR2+MS+Sag (3) 12,378.14 88.52 344.19 4,073.55 6,132.11 -2,848.634,010.06 6,006,015.10 562,665.63 1.74 6,570.58 3_MWD+IFR2+MS+Sag (3) 12,443.89 86.79 343.12 4,076.24 6,195.14 -2,867.124,012.75 6,006,077.97 562,646.60 3.09 6,636.01 3_MWD+IFR2+MS+Sag (3) 12,507.39 86.73 342.50 4,079.83 6,255.71 -2,885.854,016.34 6,006,138.36 562,627.33 0.98 6,699.07 3_MWD+IFR2+MS+Sag (3) 12,571.35 87.79 343.24 4,082.89 6,316.76 -2,904.674,019.40 6,006,199.24 562,607.98 2.02 6,762.62 3_MWD+IFR2+MS+Sag (3) 12,634.93 88.77 342.56 4,084.80 6,377.50 -2,923.364,021.31 6,006,259.81 562,588.76 1.88 6,825.84 3_MWD+IFR2+MS+Sag (3) 12,698.58 88.71 343.94 4,086.20 6,438.43 -2,941.694,022.71 6,006,320.57 562,569.89 2.17 6,889.19 3_MWD+IFR2+MS+Sag (3) 12,762.32 88.46 345.50 4,087.77 6,499.90 -2,958.494,024.28 6,006,381.88 562,552.56 2.48 6,952.75 3_MWD+IFR2+MS+Sag (3) 12,826.16 88.71 346.27 4,089.35 6,561.79 -2,974.054,025.86 6,006,443.63 562,536.46 1.27 7,016.49 3_MWD+IFR2+MS+Sag (3) 12,889.94 88.89 346.67 4,090.68 6,623.79 -2,988.974,027.19 6,006,505.49 562,521.00 0.69 7,080.21 3_MWD+IFR2+MS+Sag (3) 12,953.48 89.33 348.23 4,091.67 6,685.80 -3,002.774,028.18 6,006,567.37 562,506.65 2.55 7,143.72 3_MWD+IFR2+MS+Sag (3) 13,016.77 90.13 349.19 4,091.97 6,747.87 -3,015.164,028.48 6,006,629.32 562,493.72 1.97 7,207.01 3_MWD+IFR2+MS+Sag (3) 13,080.11 90.31 350.30 4,091.73 6,810.19 -3,026.444,028.24 6,006,691.54 562,481.89 1.78 7,270.34 3_MWD+IFR2+MS+Sag (3) 13,143.87 90.44 351.03 4,091.31 6,873.11 -3,036.784,027.82 6,006,754.35 562,471.00 1.16 7,334.06 3_MWD+IFR2+MS+Sag (3) 13,207.50 90.25 351.57 4,090.92 6,936.00 -3,046.414,027.43 6,006,817.15 562,460.83 0.90 7,397.62 3_MWD+IFR2+MS+Sag (3) 13,271.01 89.45 352.04 4,091.09 6,998.86 -3,055.464,027.60 6,006,879.93 562,451.22 1.46 7,461.04 3_MWD+IFR2+MS+Sag (3) 13,334.60 89.08 352.25 4,091.91 7,061.85 -3,064.154,028.42 6,006,942.83 562,441.98 0.67 7,524.51 3_MWD+IFR2+MS+Sag (3) 3/5/2020 1:14:49PM COMPASS 5000.15 Build 91E Page 7 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Halliburton Definitive Survey Report Well: Wellbore: MPU S-57 MPU S-57 Survey Calculation Method:Minimum Curvature MPU S-57 Actual RKB @ 63.49usft Design:MPU S-57 Database:NORTH US + CANADA MD Reference:MPU S-57 Actual RKB @ 63.49usft North Reference: Well MPU S-57 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 13,398.19 89.08 352.17 4,092.93 7,124.85 -3,072.774,029.44 6,007,005.74 562,432.81 0.13 7,587.98 3_MWD+IFR2+MS+Sag (3) 13,461.87 88.95 352.15 4,094.02 7,187.92 -3,081.454,030.53 6,007,068.73 562,423.57 0.21 7,651.53 3_MWD+IFR2+MS+Sag (3) 13,524.81 87.78 351.92 4,095.82 7,250.23 -3,090.174,032.33 6,007,130.95 562,414.31 1.89 7,714.34 3_MWD+IFR2+MS+Sag (3) 13,588.03 88.16 351.39 4,098.06 7,312.74 -3,099.344,034.57 6,007,193.38 562,404.59 1.03 7,777.44 3_MWD+IFR2+MS+Sag (3) 13,611.39 88.03 351.92 4,098.83 7,335.84 -3,102.734,035.34 6,007,216.44 562,401.00 2.33 7,800.76 3_MWD+IFR2+MS+Sag (3) 13,680.00 88.03 351.92 4,101.19 7,403.73 -3,112.374,037.70 6,007,284.24 562,390.77 0.00 7,869.22 PROJECTED to TD Approved By:Checked By:Date: 3/5/2020 1:14:49PM COMPASS 5000.15 Build 91E Page 8 Chelsea Wright Digitally signed by Chelsea Wright Date: 2020.03.05 10:23:22 -09'00'Benjamin Hand Digitally signed by Benjamin Hand Date: 2020.03.05 14:30:12 -09'00' TD Shoe Depth: PBTD: No. Jts. Returned Jts. 2 1 74 54 X Yes No X Yes No 40 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes No Liner hanger test pressure:Yes X 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: X Yes No Casing Rotated?X Yes No Reciprocated?X Yes No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: 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: X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes 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: 1.17 2/26/2020 27 Spud Mud Type I/II 375 2.35 Class G 398 1.16 5 2,150.99 Casing 9 5/8 40.0 L-80 TXP BTC Tenaris 2,115.70 2,150.99 35.29 2,169.29 2,166.47 Pup Joint 9 5/8 40.0 L-80 TXP BTC Tenaris 15.48 2,166.47 19.20 2,188.49 2,169.29 ES Cementer 10 3/4 40.0 L-80 TXP HES 2.82 Pup Joint 9 5/8 40.0 L-80 TXP BTC Tenaris 5,084.43 Casing 9 3/4 40.0 L-80 TXP BTC Tenaris 2,895.94 5,084.43 2,188.49 5,125.59 5,085.88 Baffle Adapter 10 3/4 L-80 TXP HES 1.45 5,085.88 1.27 5,126.86 5,125.59 Casing 9 5/8 40.0 L-80 TXP BTC Tenaris 39.71 Float Collar 10 3/4 BTC Innovex 2 on shoe joint, 1 every joint to 4191', 1 every other joint to 3173', 1 every joint 2384' - 1956' (5 jnts before and after ES cementer), 1 every other joint to 112' Casing 9 3/4 40.0 L-80 TXP BTC Tenaris 79.79 5,206.65 5,126.86 www.wellez.net WellEz Information Management LLC ver_04818br 3.5 208.34Water 5 No. Jts. Delivered 142 No. Jts. Run 132 Type of Shoe:Conventional Casing Crew:Weatherford 12 157 Water ES Cementer Closure OK 4.5208.34 55 Type I/II Type Class G 264 Tuned Spacer 875 2.94 Stage Collar @ 60 Bump press 100 220 5,208.235,217.00 CEMENTING REPORT Csg Wt. On Slips: Spud Mud 10:06 2/25/2020 2,166 2166 15.8 82 Bump press Returns after opening ES cementer Bump Plug? Y 4 9.2 3 147/144 370/366 1200 1 RigFIRST STAGE10Tuned Spacer 55 15.8 500 9.2 6.5 1700 10 10.7 459 5 100 680 Bump Plug? Csg Wt. On Hook:230 Type Float Collar:Conventional No. Hrs to Run:19 9 5/8 40.0 L-80 TXP BTC Tenaris BTC Innovex 1.58 5,208.23 5,206.65 10.02 35.29 25.27 Setting Depths Component Size Wt.Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.MP S-57 Date Run 24-Feb-20 CASING RECORD County State Alaska Supv.J. Lott/ C. Montague 5,125.59 Floats Held 323.6 753 280 473 ud Mud / Tuned spa Rotate Csg Recip Csg Ft. Min.PPG9.2 Shoe @ 5208.23 FC @ Top of Liner #N/A SECOND STAGERig 0:26 Returns 314.3 463.67 47 Casing (Or Liner) Detail Shoe Cut Joint 10 3/4 40.0 Allem. AlaA.n UA: DATE 03/23/2020 22001; Debra Oudean Hilcorp Alaska, LLC 3 2 2 5 J GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 Halliburton LWD FINAL 6 MAR 2020 MPU S-57 CGM 3./23/202010:59 AM File folder DefinitiveS=ey 3/23/2020 11 V AM Filefolder EMF 3/23/202011: 01 AM Filefolder LAS 3./231202011:01 AM Filefolder PDF 3/9/20202:47 PM Filefolder TIFF 3/23/202011:02 AM Filefolder Log Viewers YL/202011:02 AM File folder Please include current contact information if different from above. RECEIVED MAR 15 2020 A®GCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Schwartz, Guy L (CED) From: Joseph Engel <jengel@hilcorp.com> Sent: Wednesday, February 12, 2020 4:05 PM To: Schwartz, Guy L (CED) Cc: Cody Dinger Subject: RE: HAK MPU S-57 (PTD: 220-013) Directional Update Attachments: NorthSlope_M PS_57_wp03.pdf Follow Up Flag: Follow up Flag Status: Flagged Guy — Attached is the updated spider plot for wp03. Also attached is a screenshot of compass showing the shift of the lateral to the SW ish. -Joe FF �� .. 6750 wrx 1500 S 57 Ow �j Legend 5250 ,»X 750 ism 2?50 xm Joe Engel |DriUi�ngEngineer|Hi|corp4Jas�LL{ 3800{enteqpoint Dr, Ste. 1400 | Anchorage |AK| 99503 Office: 9U7777.8395|Cell: OO523S.6265 014 From: Joseph Engel Sent: Wednesday, February 12, 2020 3:30 PM To: 'Schwartz, Guy L (CED)' <guy.schwartz@alaska.gov> Cc: Davies, Stephen F (CED) <steve.davies@alaska.gov>; Cody Dinger <cdinger@hilcorp.com> Subject: HAK MPU S-57 (PTD: 220-013) Directional Update Guy / Steve — Recently the S-57 PTD with wp01 was approved. Due to the properties of the target Sb Ne sand, the asset team has decided to change the lateral spacing to 750'. This resulted in a shift of — 300' of the S-57 lateral. Please find the updated directional plan attached, wp03. Regarding A/C impacts of the change: Surface hole: no wells with a clearance factor less than 1.0 Production Lateral: S-29: OA Lateral, clearance factor has decreased, however this is in a different sand that S-57 target NE S-27: clearance factors have increased to > 1.0, OA lateral • H-08: clearance factors have decreased and the lateral has moved closer to H-08, we will be running a gyro on H- 08 to reduce EOL o H-08 & H -08A are abandoned, -08 was the pilot hole and -08A was a lateral in the OA sand. Only risk is damage to the bit. o H -08B is an active producer in the OA and OB sand. Please let me know if you have any questions or anything else is needed. Thanks -Joe Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 1 Anchorage I AK 199503 Office: 907.777.8395 1 Cell: 805.235.6265 The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. THE STATE (ALASKA GOVERNOR MIKE DUNLEAVY Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Milne Point Field, Schrader Bluff Oil Pool, MPU S-57 Hilcorp Alaska, LLC Permit to Drill Number: 220-013 Surface Location: 3244' FSL, 443' FEL, SEC. 12, T12N, R10E, UM, AK Bottomhole Location: 383' FNL, 2035' FWL, SEC. 35, T13N, R10E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Je e M. rice Chair DATED this I day of February, 2020. STATE OF ALASKA JAN 2 4 2020 ALr 61<A OIL AND GAS CONSERVATION COMMioSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: 1b.. Proposed Well Class: Exploratory - Gas ❑ Service- WAG ❑ Service - Disp ❑ 1c. Specify if well is proposed for: Drill ❑✓ ' Lateral ❑ Stratigraphic Test ❑ Development - Oil Q ' Service - Winj ❑ Single Zone ❑✓ Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: Hilcorp Alaska, LLC Bond No. 022224484 MPU S-57 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 13,632' - TVD: 4,103' Milne Point Field Schrader Bluff Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 3244' FSL, 443' FEL, Sec 12, T12N, R10E, UM, AK ADL380109 / ADL025518 --iv , ;!)f� l� Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 2448' FNL, 1453' FEL, Sec 12, T12N, R10E, UM, AK LONS 01-001 2/11/2020 , 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 383' FSL, 2035' FWL, Sec 35, T13N, R10E, UM, AK 5120 2831' to nearest unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 62.8' 15. Distance to Nearest Well Open Surface: x-565567 y- 5999908 ' Zone -4 GL / BF Elevation above MSL (ft): 36.3' to Same Pool: 70' to MPU-S17L1 16. Deviated wells: Kickoff depth: 250 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 1809 - Surface: 1398 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Cond 20" 215# X-42 Weld 107' Surface Surface 107' 107' ±270 ft3 Stg 1 L- 732 ft3 / T - 458 ft3 12-1/4" 9-5/8" 40# L-80 TXP SR 5,298' Surface Surface 5,298' 4,113' Stg 2 L - 1937 ft3 / T - 314 ft3 Tieback 7" 26# L-80 TXP SR 5,148' Surface Surface 5,148' 4,113' Tieback Assy. 8-1/2" 1 6-5/8" 20# L-80 Hyd 563 8,48,V 1 5,148' 4,113' 1 3,632 1 4,103' Cementless Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No 20. Attachments: Property Plat ❑ BOP Sketch Drilling Program ❑ Time v. Depth Plot ❑ ❑ Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Joe Engel Authorized Name: Monty Myers Contact Email: 'gn el hIICOr .COm Authorized Title: Drilling Manager Contact Phone: 777-8395 Authorized Signature: Date: �% , -?o ZO Commission Use Only Permit to Drill -� � Number: // // ,� l - �_-L: Permit Approval VD See cover letter for other Number: - 50 L% -- ' (=-'k--` = Date: 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: �`� )�� o� ��� - �- Samples req'd: Yes ❑ No[T' Mud log req'd: Yes❑ No Er / HzS measures: Yes ❑ No ❑ Directional svy req'd: Yes Q No ❑ Spacing exception req'd: Yes ❑ No[:]" Inclination -only svy req'd: Yes ❑ No Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BY Approved by. \ VV s COMMISSIONER THE COMMISSION Date:Z Submit Form Ind Fo m 0-4 1 R v d 5/ 17 This permit is valid f r 4RihO-INdAtappir—, per 20 AAC 25.045(g) attachment in Duplicate _`(-Ac' ��� Hilcorp Alaska, LLC Milne Point Unit (MPU) S-57 Drilling Program Version 1 1/24/2020 Table of Contents 1.0 Well Summary.................................................................................................................................2 2.0 Management of Change Information............................................................................................3 3.0 Tubular Program: ........................................................................................................................... 4 4.0 Drill Pipe Information: ................................................................................................................... 4 5.0 Internal Reporting Requirements..................................................................................................5 6.0 Planned Wellbore Schematic..........................................................................................................6 8.0 Drilling / Completion Summary.....................................................................................................7 9.0 Mandatory Regulatory Compliance / Notifications.....................................................................8 10.0 R/U and Preparatory Work..........................................................................................................10 11.0 N/U 13-5/8" 5M Diverter System.................................................................................................11 12.0 Drill 12-1/4" Hole Section.............................................................................................................13 13.0 Run 9-5/8" Surface Casing...........................................................................................................16 14.0 Cement 9-5/8" Surface Casing.....................................................................................................21 15.0 ND Diverter, NU BOPE, & Test...................................................................................................26 16.0 Drill 8-1/2" Hole Section...............................................................................................................27 17.0 Run 6-5/8" Production Liner........................................................................................................32 18.0 Run 7" Tieback..............................................................................................................................36 19.0 Run Upper Completion.................................................................................................................39 20.0 Innovation Rig Diverter Schematic.............................................................................................41 21.0 Innovation Rig BOP Schematic....................................................................................................42 22.0 Wellhead Schematic......................................................................................................................43 23.0 Days Vs Depth................................................................................................................................44 24.0 Formation Tops & Information...................................................................................................45 25.0 Anticipated Drilling Hazards.......................................................................................................46 26.0 Innovation Rig Layout..................................................................................................................49 27.0 FIT Procedure................................................................................................................................50 28.0 Innovation Rig Choke Manifold Schematic................................................................................51 29.0 Casing Design.................................................................................................................................52 30.0 8-1/2" Hole Section MASP............................................................................................................53 31.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................54 32.0 Surface Plat (As Staked) (NAD 27)..............................................................................................55 Hilcorp E—W - 1.0 Well Summary Milne Point Unit S-57 SB Producer Drilling Procedure Well MPU S-57 Pad Milne Point "S" Pad Planned Completion Type Jet Pump on 3-1/2 tubing Target Reservoir(s) Schrader Bluff NE Sand % Planned Well TD, MD / TVD 13,631' MD / 4,102' TVD PBTD, MD / TVD 13,621' MD / 4,102' TVD Surface Location (Governmental) 3244' FSL, 443' FEL, Sec 12, T12N, R10E, UM, AK Surface Location (NAD 27) X= 565567.7, Y= 5999908.8 Top of Productive Horizon (Governmental) 2448' FNL, 1453' FEL, Sec 12, T12N, R10E, UM, AK TPH Location (NAD 27) X= 564562 Y= 5999488 BHL (Governmental) 383' FSL, 2035' FWL, Sec 35, TON, R10E, UM, AK BHL (NAD 27) X= 562703, Y= 6007583 AFE Number 2010572 AFE Drilling Days 18 AFE Completion Das 4 AFE Drilling Amount $3,910,090 AFE Completion Amount $1,893,480 AFE Facility Amount $391,000 Maximum Anticipated Pressure (Surface) 1398 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1809 si Work String 5" 19.5# S-135 NC 50 Innovation KB Elevation above MSL: 26.5 ft + 36.2 ft = 62.7 ft GL Elevation above MSL: 36.2 ft BOP Equipment 13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams Page 2 2.0 Milne Point Unit 5-57 SB Producer Drilling Procedure Management of Change Information Hilcorp Alaska, LLC Hilem Changes to Approved Permit to Drill Date: 9124/2020 Subject: Changes to Approved Permit to Drill for MPU S-57 File #: MPU 5-57 Drilling and Completion Program Any modifications to MPU S-57 Drilling & Completion Progra will be documented and approved below. Changes to an approved APD will be approved in advance pthe AOGCC. Approval: Prepared: Page 3 Drilling Manager Date Drilling Engineer Date 3.0 Tubular Program: Hole Section OD (in) ID (in) Drift in Conn OD Wt (#/ft) Milne Point Unit Conn Burst Collapse S-57 SB Producer Cond Hil 2 E it Cmnpany 7 Drilling Procedure 3.0 Tubular Program: Hole Section OD (in) ID (in) Drift in Conn OD Wt (#/ft) Grade s(psi)(psi) Conn Burst Collapse Tension -lbs Cond 20" 19.25" - - - X-52 Weld Min Max(k-lbs) 12-1/4" 9-5/8" 8.835" 8.679" 10.625" 40 L-80 TXP 5,750 3,090 916 Tieback 7" 6.276" 6.151" 7.656 26 L-80 TXP 7,240 5410 604 8-1/2" 6-5/8" Slotted 6.049 5.924 7.390 20 L-80 Hydril563 6,090 3,470 459 4.0 Drill Pipe Information: Hole OD ID (in) TJ ID TJ OD Wt Grade Conn M/IT M/LT Tension Section &, in (in) (in)(#/ft) Min Max(k-lbs) Surface & 5" 4.276" 3.25" 6.625" 19.5 S-135 DS50 36,100 43,100 560klb Production 5" 1 4.276" 1 3.25" 1 6.625" 1 19.5 1 S-135 I NC50 1 30,730 34,136 560klb All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 4 ff Hilcorp E—W Company 5.0 Internal Reporting Requirements Milne Point Unit S-57 SB Producer Drilling Procedure 5.1 Fill out daily drilling report and cost report on WellEz. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area — this will not save the data entered, and will navigate to another data entry. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. • Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcorp.com, mmyers@hilcorp, jengel@hilcorp.com and cdinger@hilcorp.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by lam on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 5.4 EHS Incident Reporting • Health and Safety: Notify EHS field coordinator. • Environmental: Drilling Environmental Coordinator • Notify Drilling Manager & Drilling Engineer on all incidents • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final "As -Run" Casing tally to mmyers@hilcorp.com jengel@hilcorp.com and cdinger@hilcorp.com 5.6 Casing and Cement report • Send casing and cement report for each string of casing to mmyers@hilcorp.com jengel(2hilcorp.com and cdinger(cr�,hilcorp.com 5.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmyers@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 jengel@hilcorp.com Completion Engineer Ian Toomey 907.777.8434 907.903-3987 itoomey@hilcorp.com Geologist Kevin Eastham 907.777.8316 907.360.5087 keastham@hilcorp.com Reservoir Engineer Reid Edwards 907.777.8421 907.250.5081 reedwards@hilcorp.com Drilling Env. Coordinator Keegan Fleming 907.777.8477 907.350.9439 kfleming@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 cajones@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorp.com Page 5 Hilcorp E..w C..P-y 6.0 Planned Wellbore Schematic Milne Point Unit S-57 SB Producer Drilling Procedure Milne Paint Unit Well: MPU S-5; Proposed 'opC7sed Schematic Last Completed:FuturL i -La. PTU: TBD r----"'------'--'-'-"------"-"------------------------------------, TREE &WELLHEAD 0�& KB EeL: Mg/GL Eey__ 35-Y Trrr Camrran 4.1/16' 5M Wellhrsd FMCil"SMTC-IAwJII'x41/2'TCilTrapamWHEMI ang flarger with 3" OW "I I' BPJ praffie. gra 316' NPT carinal lines. 7.0 Page 6 TD= 13,;ZZ MJ/;I.CV Tt D PUM =13,;32' IAD/ 4,148' TM - - - -- ----------------- - - - -- - - --- -- ---- -- ------------ OPEN HOLE f CEMENT DETAIL 20' x 34" 270 113 Cemerd m surhxe in a 42" We 9 -SJ Utstage 1-732 h3 / T - 459 ft3 in a 12-1/4' hde 95/8'2ndstage L-1937ft3/T-314ft3ina12-114"hole 6-S/8" ( yy4 Slatted liner in 8-V2' hok SLATTED LINER DETAIL I Top(MD) SM (MD) Top (TVD) (N,D} FT Dace soros Teo WELL INCLINATION DETAIL XOP @ 259 Max f Io1r Angle =19ff -------------- N: ------------ h: T.p MD ---------------------------------------- CASING DETAIL IL Siz_ Type Grade/ Conn ID Top p 5PF 20'x34" Conductar(Insulatedj 21S/X-42/Weld N/A Surface lu WA 9-5/9' Surface 40 / L-80 / TXP 8.83S" Surface 5,296' 0-B758 7" Tieback 26/1-80/UP 6.276' Surface 5,146' 0-0363 65/6 L-ner(Shttedl 201L-80/U$AW 563 6.04!' 5,148' 13,632' 0.0355 8 -_4,190' TUBING DETAIL 2.685" 9 14,650 3-112" Tubing 93/L-80/EUC 1 2.867- 1 Surface 1 15,250 0-Ofl67 SLATTED LINER DETAIL I Top(MD) SM (MD) Top (TVD) (N,D} FT Dace soros Teo WELL INCLINATION DETAIL XOP @ 259 Max f Io1r Angle =19ff -------------- N: ------------ h: T.p MD Item IL Upper Cam '-n 1 12'9' Tubing Hanger- FMCTCIA 2 130' Crmumr.. 4-112' x 3-1/2" 2.867" 3 -_2,10(7 StAl: 3-1/2"x ]" SLB GLM w/shear-cut varve 2.867' 4 14,161E 3-1,12" BH Discharge Gauge (Tubing Rradj 2.675" S -_4,165' 3-In-IIESSliding Sleeve {2813"Padri 8orej 2.613' 6 14,170' 3412' 611 Suction Gauge jrubin g Readl 2.675" 7 14,176' X -Ni Ple(HES) I 2.813" 8 -_4,190' T x 3-112' HES PHL Rrtrrevable Pack+_r 2.685" 9 14,650 XNNipple(1{CSjM1N1D=2.75"{WhhRHCPLUGI 2.754" 10 5,2511 3-1,Q_^ Tubing WLEG 2.667" Lrnvrr C - - . ktion 11 5,146' S12)iP LTP with LIG slips (IUT TO Sleme)T 6.190" 125,155' Lor3tar Sub TC -11 Smx Bax (625" 00 Nu -Go) 6.151" 13 5,2w Crmsaver, 7' 563 Box x 6-518" 563 Pin 5.924" 14 113,632' I Shoe - I--------------------------------------------- GENERAL WELL INFO APL-T2D Drilled Cased&Completed InrmatiQrFuWrr Milne Point Unit S-57 SB Producer Drilling Procedure 8.0 Drilling / Completion Summary MPU 5-57 is a grassroots jet pump producer planned to be drilled in the Schrader Bluff Ne sand. S-57 is part of a two well program targeting the Schrader Bluff Ne sand on S -Pad. -K— The K- The directional plan is a catenary well path build, 12.25" hole with 9-5/8" surface casing set into the top of the Schrader Bluff Ne sand. An 8.5" lateral section will then be drilled. A 6-5/8" slotted liner will be run in the open hole section and the well produced with a jet pump assembly. The Innovation Rig will be used to drill and complete the wellbore Drilling operations are expected to commence approximately February 11, 2020, pending rig schedule. Surface casing will be run to 5,297' MD / 4,112' TVD and cemented to surface via a 2 stage primary cement job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed, necessary remedial action will then be discussed with AOGCC authorities. All cuttings & mud generated during drilling operations will be hauled to the Milne Point "B" pad G&I facility. - General sequence of operations: 1. MIRU Innovation Rig to well site 2. N/U & Test 13-5/8" Diverter and 16" diverter line 3. Drill 12-1/4" hole to TD of surface hole section. Run and cement 9-5/8" surface casing 4. N/D diverter, N/U wellhead, NU 13-5/8" 5M BOP & Test 5. Drill 8-1/2" lateral to well TD. 6. Run 6-5/8" production liner 7. Run 7" tieback 8. Run Upper Completion 9. N/D BOP, N/U Tree, RDMO Reservoir Evaluation Plan: 1. Surface hole: No mud logging. On Site geologist. LWD: GR + Res 2. Production Hole: No mud logging. On site geologist. LWD: GR + ADR (For geo-steering) Page 7 Milne Point Unit S-57 SB Producer Drilling Procedure 9.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the all applicable AOGCC regulations, specific regulations are listed below. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2) week intervals during the drilling and completion of MPU S-57. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3000 psi & subsequent tests of the BOP equipment will be to 250/3000 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation or control fluid flow from the well bore, AOGCC is to he notified and we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will he charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements". o Ensure the diverter vent line is at least 75' away from potential ignition sources • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: No variances are requested at this time. Page 8 Milne Point Unit S-57 SB Producer Drilling Procedure Summary of Innovation BOP Equipment & Test Requirements Hole Section Equipment Test Pressure(psi) 12 1/4" 0 13-5/8" 5M CTI Annular BOP w/ 16" diver -ter line Function Test Only • 13-5/8" x 5M Control Technology Inc Annular BOP • 13-5/8" x 5M Control Technology Inc Double Gate Initial Test: 250/3000 o Blind ram in btm cavity • Mud cross w/ 3" x 5M side outlets 8-1/2" 0 13-5/8" x 5M Control Technology Single ram • 3-1/8" x 5M Choke Line Subsequent Tests: i • 3-1/8" x 5M Kill line 250/3000 • 3-1/8" x 5M Choke manifold • Standpipe, floor valves, etc Primary closing unit: Control Technology Inc. (CTI), 6 station, 3000 psi, 220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an electric triplex pump on a different electrical circuit and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: • Well control event (BOPS utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: jim.regggalaska.gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartzgalaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: Victoria. loepp2alaska. gov Mel Rixse / Petroleum Engineer / (0): 907-793-1231 / (C): 907-223-3605 / Email: melvin.rixsenaegalaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotifhtml Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 Milne Point Unit S-57 SB Producer Drilling Procedure 10.0 RX and Preparatory Work 9.1 S-57 will utilize a newly set 20" conductor on S -Pad. Ensure to review attached surface plat and make sure rig is over appropriate conductor. 9.2 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.3 Install landing ring. 9.4 Insure (2) 4" nipples are installed on opposite sides of the conductor with ball valves on each. 9.5 Level pad and ensure enough room for layout of rig footprint and R/U. 9.6 Rig mat footprint of rig. 9.7 MIRU Innovation. Ensure rig is centered over conductor to prevent any wear to BOPE or wellhead. 9.8 Mud loggers WILL NOT be used on either hole section. 9.9 Mix spud mud for 12-1/4" surface hole section. Ensure mud temperatures are cool (<80°F). 9.10 Ensure 5" liners in mud pumps. • White Star Quattro 1300 Hp mud pumps are rated at 4097 psi, 381 gpm @ 140 spm @ 96.5% volumetric efficiency. Page 10 11.0 NX 13-5/8" 5M Diverter System Milne Point Unit S-57 SB Producer Drilling Procedure 10.1 N/U 13-5/8" CTI BOP stack in diverter configuration (Diverter Schematic attached to program). • N/U 20" x 13-5/8" DSA • N/U 13 5/8", 5M diverter "T". • NU Knife gate & 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). • Diverter line must be 75 ft from nearest ignition source • Place drip berm at the end of diverter line. • Utilized extensions if needed. 10.2 Notify AOGCC. Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked "warning zone" is established on each side and ahead of the vent line tip. "Warning Zone" must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. Page 11 L/ Hilcorp Energy C—v+Fr 10.4 Rig & Diverter Orientation: • May change on location 7S' Radius Clear of Ignition Sources —• Diverter tine MPU S Pad Page 12 Milne Point Unit S-57 SB Producer Drilling Procedure ■Q 41 ■� I I S-57 3 1 ■ :32 I ■ 311 *Drawing Not To Scale Hilcorp 12.0 Drill 12-1/4" Hole Section Milne Point Unit S-57 SB Producer Drilling Procedure 11.1 P/U 12-1/4" directional drilling assembly: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Be sure to run a UBHO sub for wireline gyro • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Drill string will be 5" 19.5# 5-135. • Run a solid float in the surface hole section. 11.2 Begin drilling out from 20" conductor at reduced flow rates to avoid broaching the conductor. • Consider using a trash bit to clean out conductor to mitigate potential damage from debris in conductor. 11.3 Drill 12-1/4" hole section to section TD, in the Schrader NE sand. Confirm this setting depth with the Geologist and Drilling Engineer while drilling the well. • Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. • Efforts should be made to minimize dog legs in the surface hole. Keep DLS < 6 deg / 100. • Hold a safety meeting with rig crews to discuss: • Conductor broaching ops and mitigation procedures. • Well control procedures and rig evacuation • Flow rates, hole cleaning, mud cooling, etc. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Keep mud as cool as possible to keep from washing out permafrost. • Pump at 400-600 gpm. Monitor shakers closely to ensure shaker screens and return lines can handle the flow rate. • Ensure to not out drill hole cleaning capacity, perform clean up cycles or reduce ROP if packoffs, increase in pump pressure or changes in hookload are seen • Slow in/out of slips and while tripping to keep swab and surge pressures low • Ensure shakers are functioning properly. Check for holes in screens on connections. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of pea gravel, clay balling or packing off. • Adjust MW and viscosity as necessary to maintain hole stability, ensure MW is at a 9.2 minimum at TD (pending MW increase due to hydrates). • Perform wireline gyros until clean MWD surveys are seen. Take MWD surveys every stand drilled. Page 13 Milne Point Unit S-57 SB Producer Drilling Procedure Y • Gas hydrates have not been seen on M -Pad. However, be prepared for them. In MPU they have been encountered typically around 2100-2400' TVD (just below permafrost). Be prepared for hydrates: • Gas hydrates can be identified by the gas detector and a decrease in MW or ECD • Monitor returns for hydrates, checking pressurized & non -pressurized scales • Do not stop to circulate out gas hydrates — this will only exacerbate the problem by washing out additional permafrost. Attempt to control drill (150 fph MAX) through the zone completely and efficiently to mitigate the hydrate issue. Flowrates can also be reduced to prevent mud from belching over the bell nipple. Consider adding Lecithin to allow the gas to break out. • Gas hydrates are not a gas sand, once a hydrate is disturbed the gas will come out of the well. MW will not control gas hydrates, but will affect how gas breaks out at surface. Surface Hole AC: • There are no wells with a clearance factor of <1.0 11.4 12-1/4" hole mud program summary: • Density: Weighting material to be used for the hole section will be barite. Additional barite or spike fluid will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg and TD with 9.2+ ppg. Depth Interval MW (ppg) Surface — Base Permafrost 8.9+ Base Permafrost - TD 9.2+ (For Hydrates if need based on offset wells) MW can be cut once —500' below hydrate zone • PVT System: PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. • Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. • Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM (10 ppb total) BARACARBsBAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. • Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high -clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5 — 9.0 range with caustic soda. Daily additions of ALDACIDE G / X- CIDE 207 MUST be made to control bacterial action. Page 14 • Casing Running: Reduce system YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what YP value they have targeted). System Type: 8.8 - 9.2 ppg Pre -Hydrated Aquagel/freshwater spud mud Properties: Section Density Viscosity Plastic Viscosity Yield Point API FL pH Milne Point Unit Surface 8.8 - 9.8 75-175 20-40 S-57 SB Producer <10 Hilco+T/�+� E—W Comyuy Drilling Procedure • Casing Running: Reduce system YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what YP value they have targeted). System Type: 8.8 - 9.2 ppg Pre -Hydrated Aquagel/freshwater spud mud Properties: Section Density Viscosity Plastic Viscosity Yield Point API FL pH Tem Surface 8.8 - 9.8 75-175 20-40 25-45 <10 8.5 - 9.0 <- 70 F System Formulation: Gel + FW spud mud Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 15 - 20 ppb caustic soda 0.1 ppb (8.5 - 9.0 pH) BARAZAN D+ as needed BAROID 41 as required for 8.8 - 9.2 ppg PAC -L /DEXTRID LT if required for <10 FL ALDACIDE G 0.1 ppb 11.5 At TD; PU 2-3 stands off bottom, CBU, pump tandem sweeps and drop viscosity. 11.6 RIE t/ bottom, proceed to BROOH t/ HWDP • Pump at full drill rate (400-600 gpm), and maximize rotation. • Pull slowly, 5 — 10 ft / minute, adjust as dictated by hole conditions • Monitor well for any signs of packing off or losses. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. • If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.7 TOOH and LD BHA J 11.8 No open hole logging program planned. Page 15 ./ 13.0 Run 9-5/8" Surface Casing 12.1 R/U and pull wearbushing. Milne Point Unit S-57 SB Producer Drilling Procedure 12.2 R/U Weatherford 9-5/8" casing running equipment (CRT & Tongs) • Ensure 9-5/8" TXP x DS50 XO on rig floor and M/U to FOSV. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • R/U of CRT if hole conditions require. • R/U a fill up tool to fill casing while running if the CRT is not used. • Ensure all casing has been drifted to 8.75" on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 12.3 PIU shoe joint, visually verify no debris inside joint. 12.4 Continue M/U & thread locking 120' shoe track assemblv consisting of: Page 16 9-5/8" Float Shoe 1 joint — 9-5/8" TXP, 2 Centralizers 10' from each end w/ stop rings 1 joint — 9-5/8" TXP, 1 Centralizer mid joint w/ stop ring 9-5/8" Float Collar w/ Stage Cementer Bypass Baffle `Top Hat' 1 joint — 9-5/8" TXP, 1 Centralizer mid joint with stop ring 9-5/8" HES Baffle Adaptor Ensure bypass baffle is correctly installed on top of float collar. This end up. Bypass Baffle Ensure proper operation of float equipment while picking up. Ensure to record S/N's of all float equipment and stage tool components. 12.5 Float equipment and Stage tool equipment drawings: Type H ES Cementer Part No. SO No_ Closing Sleeve No. Shear Pins Opening Sleeve No. Shear Pins ES Cementer Depth Baffle Adapter (if used) ID Depth Bypass or Shut-off Baffle ID Depth Float Collar Depth Float Shoe Depth Hole TD "Reference Casing Sales Manual Section 5 Page 17 "A Hikarp ES4I Running Order Part No. Overall Length B Shut Off Plug Lim. ID after Drillout C OD Me.. Terol OD D Br -Dass Plug Opening Seat ID E OD Closing Seat ID Plug Set Hikarp ES4I Running Order Part No. ES41 Cementer SO No_ Shut Off Plug Closing Plug OD Opening Plug Br -Dass Plug OD OD Shut-off Plug OD Bypass Plug (if used) OD Milne Point Unit S-57 SB Producer Drilling Procedure Hikarp ES4I Running Order ES41 Cementer Shut Off Plug Baffle Adapter Br -Dass Plug By Pus Baffle Float Collar Mat Shoe Milne Point Unit S-57 SB Producer Drilling Procedure 12.6 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • Centralization: • 1 centralizer every joint t/ — 1000' MD from shoe • 1 centralizer every joints to 2,000' above shoe (Top of Lowest Ugnu) • Verify depth of lowest Ugnu water sand for isolation with Geologist • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. • Any packing off while running casing should be treated as a major problem. It is preferable to POH with casing and condition hole than to risk not getting cement returns to surface. 12.7 Install the Halliburton Type H ES -11 Stage tool so that it is positioned at least 100' TVD below the permafrost (— 2,500' MD). (Halliburton ESIPC with packer element may be used). • Install centralizers over couplings on 5 joints below and 5joints above stage tool. • Do not place tongs on ES cementer, this can cause damaged to the tool. • Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3300 psi. • ESIPC: Ensure tool is pinned properly. ESIPC packer to inflate at — 2080 psi, and the tool to open at — 3000 psi. Reference ESIPC Procedure. 9-5/8" 40# L-80 TXP Make Up Torques: Casing OD Minimum Optimum Maximum 9-5/8" 18,860 ft -lbs 20,960 ft -lbs 23,060 ft -lbs Page 18 Y/ GEOMETRY Nominal OD 9.625 in Nominal lNeight 40 lbsfft Drift 8.679 in. Nominal ID 8.835 in 1%raTThickness 0.395 In_ Plain Endth'eight 38.97 lbsYt OD Tolerance API PERFORMANCE Body Y Sve & 916 x1000lbs trAema!! Y56d 5750 psi SMYS 60000 psi Collapse 3090 psi GEOMETRY Cannectlon OD 10.625 in. C %cI-g _e g:h 10.825 in. Connection ID 8.823 in Make-up Lcss 4.891 in. Tares:_- per,h 5 Connection OD Option REGULAR PERFORMANCE Tension Eirciency 100.0% :tart Y-aed Strength 916.000x1000 Internal Pressure Capacity In 5750.000 psi Milne Point Unit lbs Compression Efficiency 100% Compression Stre-,:l, 916..000 x1000 Max. Allowable Bending 38 `3i 00 ft lbs S-57 SB Producer Hilcox Energy Company M ,murr 18860 8- s Optimum 20960 f:-bs Maximum 231560 ft -lbs Drilling Procedure Operating Torgae 35600 itks Yield Torque 43400 f: -'t=_ Notes This connection is fully interchangeable with: TXPQ BTC TXPt BTC - 9.625 in_ - 36143.5147133.5158.4 ibsAt �daa 11/0812018 Outside Diameter 9.625 in. Min. Wall Thickness 87.535 lai Grade L80 11111111111110i, Please contact a local Tenarts technical sales representative. Type 1 Wall Thickness 0.395 in. Connection OD Option REGULAR COUPLING PIPE BODY 0 Grade LBO Type A' Orirt API Standard may: Red 1st Land: Red 1st Bard: Brown 2rc Bard: 2nd Sand: - Brown Type Casing 3rd Band:- 3rd Band: - 4th Band. - GEOMETRY Nominal OD 9.625 in Nominal lNeight 40 lbsfft Drift 8.679 in. Nominal ID 8.835 in 1%raTThickness 0.395 In_ Plain Endth'eight 38.97 lbsYt OD Tolerance API PERFORMANCE Body Y Sve & 916 x1000lbs trAema!! Y56d 5750 psi SMYS 60000 psi Collapse 3090 psi GEOMETRY Cannectlon OD 10.625 in. C %cI-g _e g:h 10.825 in. Connection ID 8.823 in Make-up Lcss 4.891 in. Tares:_- per,h 5 Connection OD Option REGULAR PERFORMANCE Tension Eirciency 100.0% :tart Y-aed Strength 916.000x1000 Internal Pressure Capacity In 5750.000 psi lbs Compression Efficiency 100% Compression Stre-,:l, 916..000 x1000 Max. Allowable Bending 38 `3i 00 ft lbs Ezemal Presssre Capacity 3090.000 ps MAKE-UP TORQUES M ,murr 18860 8- s Optimum 20960 f:-bs Maximum 231560 ft -lbs OPERATION LIMIT TORQUES Operating Torgae 35600 itks Yield Torque 43400 f: -'t=_ Notes This connection is fully interchangeable with: TXPt BTC - 9.625 in_ - 36143.5147133.5158.4 ibsAt [1] Intemal Pressure Capacity related to structural resistance only. Internal pressure leak resistance as per section 10.3 API 5C31 ISO 10400 - 2007. Datasheet is also valid for Special Bevel option when applicable - except for Coupling Face Load, which will be reduced. Please contact a local Tenarts technical sales representative. Page 19 PAV 12.8 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • Centralization: o 1 centralizer every 2 joints to base of conductor 12.9 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.10 Slow in and out of slips. 12.11 P/U landing joint and M/U to casing string. Position the casing shoe +/- 10' from TD. Strap the landing joint prior to the casing job and mark the joint at (1) ft intervals to use as a reference when getting the casing on depth. 12.12 Lower casing to setting depth. Confirm measurements. 12.13 Have slips staged in cellar, along with necessary equipment for the operation. 12.14 Circulate and condition mud through CRT. Reduce YP to < 20 to help ensure success of cement job. Ensure adequate amounts of cold M/U water are available to achieve this. If possible reciprocate casing string while conditioning mud. Page 20 Milne Point Unit S-57 SB Producer Hilco E—Wc Drilling Procedure 12.8 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • Centralization: o 1 centralizer every 2 joints to base of conductor 12.9 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.10 Slow in and out of slips. 12.11 P/U landing joint and M/U to casing string. Position the casing shoe +/- 10' from TD. Strap the landing joint prior to the casing job and mark the joint at (1) ft intervals to use as a reference when getting the casing on depth. 12.12 Lower casing to setting depth. Confirm measurements. 12.13 Have slips staged in cellar, along with necessary equipment for the operation. 12.14 Circulate and condition mud through CRT. Reduce YP to < 20 to help ensure success of cement job. Ensure adequate amounts of cold M/U water are available to achieve this. If possible reciprocate casing string while conditioning mud. Page 20 14.0 Cement 9-5/8" Surface Casing Milne Point Unit S-57 SB Producer Drilling Procedure 13.1 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. Ensure mud & water can be delivered to the cementing unit at acceptable rates. • How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. • Which pumps will be utilized for displacement, and how fluid will be fed to displacement PUMP. • Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. • Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses • Review test reports and ensure pump times are acceptable. • Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 13.4 RAJ cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 13.5 Fill surface cement lines with water and pressure test. 13.6 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug (flexible bypass plug) — HEC rep to witness. Mix and pump cement per below calculations for the 1 st stage, confirm actual cement volumes with cementer after TD is reached. 13.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead & tail, TOC brought to stage tool. Estimated 111 Stage Total Cement Volume: Page 21 Section Calculation Vol (bbl) Vol (ft3) 12-1/4" OH x 9-5/8" (4,297' - 2500') x .0558 bpf x 1.3 = 130.4 731.9 J Casing Total Lead 130.4 731.9 12-1/4" OH x 9-5/8" (5,297' - 4,297') x .0558 bpf x 1.3 = 72.5 407 — Casing" F�-5/8Shoe Track 120'x .0758 bpf = 9.1 51.09 Total Tail 81.6 458 Page 21 Hilcorp Energy Company Milne Point Unit S-57 SB Producer Drilling Procedure Cement Slurry Design (1st Stage Cement Job): 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets "sticky", cease pipe reciprocation and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. • Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very accurate using 0.0625 bps (5" liners) for the Quattro pump output. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: 5177' x .0758 bpf = 392.4bbls 80 bbls of tuned spacer to be left behind stage tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, ±4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. 13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until Page 22 Lead Slurry Tail Slurry Density 12.0 lb/gal 15.8 lb/gal Yield 2.35 ft3/sk 1.16 ft3/sk Mixed Water 13.92 gal/sk 4.98 gal/sk 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets "sticky", cease pipe reciprocation and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. • Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very accurate using 0.0625 bps (5" liners) for the Quattro pump output. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: 5177' x .0758 bpf = 392.4bbls 80 bbls of tuned spacer to be left behind stage tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, ±4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. 13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until Page 22 HilmEnema: Milne Point Unit S-57 SB Producer Drilling Procedure cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held, this is to ensure the stage tool is not prematurely opened. 13.16 Increase pressure to 3300 psi to open circulating ports in stage collar.Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface and volume pumped to see the returns. Circulate until YP < 20 again in preparation for the 2nd stage of the cement job. J 13.17 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker bypass line to the cuttings tank. Have black water available and vac trucks ready to assist. Ensure to flush out any rig components, hard lines and BOP stack that may have come in contact with the cement. Page 23 Hilc E..W'2orp Second Stage Surface Cement Job: Milne Point Unit S-57 SB Producer Drilling Procedure 13.18 Prepare for the 2nd stage as necessary. Circulate until first stage reaches sufficient compressive strength. Try to maintain flow rate through stage tool until 2nd stage is ready. Hold pre job safety meeting. • Past wells have seen pressure increase while circulating through stage tool after reduced rate 13.19 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 13.20 Fill surface lines with water and pressure test. 13.21 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.22 Mix and pump cmt per below recipe for the 2nd stage. 13.23 Cement volume based on annular volume + open hole excess (200% for lead and 100% for tail). Job will consist of lead & tail, TOC brought to surface. However cement will continue to be pumped until clean spacer is observed at surface. Estimated 21d Stage Total Cement Volume: Cement Slurry Design (2nd stage cement job): Section Calculation Vol (bbl) Vol (ft3) 20" Conductor x 9-5/8" Casing (110') x .26 bpf x 1= 28.6 161 4.41 ft3/sk 12-1/4" OH x 9-5/8" Casing (2000'- 110') x.0558 bpf x 3 = 316.4 1776.3 Total Lead 345 1937 — 12-1/4" OH x 9-5/8" Casing ( 2500' - 2000') x .0558 b pf x 2 = 55.8 314 ~ Total Tail 55.8 314 Cement Slurry Design (2nd stage cement job): Page 24 Lead Slurry Tail Slurry System Permafrost L Density 10.7 Ib/gal 15.8 Ib/gal Yield 4.41 ft3/sk 1.17 ft3/sk Mixed Water 22.02 gal/sk 5.08 gal/sk Page 24 Hilcorp Energy COIDPmY Milne Point Unit 5-57 SB Producer Drilling Procedure 13.24 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail. 13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. 13.26 Displacement calculation: 2500' x .0758 bpf = 190 bbls mud 13.27 Monitor returns closely while displacing cement. Adjust pump rate if necessary. Wellhead side outlet valve in cellar can be opened to take returns to cellar if required. Be prepared to pump out fluid from cellar. Have black water available to retard setting of cement. 13.28 Decide ahead of time what will be done with cement returns once they are at surface. We should circulate approximately 100 - 150 bbls of cement slurry to surface. �- 13.29 Land closing plug on stage collar and pressure up to 1000 — 1500 psi to ensure stage tool closes. Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool has closed. Slips will be set as per plan to allow full annulus for returns during surface cement job. Set slips 13.30 Make initial cut on 9-5/8" final joint. L/D cut joint. Make final cut on 9-5/8". Dress off stump. Install 9-5/8" wellhead. If transition nipple is welded on, allow to cool as per schedule. 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 a. Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure e. Note if pre flush or cement returns at surface & volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As -Run "casing tally & casing and cement report to lengeighilcorp. com and cdinger(a,hilcorp. com This will be included with the EOW documentation that goes to the AOGCC. Page 25 15.0 ND Diverter, NU BOPE, & Test Milne Point Unit S-57 SB Producer Drilling Procedure 14.1 ND the diverter T, knife gate, diverter line & NU 11" x 13-5/8" 5M casing spool. 14.2 NU 13-5/8" x 5M BOP as follows: • BOP configuration from top down: 13-5/8" x 5M annular / 13-5/8" x 5M double gate / 13- 5/8" x 5M mud cross / 13-5/8" x 5M single gate • Double gate ram should be dressed with 2-7/8" x 5" VBRs in top cavity, blind ram in bottom cavity. • Single ram can be dressed with 2-7/8" x 5" VBRs • NU bell nipple, install flowline. • Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to mud cross). • Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual valve 14.3 RU MPD RCD and related equipment 14.4 Run 5" BOP test plug 14.5 Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Test 5" tes 'oints p -r • Confirm test pressures with PTD • Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug • Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 14.6 RD BOP test equipment 14.7 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.8 Mix 8.9 ppg Baradrill-N fluid for production hole. 14.9 Set wearbushing in wellhead. 14.10 If needed, rack back as much 5" DP in derrick as possible to be used while drilling the hole section. 14.11 Ensure 5" liners in mud pumps. Page 26 16.0 Drill 8-1/2" Hole Section 15.1 MU 8.5" Cleanout BHA (Milltooth Bit & 1.22° PDM) Milne Point Unit S-57 SB Producer Drilling Procedure 15.2 TIH w/ 8-1/2" cleanout BHA to stage tool. Note depth TOC tagged on AM report. Drill out stage tool. 15.3 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 15.4 RU and test casing to 2500 psi / 30 min. Ensure to record volume / pressure (every 1/4 bbl) and plot on FIT graph. AOGCC reg is 50% of burst = 5750 / 2 = —2875 psi, but max test pressure on Vk the well is 2,500 psi as per AOGCC. Document incremental volume pumped (and subsequent Ls� pressure) and volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 15.5 Drill out shoe track and 20' of new formation. 15.6 CBU and condition mud for FIT. 15.7 Conduct FIT to 12.0 ppg EMW. Chart Test. Ensure test is recorded on same chart as FIT. Document increnrenfal volume pumped (and subsequent pressure) and volume returned. 15.8 POOH and LD cleanout BHA 15.9 PU 8-1/2" directional BHA. • Ensure BHA components have been inspected previously. • Drift and caliper all components before MU. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Ensure MWD is RU and operational. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Drill string will be 5" 19.5# 5-135 DS50 & NC50. • Run a ported float in the production hole section. 15.10 8-1/2" hole section mud program summary: • Density: Weighting material to be used for the hole section will be calcium carbonate. f Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. • Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid Page 27 Milne Point Unit S-57 SB Producer Drilling Procedure running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. • Rheology: Keep viscosifier additions to an absolute minimum (N -VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8.5 (hole diameter) for sufficient hole cleaning • Run the centrifuge continuously while drilling the production hole, this will help with solids removal. • Dump and dilute as necessary to keep drilled solids to an absolute minimum. • MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, & Toolpusher office. System Type: 8.9 — 9.5 ppg Baradrill-N drilling fluid Properties: Interval [ADensity PV YP LSYP Total Solids MBT HPHT Hardness Production 4 8.9-9.5 15-25 - ALAP 15-30 4-6 <10% <8 <1 1.0 <100 System Formulation: Product Concentration Water 0.955 bbl KCL 11 ppb KOH 0.1 ppb N -VIS 1.0 — 1.5 ppb DEXTRID LT 5 ppb BARACARB 5 4 ppb BARACARB 25 4 ppb BARACARB 50 2 ppb BARACOR 700 1.0 ppb BARASCAV D 0.5 ppb X-CIDE 207 0.015 ppb 15.11 TIH with 8-1/2" directional assembly to bottom 15.12 Install MPD RCD Page 28 15.13 Displace wellbore to 8.9 ppg Baradrill-N drilling fluid Milne Point Unit S-57 SB Producer Drilling Procedure 15.14 Begin drilling 8-1/2" hole section, on -bottom staging technique: • Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8K. • Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations • If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to PU off bottom and restart on bottom staging technique. If stick slip continues, consider adding .5% lubes 15.14 Drill 8-1/2" hole section to section TD per Geologist and Drilling Engineer. • Flow Rate: 350-550 GPM, target min. AV's 200 ft/min, 385 GPM • RPM: 120+ • Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly wet to maximize solids removal efficiency. Check for holes in screens on every connection. • Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low • Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection • Monitor Torque and Drag with pumps on every 5 stands • Monitor ECD, pump pressure & hookload trends for hole cleaning indication • Surveys can be taken more frequently if deemed necessary. • Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time.tet' • Use ADR to stay in section. Reservoir plan is to stay in 4S and. • Limit maximum instantaneous ROP to < 250 FPH. The sands will drill faster than this, but when concretions are hit when drilling this fast, cutter damage can occur. • Target ROP is as fast as we can clean the hole without having to backream connections • Schrader Bluff NB Concretions: 4-6% Historically • Anticipate similar concentrations in NE • MPD will be utilized to monitor pressure build up on connections. • 8-1/2" Lateral A/C: • S-17 1s an active OA sand lateral. Geologically there is no risk. • H-08 & H -08A are abandoned, -08 was the pilot hole and -08A was a lateral in the �lr t5� OA sand. The only risk is damage to the bit. • H -08B i an active producer in the OA & OB Sand (dual lateral). Geologically there is no risk._ • S -29L1 is an OA sand lateral and is shut in. Geologically there is no risk. 15.15 Reference: Open hole sidetracking practice: If a known fault is coming up, put a slight "kick-off ramp" in wellbore ahead of the fault so we have a nice place to low side. Page 29 Milne Point Unit S-57 SB Producer Drilling Procedure • Attempt to lowside in a fast drilling interval where the wellbore is headed up. • Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string back and forth. Trough for —30 min. • Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. 15.16 At TD, CBU at least 4 times at 200 ft/min AV (385+ GPM) and rotation (120+ RPM). Pump tandem sweeps if needed • Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent stream, circulate more if necessary • If seepage losses are seen while drilling, consider reducing MW at TD to 9.0 ppg minimum 15.17 Mix and pump 40 bbl 10 ppb SAPP pill. Lineup to a closed loop system and circulate three SAP pills with 50 bbl in between. Displace out SAP pills. Monitor shakers for returns of mud filter cake and calcium carbonate. Circulate the well clean. Losses during the cleanup of the wellbore are a good indication that the mud filter cake is being removed, including an increase in the loss rate. 15.18 Displace 1.5 OH + liner volume with viscosified brine. • Proposed brine blend (same as used on M-16, aiming for an 8 on the 6 RPM reading) - KCl: 7.1bbp for 2% NaCl: 60.9ppg for 9.4ppg Lotorq: 1.5% Lube 776: 1.5% Soda Ash: as needed for 9.5pH Busan 1060: 0.42ppb Flo -Vis Plus: 1.25ppb • Monitor well for loss rate and contact Drilling Engineer and/or Ops Engineer if further discussion needed prior to BROOH. 15.19 BROOH with the drilling assembly to the 9-5/8" casing shoe • Circulate at full drill rate (less if losses are seen, 350 GPM minimum). • Rotate at maximum RPM that can be sustained. • Pulling speed 5 — 10 min/stand (slip to slip time, not including connections), adjust as dictated by hole conditions • If backreaming operations are commenced, continue backreaming to the shoe Page 30 Hilcorp E—V C -Pay Milne Point Unit S-57 SB Producer Drilling Procedure 15.20 If abnormal pressure has been observed in the lateral, utilize MPD to close on connections while BROOH. 15.21 CBU minimum two times at 9-5/8" shoe and clean casing with high vis sweeps. 15.22 Monitor well for flow/pressure build up with MPD. Increase fluid weight if necessary. • Wellbore breathing has been seen on past MPU SB wells. Perform extended flow checks to ✓ determine if the well is breathing, treat all flow as an influx until proven otherwise. 15.23 POOH and LD BHA. 15.24 Continue to POOH and stand back BHA if possible. Rabbit DP on TOOH, ensure rabbit diameter is sufficient for future ball drops. 1 Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any additional logging runs conducted. -- ,i Page 31 17.0 Run 6-5/8" Production Liner Milne Point Unit S-57 SB Producer Drilling Procedure 16.1 Well control preparedness: In the event of an influx of formation fluids while running the 6- 5/8" pre drilled liner, the following well control response procedure will be followed: • PU & MU the 5" safety joint (with 6-5/8" crossover installed on bottom, TIW valve in open position on top, 6-5/8" handling joint above TIW). This joint shall be fully MU and available prior to running the first joint of 6-5/8" Predrilled liner. • Slack off and with 5" DP across the BOP, shut in ram or annular on 5" DP. Close TIW. • Proceed with well kill operations. 16.2 RU 6-5/8" liner running equipment. • Ensure 6-5/8" 20# Hydril 563 x DS -50 crossover is on rig floor and MU to FOSV. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck before running. • Keep hole covered while RU casing tools. • Record OD's, ID's, lengths, SN's of all components with vendor & model info. 16.3 Run 6-5/8" slotted production liner • Use API Modified or "Best O Life 2000 AG" thread compound. Dope pin end only with paint brush. Wipe off excess. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Run round nose float shoe on bottom. • 6-5/8" slotted liner will auto —fill • 6-5/8" Liner will be centralized with 1 per joint free floating • If needed, install swell packers as per the lower completion tally. • Remove protective packaging on swell packers just prior to picking up • Do not place tongs or slips on the packer element 6-5/8" 20 # Hydri1563 Torque OD Minimum Optimum Maximum Yield Torque 6-5/8 5,900 ft -lbs 7,100 ft -lbs 10,300 ft -lbs 36,000 ft -lbs Page 32 Hilcorp Energy Cmpaa, Wedge 5630 Page 33 Milne Point Unit S-57 SB Producer Drilling Procedure rmw m, 1111[161201 B Outsade DiamctLr 6.625 n Min. Wall 87.5% Thickness 7.390in- 4.950 in. j`j Grade LOD I WO CannacLx. ID C.annact" '13C. ii eta 5.959 : REGULAR PERFORMANCE Type 1 Wall Thicknews Ome nn Coratection OD REGULAR To r.r n Erc,er,-, Campf�-ewn Elicarwi, Eafnrnal Prassum caps it, 95.7 t: 100.0 2:, 3470.000 psi .Icint Y:cid Strc-gth C�mpr.,sr ry Sirany l^ CoupIng Fac* Load Option Vd.^.mat Prassva capaety Mas. Alc*z-,ic gsr lt^q COUPLING PIPE BOGY Body- Red 1 s1 Bald. Red {grade LBO Type 1 Drift APi Standard 15t Band: Brawn 2nd Band: 10309 `:.IDs OPERATION UMFT TORQUES 2nd Band-' Brown Type Casing 3Rd Baird... 3rd Band: . BUCK -ON 41h Bind. . PIPE BODY DATA, GEO6lETRY !+laminas©D 6.62 in. Alamiaal Weight 20.04[Wh Ligll 5.924 in. Naminal;�� 6.049tn. Vials 7hir-kness 0394 in. =lain End IV04 ,f,l 19511tsi9 00 TaIL-wca API PERFORIAANCE ee.9pYcidatra�n'Ith 459x100011ts k4emigYlold 6090 psi VAYS 90000osi =�atapso 3476 psi GOA NEC.TI _,f DATA C�EOBIEfRY Gonnectern 130 Maig-up Lc,-,- 7.390in- 4.950 in. Cadpirq Lon4lh Threads pa:. in 9.2Sin. 9.29 CannacLx. ID C.annact" '13C. ii eta 5.959 : REGULAR PERFORMANCE To r.r n Erc,er,-, Campf�-ewn Elicarwi, Eafnrnal Prassum caps it, 95.7 t: 100.0 2:, 3470.000 psi .Icint Y:cid Strc-gth C�mpr.,sr ry Sirany l^ CoupIng Fac* Load 439.2+63..1cCo lbs 459-9-- u:1@:0 Ias 313M lts Vd.^.mat Prassva capaety Mas. Alc*z-,ic gsr lt^q 6090AM psi 52.6 3: MAKE-UP TORQUES hirimum 5900 ft -lbs Opdmum 7taot.tDs Vqa mum 10309 `:.IDs OPERATION UMFT TORQUES 0f1.W2t;*g Tcraaa - 310401:.1as 'YiL-u Tama 360w t- s BUCK -ON mrimum 104OO 1. las &U imam 11300 h-ts Notes This connection is fully interchangeable with: Wedge 5639D - 6-625 in. - 24 f 28132 IbstTt connections with DopelessO Technok)gy are fully compatible w the same connectic in in its Standard version Milne Point Unit S-57 SB Producer Drilling Procedure 16.6. Ensure to run enough liner to provide for —150' overlap inside 9-5/8" casing. Ensure hanger/packer will not be set in a 9-5/8" connection. • AOGCC regulations require a minimum 100' overlap between the inner and outer strings as per 20 AAC 25.030(d)(6). Do not place liner hanger/packer across 9-5/8" connection. 16.7. Before picking up Baker SLZXP liner hanger/packer assembly, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 16.8. MU Baker SLZXP liner top packer to 6-5/8" liner. 16.9. Note PUW, SOW, ROT and torque of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 16.10. RIH with liner on 5" HWDP no faster than 30 ft/min — this is to prevent buckling the liner and drill string and weight transfer to get liner to bottom with minimal rotation. Watch displacement carefully and avoid surging the hole or buckling the liner. Slow down running speed if necessary. • Ensure 5" HWDP has been drifted • There is no inner string planned to be run, as opposed to previous wells. The DP should auto fill. Monitor FL and if filling is required due to losses/surging. 16.11. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + SO depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 16.12. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10 & 20 RPM. 16.13. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.14. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.15. Rig up to pump down the work string with the rig pumps. 16.16. Break circulation. Begin circulating at —1 BPM and monitor pump pressures. Do not exceed 1,600 psi while circulating. Pusher tool is set at 2,100 psi with f5% shear screws but it should be discussed before exceeding 1,600 psi. Note all losses. Confirm all pressures with Baker. 16.17. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. t� Page 34 Milne Point Unit S-57 SB Producer Drilling Procedure 16.18. Shut down pumps. Drop setting ball (ball seat now located in HRDE setting tool and not at the WIV) down the DP and pump slowly (1-2 BPM). Slow pump before the ball seats. Do not allow ball to slam into ball seat. 16.19. Continue pressuring up to 2,700 psi to set the SLZXP liner hanger/packer. Hold for 5 minutes. Slack off 20K on the ZXP liner hanger to ensure the HRDE setting tool is in compression for release from the SLZXP liner hanger/packer. Continue pressuring up 4,500 psi to release the HRDE running tool. 16.20. Bleed DP pressure to zero. Pick up to expose rotating dog sub and set down 50K without pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20 RPM and set down 50K again, 16.21. PU to neutral weight, close BOP and test annulus to 1500 psi for 10 min and chart record same. 16.22. Bleed off pressure and open BOPE. PU to verify that the HRDE setting tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. 16.23. PU pulling running tool free of the packer and circulate at max rate to wash the liner top. Pump sweeps as needed. 16.24. POOH. LD and inspect running tools. If setting of liner hanger/packer proceeded as planned, LD DP on the TOOH. Note: Once running tool is LD, swap to the completion AFE. 16.25. MU 3-1/2" wash tool and RIH with remaining DP out of derrick to liner top. 16.26. Wash through liner top at max rate and circulate hole clean. Pump sweeps around. Displace well to clean filtered brine after no solids are returned. 16.27. POOH and LD remaining 5" DP. Page 35 18.0 Run 7" Tieback Milne Point Unit S-57 SB Producer Drilling Procedure 17.1 RU and pull wear bushing. Get an accurate measurement of RKB to tubing hanger load shoulder to be used for tie -back space out calculation. Install 7" solid body casing rams in the upper ram cavity. RU testing equipment. PT to 250/3,000 psi with 7" test joint. RD testing equipment. 17.2 RU 7" casing handling equipment. �01' • Ensure Oto ade up to FOSV and ready on rig floor. • Rig up computer torque monitoring service. • String should stay full while running, RU fill up line and check as appropriate. 17.3 PU 7" tieback seal assembly and set in rotary table. Ensure 7" seal assembly has (4) 1" holes above the first seal. These holes will be used to spot diesel freeze protect in the 9-5/8" x 7" annulus. 17.4 MU first joint of 7" to seal assy. 17.6 Run 7", 26#, L-80 TXP tieback to position seal assembly two joints above tieback sleeve. Record PU and SO weights. 797,26#, L-80, TXP MU Torque OD Minimum Optimum Maximum Yield Torque 7" 13,280 ft -lbs 14,750 ft -lbs 16,230 ft -lbs 23,400 ft -lbs G/ Page 36 HilcoPP � S 7-656 in. Coupling Length, 10201 er Ccnnection 9D Milne Point Unit S-57 SB Producer Drilling Procedure Make-up Loss 4-579 in. Threads per kr 5 Ccnnecbcn 00, Cptcn REGULAR PERFORMANCE TXP(H) BTC �. Tension Effa,ir rrcy 100.0% Joint Y'*Id Strength 604.010 x 1000 kraa ral Press3re Capacity " ra of ,.mom 12106,+2018 Outside Diameter 7.000 in. Min. Wall 87.5% 100% Compression Strength 604-010 x1{G0 Max. Aiiwable Bending Thickness {•j Grade LBD lbs Extemal Pressure Capacity Type 1 Wall Thickness 0.362 in Connection OD REGULAR Option Minimum COUPLING PIPE BODY Opu— 14750 ft -lbs Ma)*M= 16230 it4bs OPERATION LIMIT TORQUES Body: Red 1st Band: Red Grade LBO Type 1' Drift API Standard 1st Bard: Brown 2nd Band: 23400 ft -lbs 2nd Band: - Brown Type Casing 3rd P.snd - 3rd Band: - 4th Band: - PIPE BODY DA—A GEOMETRY Plorrinal OD 7-000 in. Nominal Wedght 26lbs�`t Drift 6.151 r.. Piorrinal 0 6276 in. Wall T-Ndrw-ss 0.362 in. Plain Eerd'Aleight 25.69 ts1ti OD Trlera€. a API PERFORMANCE Body Yield Strength 604 x1000 lbs Internal Yield 7240 psi SMY'S BOODD psi Collapse 5410 psi Ci)ldN'EGT1CsN C3F;TA GEOMETRY Connee-ton OD 7-656 in. Coupling Length, 10201 er Ccnnection 9D 6264 in, Make-up Loss 4-579 in. Threads per kr 5 Ccnnecbcn 00, Cptcn REGULAR PERFORMANCE Tension Effa,ir rrcy 100.0% Joint Y'*Id Strength 604.010 x 1000 kraa ral Press3re Capacity " 7240.000 psi lbs Compression Effbarcy 100% Compression Strength 604-010 x1{G0 Max. Aiiwable Bending 52';100 €i lbs Extemal Pressure Capacity 5410.00} psi I- MAKE-UP TORQUES Minimum 13280 ft -lbs Opu— 14750 ft -lbs Ma)*M= 16230 it4bs OPERATION LIMIT TORQUES Crparafing Toque 20000 ft -lbs Yield TorTre 23400 ft -lbs Notes This connection is fully interchangeable with: TXP& BTC - 7 in. - 23129 J 32 135 138 Ibsift [1] Internal Pressure Capacity related to structural resistance only. Internal pressure leak resistance as per section 10.3 API 5031 ISO 10400 - 2007. Page 37 17.7 MU 7" to DP crossover. 17.8 MU stand of DP to string, and MU top drive. 17.9 Break circulation at 1 BPM and begin lowering string. Milne Point Unit 5-57 SB Producer Drilling Procedure 17.10 Note seal assembly entering tieback sleeve with a pressure increase, stop pumping and bleed off pressure. Leave standpipe bleed off valve open. 17.11 Continue lowering string and land out on no-go. Set down 5 — l OK and mark the pipe as "NO- GO DEPTH". 17.12 PU string & remove unnecessary 7" joints. 17.13 Space out with pups as needed to leave the no-go 1 ft above fully no-go position when the casing hanger is landed. Ensure one full joint is below the casing hanger. 17.14 PU and MU the 7" casing hanger. 17.15 Ensure circulation is possible through 7" string. 17.16 RU and circulation corrosion inhibited brine in the 9-5/8" x 7" annulus. 17.17 With seals stabbed into tieback sleeve, spot diesel freeze protection from 2,500' TVD to surface in 9-5/8" x 7"annulus by reverse circulating through the holes in the seal assembly. Ensure annular pressure are limited to prevent collapse of the 7" casing (verify collapse pressure of 7" tieback seal assembly). 17.18 SO and land hanger. Confirm hanger has seated properly in wellhead. Make note of actual weight on hanger on morning report. 17.19 Back out the landing joint. MU packoff running tool and install packoff on bottom of landing joint. Set casing hanger packoff and RILDS. PT void to 3,000 psi for 10 minutes. 17.20 RD casing running tools. 17.21 PT 9-5/8" x 7" annulus to 1,000 psi for 3Q minutes charted. ('v1 r Page 38 19.0 Run Upper Completion l�,,.�� Milne Point Unit S-57 SB Producer �� �'("X Drilling Procedure 18.1 Set test plug and change UPR from 7" solid body to 2-7/8" x 5-1/2" VBRs. RU testing equipment. PT VBRs and annular to 250/3000 psi with 3-1/2" test joint. RD testing equipment. 18.2 RU to rung 3-1/2" completion. Verify the jet pump completion components and depths with Ops Engineer. 18.3 PU, MU and RIH with the following 3-1/2" jet pump completion: a. WLEG b. XX joints, 3-1/2", 9.3#, L-80, EUE 8rd tubing c. 2.813" XN nipple (no-go ID = 2.75") with RHC plug body install, 10' handling pups above and below. d. 1 joints, 3-1/2", 9.3#, L-80, EUE 8rd tubing e. Packer, 7" x 3-1/2" retrievable packer f. 1 joints, 3-1/2", 9.3#, L-80, EUE 8rd tubing g. 2.813" X nipple, 10' handling pups above and below. h. 3-1/2" Multi -drop Gauge Mandrel i. Sliding Sleeve j. 3-1/2" Gauge Mandrel k. XX joints, 3-1/2", 9.3#, L-80, EUE 8rd tubing 1. GLM, 3-1/2" x 1-1/2" with SOV installed (2,000 psi casing —),tubing) m. XX joints, 3-1/2", 9.3#, L-80, EUE 8rd tubing 18.4 Continue to RIH to setting depth. i. Ensure appropriate well control crossovers on rig floor and ready. ii. Monitor displacement from wellbore while RIH. 18.5 PU and MU the tubing hanger with landing joint. Terminate TEC wire. 18.6 Record PU and SO weights before landing hanger on the tally along with band/clamp summary. Land tubing hanger and RILDS 18.7 Drop ball & rod, pressure up to 1,700 psi to start setting the packer. 18.8 Continue to pressure up to 3,000 psi to set packer. 18.9 PT the tubing to 3,500 psi for 30 minutes charted. 18.10 Bleed tubing to 2,300 psi. 18.11 PT the IA to 3,500 psi for 30 minutes charted. 18.12 Bleed IA 0 psi and then bleed the tubing to 0 psi. Ramp up the pressure on the IA to shear the SOV. LD landing joint. 18.13 Install BPV. ND BOP. Install the plug off tool into the BPV 18.14 NU tubing head adapter and tree. PT tubing hanger void to 500/5,000 psi. Terminate the cap strings. 18.15 PT the tree to 250/5,000 psi. Pull plug off tool and BPV. Page 39 18.16 Freeze protect the tubing and IA with diesel to 2,500' TVD. Milne Point Unit S-57 SB Producer Drilling Procedure 18.17 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 18.18 Notify AOGCC of SVS testing. Test SVS on horizontal run of tree within 5 days of the start of production. Set low pressure trip below 275 psi Moose Pad header & separator pressure. 18.19 RDMO Innovation Page 40 20.0 Innovation Rig Diverter Schematic 3.1/8' Kill line 13.5/8' SM Technology Sine 13.5'8' Page 41 Milne Point Unit S-57 SB Producer Drilling Procedure Wtrol Technology 3-5/8'5M Control echnology Double Ram . //L1 P C,/C- -118' >>/_-1/8' Choke Line �"-16' Diverter Line 21.0 Innovation Rig BOP Schematic 3-1/8" Kill Line S-22 13-5/8" NOM 9-5/8" BTC Btm x 10.5"-4 SA Pin Top W/ Primary Seal Page 42 13-5/8" 5M Control Technology Annular BOP �"--13-5/8" 5M Control Technology Double Ram 13-5/8"x 5M 11"x5M 2-1/16" x 5M 13-518" x 5M \-2-1/16" x 5M 9-5/8" Casing 3-118" Choke Line —13-518" 5M Control Technology Single Ram Milne Point Unit S-57 SB Producer Hilco �CZT Drilling Procedure 21.0 Innovation Rig BOP Schematic 3-1/8" Kill Line S-22 13-5/8" NOM 9-5/8" BTC Btm x 10.5"-4 SA Pin Top W/ Primary Seal Page 42 13-5/8" 5M Control Technology Annular BOP �"--13-5/8" 5M Control Technology Double Ram 13-5/8"x 5M 11"x5M 2-1/16" x 5M 13-518" x 5M \-2-1/16" x 5M 9-5/8" Casing 3-118" Choke Line —13-518" 5M Control Technology Single Ram 22.0 Wellhead Schematic 'TIFIlla 4AJ[P. TC -IA EMS 4 ',e ETOC M.21O 51M A , F 67157, TOP, w T.r5 EN "-y Q Milne Point Unit S-57 SB Producer Drilling Procedure acPEa G OF r'l -nac? L -T fu lop W-20 C. 4 : 0.W) I Q�!,. al VA_ AzDk Pkle.lfi. 0104'1_ -FL LITE V '10S— 0 SOW —t 5Ax L6 It It I BrM 9 SO% W TP 6 11) 4 f14 21-L. N TOP SEALPICOD 24['15 fL QV 1, ,� IANCI%C FiIl3 ,i2IS" 5.6140 IE. -F I' 1; 1, IV. l5l)- a l-ZV-Lll V-. N% 5 OtE N Wto-M SEAL i'REF NPlixTnq4mj3 12 0%'11'64 Fiwt I - - - SP6 bry INlP I rl.en 50 f trC, TOP. :4 'E, -C D 1 15.27 KIN. 40 (0 Vlr, :z 01) 111C 5 `LIFT HOLE THD CONFIDENTIAL I P I I fill IARFI" E NEI LH -AD LAT AV F C AS MC, PROGRAM, 16- 5€ ICItIV ttll�K-I 1�00(0 �. tj Page 43 QAJOlf LA,Cu T V111ROLIE I[1 -?5-0 C. MR:L?S 0-25-17 Fld (1 215 57 HiIC2TE�usr �r�r 23.0 Days Vs Depth Page 44 0 2Gaa 4000 6000 � 10000 12000 14000 16000 Milne Point Unit S-57 SB Producer Drilling Procedure MPU S-57 SB Ne Producer Days vs Depth 5 10 15 20 Days 25 Hilcox 24.0 Formation Tops & Information Milne Point Unit S-57 SB Producer Drilling Procedure MPU S-57 Formations (Wp01) MD (ft) TVDss (ft) ND (ft) Formation Pressure (psi) EMW (ppg) Base Permafrost 2005 -1809 1871 823.24 8.46 LA3 3931 -3517 3579 1574.76 8.46 Ugnu MB 4272 -3766 3828 1684.32 8.46 Schrader Bluff NA 4726 -3986 4048 1781.12 8.46 Schrader Bluff NE 5052 -4048 4110 1808.4 8.46 GENERALIZED GEOLOGICAL INFORMATION TVD FORMATION LITH GEOL. DESCRIPTION COMMENTS SS o .pO, robranca ° � ' ° o o Predominantly heavy, pebbly gravel conglomerate from surface to 1800 fL Perm ifrost. • ° DIRECTIONAL PROBLEMS: • ° ° o a ° HIGH DEGREE DOGLEGS AT 1397 IN 5-211 CeaJdnt wipe cat. S14: Sidetracked at 1,000' ° o bridge at 2826 (2201 Ivd). 1273'• SV5 0 0 rt- 100' G 0 00 Predominantly conglomerate gravel with increasing concentrations of GAS HYDRATES MAY BE O o 0 0 o clay down to 2500. PRESENT AT S -PAD. 1822 +i - 100' SW ° ° o S -15i (2002) encountered hydrates in 1750' o o permafrost. None of the below Base of Permafrost +,1-1750 ss. and P 0 p the other 2002 and 2003 S -Pad wells ° ° drilled reported any shallow hydrate . 2,000' c 2100 SV31T5 0 ° o SV3: Fine grained and well sorted sand, coarsening upward, deposited in SURFACE CASING AT +A 2500 TVDSS IS +F-100' 2183' SV21T4 o a shallow marine shelf environment- Overlain by a 65 ft marine shale and REQUIRED ON ALL NEW S•PAD WELLS BEGINNING WITH S-19 IN OCT. 2002 DUE +l-100' silty shale bed which acts as a major confining layer and isolates TO POTENTIAL OVER -PRESSURE FROM Say Vanirktok injection into the lower Sagavanrtok sands. SV3 may contain gas ti INJECTORS. hydrates underS-Pad. SURFACE CASING RUNNING,' SV2: Fine grained and well sorted marine sandstone, coarsening upw CE W NTING PROBLEMS: 2600' Top SV1fT3 with shale in lower section. SV2 may contain gas hydrates under S -Pad. Moderate incidents. S-01 swel, cas nb +i-100• 5ft high and had to set casing on slips SV7: Shallow marine sandstone with shale in lower section. SV1 may l S 34 hit bridge, loet returns and had to contain gasJgas hydrates under S -Pad. do atop cernEnt;ob. Cther rtnorught ole incidartt' S-3Ci, -Cd, -1n"i, -32, •C9 3 S-90(set at 3864tvd). 3,000' Continued interbeds of sands, clays and siltstones with occasional shows of coal from 2300 to 3000- STUCK PIPE! S-181, 5855 (3244 tvd), 3384'- UG41K15 had to sidetrack around BHA fish. AUGNU: 3456' CAUSE: LACK OF HOLE CLEANINGM! 'a Gas Cut PAN] at 3700 tvd: Thick hydrocarbon column —200 to 300 ft thick in some S -30i and 20i (both minor). B areas. The Ugnu section (interbedded fluvial sandstone and shale) C represents the initial progradation of the Ugnu deltaic system over D Y the underlying shallow marine Schrader Bluff section. Fluvial nature can make itdifficult todetermine top and base ofinclividualunits. TIGHT HOLE IN MONOBORES. Bottom bounding surface of the entire Ugnu package is picked at the S -21i, S-25, S-23, S-05, S-03 and A regional below). S•29 CIRC ULATETHOROUGHLY PRIOR TO TRIPPING. 3 BOTTOMS UP M -sands: Fluvial, deltaic channel sandstones prograded over OR MORE. USE PWD+ECD'S FOR N the underlying shallow marine sandstones of the Schrader Bluff. The MONITOP.ING HOLE CLEANING. J B M -Sands are subdivided into three tittwstratigraphic units (Ma, Mb, 3870,- Me from top to bottom) that can be difficult to correlate due to their fluvial nature. The M70S marks the boundary at the base of the MC- DIFFERENTIAL STICKING! J4 4120' sand. M -sand intervals are typically coarsening upward packages of S -10A, OB sand. Treated with sized CaCO3. fJ1 varying thicknesses, ranging from5080'thick- All zones are highly B = unconsolidated sandstones with porosities range in the 3038% and permeabilities reaching upwards of 2000-5000 md. Each M -sand interval acts as a hydraulically separate reservoir based on current G. r understandino. 3890' - Page 45 Hilcorp Energy C—p.Sy 25.0 Anticipated Drilling Hazards Milne Point Unit 5-57 SB Producer Drilling Procedure 12-1/4" Hole Section: Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates -1 J Gas hyrates have not been seen on M96'se pad. However, be prepared for them. Remember that hydrate gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates, but can help control the breakout at surface. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non -pressurized mud scale. The non -pressurized scale will reflect the actual mud cut weight. Add 1.0 — 2.0 ppb Lecithin to the system to help thin the mud and release the gas. Isolate/dump contaminated fluid to remove hydrates from the system. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti -Collison: There are no known wells with a clearance factory <1.0. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Wellbore stability (Permafrost, running sands and gravel, conductor broaching): Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations between surge and swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. H2S: Page 46 Treat every hole section as though it has the potential for 1-12S. No H2S events have been documented on drill wells on this pad. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 47 Milne Point Unit S-57 SB Producer Hilco �C®� Drilling Procedure Treat every hole section as though it has the potential for 1-12S. No H2S events have been documented on drill wells on this pad. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 47 Hilcorp EneW Cmnmr 8-1/2" Hole Section: Milne Point Unit S-57 SB 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 of > 300 gpm Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: There is at least (1) fault that will be crossed while drilling the well. There could be others and the throw of these faults is not well understood at this point in time. When a known fault is coming up, ensure to put a "ramp" in the wellbore to aid in kicking off (low siding) later. Once a fault is crossed, we'll need to either drill up or down to get a look at the LWD log and determine the throw and then replan the wellbore. H2S: J Treat every hole section as though it has the potential for 1-12S. No 1-12S events have been documented on drill wells on this pad. 1. The AOGCC will be notified within 24 hours if 1-12S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic 1-12S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event 1-12S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: Reservoir pressures are expected to be normal. Abnormal (offset injection) pressure has been seen on�4= Pad. Utilize MPD to mitigate any abnormal pressure seen. Anti -Co llision / Take devery stand, take additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic interference with another well. Reference A/C report in directional plan. See section 15.14 for well specific A/C. Nt(.4-0� Page 48 26.0 Innovation Rig Layout Milne Point Unit S-57 SB Producer Drilling Procedure Page 49 27.0 FIT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: Milne Point Unit S-57 SB Producer Drilling Procedure 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1 -minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre -determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre -determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Ensure that casing test and subsequent FIT tests are recorded on the same chart. Document incremental volume pumped and returned during test. Page 50 28.0 Innovation Rig Choke Manifold Schematic Page 51 Milne Point Unit S-57 SB Producer Hilco+rn►� Euegy Compevy Drilling Procedure 28.0 Innovation Rig Choke Manifold Schematic Page 51 HilcmE.. W'Compwy 29.0 Casing Design 14 Calculation & Casing Design Factors Hilcorp DATE: 1/23/2020 WELL: MPU S-57 DESIGN BY: Joe Engel Hole Size 12-1/4" Hole Size 8-1/2" Hole Size Design Criteria: Mud Density: 9.2 ppg Mud Density: 9.2 ppg Mud Density: Milne Point Unit S-57 SB Producer Drilling Procedure Drilling Mode MASP: 1398 psi (see attached MASP determination & calculation) MASP: Production Mode MASP: 1398 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.494 psi/ft) and the casing evacuated for the internal stress Page 52 Casing Section Calculation/Specification 1 2 3 4 Casing OD 9-5/8" 6-5/8" Top (MD) 0 5,297 Top (TVD) 0 4,112 Bottom (MD) 5,297 13,631 Bottom (TVD) 4,112 4,102 Length 5,297 8,334 Weight (ppf) 40 20 Grade L-80 L-80 Connection TXP H563 Weight w/o Bouyancy Factor (lbs) 211,880 166,680 Tension at Top of Section (Ibs) 211,880 166,680 Min strength Tension (1000 lbs) 916 459 Worst Case Safety Factor (Tension) 4.32 2.75 Collapse Pressure at bottom (Psi) 2,031 2,026 Collapse Resistance w/o tension (Psi) 3,090 3,470 Worst Case Safety Factor (Collapse) 1.52 v 1.71 MASP (psi) 1,398 1,398 Minimum Yield (psi) 5,750 6,090 Worst case safety factor (Burst) 4.11 4.36 Page 52 30.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation Hil 1 8-1/2" Hole Section MPU S-57 Milne Point Unit MD TVD Planned Top: 5297 4112 Planned TD: 13631 4102 Milne Point Unit S-57 SB Producer Drilling Procedure 4nticlpated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff OB Sand 4,112 1809 1 Oil 8.46 1 0.440 Offset Well Mud Densities Well MW range Top (TVD) Bottom (TVD) Date S-34 L2 8.9 4,229 4242 2003 Assumptions: 1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW. 2. Maximum planned mud density for the 8-1/2" hole section is 9.5 ppg. 3. Calculations assume full evacuation of wellbore to gas Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface: 4112 (ft) x 0.78(psi/ft)= 3207 3207(psi) - [0.1(psi/ft)*4112(ft)]= 2796 psi MASP from pore pressure (complete evacuation of wellbore to gas from Schrader Bluff OA sand) 4112 (ft) x 0.44(psi/ft)= 1809 psi �. 1809(psi) - 0.1(psi/ft)*4112(ft) 1398 psi. Summary: 1. MASP while drilling 8-1/2" production hole is governed by pore pressure and evacuation of entire wellbore to gas at 0.1 psi/ft. Page 53 31.0 Spider Plot (NAD 27) (Governmental Sections) Milne Point Unit S-57 SB Producer Drilling Procedure � •, E.278s ADL025906 ` �. Sec. 33 ° rl y ♦` _`eA - U013NO10E 62sLi Sate Sec. 36 r, ` `♦ ,,:�``� _ ' ADL025518 Sec- 35 11 < + + 'H: � ` ` � .r+t t K12� '.F .. y it , �J / a r r °y % s. 30LIEIZ- E-�2 I! 637{.': e, 1-f.9 .�5. •.y3 \ , 1 r , 's3rFB7 i , ��• \\ 1 > BID r f /% " • � 1 tr� �;-osy` + Sec. E Sec p, H-3.. E.=c.2 �� tl ;Sec..1•,`*.oss.1�� r 5.?y -I BPs.', • f� MILNE POINT UNrr �\ �, • r 1 620 "Ess.,E + 1 I r 1 t �\ti 6,ri5 r i �1 Y I E-27PE, Ij \\♦ I i S;C �, / I E.35 M 17 ,•.`°. ADL -380/10' - . _ .. _ _._.__4 •�.___- . ADL380109 i IDL025 27 .1 or,>r PP 1 4" Ij �' HA.4. B, H C7AL1 1 ; iH.C6 5 y, U012N011E' 1 ` U012NO10E� - 1 1 62 •--'2 s-14 11 +•s3 .s ` XJPL' S-57 -IL • 1 h7PU 5-57_TPH Sec, 7. SSacet. 11 5.31 Sfc. 12 ~� 5 H -B Legend i MPU S-57 SHL Other BotbD n Holes (BHLI _Other Well Paths s 2 i `-. ESE S 2 MPU 5-57 TPH - }' � 2,;-5 % ♦ � Oil and Gas Unit Boundary MPU S-57 BHL s2 5-2 - 'Pad Faot�aint Sec -,15 I DL / \ V* p DMta 1.122 :CQ J Page 54 KUPARUK RIVER UNITADL047446 PRUDHOE BAY UNIT ADL025637 Sec. 14 Sec. 13 Sec. 18 5831 Milne Point Unit MPS -57 Well WPM 0 1,000 2,000 3,000 Feet 32.0 Surface Plat (As Staked) (NAD 27) Milne Point Unit S-57 SB Producer Drilling Procedure 30 - 5 t e I ( 14 FEET ) NOTES: SURVEYOR'S CERTIFICATE I hM . 160 LL GRAVEL I HEREBY CERTIFY THAT I AM SECTION 1. DATE OF SJR1E1; OCTOBER 6 2619 PROPERLY REPSTETT® AND LJCIN= POSITION DMS E -Pu I ■ 43 — '� 15roaroo FP,A 26 25 SUPERMSLCN AND THAT ALL 203 PAD MEAN SCALE FACTOR IS: 0.99940492 DIMENSIONS CCRR a As OF DCTDEER 4, 2mi ! 6. HORIZONTAL AND MJE7ICA. COITRQ 6 SAS'b ON 10 5 PM 149'27'57.973" I i ■ ad37 443' FEL 7. UVATXNb ARE MLNE PMT MEAN SEA LEVEL SS -57 i H- AAD 3S 19 I 33j I E 3334 'TIM nal ( ■ 311 T1TN 0m ■22 I 27 i26 2 1 , 6 I I I M 22 I ■ 23 I rc ¢ { {I I I 020 I it I 1T PAD 7 I I So 161 iii I I ■ le1 RENAMED CONDUCTOR REVISION NOTE VICINITY MAP WELL S-57 ✓ A;2 I ii TMS AS—BUILT =RAYING IS A REISSUE OF PREVIOUS AS-BtRT DRAINING FOR COHOUCTOR SS -19. RENAMED CONDUCTOR 6 AS FOLLOWS: _ S'EcT�y e ( OLD COND, NAME NEW COND. NAME SE ayT �7 i`1 I S-204 S-57 I 2 I � � fl��l r� I (�.©F•q�� J I I 9 ( •. Tom F. Bemhmi 0200; , 10200......, GRAPHIC SCALE O Eo 190 320 Milne Point Unit S-57 SB Producer Drilling Procedure 30 - 5 t e I ( 14 FEET ) NOTES: SURVEYOR'S CERTIFICATE I hM . 160 LL GRAVEL I HEREBY CERTIFY THAT I AM SECTION 1. DATE OF SJR1E1; OCTOBER 6 2619 PROPERLY REPSTETT® AND LJCIN= POSITION DMS 2, REFvea FIELD SODIC HC19-M PG. 26.22 TO LAM SURNEVINC IN TPIF STAN ALASKA AND THAT LEGEND 1 HO82MTAL OATUH IS ALASKA STATE PLME, ZONE 4, HAC27. TSS AS-8UILT SENTS A SL#tVEY MADE BY WE OR UNDER MY MCT N=2,237.27' •. GEODETIC POSITIONS ARE NAM SUPERMSLCN AND THAT ALL AS-SAULT OONDUCTCR3, PAD MEAN SCALE FACTOR IS: 0.99940492 DIMENSIONS CCRR a As OF DCTDEER 4, 2mi ■ EXJSW C&ODUCTCR 6. HORIZONTAL AND MJE7ICA. COITRQ 6 SAS'b ON 10 5 PM 149'27'57.973" 149.4661036' OPERATOR MONUMENTS 5 -EAST. S -MD. AND S -VM. 443' FEL 7. UVATXNb ARE MLNE PMT MEAN SEA LEVEL LOCATED WITHIN PROTRACTED SEC. 12. T. 12 N„ R. 10 E., UMIAT MERIDIAN, AK, WELL A.S.P. PLANT GEODETIC GEODETIC GRAVEL CELLAR SECTION EMI COORDINATES POSITION DMS POSITION(D.DO) PAD ELEV. BO% ELEV. OFFSETS 5-57 • Y=5.999,908.82 N=2,237.27' 70'24'36.716- 70.4101988' 36.2 - 36.3' 3.244:FSL • %- 565 567.71' E= 6.431.99' 149'27'57.973" 149.4661036' 443' FEL �•� Hilcorp Alaska to 9 "w1Q MPG 02 MPU S PAD'S o -x+ uo >rm 1n 0, 1 a mm= W 35z At:emez AS -BUILT CONDUCTOR fpf1pi"O' ievem w m — — L" - ted WELL S-57 t n 1 Page 55 Hilcorp Alaska, LLC Milne Point M Pt S Pad Plan: MPU S-57 (MPU S-204) MPU S-57 Plan: MPU S-57 wp01 Standard Proposal Report 08 January, 2020 HALLIBURTON Sperry Drilling Services Project: Milne Point Site: M Pt S Pad Well: Plan: MPU S-57 (MPU S-204) Wellbore: MPU S-57 Design: MPU S-57 wp01 NALUBURTON JIM e4a.m orunne Vertical Section at 348.73° (1200 usWin) WELL DETAILS: Pan: MPU S-57 (MPU S-204) SURVEY PROGRAM Hilcorp Alaska, LLC SECTION DETAILS Date: 2019-07-05T00:0010 Validated: Yes Version: Calculation Method: Curvature Sec MDInc Depth From Ali ND +N/ -S +E/ -W Dleg TFace VSect Target Annotation 1 26.50 0.00 0.00 26.50 0.00 0.00 0.00 0.00 0.00 MPU 5-57 wp01 (MPU 6-57) ND NDSS 3_MWD+IFR2+MS+Sag CASING DETAILS MD S¢e Name 2 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3°/100' : 250' MD, 250'ND 3 600.00 10.50 135.00 598.04 -22.61 22.61 3.00 135.00 -26.60 3000 'O 4 850.00 18.00 135.00 840.18 E6.10 66.10 3.00 0.00 -77.74 5 1527.71 30.51176 03 1460.91 -314.39 152.95 3.00 73.61 -338.22 End Dir : 1527.71' MD, 1460.91' ND 6 2844.35 30.51 176.03 2595.21 -981.29 199.18 0.00 0.00 -1001.29 StartDir 5°/100' : 2844.35' MD, 2595.21'-R 7 5122.56 9000 319.00 4112.80 544.09 -894.65 5.00 138.79 -358.75 End Dir : 5122.56' MD, 4112.8' ND 8 5297.56 90.00 319.00 4112.80 -412.01 -1009.46 0.00 0.00 -206.79 MPS -57 Wp02 CP1 Start Dir 4.5°/100' : 5297.56' MD, 4112ST 95958.12 9007 348.73 4112.38 174.37 -1297.20 4.50 89.86 424.52 End Dir : 5958.12' MD, 4112.38' TVD 10 13631.62 90.07 348.73 4102.80 7699.77 -2797.49 0.00 0.00 8098.01 MPS -57 wp02 Toe Total Depth : 13631.67 MD, 4102.8' ND Vertical Section at 348.73° (1200 usWin) WELL DETAILS: Pan: MPU S-57 (MPU S-204) SURVEY PROGRAM Hilcorp Alaska, LLC 36.30 Lo gd de +NIS +Fl -W Northing Fasting 36.30 Date: 2019-07-05T00:0010 Validated: Yes Version: Calculation Method: Curvature EErrorSy51¢T: SCWSA ISCWSA 0.00 0.00 5999908.82 56556].]1 ]0. 224' 36.716 N 149' 2T 51973W Depth From Depth TO Survey/Plan T00 Scan Method: Closest Approach 3D End Dir : 1527.71' MD, 1460.91' ND 26.50 800.00 MPU S-57 Wp01 (MPU S-57) 3_Gyro-GC _Csg Error Surface: Pedal Curve REFERENCE INFORMATION 800.00 5297.56 MPU S-57 wp01 (MPU 6-57) 3 MWD+IFR2+MS+Sag Warning Method: Error Ratio Co-ordinam NIE Reverence ( ) : Wall Plan: MPU ift (MIN 5304), True NOM Vertical (ND) Reference: MPU B-57As-Buih RKB @ 6280ush Measured Depth Reference: MPU S-5]As-0uiN RKB 62.BOusfl Calculation Method: Minimum Cervatwe 5297.56 13631.62 MPU 5-57 wp01 (MPU 6-57) ND NDSS 3_MWD+IFR2+MS+Sag CASING DETAILS MD S¢e Name FORMATION TOP DETAILS NDPeM WDnsPeth MDPath FormMlon 1469.80 1407 00 1538.03 BPS _ _ _ _ _ _ g- _ _ _ _ __ _ - _ - _ - _ � _ - _ _ _ _- _ - _ _ _ _ _ _ _ - _ - _ - _ _ _ - 4112.80 4050.00 5297.5fi 9-5/8 95/8"X121/4" 10]1.80 180900 2004.85 BPRF 2302.:0 224000 2504.94 N1 4102.80 4040.00 13631.62 6-5/8 6 5/8!'x 8 12" W79.80 351]00 3931.09 LA3 3500 h6 try. gyp• W28803768.00 4272.11 UONU MB 3000 'O 3000 2 4048.80 M8600 4726.07 SB NA 4110.80 401800 5052.80 BB NE (heap oz r F- 3500 Vertical Section at 348.73° (1200 usWin) 0 Start Dir 30/100' : 250' MD, 2507VD 600 500 End Dir : 1527.71' MD, 1460.91' ND 100, _ / s 1200SVS Start Dir 50/100': 2844.35' MD, 2595.217VD 00N N 1800 BPRF _ _ - _ _ _ _ _ _ _ g- _ _ _ _ __ _ - _ - _ - _ � _ - _ _ _ _- _ - _ _ _ _ _ _ _ - _ - _ - _ _ _ - 2po � V' O 0 2400 SVi 3500 h6 try. gyp• 3000 'O 3000 2 oz r F- 3500 3600 LA3 - - - - - - - - - - � - _ - - _ - _ _ _ _ _ _ _ - _ _ _ - - - -_ - 11ep9 Thr co_ o �, �' r --o' 1. MPU S-57 wp01 _._. --SB_ NA Chi.. ' �.` _ SB_NE (heel)0 O O O O O 0 0 0 0 0 O O O (OT O -+ 0 0 0 0 0 p 6 5/8" x 8 1/2" O O O O O O p N 4200 9 5/8" x 12 1/4`� 4800 MPS -57 wp01 Heel MPS -57 wp02 CP1 MPS -57 wpO2 Toe -2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 1200 7800 8400 9000 Vertical Section at 348.73° (1200 usWin) MPU S-57 wp01 WELL DETAILS Plan: MPU S-57 (MPU S-204) 6 5/8" x 8 1/2" — 4103_ 36.30 7600 Total Depth: 13631.62' MD, 4102.8' TVD +N/ -S +E/ -W Northing Easting Latittude Longitude MPS -57 wp02 To 0.00 0.00 5999908.82 565567.71 70° 24'3&716 N 149° 2757.973 W REFERENCE INFORMATION Cc -ordinate (N/E) Reference: Well Plan: MPU S-57 (MPU 5204), Two North 7125 Vertical (TVD) Reference: MPU S-57 As -built RKB @ 62.80usft Measured Depth Reference: MPU S-57 As -built RKB @ 62.80usft Calculation Method: Minimum Curvature 6650 CASING DETAILS TVD TVDSS MD Size Name 4112.80 4050.00 5297.56 9-5/8 9 5/8" x 12 1/4" 4102.80 4040.00 13631.62 6-5/8 6 5/8" x 8 1/2" 6175 Project: Milne Point Site: M Pt S Pad 5700 Well: Plan: MPU S-57 (MPU S-204) Wellbore: MPU S-57 Plan: MPU S-57 wp01 5225 HALLIBURTON 4750 --- - Sporty Grilling 4275 C 3800 + 3325 V 0 2850 0 to 2375 1900 n 1425 95 475 End Dir : 5958.12' MD, 4112.38' TVD 0 9 5/8" x 12 1/4" -Qo-- - - - - - Start Dir 3°/100' : 250' MD, 250TVD MPS -57 wp02 CPl 1250 -475 Start Dir 4.5°/100' : 5297.56' MD, 4112.8TVD MPS -57 wp01 Heel 1750 End Dir : 1527.71' MD, 1460.91' TVD End Dir : 5122.56' MD, 4112.8' TVD p� 2250 -950 a ho _ _ _ _ _ Start Dir 50/100': 2844.35' MD, 2595.217VD n 2750 -4750 4275 -3800 -3325 -2850 -2375 -1900 -1425 -950 -475 0 475 950 1425 1900 West( -)/East(+) (950 usfl/in) Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: Plan: MPU S-57 (MPU S-204) Wellbore: MPU S-57 Design: MPU S-57 wp01 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU S-57 (MPU S-204) TVD Reference: MPU S-57 As -built RKB @ 62.80usft MD Reference: MPU S-57 As -built RKB @ 62.80usft North Reference: True Survey Calculation Method: Minimum Curvature Project Milne Point, ACT, MILNE POINT Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site M Pt S Pad Site Position: Northing: 5,999,978.00 usft Latitude: 70° 24'37.329 N From: Map Easting: 566,345.00usft Longitude: 149° 27'35.171 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.51 ° Well Plan: MPU S-57 (MPU S-204) Well Position +N/ -S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore MPU S-57 5,999,908.82 usfl Latitude: 565,567.71 usfl Longitude: usfl Ground Level: 70° 24'36.716 N 149° 27'57.973 W 36.30 usft Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2019 2/7/2020 16.06 80.84 57,373.40541070 Design MPU S-57 wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 26.50 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 26.50 0.00 0.00 348.73 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/ -S +E/ -W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°1100usft) (°1100usft) (°/100usft) (°) 26.50 0.00 0.00 26.50 -36.30 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 18720 0.00 0.00 0.00 0.00 0.00 0.00 600.00 10.50 135.00 598.04 535.24 -22.61 22.61 3.00 3.00 0.00 135.00 850.00 18.00 135.00 840.18 77738 -66.10 66.10 3.00 3.00 0.00 0.00 1,527.71 30.51 176.03 1,460.91 1,398.11 -314.39 152.95 3.00 1.85 6.05 73.61 2,844.35 30.51 176.03 2,595.21 2,532.41 -981.29 199.18 0.00 0.00 0.00 0.00 5,122.56 90.00 319.00 4,112.80 4,050.00 -544.09 -894.65 5.00 2.61 6.28 138.79 5,297.56 90.00 319.00 4,112.80 4,050.00 -412.01 -1,009.46 0.00 0.00 0.00 0.00 5,958.12 90.07 348.73 4,112.38 4,049.58 174.37 -1,297.20 4.50 0.01 4.50 89.86 13,631.62 90.07 348.73 4,102.80 4,040.00 7,699.77 -2,797.49 0.00 0.00 0.00 0.00 1/812020 5:57:17PM Page 2 COMPASS 5000.15 Build 91E Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: " M Pt S Pad Well: Plan: MPU S-57 (MPU S-204) Wellbore: MPU 5-57 Design: MPU S-57 wp01 Planned Survey Measured Map Vertical Depth Inclination Azimuth Depth TVDss (usft) (°) (°) (usft) usft 26.50 0.00 0.00 26.50 -36.30 100.00 0.00 0.00 100.00 37.20 200.00 0.00 0.00 200.00 137.20 250.00 0.00 0.00 250.00 187.20 Start Dir 301100': 250' MD, 2507VD 0.00 300.00 1.50 135.00 299.99 237.19 400.00 4.50 135.00 399.85 337.05 500.00 7.50 135.00 499.29 436.49 600.00 10.50 135.00 598.04 535.24 700.00 13.50 135.00 695.85 633.05 800.00 16.50 135.00 792.43 729.63 850.00 18.00 135.00 840.18 777.38 900.00 18.48 139.54 887.67 824.87 1,000.00 19.73 147.88 982.18 919.38 1,100.00 21.32 155.14 1,075.84 1,013.04 1,200.00 23.18 161.37 1,168.40 1,105.60 1,300.00 25.25 166.67 1,259.61 1,196.81 1,400.00 27.48 171.19 1,349.20 1,286.40 1,500.00 29.84 175.06 1,436.95 1,374.15 1,527.71 30.51 176.03 1,460.91 1,398.11 End Dir : 1527.71' MD, 1460.91' TVD -232.21 1,538.03 30.51 176.03 1,469.80 1,407.00 SV5 -300.50 151.87 5,999,609.69 565,722.20 1,600.00 30.51 176.03 1,523.18 1,460.38 1,700.00 30.51 176.03 1,609.34 1,546.54 1,800.00 30.51 176.03 1,695.49 1,632.69 1,900.00 30.51 176.03 1,781.64 1,718.84 2,000.00 30.51 176.03 1,867.79 1,804.99 2,004.65 30.51 176.03 1,871.80 1,809.00 BPRF -475.34 -502.96 166.02 5,999,407.39 2,100.00 30.51 176.03 1,953.94 1,891.14 2,200.00 30.51 176.03 2,040.09 1,977.29 2,300.00 30.51 176.03 2,126.24 2,063.44 2,400.00 30.51 176.03 2,212.40 2,149.60 2,500.00 30.51 176.03 2,298.55 2,235.75 2,504.94 30.51 176.03 2,302.80 2,240.00 SV1 0.00 -727.15 -756.22 183.57 2,600.00 30.51 176.03 2,384.70 2,321.90 2,700.00 30.51 176.03 2,470.85 2,408.05 2,800.00 30.51 176.03 2,557.00 2,494.20 2,844.35 30.51 176.03 2,595.21 2,532.41 Start Dir 511100': 2844.35' MD, 2595.21'TVD 194.11 2,900.00 28.47 179.88 2,643.65 2,580.85 3,000.00 25.14 188.16 2,732.92 2,670.12 3,100.00 22.38 198.54 2,824.48 2,761.68 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU S-57 (MPU S-204) TVD Reference: MPU S-57 As -built RKB @ 62.80usft MD Reference: MPU S-57 As -built RKB @ 62.80usft North Reference: True Survey Calculation Method: Minimum Curvature 1/82020 5:57:17PM Page 3 COMPASS 5000.15 Build 91E Map Map +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (usft) (usft) (usft) -36.30 0.00 0.00 5,999,908.82 565,567.71 0.00 0.00 0.00 0.00 5,999,908.82 565,567.71 0.00 0.00 0.00 0.00 5,999,908.82 565,567.71 0.00 0.00 0.00 0.00 5,999,908.82 565,567.71 0.00 0.00 -0.46 0.46 5,999,908.36 565,568.18 3.00 -0.54 -4.16 4.16 5,999,904.69 565,571.91 3.00 -4.90 -11.55 11.55 5,999,897.37 565,579.36 3.00 -13.59 -22.61 22.61 5,999,886.41 565,590.52 3.00 -26.60 -37.31 37.31 5,999,871.84 565,605.35 3.00 -43.89 -55.61 55.61 5,999,853.70 565,623.80 3.00 -65.41 -66.10 66.10 5,999,843.31 565,634.38 3.00 -77.74 -77.59 76.70 5,999,831.91 565,645.08 3.00 -91.08 -103.95 95.96 5,999,805.73 565,664.57 3.00 -120.70 -134.75 112.58 5,999,775.07 565,681.46 3.00 -154.16 -169.91 126.52 5,999,740.04 565,695.70 3.00 -191.36 -209.33 137.73 5,999,700.73 565,707.26 3.00 -232.21 -252.90 146.19 5,999,657.24 565,716.10 3.00 -276.59 -300.50 151.87 5,999,609.69 565,722.20 3.00 -324.38 -314.39 152.95 5,999,595.82 565,723.40 3.00 -338.22 -319.62 153.31 5,999,590.59 565,723.81 0.00 -343.41 -351.00 155.49 5,999,559.23 565,726.26 0.00 -374.62 A01.65 159.00 5,999,508.62 565,730.21 0.00 -424.98 -452.31 162.51 5,999,458.00 565,734.17 0.00 -475.34 -502.96 166.02 5,999,407.39 565,738.12 0.00 -525.70 -553.61 169.53 5,999,356.77 565,742.08 0.00 -576.07 -555.97 169.69 5,999,354.42 565,742.26 0.00 -578.41 -604.26 173.04 5,999,306.16 565,746.03 0.00 -626.43 -654.91 176.55 5,999,255.54 565,749.99 0.00 -676.79 -705.56 180.06 5,999,204.93 565,753.94 0.00 -727.15 -756.22 183.57 5,999,154.32 565,757.90 0.00 -777.51 -806.87 187.09 5,999,103.70 565,761.85 0.00 -827.87 -809.37 187.26 5,999,101.20 565,762.05 0.00 -830.36 -857.52 190.60 5,999,053.09 565,765.81 0.00 -878.23 -908.17 194.11 5,999,002.47 565,769.76 0.00 -928.59 -958.82 197.62 5,998,951.86 565,773.72 0.00 -978.96 -981.29 199.18 5,998,929.41 565,775.47 0.00 -1,001.29 -1,008.65 200.18 5,998,902.06 565,776.72 5.00 -1,028.32 -1,053.54 197.21 5,998,857.15 565,774.15 5.00 -1,071.77 -1,092.64 188.14 5,998,817.98 565,765.41 5.00 -1,108.34 1/82020 5:57:17PM Page 3 COMPASS 5000.15 Build 91E HALLIBURTON Halliburton Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU S-57 (MPU S-204) Company: Hilcorp Alaska, LLC TVD Reference: MPU S-57 As -built RKB @ 62.80usft Project: Milne Point MD Reference: MPU S-57 As -built RKB @ 62.80usft Site: M Pt S Pad North Reference: True Well: Plan: MPU S-57 (MPU S-204) Survey Calculation Method: Minimum Curvature Wellbore: MPU S-57 Design: MPU S-57 wp01 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 2,854.82 3,200.00 20.45 211.21 2,917.62 2,854.82 -1,125.65 173.02 5,998,784.84 565,750.59 5.00 -1,137.76 3,300.00 19.57 225.63 3,011.64 2,948.84 -1,152.32 151.99 5,998,757.99 565,729.79 5.00 -1,159.80 3,400.00 19.91 240.44 3,105.83 3,043.03 -1,172.44 125.19 5,998,737.63 565,703.17 5.00 -1,174.30 3,500.00 21.39 254.02 3,199.45 3,136.65 -1,185.87 92.82 5,998,723.92 565,670.93 5.00 -1,181.15 3,600.00 23.81 265.44 3,291.81 3,229.01 -1,192.51 55.15 5,998,716.96 565,633.32 5.00 -1,180.29 3,700.00 26.91 274.62 3,382.20 3,319.40 -1,192.29 12.45 5,998,716.80 565,590.62 5.00 -1,171.73 3,800.00 30.48 281.92 3,469.93 3,407.13 -1,185.23 -34.96 5,998,723.45 565,543.16 5.00 -1,155.54 3,900.00 34.39 287.76 3,554.34 3,491.54 -1,171.37 -86.70 5,998,736.85 565,491.30 5.00 -1,131.84 3,931.09 35.65 289.34 3,579.80 3,517.00 -1,165.69 -103.61 5,998,742.38 565,474.34 5.00 -1,122.96 LA3 4,000.00 38.51 292.51 3,634.77 3,571.97 -1,150.82 -142.39 5,998,756.90 565,435.44 5.00 -1,100.80 4,100.00 42.80 296.46 3,710.63 3,647.83 -1,123.75 -201.61 5,998,783.45 565,375.99 5.00 -1,062.68 4,200.00 47.21 299.81 3,781.33 3,718.53 -1,090.34 -263.90 5,998,816.31 565,313.42 5.00 -1,017.74 4,272.11 50.44 301.95 3,828.80 3,766.00 -1,062.47 -310.45 5,998,843.76 565,266.63 5.00 -981.31 UGNU MB 4,300.00 51.69 302.72 3,846.33 3,783.53 -1,050.87 -328.78 5,998,855.20 565,248.20 5.00 -966.35 4,400.00 56.25 305.28 3,905.14 3,842.34 -1,005.63 -395.77 5,998,899.86 565,180.82 5.00 -908.89 4,500.00 60.85 307.58 3,957.31 3,894.51 -954.95 -464.36 5,998,949.92 565,111.80 5.00 -845.79 4,600.00 65.48 309.68 4,002.45 3,939.65 -899.24 -534.02 5,999,005.01 565,041.66 5.00 -777.54 4,700.00 70.14 311.63 4,040.21 3,977.41 -838.91 -604.22 5,999,064.72 564,970.93 5.00 -704.65 4,726.07 71.36 312.12 4,048.80 3,986.00 -822.49 -622.54 5,999,080.98 564,952.47 5.00 -684.96 SB NA 4,800.00 74.82 313.47 4,070.30 4,007.50 -774.43 -674.43 5,999,128.58 564,900.17 5.00 -627.69 4,900.00 79.52 315.24 4,092.50 4,029.70 -706.27 -744.12 5,999,196.11 564,829.89 5.00 -547.23 5,000.00 84.23 316.94 4,106.63 4,043.83 -634.97 -812.75 5,999,266.80 564,760.65 5.00 -463.89 5,052.80 86.71 317.83 4,110.80 4,048.00 -596.23 -848.38 5,999,305.22 564,724.68 5.00 -418.94 SB NE (heel) 5,100.00 88.94 318.62 4,112.59 4,049.79 -561.06 -879.80 5,999,340.11 564,692.96 5.00 -378.30 5,122.56 90.00 319.00 4,112.80 4,050.00 -544.09 -894.65 5,999,356.95 564,677.95 5.00 -358.75 End Dir : 5122.56' MD, 4112.8' ND 5,200.00 90.00 319.00 4,112.80 4,050.00 -485.64 -945.46 5,999,414.94 564,626.64 0.00 -291.50 5,297.56 . 90.00 319.00 4,112.80 4,050.00 -412.01 -1,009.46 5,999,488.00 564,562.00 0.00 -206.79 Start Dir 4.5°/100' : 5297.56' MD, 4112.8'TVD - 9 5/8" x 121/4" 5,300.00 90.00 319.11 4,112.80 4,050.00 -410.17 -1,011.06 5,999,489.83 564,560.38 4.50 -204.67 5,400.00 90.01 323.61 4,112.79 4,049.99 -332.08 -1,073.49 5,999,567.36 564,497.28 4.50 -115.88 5,500.00 90.02 328.11 4,112.76 4,049.96 -249.34 -1,129.60 5,999,649.60 564,440.45 4.50 -23.77 5,600.00 90.03 332.61 4,112.71 4,049.91 -162.44 -1,179.04 5,999,736.05 564,390.26 4.50 71.11 5,700.00 90.04 337.11 4,112.64 4,049.84 -71.94 -1,221.51 5,999,826.17 564,346.99 4.50 168.17 5,800.00 90.06 341.61 4,112.55 4,049.75 21.62 -1,256.75 5,999,919.40 564,310.94 4.50 266.81 5,900.00 90.07 346.11 4,112.45 4,049.65 117.65 -1,284.54 6,000,015.18 564,282.31 4.50 366.42 5,958.12 90.07 348.73 4,112.38 4,049.58 174.37 -1,297.20 6,000,071.78 564,269.15 4.50 424.52 End Dir : 5958.12' MD, 4112.38' ND 6,000.00 90.07 348.73 4,112.33 4,049.53 215.44 -1,305.39 6,000,112.77 564,260.60 0.00 466.40 6,100.00 90.07 348.73 4,112.20 4,049.40 313.51 -1,324.94 6,000,210.66 564,240.19 0.00 566.40 6,200.00 90.07 348.73 4,112.08 4,049.28 411.58 -1,344.49 6,000,308.55 564,219.78 0.00 666.40 1/8/2020 5:57:17PM Page 4 COMPASS 5000.15 Build 91E Planned Survey Measured Halliburton HALLIBURTON Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU S-57 (MPU S-204) Company: Hilcorp Alaska, LLC TVD Reference: MPU S-57 As -built RKB @ 62.80usft Project: Milne Point MD Reference: MPU S-57 As -built RKB @ 62.80usft Site: M Pt S Pad North Reference: True Well: Plan: MPU S-57 (MPU S-204) Survey Calculation Method: Minimum Curvature Wellbore: MPU S-57 (1) (1) Design: MPU S-57 wp01 usft (usft) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (1) (1) (usft) usft (usft) (usft) (usft) (usft) 4,049.15 6,300.00 90.07 348.73 4,111.95 4,049.15 509.65 -1,364.05 6,000,406.43 564,199.37 0.00 766.40 6,400.00 90.07 348.73 4,111.83 4,049.03 607.72 -1,383.60 6,000,504.32 564,178.96 0.00 866.40 6,500.00 90.07 348.73 4,111.70 4,048.90 705.79 -1,403.15 6,000,602.20 564,158.55 0.00 966.40 6,600.00 90.07 348.73 4,111.58 4,048.78 803.86 -1,422.70 6,000,700.09 564,138.14 0.00 1,066.40 6,700.00 90.07 348.73 4,111.45 4,048.65 901.93 -1,442.25 6,000,797.97 564,117.73 0.00 1,166.40 6,800.00 90.07 348.73 4,111.33 4,048.53 1,000.00 -1,461.80 6,000,895.86 564,097.32 0.00 1,266.40 6,900.00 90.07 348.73 4,111.20 4,048.40 1,098.07 -1,481.36 6,000,993.74 564,076.91 0.00 1,366.40 7,000.00 90.07 348.73 4,111.08 4,048.28 1,196.14 -1,500.91 6,001,091.63 564,056.50 0.00 1,466.40 7,100.00 90.07 348.73 4,110.95 4,048.15 1,294.21 -1,520.46 6,001,189.51 564,036.09 0.00 1,566.40 7,200.00 90.07 348.73 4,110.83 4,048.03 1,392.28 -1,540.01 6,001,287.40 564,015.68 0.00 1,666.40 7,300.00 90.07 348.73 4,110.70 4,047.90 1,490.35 -1,559.56 6,001,385.28 563,995.27 0.00 1,766.40 7,400.00 90.07 348.73 4,110.58 4,047.78 1,588.42 -1,579.11 6,001,483.17 563,974.86 0.00 1,866.40 7,500.00 90.07 348.73 4,110.45 4,047.65 1,686.49 -1,598.67 6,001,581.05 563,954.45 0.00 1,966.40 7,600.00 90.07 348.73 4,110.33 4,047.53 1,784.56 -1,618.22 6,001,678.94 563,934.04 0.00 2,066.40 7,700.00 90.07 348.73 4,110.20 4,047.40 1,882.63 -1,637.77 6,001,776.82 563,913.63 0.00 2,166.40 7,800.00 90.07 348.73 4,110.08 4,047.28 1,980.70 -1,657.32 6,001,874.71 563,893.22 0.00 2,266.40 7,900.00 90.07 348.73 4,109.95 4,047.15 2,078.77 -1,676.87 6,001,972.59 563,872.81 0.00 2,366.40 8,000.00 90.07 348.73 4,109.83 4,047.03 2,176.84 -1,696.42 6,002,070.48 563,852.40 0.00 2,466.40 8,100.00 90.07 348.73 4,109.70 4,046.90 2,274.91 -1,715.98 6,002,168.36 563,831.99 0.00 2,566.40 8,200.00 90.07 348.73 4,109.58 4,046.78 2,372.98 -1,735.53 6,002,266.25 563,811.58 0.00 2,666.40 8,300.00 90.07 348.73 4,109.46 4,046.66 2,471.05 -1,755.08 6,002,364.14 563,791.18 0.00 2,766.40 8,400.00 90.07 348.73 4,109.33 4,046.53 2,569.12 -1,774.63 6,002,462.02 563,770.77 0.00 2,866.40 8,500.00 90.07 348.73 4,109.21 4,046.41 2,667.19 -1,794.18 6,002,559.91 563,750.36 0.00 2,966.40 8,600.00 90.07 348.73 4,109.08 4,046.28 2,765.26 -1,813.73 6,002,657.79 563,729.95 0.00 3,066.40 8,700.00 90.07 348.73 4,108.96 4,046.16 2,863.33 -1,833.28 6,002,755.68 563,709.54 0.00 3,166.40 8,800.00 90.07 348.73 4,108.83 4,046.03 2,961.40 -1,852.84 6,002,853.56 563,689.13 0.00 3,266.40 8,900.00 90.07 348.73 4,108.71 4,045.91 3,059.47 -1,872.39 6,002,951.45 563,668.72 0.00 3,366.40 9,000.00 90.07 348.73 4,108.58 4,045.78 3,157.54 -1,891.94 6,003,049.33 563,648.31 0.00 3,466.40 9,100.00 90.07 348.73 4,108.46 4,045.66 3,255.61 -1,911.49 6,003,147.22 563,627.90 0.00 3,566.40 9,200.00 90.07 348.73 4,108.33 4,045.53 3,353.68 -1,931.04 6,003,245.10 563,607.49 0.00 3,666.40 9,300.00 90.07 348.73 4,108.21 4,045.41 3,451.75 -1,950.59 6,003,342.99 563,587.08 0.00 3,766.40 9,400.00 90.07 348.73 4,108.08 4,045.28 3,549.82 -1,970.15 6,003,440.87 563,566.67 0.00 3,866.40 9,500.00 90.07 348.73 4,107.96 4,045.16 3,647.89 -1,989.70 6,003,538.76 563,546.26 0.00 3,966.40 9,600.00 90.07 348.73 4,107.83 4,045.03 3,745.96 -2,009.25 6,003,636.64 563,525.85 0.00 4,066.40 9,700.00 90.07 348.73 4,107.71 4,044.91 3,844.03 -2,028.80 6,003,734.53 563,505.44 0.00 4,166.40 9,800.00 90.07 348.73 4,107.58 4,044.78 3,942.10 -2,048.35 6,003,832.41 563,485.03 0.00 4,266.40 9,900.00 90.07 348.73 4,107.46 4,044.66 4,040.17 -2,067.90 6,003,930.30 563,464.62 0.00 4,366.40 10,000.00 90.07 348.73 4,107.33 4,044.53 4,138.24 -2,087.46 6,004,028.18 563,444.21 0.00 4,466.40 10,100.00 90.07 348.73 4,107.21 4,044.41 4,236.31 -2,107.01 6,004,126.07 563,423.80 0.00 4,566.40 10,200.00 90.07 348.73 4,107.08 4,044.28 4,334.38 -2,126.56 6,004,223.95 563,403.39 0.00 4,666.40 10,300.00 90.07 348.73 4,106.96 4,044.16 4,432.45 -2,146.11 6,004,321.84 563,382.98 0.00 4,766.40 10,400.00 90.07 348.73 4,106.83 4,044.03 4,530.52 -2,165.66 6,004,419.73 563,362.57 0.00 4,866.40 10,500.00 90.07 348.73 4,106.71 4,043.91 4,628.59 -2,185.21 6,004,517.61 563,342.16 0.00 4,966.40 10,600.00 90.07 348.73 4,106.58 4,043.78 4,726.66 -2,204.77 6,004,615.50 563,321.75 0.00 5,066.40 10,700.00 90.07 348.73 4,106.46 4,043.66 4,824.73 -2,224.32 6,004,713.38 563,301.34 0.00 5,166.40 1/82020 5:57:17PM Page 5 COMPASS 5000.15 Build 91E Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: `" M Pt S Pad Well: Plan: MPU S-57 (MPU S-204) Wellbore: MPU S-57 Design: MPU S-57 wp01 Planned Survey Measured Dip Angle Map Vertical +N/ -S Depth Inclination Azimuth Depth TVDss (usft) (°) (°) (usft) usft 10,800.00 90.07 348.73 4,106.33 4,043.53 10,900.00 90.07 348.73 4,106.21 4,043.41 11,000.00 90.07 348.73 4,106.08 4,043.28 11,100.00 90.07 348.73 4,105.96 4,043.16 11,200.00 90.07 348.73 4,105.84 4,043.04 11,300.00 90.07 348.73 4,105.71 4,042.91 11,400.00 90.07 348.73 4,105.59 4,042.79 11,500.00 90.07 348.73 4,105.46 4,042.66 11,600.00 90.07 348.73 4,105.34 4,042.54 11,700.00 90.07 348.73 4,105.21 4,042.41 11,800.00 90.07 348.73 4,105.09 4,042.29 11,900.00 90.07 348.73 4,104.96 4,042.16 12,000.00 90.07 348.73 4,104.84 4,042.04 12,100.00 90.07 348.73 4,104.71 4,041.91 12,200.00 90.07 348.73 4,104.59 4,041.79 12,300.00 90.07 348.73 4,104.46 4,041.66 12,400.00 90.07 348.73 4,104.34 4,041.54 12,500.00 90.07 348.73 4,104.21 4,041.41 12,600.00 90.07 348.73 4,104.09 4,041.29 12,700.00 90.07 348.73 4,103.96 4,041.16 12,800.00 90.07 348.73 4,103.84 4,041.04 12,900.00 90.07 348.73 4,103.71 4,040.91 13,000.00 90.07 348.73 4,103.59 4,040.79 13,100.00 90.07 348.73 4,103.46 4,040.66 13,200.00 90.07 348.73 4,103.34 4,040.54 13,300.00 90.07 348.73 4,103.21 4,040.41 13,400.00 90.07 348.73 4,103.09 4,040.29 13,500.00 90.07 348.73 4,102.96 4,040.16 13,600.00 90.07 348.73 4,102.84 4,040.04 13,631.62 - 90.07 348.73 4,102.80 • 4,040.00 Total Depth: 13631.62' MD, 4102.8' TVD Targets Target Name Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Plan: MPU S-57 (MPU S-204) MPU S-57 As -built RKB @ 62.80usft MPU S-57As-built RKB @ 62.80usft True Minimum Curvature hittmiss target Dip Angle Map Map +N/ -S +N/ -S +E/ -W Northing Easting DLS (usft) (usft) (usft) (usft) 4,043.53 4,922.80 -2,243.87 6,004,811.27 563,280.93 0.00 5,020.87 -2,263.42 6,004,909.15 563,260.52 0.00 5,118.94 -2,282.97 6,005,007.04 563,240.11 0.00 5,217.01 -2,302.52 6,005,104.92 563,219.70 0.00 5,315.08 -2,322.07 6,005,202.81 563,199.29 0.00 5,413.15 -2,341.63 6,005,300.69 563,178.88 0.00 5,511.22 -2,361.18 6,005,398.58 563,158.47 0.00 5,609.29 -2,380.73 6,005,496.46 563,138.06 0.00 5,707.36 -2,400.28 6,005,594.35 563,117.65 0.00 5,805.43 -2,419.83 6,005,692.23 563,097.24 0.00 5,903.50 -2,439.38 6,005,790.12 563,076.83 0.00 6,001.57 -2,458.94 6,005,888.00 563,056.42 0.00 6,099.64 -2,478.49 6,005,985.89 563,036.01 0.00 6,197.71 -2,498.04 6,006,083.77 563,015.60 0.00 6,295.78 -2,517.59 6,006,181.66 562,995.19 0.00 6,393.85 -2,537.14 6,006,279.54 562,974.78 0.00 6,491.92 -2,556.69 6,006,377.43 562,954.37 0.00 6,589.99 -2,576.25 6,006,475.32 562,933.96 0.00 6,688.06 -2,595.80 6,006,573.20 562,913.55 0.00 6,786.13 -2,615.35 6,006,671.09 562,893.14 0.00 6,884.20 -2,634.90 6,006,768.97 562,872.73 0.00 6,982.27 -2,654.45 6,006,866.86 562,852.32 0.00 7,080.34 -2,674.00 6,006,964.74 562,831.91 0.00 7,178.41 -2,693.56 6,007,062.63 562,811.50 0.00 7,276.48 -2,713.11 6,007,160.51 562,791.09 0.00 7,374.55 -2,732.66 6,007,258.40 562,770.68 0.00 7,472.62 -2,752.21 6,007,356.28 562,750.27 0.00 7,570.69 -2,771.76 6,007,454.17 562,729.86 0.00 7,668.76 -2,791.31 6,007,552.05 562,709.45 0.00 7,699.77 -2,797.49 6,007,583.00 562,703.00 0.00 hittmiss target Dip Angle Dip Dir. TVD +N/ -S Shape (°) (°) (usft) (usft) MPS -57 wp02 Toe 0.00 0.00 4,102.80 7,699.77 - plan hits target center - Point MPS-57wp02 CP1 0.00 0.00 4,112.80 -412.01 - plan hits target center - Point MPS -57 wp01 Heel 0.00 0.00 4,062.80 -820.14 - plan misses target center by 23.31 usft at 4757.25usft MD (4058.39 TVD, -802.47 N, -644.45 E) - Circle (radius 30.00) Vert Section 5,266.40 5,366.40 5,466.40 5,566.40 5,666.40 5,766.40 5,866.40 5,966.40 6,066.40 6,166.40 6,266.40 6,366.40 6,466.40 6,566.40 6,666.40 6,766.40 6,866.40 6,966.40 7,066.40 7,166.40 7,266.40 7,366.40 7,466.40 7,566.40 7,666.40 7,766.40 7,866.40 7,966.40 8,066.40 8.098.01 +E/ -W Northing Easting (usft) (usft) (usft) -2,797.49 6,007,583.00 562,703.00 -1,009.46 5,999,488.00 564,562.00 -659.00 5,999,083.00 564,916.00 1/8/2020 5:57:17PM Page 6 COMPASS 5000.15 Build 91E HALLIBURTON Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: Plan: MPU S-57 (MPU S-204) Wellbore: MPU S-57 Design: MPU S-57 wp01 Casing Points Measured Vertical Depth Depth (usft) (usft) 5,297.56 4,112.80 9 5/8" x 12 1/4" 13,631.62 4,102.80 6 5/8" x 8 1/2" Formations Hole Measured Vertical Depth Depth (usft) (usft) 4,272.11 3,828.80 3,931.09 3,579.80 5,052.80 4,110.80 2,004.65 1,871.80 4,726.07 4,048.80 2,504.94 2,302.80 1,538.03 1,469.80 Plan Annotations 174.37 Measured Vertical Depth Depth (usft) (usft) 250.00 250.00 1,527.71 1,460.91 2,844.35 2,595.21 5,122.56 4,112.80 5,297.56 4,112.80 5,958.12 4,112.38 13,631.62 4,102.80 Vertical Depth SS Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU S-57 (MPU S-204) TVD Reference: MPU S-57 As -built RKB @ 62.80usft MD Reference: MPU S-57 As -built RKB @ 62.80usft North References True Survey Calculation Method: Minimum Curvature UGNU MB LA3 SB NE (heel) BPRF SB_NA SV1 SV5 Casing Hole Diameter Diameter Name (usft) 9-5/8 12-1/4 6-5/8 8-1/2 Dip Dip Direction Name Lithology (I (I Local Coordinates +N/ -S +E/ -W (usft) (usft) Comment 0.00 0.00 Start Dir 31/100' : 250' MD, 250'TVD -314.39 152.95 End Dir : 1527.71' MD, 1460.91' TVD -981.29 199.18 Start Dir 5°/100' : 2844.35' MD, 2595.217VD -544.09 -894.65 End Dir : 5122.56' MD, 4112.8' TVD -412.01 -1,009.46 Start Dir 4.5°/100' : 5297.56' MD, 4112.8'TVD 174.37 -1,297.20 End Dir : 5958.12' MD, 4112.38' TVD 7,699.77 -2,797.49 Total Depth : 13631.62' MD, 4102.8' TVD 1/8/2020 5.57:17PM Page 7 COMPASS 5000.15 Build 91E Hilcorp Alaska, LLC Milne Point M Pt S Pad Plan: MPU S-57 (MPU S-204) MPU S-57 MPU S-57 wp01 Sperry Drilling Services Clearance Summary Anticollision Report 08 January, 2020 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Plan: MPU S-57 (MPU S-204) - MPU S-57 - MPU S-57 wp01 Well Coordinates: 5,999,908.82 N, 565,567.71 E (700 24' 36.72" N, 1490 27' 57.97" W) Datum Height: MPU S-57 As -built RKB @ 62.80usft Scan Range: 26.50 to 5,297.56 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft Geodetic Scale Factor Applied Version: 5000.15 Build: 91E Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU S-57 (MPU S-204) - MPU S-57 wp01 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Plan: MPU S-57 (MPU S-204). MPU S-57 - MPU S-57 wp01 Scan Range: 26.50 to 5,297.56 usft. Measured Depth. 0-75-3 0 -,-) Scan Radius Is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft 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 (usft) (usft) (usft) (usft) usft M Pt H Pad M Pt S Pad MPS -06 - MPS -06 - MPS -06 3,526.50 301.69 3,526.50 245.60 3,616.03 5.378 Clearance Factor Pass - MPS -06 - MPS -06 - MPS -06 3,576.50 300.23 3,576.50 244.96 3,656.67 5.432 Ellipse Separation Pass - MPS -06 - MPS -06 - MPS -06 3,607.50 299.95 3,607.50 245.50 3,681.46 5.509 Centre Distance Pass - MPS -08 - MPS -08 - MPS -08 3,476.50 181.42 3,476.50 137.19 3,722.77 4.102 Clearance Factor Pass - MPS -08 - MPS -08 - MPS -08 3,576.50 153.17 3,576.50 119.80 3,800.62 4.590 Ellipse Separation Pass - MPS -08 -MPS -08 -MPS -08 3,608.32 150.99 3,608.32 120.50 3,822.20 4.953 Centre Distance Pass - MPS -08 - MPS -08P81 - MPS-08PB1 3,476.50 181.42 3,476.50 137.19 3,722.77 4.102 Clearance Factor Pass - MPS -08 - MPS-08PB1 - MPS-08PB1 3,576.50 153.17 3,576.50 119.80 3,800.62 4.590 Ellipse Separation Pass - MPS -08 - MPS-08PB1 - MPS-08PB1 3,608.32 150.99 3,608.32 120.50 3,822.20 4.953 Centre Distance Pass - MPS -13 - MPS -13 - MPS -13 4,201.50 108.90 4,201.50 55.87 4,071.10 2.054 Clearance Factor Pass - MPS -13 - MPS -13 - MPS -13 4,226.50 100.84 4,226.50 51.95 4,086.47 2.062 Ellipse Separation Pass - MPS -13 - MPS -13 - MPS -13 4,268.27 95.15 4,268.27 56.11 4,111.18 2.438 Centre Distance Pass - MPS -I4 -MPS -I4 -MPS -14 1,151.44 158.19 1,151.44 147.26 1,197.86 14.476 Centre Distance Pass - MPS -I4 -MPS -I4 -MPS -14 1,151.50 158.19 1,151.50 147.26 1,197.91 14.475 Ellipse Separation Pass - MPS -I4 -MPS -I4 -MPS -14 1,226.50 163.40 1,226.50 151.93 1,265.59 14.248 Clearance Factor Pass - MPS -15 - MPS -15 - MPS -15 918.38 287.79 918.36 281.55 910.06 46.111 Centre Distance Pass - MPS -15 - MPS -15 - MPS -15 926.50 287.82 926.50 281.53 917.77 45.810 Ellipse Separation Pass - MPS -I5 -MPS -I5 -MPS -15 1,201.50 325.16 1,201.50 317.23 1,166.42 41.021 Clearance Factor Pass- MPS -16 - MPS -16 - MPS -16 794.66 279.38 794.66 272.55 781.36 40.928 Centre Distance Pass - MPS -16 - MPS -16 - MPS -16 801.50 279.39 801.50 272.53 787.51 40.730 Ellipse Separation Pass - MPS -16 - MPS -16 - MPS -16 926.50 286.02 926.50 278.83 896.71 39.816 Clearance Factor Pass - MPS -17 - MPS -17 - MPS -17 939.04 253.26 939.04 247.09 930.15 41.020 Ellipse Separation Pass - MPS -17 -MPS -17 -MPS -17 5,297.56 1,355.50 5,297.56 1,293.60 4,098.36 21.897 Clearance Factor Pass - MPS -17 -MPS -171-1 -MPS-171-1 939.04 253.26 939.04 247.22 930.15 41.904 Ellipse Separation Pass - MPS -17 -MPS -171 -1 -MPS -171-1 5,297.56 1,355.50 5,297.56 1,293.73 4,098.36 21.943 Clearance Factor Pass - MPS -18 - MPS -18 - MPS -18 567.99 269.44 567.99 262.78 561.82 40.432 Centre Distance Pass - 08 January, 2020 - 17:59 Page 2 of 10 COMPASS Hilcorp Alaska, LLC HALLI B U RTO N Milne Point Anticollision Report for Plan: MPU S-57 (MPU S-204) - MPU S-57 wp01 736.68 240.88 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) 235.67 728.39 46.250 Centre Distance Pass - MPS -19 - MPS-19APB1 - MPS-19APB1 Reference Design: M Pt S Pad - Plan: MPU S-57 (MPU S-204) - MPU S-57 - MPU S-57 Wp01 751.50 235.65 740.97 45.385 Ellipse Separation Scan Range: 26.50 to 5,297.56 usft. Measured Depth. MPS -19 - MPS-19APB1 - MPS-19APB1 876.50 249.51 876.50 243.53 845.05 41.733 Clearance Factor Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft 208.79 854.87 201.95 851.76 30.529 Ellipse Separation Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on 916.10 Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft 203.83 675.87 MPS -18 - MPS -18 - MPS -18 601.50 269.55 601.50 262.50 593.27 38.215 Ellipse Separation Pass - MPS -18 - MPS -18 - MPS -18 801.50 280.09 801.50 271.64 774.33 33.167 Clearance Factor Pass - MPS -19 - MPS -19 - MPS -19 736.68 240.88 736.68 235.67 722.19 46.246 Centre Distance Pass - MPS -19 - MPS -19 - MPS -19 751.50 240.96 751.50 235.65 734.77 45.380 Ellipse Separation Pass - MPS -19 - MPS -19 - M PS -19 876.50 249.51 876.50 243.53 838.85 41.726 Clearance Factor Pass - MPS -19 - MPS -19A - MPS -19A 736.68 240.88 736.68 235.67 728.39 46.249 Centre Distance Pass - MPS -19 - MPS -19A- MPS -19A 751.50 240.96 751.50 235.65 740.97 45.384 Ellipse Separation Pass - MPS -19 - MPS -19A- MPS -19A 876.50 249.51 876.50 243.53 845.05 41.732 Clearance Factor Pass - MPS -19 - MPS-19AL1 - MPS-19AL1 736.68 240.88 736.68 235.67 728.39 46.246 Centre Distance Pass - MPS -19 - MPS-19AL1 - MPS-19AL1 751.50 240.96 751.50 235.65 740.97 45.380 Ellipse Separation Pass - MPS -19 - MPS-19AL1 - MPS-19AL1 876.50 249.51 876.50 243.53 845.05 41.726 Clearance Factor Pass - MPS -19 - MPS-19APB1 - MPS-19APB1 736.68 240.88 736.68 235.67 728.39 46.250 Centre Distance Pass - MPS -19 - MPS-19APB1 - MPS-19APB1 751.50 240.96 751.50 235.65 740.97 45.385 Ellipse Separation Pass - MPS -19 - MPS-19APB1 - MPS-19APB1 876.50 249.51 876.50 243.53 845.05 41.733 Clearance Factor Pass - MPS -20 - MPS -20 - MPS -20 854.87 208.79 854.87 201.95 851.76 30.529 Ellipse Separation Pass - MPS -20 - MPS -20 - MPS -20 926.50 212.26 926.50 205.21 916.10 30.088 Clearance Factor Pass - MPS -21 - MPS -21 - MPS -21 658.83 208.67 658.83 203.88 659.83 43.557 Centre Distance Pass - MPS -21 - MPS -21 - MPS -21 676.50 208.78 676.50 203.83 675.87 42.224 Ellipse Separation Pass - MPS -21 - MPS -21 - MPS -21 851.50 225.23 851.50 218.92 828.29 35.659 Clearance Factor Pass - MPS -22 - MPS -22 - MPS -22 1,001.44 133.40 1,001.44 124.92 1,018.54 15.720 Centre Distance Pass - MPS -22 - MPS -22 - MPS -22 1,001.50 133.40 1,001.50 124.92 1,018.60 15.720 Ellipse Separation Pass - MPS -22 - MPS -22 - MPS -22 1,051.50 136.33 1,051.50 127.51 1,060.77 15.462 Clearance Factor Pass - MPS -23 - MPS -23 - MPS -23 868.99 169.53 868.99 163.78 864.60 29.469 Ellipse Separation Pass - MPS -23 - MPS -23 - MPS -23 5,297.56 513.30 5,297.56 451.92 5,822.79 8.363 Clearance Factor Pass - MPS -23 - MPS -231-1 - MPS -231-1 868.99 169.53 868.99 163.78 864.60 29.469 Ellipse Separation Pass - MPS -23 - MPS -231-1 - MPS -231-1 5,297.56 458.69 5,297.56 401.75 5,785.44 8.056 Clearance Factor Pass - MPS -24 - MPS -24 - MPS -24 816.20 152.52 816.20 144.81 818.77 19.793 Ellipse Separation Pass - MPS -24 - MPS -24 - MPS -24 5,297.56 747.88 5,297.56 688.84 4,638.00 12.666 Clearance Factor Pass - MPS -24 - MPS-24PB1 - MPS-24PB1 816.20 152.52 816.20 144.81 818.77 19.793 Ellipse Separation Pass - MPS -24 - MPS-24PB1 - MPS-24PB1 5,297.56 747.88 5,297.56 688.71 4,638.00 12.638 Clearance Factor Pass - 08 January, 2020 - 17:59 Page 3 of 10 COMPASS HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU S-57 (MPU S-204) - MPU S-57 wp01 1,029.34 57.94 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) 50.71 1,048.02 8.015 Ellipse Separation Pass - Reference Design: M Pt S Pad - Plan: MPU S-57 (MPU S-204) - MPU S-57 - MPU S-57 wp01 1,076.50 60.20 1,076.50 52.48 Scan Range: 26.50 to 5,297.56 usft. Measured Depth. 7.797 Clearance Factor Pass - MPS -27 - MPS -27 - MPS -27 745.04 Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft 745.04 116.17 745.40 22.785 Centre Distance Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on 751.50 Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft 119.05 821.61 MPS -24 - MPS-24PB2 - MPS-24PB2 816.20 152.52 816.20 144.81 818.77 19.793 Ellipse Separation Pass - MPS -24 - MPS-24PB2 - MPS-24PB2 5,297.56 747.88 5,297.56 688.84 4,638.00 12.666 Clearance Factor Pass - MPS -25 - MPS -25 - MPS -25 657.15 151.90 657.15 147.17 652.96 32.147 Ellipse Separation Pass - MPS -25 - MPS -25 - MPS -25 801.50 161.25 801.50 155.44 784.46 27.742 Clearance Factor Pass - MPS -25 - MPS -251-1 - MPS -251-1 657.15 151.90 657.15 147.17 652.96 32.146 Ellipse Separation Pass - MPS -25 - MPS -251-1 - MPS -251-1 801.50 161.25 801.50 155.44 784.46 27.741 Clearance Factor Pass - MPS -26 -MPS -26 -MPS -26 1,029.34 57.94 1,029.34 50.71 1,048.02 8.015 Ellipse Separation Pass - MPS -26 -MPS -26 -MPS -26 1,076.50 60.20 1,076.50 52.48 1,093.08 7.797 Clearance Factor Pass - MPS -27 - MPS -27 - MPS -27 745.04 121.50 745.04 116.17 745.40 22.785 Centre Distance Pass - MPS -27 - MPS -27 - MPS -27 751.50 121.52 751.50 116.14 751.61 22.588 Ellipse Separation Pass - MPS -27 - MPS -27 - MPS -27 826.50 124.92 826.50 119.05 821.61 21.288 Clearance Factor Pass - MPS -27 - MPS -271-1 - MPS -271-1 745.04 121.50 745.04 116.17 745.40 22.785 Centre Distance Pass - MPS -27 - MPS -271-1 - MPS -271-1 751.50 121.52 751.50 116.14 751.61 22.589 Ellipse Separation Pass - MPS -27 - MPS -271-1 - MPS -271-1 826.50 124.92 826.50 119.05 821.61 21.290 Clearance Factor Pass - MPS -27 - MPS-27PB1 - MPS-27PB1 745.04 121.50 745.04 115.62 745.40 20.684 Centre Distance Pass - MPS -27 - MPS-27PB1 - MPS-27PB1 751.50 121.52 751.50 115.59 751.61 20.522 Ellipse Separation Pass - MPS -27 - MPS-27PB1 - MPS-27PB1 826.50 124.92 826.50 118.51 821.61 19.489 Clearance Factor Pass - MPS -28 - MPS -28 - MPS -28 706.07 106.29 706.07 98.80 713.29 14.184 Centre Distance Pass - MPS -28 - MPS -28 - MPS -28 726.50 106.44 726.50 98.78 733.17 13.904 Ellipse Separation Pass - MPS -28 - MPS -28 - MPS -28 776.50 108.32 776.50 100.37 781.36 13.625 Clearance Factor Pass - MPS -28 - MPS-28PB1 - MPS-28PB1 706.07 106.29 706.07 98.80 713.29 14.184 Centre Distance Pass - MPS -28 - MPS-28PB1 - MPS-28PB1 726.50 106.44 726.50 98.78 733.17 13.904 Ellipse Separation Pass - MPS -28 - MPS-28PB1 - MPS -28P61 776.50 108.32 776.50 100.37 781.36 13.625 Clearance Factor Pass - MPS -28 - MPS-28PB2 - MPS-28PB2 706.07 106.29 706.07 98.80 713.29 14.184 Centre Distance Pass - MPS -28 - MPS-28PB2 - MPS-28PB2 726.50 106.44 726.50 98.78 733.17 13.904 Ellipse Separation Pass - MPS -28 - MPS-28PB2 - MPS-28PB2 776.50 108.32 776.50 100.37 781.36 13.625 Clearance Factor Pass - MPS -29 - MPS -29 - MPS -29 552.50 96.85 552.50 93.06 554.88 25.555 Ellipse Separation Pass - MPS -29 - MPS -29 - MPS -29 701.50 108.35 701.50 103.47 693.42 22.222 Clearance Factor Pass - MPS -29 - MPS -291-1 - MPS -291-1 552.50 96.85 552.50 93.06 554.88 25.555 Ellipse Separation Pass - MPS -29 - MPS -291-1 - MPS -291-1 701.50 108.35 701.50 103.47 693.42 22.222 Clearance Factor Pass - 08 January, 2020 - 17.59 Page 4 of 10 COMPASS HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU S-57 (MPU S-204) - MPU S-57 wp01 499.84 58.11 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) 52.39 507.93 10.153 Centre Distance Pass - Reference Design: M Pt S Pad - Plan: MPU S-57 (MPU S-204) - MPU S-57 - MPU S-57 wp01 526.50 58.30 526.50 52.26 Scan Range: 26.50 to 5,297.56 usft. Measured Depth. 9.652 Ellipse Separation Pass - MPS -32 - MPS -32 - MPS -32 601.50 Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft 601.50 55.63 605.91 Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on 41.13 Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft 551.50 37.12 MPS -30 - MPS -30 - MPS -30 674.61 74.42 674.61 65.98 681.56 8.823 Centre Distance Pass - MPS -30 - MPS -30 - MPS -30 676.50 74.42 676.50 65.96 683.37 8.800 Ellipse Separation Pass - MPS -30 - MPS -30 - MPS -30 726.50 76.01 726.50 67.14 731.05 8.575 Clearance Factor Pass - MPS -31 - MPS -31 - MPS -31 715.95 56.15 715.95 51.20 726.66 11.349 Centre Distance Pass - MPS -31 - MPS -31 - MPS -31 726.50 56.21 726.50 51.20 736.98 11.205 Ellipse Separation Pass - MPS31 - MPS -31 - MPS -31 776.50 58.57 776.50 53.23 785.52 10.962 Clearance Factor Pass - MPS -32 - MPS -32 - MPS -32 499.84 58.11 499.84 52.39 507.93 10.153 Centre Distance Pass - MPS32 - MPS -32 - MPS -32 526.50 58.30 526.50 52.26 534.24 9.652 Ellipse Separation Pass - MPS -32 - MPS -32 - MPS -32 601.50 62.54 601.50 55.63 605.91 9.047 Clearance Factor Pass - MPS -33 - MPS -33 - MPS -33 540.35 41.13 540.35 37.14 542.15 10.314 Centre Distance Pass - MPS -33 - MPS -33 - MPS -33 551.50 41.17 551.50 37.12 553.17 10.169 Ellipse Separation Pass - MPS -33 - MPS -33 - MPS -33 626.50 43.81 626.50 39.35 627.08 9.812 Clearance Factor Pass - MPS -33 - MPS -33A- MPS -33A 540.35 41.13 540.35 37.14 548.46 10.314 Centre Distance Pass - MPS -33 - MPS -33A- MPS -33A 551.50 41.17 551.50 37.12 559.48 10.169 Ellipse Separation Pass - MPS -33 - MPS -33A- MPS -33A 626.50 43.81 626.50 39.35 633.39 9.812 Clearance Factor Pass - MPS -34 - MPS -34 - MPS -34 446.56 27.90 446.56 24.08 456.29 7.310 Centre Distance Pass - MPS -34 - MPS -34 - MPS -34 451.50 27.91 451.50 24.07 461.17 7.273 Ellipse Separation Pass - MPS -34 - MPS -34 - MPS -34 476.50 28.43 476.50 24.48 485.81 7.206 Clearance Factor Pass - MPS -34 - MPS -341-1 - MPS -341-1 446.56 27.90 446.56 24.08 456.29 7.310 Centre Distance Pass - MPS -34 - MPS -341-1 - MPS -341-1 451.50 27.91 451.50 24.07 461.17 7.273 Ellipse Separation Pass - MPS -34 - MPS -341-1 - MPS -341-1 476.50 28.43 476.50 24.48 485.81 7.206 Clearance Factor Pass - MPS -34 - MPS -341-2 - MPS -341-2 446.56 27.90 446.56 24.08 456.29 7.310 Centre Distance Pass - MPS -34 - MPS -341-2 - MPS -341-2 451.50 27.91 451.50 24.07 461.17 7.273 Ellipse Separation Pass - MPS -34 - MPS -341-2 - MPS -341-2 476.50 28.43 476.50 24.48 485.81 7.206 Clearance Factor Pass - MPS -35 - MPS -35 - MPS -35 378.72 8.64 378.72 4.31 387.80 1.995 Clearance Factor Pass - MPS -35 - MPS-35PB1 - MPS-35PB1 378.72 8.64 378.72 4.31 387.80 1.995 Clearance Factor Pass - MPS -35 - MPS-35PB2 - MPS-35PB2 378.72 8.64 378.72 4.31 387.80 1.995 Clearance Factor Pass - MPS -37 - MPS -37 - MPS -37 26.50 17.05 26.50 15.70 35.57 12.639 Centre Distance Pass - MPS -37 - MPS -37 - MPS -37 326.50 17.88 326.50 14.64 335.68 5.511 Ellipse Separation Pass - MPS -37 - MPS -37 - MPS -37 551.50 22.06 551.50 16.99 561.16 4.356 Clearance Factor Pass - 08 January, 2020 - 17:59 Page 5 of 10 COMPASS HALLIBURTON Hileorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU S-57 (MPU S-204) - MPU S-57 wp01 26.50 77.13 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) 76.21 35.23 83.990 Centre Distance Pass - Reference Design: M Pt S Pad - Plan: MPU S-57 (MPU S-204) - MPU S-57 - MPU S-57 wp01 276.50 78.18 276.50 74.59 Scan Range: 26.50 to 5,297.56 usft. Measured Depth. 21.799 Ellipse Separation Pass - MPS-41-MPS-4IA-MPS-41A 3,176.50 Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is 1,500.00 usft 3,176.50 157.55 3,258.62 3.847 Clearance Factor Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on 26.50 Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft 74.59 284.66 MPS -39 - MPS -39 - MPS -39 1,297.78 36.67 1,297.78 26.49 1,305.73 3.601 Ellipse Separation Pass - MPS -39 -MPS -39 -MPS -39 1,301.50 36.69 1,301.50 26.49 1,309.35 3.598 Clearance Factor Pass - MPS -41 - MPS -41 - MPS -41 26.50 77.13 26.50 76.21 35.23 83.990 Centre Distance Pass - MPS -41 - MPS -41 - MPS -41 276.50 78.18 276.50 74.59 284.66 21.799 Ellipse Separation Pass - MPS -4I -MPS -4I -MPS -41 3,176.50 212.90 3,176.50 157.55 3,258.62 3.847 Clearance Factor Pass - MPS -41 -MPS -41A -MPS -41A 26.50 77.13 26.50 76.21 35.23 83.990 Centre Distance Pass - MPS-4I-MPS-0IA-MPS-41A 276.50 78.18 276.50 74.59 284.66 21.799 Ellipse Separation Pass - MPS-41-MPS-4IA-MPS-41A 3,176.50 212.90 3,176.50 157.55 3,258.62 3.847 Clearance Factor Pass - MPS -41 - MPS-41APB1 - MPS-41APB1 26.50 77.13 26.50 76.21 35.23 83.990 Centre Distance Pass - MPS -41 - MPS-41APB1 - MPS-4IAPB1 276.50 78.18 276.50 74.59 284.66 21.799 Ellipse Separation Pass - MPS -41 - MPS-4IAPB1 - MPS-41AP61 3,176.50 212.90 3,176.50 157.55 3,258.62 3.847 Clearance Factor Pass - MPS -41 - MPS-4IAPB2 - MPS-41APB2 26.50 77.13 26.50 76.21 35.23 83.990 Centre Distance Pass - MPS-4I-MPS-41APB2-MPS-41APB2 276.50 78.18 276.50 74.59 284.66 21.799 Ellipse Separation Pass - MPS-4I-MPS-41APB2-MPS-41APB2 3,176.50 212.90 3,176.50 157.55 3,258.62 3.847 Clearance Factor Pass - MPS -43 - MPS43 - MPS43 578.10 94.72 578.10 87.50 593.34 13.113 Centre Distance Pass - MPS -43 - MPS -43 - MPS43 626.50 95.10 626.50 87.24 640.83 12.088 Ellipse Separation Pass - MPS -43 - MPS43 - MPS43 751.50 100.32 751.50 90.98 761.90 10.732 Clearance Factor Pass - MPS -90 -MPS -90 -MPS -90 1,064.69 516.48 1,064.69 505.96 1,052.74 49.090 Ellipse Separation Pass - MPS -90 -MPS -90 -MPS -90 1,376.50 553.89 1,376.50 541.86 1,330.55 46.054 Clearance Factor Pass - MPU S-203- MPU S-203 - MPU S-203 1,326.50 27.46 1,326.50 17.03 1,332.77 2.631 Clearance Factor Pass - MPU S-203- MPU S-203 - MPU S-203 1,331.22 27.43 1,331.22 17.06 1,337.26 2.644 Centre Distance Pass - MPU S -203 -MPU S-203PB1 - MPU S-203PB1 1,326.50 27.46 1,326.50 17.03 1,332.77 2.631 Clearance Factor Pass - MPU S -203 -MPU S-203PB1 -MPU S-203PB1 1,331.22 27.43 1,331.22 17.06 1,337.26 2.644 Centre Distance Pass - M PU S-203 - MPU S-203PB2 - MPU S-203PB2 1,326.50 27.46 1,326.50 17.03 1,332.77 2.631 Clearance Factor Pass - MPU S-203 - MPU S-203PB2 - MPU S-203PB2 1,331.22 27.43 1,331.22 17.06 1,337.26 2.644 Centre Distance Pass - Plan: MPU S-201 - MPU S-201 - MPU S-201 wp07 - a 1,426.50 56.56 1,426.50 45.98 1,448.48 5.349 Clearance Factor Pass - Plan: MPU S-201 - MPU S-201 - MPU S-201 wp07 - a 1,451.50 54.52 1,451.50 44.39 1,470.98 5.382 Ellipse Separation Pass - Plan: MPU S-201 - MPU S-201 - MPU S-201 wp07 -a 1,467.86 54.12 1,467.86 44.44 1,485.56 5.591 Centre Distance Pass - Plan: MPU S-202 - MPU S-202 - MPU S-202 wp10 - a 1,651.50 30.95 1,651.50 19.38 1,672..10 2.674 Clearance Factor Pass - Plan: MPU S-202 - MPU S-202 - MPU S-202 wp10 - a 1,676.50 29.27 1,676.50 18.85 1,695.12 2.810 Ellipse Separation Pass - 08 January, 2020 - 17:59 Page 6 of 10 COMPASS Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU S-57 (MPU S-204) - MPU S-57 wp01 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Plan: MPU S-57 (MPU 5-204) - MPU S-57 - MPU S-57 WP01 Scan Range: 26.50 to 5,297.56 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft 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 (usft) (usft) (usft) (usft) usft Plan: MPU 5-202 - MPU 5-202 - MPU S-202 wp10 - a 1,677.54 29.26 1,677.54 18.91 1,696.08 2.826 Centre Distance Pass - Plan MPU S-56 (MPU S-205) - MPU S-56 - MPU M-5( 226.50 92.20 226.50 90.04 227.10 42.780 Centre Distance Pass - Plan MPU 5-56 (MPU S-205) - MPU S-56 - MPU M-5( 276.50 92.29 276.50 89.82 277.10 37.428 Ellipse Separation Pass - Plan: MPU 5-56 (MPU S-205) - MPU S-56 - MPU M-5( 5,297.56 817.07 5,297.56 746.42 5,778.06 11.565 Clearance Factor Pass - Proposal Plan: MPU S-206 - 5-206 - UGNU#6 - S-206 226.50 137.20 226.50 134.92 228.40 60.128 Centre Distance Pass - Proposal Plan: MPU S-206 - 5-206 - UGNU#6 - 5-206 276.50 137.29 276.50 134.67 278.40 52.348 Ellipse Separation Pass - Proposal Plan: MPU S-206 - 5-206 - UGNU#6 - 5-206 5,297.56 1,245.87 5,297.56 1,186.25 5,099.99 20.897 Clearance Factor Pass - Proposal Plan: MPU 5-207 - MPU 5-207 - MPU S-207 226.50 152.40 226.50 150.11 229.80 66.620 Centre Distance Pass - Proposal Plan: MPU 5-207 - MPU 5-207 - MPU S-207 276.50 152.49 276.50 149.87 279.80 58.015 Ellipse Separation Pass - Proposal Plan: MPU 5-207 - MPU 5-207 - MPU 5-207 701.50 181.13 701.50 175.50 702.10 32.168 Clearance Factor Pass - Proposal Plan: MPU 5-208 - MPU 5-208 - MPU 5-208 226.50 167.61 226.50 165.32 229.80 73.267 Centre Distance Pass - Proposal Plan: MPU S-208 - MPU 5-208 - MPU 5-208 276.50 167.70 276.50 165.07 279.80 63.800 Ellipse Separation Pass - Proposal Plan: MPU 5-208 - MPU 5-208 - MPU 5-208 701.50 203.72 701.50 198.10 694.62 36.242 Clearance Factor Pass - Proposal Plan: MPU S-209 - S-209 - MPU S-209 wp01 226.50 182.81 226.50 180.52 229.80 79.913 Centre Distance Pass - Proposal Plan: MPU 5-209 - 5-209 - MPU S-209 wp01 276.50 182.90 276.50 180.27 279.80 69.585 Ellipse Separation Pass - Proposal Plan: MPU 5-209 - 5-209 - MPU 5-209 wp01 701.50 225.46 701.50 219.85 687.83 40.168 Clearance Factor Pass - Proposal Plan: MPU S-210 - MPU 5-210 - MPU 5-210 226.50 198.01 226.50 195.73 229.80 86.560 Centre Distance Pass - Proposal Plan: MPU 5-210 - MPU 5-210 - MPU 5-210 276.50 198.11 276.50 195.48 279.80 75.369 Ellipse Separation Pass - Proposal Plan: MPU 5-210 - MPU S-210 - MPU 5-210 751.50 252.68 751.50 246.72 730.17 42.383 Clearance Factor Pass - From To Survey/Plan Survey Tool (usft) (usft) 26.50 800.00 MPU S-57 wp01 3_Gyro-GC_Csg 800.00 5,297.56 MPU S-57wp01 3_MWD+IFR2+MS+Sag 5,297.56 13,631.62 MPU 5-57 wp01 3_MWD+IFR2+MS+Sag 08 January, 2020 - 17:59 Page 7 of 10 COMPASS HALLIBURTON Anticollision Report for Plan: MPU S-57 (MPU S-204) - MPU S-57 wp01 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor= Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Hilcorp Alaska, LLC Milne Point 08 January, 2020 - 17:59 Page 8 of 10 COMPASS MALLIBURTON Project: Milne Point REFERENCE INFORMATION WELL DETAUS:Pl n MPU S-57(MPU S-204) NAD 1927 (NADCON CONUS) Alaska Zone 04 Site: M Pt S Pad Corordi- (NIE) Reteronca: Wall Plan: MPU 5-57 (MPU S -204), T- Nodb B��s,), O�Nting Well: Plan: MPU S-57 (MPU 5204) V. -I (TVD) Reference: MPU 5-57 M -built RKB @ 62.80usfl 36.30 Wellbore: MPU S-57 Measured Depth R--- MPU S -S/ As ilt RKB @ 62 e0uafl +N/ -S +E/ -W Noraung Pasting L tittude L.Ogimde Plan: MPU 857 wp01 calculation -h Minimum CuNa 0.00 0.00 5999908.82 565567.71 70° 24'36,716 N 149° 27 57.973 SURVEY PIOGIAM GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Date: zat&W-Dar00:00:W va d -d: Ya: Veromn: 26.50 To 13831.62 Depen From Dep- W sunaylPlan root CASING DETAILS 26.50 800.00 MPU S-5] 857) 3 Gyr Csg _p l (MPU Ladder/ S.F. Plots 800.00 5291.1 MPU S-5] wp01 (MPU SS]) 3 MWD+IFR2+MS+Sag D.IF TVD TVD TVD00 ND 5128 Namc 2 529].58 13831.62 MPU 5-57 Vol (MPU 85 3_MWD+IFR2+MS+Sag c 1 of 1 G 81 4050.00 5297.56MID 9-5/8 9 5 X 12 1/4" 4102.80 4040.00 13631.62 6-5/8 6 5/8" x 8 1/2" 180.00 T L150.00 I I IO 8120.00 MPS -4 ! m MPS -3 I n90.00 6 V02 �. in MPS- d MPS -4- MPU 03 l - j 0.00 a) 60.00- U MPS - (.) o MPS -3 - � MPS -31 .. MPU S-02 c 30.00- 0.00 C) U MPS -31 MPS_31 I MPS -3 0.00 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 4800 5100 5400 5700 Measured Depth (600 usfUin) 4.00 3.00 LL c O m 2.00 o (U Collision Risk Procedures Req. Collision Avoidance Req. j 1.00 No -Go Zone - Stop Drilling I NOERRORS � 000 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 4800 5100 5400 5700 Measured Depth (600 usft/in) Hilcorp Alaska, LLC Milne Point M Pt S Pad Plan: MPU S-57 (MPU S-204) MPU S-57 MPU S-57 wp01 Sperry Drilling Services Clearance Summary Anticollision Report 08 January, 2020 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Plan: MPU S-57 (MPU S-204) - MPU S-57 - MPU S-57 wp01 Well Coordinates: 5,999,908.82 N, 565,567.71 E (70° 24' 36.72" N, 149° 27' 57.97" W) Datum Height: MPU S-57 As -built RKB @ 62.80usft Scan Range: 5,297.56 to 13,631.62 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft Geodetic Scale Factor Applied Version: 5000.15 Build: 91E Scan Type: GLOBAL FILTER APPLIED: All well paths within 200'+ 100/1000 0f reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU S-57 (MPU S-204) - MPU S-57 wp01 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Plan: MPU 5-57 (MPU 5-204) - MPU 5-57 - MPU 5-57 wp01 S C/ <--� 1 .�/'✓1 Scan Range: 5,297.56 to 13,631.62 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft -- 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 (usft) (usft) (usft) (usft) usft M Pt H Pad MPH -05 - MPH -05 - MPH -05 MPH -05 - MPH -05 - MPH -05 MPH -05 - MPH -05 - MPH -05 MPH -08 - MPH -08 - MPH -08 MPH -08 - MPH -08 - MPH -08 MPH -08 - MPH -08A- MPH -OSA MPH -08 - MPH -08A- MPH -OSA MPH -08 - MPH -08A- MPH -08A MPH -08 - MPH-08APB1 - MPH-08APB1 MPH -08 - MPH-08APB1 - MPH-08APB1 MPH -08 - MPH-08APB1 - MPH-08APB1 MPH -08 - MPH -08B - MPH -08B MPH -08 - MPH -08B - MPH -OSB MPH -08 - MPH -08B - MPH -OSB MPH -08 - MPH -081311 - MPH -0881-1 MPH -08 - MPH -081311 - MPH -081311 MPH -08 - MPH -08[311 - MPH -08811 MPH -08 - MPH-083PB1 - MPH-08BPB1 MPH -08 - MPH-088PB1 - MPH-0813PB1 MPH -08 - MPH-088PB1 - MPH-08BPB1 MPH -12 - MPH -12 - MPH -12 M Pt S Pad MPS -06 - MPS -06 - MPS -06 MPS -13 - MPS -13 - MPS -13 MPS -13 - MPS -13 - MPS -13 MPS -14 - MPS -14 - MPS -14 MPS -14 - MPS -14 - MPS -14 08 January, 2020 - 18:00 12,413.91 1,339.80 12,413.91 1,201.61 9,518.50 9.695 Centre Distance Pass - 12,622.56 1,350.36 12,622.56 1,192.84 9,400.00 8.573 Ellipse Separation Pass - 13,39Z56 1,537.19 13,397.56 1,324.99 8,862.17 7.244 Clearance Factor Pass - 12,488.55 301.23 12,488.55 2.77 9,130.97 1.009 Centre Distance Pass- e 11,996.97 135.11 11,996.97 53.85 9,609.56 1.663 Centre Distance Pass - 13,631.62 769.18 13,631.62 543.65 8,365.00 3.411 Clearance Factor Pass - 5,297.56 1,353.12 5,297.56 1,293.89 4,164.58 22.846 Clearance Factor Pass - 5,297.56 980.93 5,297.56 922.16 4,306.75 16.691 Ellipse Separation Pass - 5,322.56 1,005.60 5,322.56 945.23 4,303.80 16.656 Clearance Factor Pass - 5,899.10 1,321.30 5,899.10 1,282.78 4,026.03 34.306 Centre Distance Pass- 5,972.56 1,324.01 5,972.56 1,281.21 4,049.25 30.935 Ellipse Separation Pass - Page 2 of 9 r,%S �- -I--7 IU Z. .r----- HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU S-57 (MPU S-204) - MPU S-57 wp01 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Plan: MPU S-57 (MPU S-204) - MPU S-57 - MPU S-57 Wp01 Scan Range: 5,297.56 to 13,631.62 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is 1,500.00 usft 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 (usft) (usft) (usft) (usft) usft MPS -14 - MPS -14 - MPS -14 6,722.56 1,552.69 6,722.56 1,457.07 4,259.66 16.238 Clearance Factor Pass - MPS -I6 -MPS -I6 -MPS -16 9,172.56 506.70 9,172.56 280.33 6,128.02 2.238 Clearance Factor Pass - MPS -16 - MPS -16 - MPS -16 9,222.56 503.33 9,222.56 279.09 6,166.20 2.245 Ellipse Separation Pass - MPS -16 - MPS -16 - MPS -16 9,286.83 501.78 9,286.83 281.46 6,215.73 2.277 Centre Distance Pass - MPS -17 - MPS -17 - MPS -17 7,484.16 111.03 7,484.16 77.09 6,096.14 3.271 Centre Distance Pass - MPS -17 - MPS -17 - MPS -17 7,572.56 135.83 7,572.56 36.24 6,137.79 1.364 Ellipse Separation Pass - MPS -17 - MPS -17 - MPS -17 7,597.56 149.70 7,597.56 37.35 6,149.27 1.332 Clearance Factor Pass - MPS -17 - MPS -17L1 - MPS -171-1 7,489.27 64.09 7,489.27 35.37 6,082.07 2.232 Centre Distance Pass - MPS -17 - MPS -17L1 -MPS-171-1 ® - MPS -18 - MPS -18 - MPS -18 12,306.50 1,397.21 12,306.50 1,064.71 8,696.13 4.202 Centre Distance Pass - MPS -I8 -MPS -I8 -MPS -18 12,322.56 1,397.27 12,322.56 1,064.44 8,704.00 4.198 Clearance Factor Pass - MPS -19 - MPS-19AL1 - MPS-19AL1 8,101.36 1,360.27 8,101.36 1,139.63 11,630.00 6.165 Centre Distance Pass - MPS -19 - MPS-19AL1 - MPS-19AL1 8,147.56 1,361.06 8,147.56 1,139.13 11,630.00 6.133 Ellipse Separation Pass - MPS-I9-MPS-19AL1-MPS-19AL1 8,247.56 1,368.11 8,247.56 1,144.16 11,630.00 6.109 Clearance Factor Pass - MPS -20 - MPS -20 - MPS -20 8,709.30 704.19 8,709.30 559.52 5,742.85 4.867 Centre Distance Pass - MPS -20 - MPS -20 - MPS -20 8,997.56 727.15 8,997.56 529.99 5,966.00 3.688 Ellipse Separation Pass - MPS -20 - MPS -20 - MPS -20 9,472.55 851.28 9,472.56 589.24 6,351.90 3.249 Clearance Factor Pass - MPS -21 - MPS -21 - MPS -21 7,684.84 1,492.15 7,684.84 1,420.46 4,594.63 20.815 Centre Distance Pass - MPS -2I -MPS -2I -MPS -21 7,872.56 1,500.56 7,872.56 1,410.91 4,690.66 16.737 Ellipse Separation Pass - MPS -21 - MPS -21 - MPS -21 8,222.56 1,560.29 8,222.56 1,436.95 4,856.39 12.651 Clearance Factor Pass - MPS -22 - MPS -22 - MPS -22 5,685.73 982.62 .5,685.73 944.07 4,125.00 25.491 Centre Distance Pass - MPS -22 - MPS -22 - MPS -22 5,697.56 982.72 5,697.56 943.97 4,125.71 25.360 Ellipse Separation Pass - MPS -22 - MPS -22 - MPS -22 6,097.56 1,093.56 6,097.56 1,045.36 4,144.87 22.688 Clearance Factor Pass - MPS -23 - MPS -23 - MPS -23 6,038.70 96.76 6,038.70 72.27 5,070.07 3.951 Centre Distance Pass - MPS -23 - MPS -23 - MPS -23 6,072.56 100.63 6,072.56 70.63 5,051.16 3.354 Ellipse Separation Pass - MPS -23 - MPS -23 - MPS -23 6,122.56 118.57 6,122.56 79.16 5,020.92 3.009 Clearance Factor Pass - MPS -23 - MPS -231-1 - MPS -231-1 6,037.69 76.20 6,037.69 54.79 5,076.45 3.559 Centre Distance Pass - MPS -23 - MPS -231-1 - MPS -23L1 6,072.56 81.34 6,072.56 51.35 5,056.73 2.712 Ellipse Separation Pass - MPS -23 - MPS-23LI - MPS -231-1 6,097.56 90.63 6,097.56 54.06 5,043.14 2.478 Clearance Factor Pass - MPS -24 - MPS -24 - MPS -24 5,977.72 288.64 5,977.72 250.43 4,447.84 7.553 Centre Distance Pass - MPS -24 - MPS -24 - MPS -24 5,997.56 289.22 5,997.56 249.51 4,440.68 7.282 Ellipse Separation Pass - 08 January, 2020 - 18:00 Page 3 of 9 COMPASS HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU S-57 (MPU S-204) - MPU S-57 wp01 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Plan: MPU S-57 (MPU S-204) - MPU S-57 - MPU S-57 Wp01 Scan Range: 5,297.56 to 13,631.62 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft 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 (usft) (usft) (usft) (usft) usft MPS -24 - MPS -24 - MPS -24 6,147.56 328.96 6,147.56 272.94 4,395.14 5.872 Clearance Factor Pass - MPS -24 - MPS24PB1 - MPS-24PB1 5,977.72 288.64 5,977.72 250.30 4,447.84 7.527 Centre Distance Pass - MPS -24 - MPS-24PB1 - MPS-24PB1 5,997.56 289.22 5,997.56 249.38 4,440.68 7.258 Ellipse Separation Pass - MPS-24-MPS24PB1-MPS-24PB1 6,147.56 328.96 6,147.56 272.81 4,395.14 5.859 Clearance Factor Pass - MPS -24 - MPS-24PB2 - MPS-24PB2 5,977.72 288.64 5,977.72 250.43 4,447.84 7.553 Centre Distance Pass - MPS -24 - MPS24PB2 - MPS-24PB2 5,997.56 289.22 5,997.56 249.51 4,440.68 7.282 Ellipse Separation Pass - MPS -24 - MPS24PB2 - MPS-24PB2 6,147.56 328.96 6,147.56 272.94 4,395.14 5.872 Clearance Factor Pass - MPS -25 - MPS -25 - MPS -25 7,466.01 763.66 7,466.01 676.00 4,703.52 8.712 Centre Distance Pass - MPS -25 - MPS -25 - MPS -25 7,572.56 770.39 7,572.56 667.07 4,731.45 7.456 Ellipse Separation Pass - MPS -25 - MPS -25 - MPS -25 7,922.56 880.31 7,922.56 736.74 4,808.09 6.218 Clearance Factor Pass - MPS -25 - MPS -251-1 - MPS -251-1 7,466.01 763.66 7,466.01 675.98 4,703.52 8.709 Centre Distance Pass - MPS -25 - MPS -251-1 - MPS -251-1 7,572.56 770.39 7,572.56 667.03 4,731.45 7.454 Ellipse Separation Pass - MPS -25 - MPS -251-1 - MPS -251-1 7,922.56 880.31 7,922.56 738.67 4,808.09 6.215 Clearance Factor Pass - MPS -26 -MPS -26 -MPS -26 5,297.56 1,358.21 5,297.56 1,307.91 3,904.49 27.005 Ellipse Separation Pass - MPS -26 -MPS -26 -MPS -26 5,622.56 1,508.39 5,622.56 1,448.18 3,913.17 25.053 Clearance Factor Pass - MPS -27 -MPS -27 -MPS -27 7,493.62 1,267.81 7,493.62 1,197.41 4,521.17 18.009 Centre Distance Pass - MPS -27 - MPS -27 - MPS -27 7,747.56 1,281.68 7,747.56 1,184.99 4,687.70 13.256 Ellipse Separation Pass - MPS -27 - MPS -27 - MPS -27 8,722.56 1,554.92 8,722.56 1,359.68 5,358.87 7.964 Clearance Factor Pass - MPS -27 -MPS -271 -1 -MPS -27L1 7,493.62 1,267.81 7,493.62 1,197.52 4,521.17 18.037 Centre Distance Pass - MPS -27 -MPS -27L1 -MPS -271-1 7,747.56 1,281.68 7,747.56 1,185.17 4,687.70 13.281 Ellipse Separation Pass - MPS -27 -MPS -271 -1 -MPS -271-1 8,722.56 1,554.92 8,722.56 1,360.11 5,358.87 7.982 Clearance Factor Pass - MPS -27 - MPS-27PB1 - MPS-27PB1 7,493.62 1,267.81 7,493.62 1,196.87 4,521.17 17.871 Centre Distance Pass - MPS -27 - MPS-27PB1 - MPS-27PB1 7,747.56 1,281.68 7,747.56 1,184.45 4,687.70 13.182 Ellipse Separation Pass - MPS -27 - MPS-27PB1 - MPS-27PB1 8,722.56 1,554.92 8,722.56 1,359.14 5,358.87 7.942 Clearance Factor Pass - MPS -28 - MPS -28 - MPS -28 6,699.11 585.13 6,699.11 515.54 4,452.84 8.409 Centre Distance Pass - MPS -28 - MPS -28 - MPS -28 6,822.56 595.08 6,822.56 506.91 4,507.93 6.749 Ellipse Separation Pass - MPS -28 -MPS -28 -MPS -28 11,272.56 864.19 11,272.56 572.66 9,177.37 2.964 Clearance Factor Pass - MPS -28 - MPS-28PB1 - MPS-28PB1 6,699.11 585.13 6,699.11 515.54 4,452.84 8.409 Centre Distance Pass - MPS-28-MPS-28PB1-MPS-28PB1 6,822.56 595.08 6,822.56 506.91 4,507.93 6.749 Ellipse Separation Pass - MPS-28-MPS-28PB1-MPS-28PB1 9,022.56 1,148.99 9,022.56 907.27 6,745.00 4.753 Clearance Factor Pass - 08 January, 2020 - 18:00 Page 4 of 9 COMPASS Hileorp Alaska, LLC HALLI B U RTO N Milne Point Anticollision Report for Plan: MPU S-57 (MPU S-204) - MPU S-57 wp01 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Plan: MPU S-57 (MPU S-204) - MPU S-57 - MPU S-57 Wp01 Scan Range: 5,297.56 to 13,631.62 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft 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 (usft) (usft) (usft) (usft) usff MPS -28 - MPS-28PB2 - MPS-28PB2 6,699.11 585.13 6,699.11 515.54 4,452.84 8.409 Centre Distance Pass - MPS -28 - MPS-28PB2 - MPS-28PB2 6,822.56 595.08 6,822.56 506.91 4,507.93 6.749 Ellipse Separation Pass - MPS-28-MPS-28PB2-MPS-28PB2 10,172.56 977.75 10,172.56 713.03 8,010.00 3.693 Clearance Factor Pass - MPS -29 - MPS -29 - MPS -29 13,297.56 139.10 13,297.56 19.58 10,510.00 1.164 Clearance Factor Pass - MPS -29 - MPS -29 - MPS -29 13,322.56 134.17 13,322.56 19.17 10,521.12 1.167 Ellipse Separation Pass - MPS -29 - MPS -29 - MPS -29 13,343.80 132.83 13,343.80 21.57 10,530.61 1.194 Centre Distance Pass - MPS -29 - MPS -291-1 - MPS -291-1 - MPS -29 -MPS -291 -1 -MPS -29L1 - MPS -30 -MPS -30 -MPS -30 6,390.50 1,332.43 6,390.50 1,291.98 3,918.58 32.938 Centre Distance Pass - MPS -30 -MPS -30 -MPS -30 6,522.56 1,336.89 6,522.56 1,285.38 4,024.24 25.956 Ellipse Separation Pass - MPS -30 -MPS -30 -MPS -30 7,272.56 1,550.20 7,272.56 1,441.34 4,278.53 14.239 Clearance Factor Pass- MPS -31 - MPS -31 - MPS -31 5,422.81 1,518.51 5,422.81 1,493.70 3,489.15 61.196 Centre Distance Pass - MPS -31 - MPS -31 - MPS -31 5,472.56 1,519.31 5,472.56 1,492.74 3,523.06 57.180 Ellipse Separation Pass - MPS -31 - MPS -31 - MPS -31 5,747.56 1,555.35 5,747.56 1,515.40 3,682.98 38.927 Clearance Factor Pass - MPS -32 - MPS -32 - MPS -32 7,559.39 1,431.34 7,559.39 1,357.22 4,414.07 19.313 Centre Distance Pass - MPS -32 - MPS -32 - MPS -32 7,822.56 1,446.00 7,822.56 1,345.41 4,600.58 14.374 Ellipse Separation Pass - MPS -32 - MPS -32 - MPS -32 8,372.56 1,559.42 8,372.56 1,404.12 4,936.85 10.042 Clearance Factor Pass - MPS -33 - MPS -33 - MPS -33 6,140.71 768.75 6,140.71 715.89 4,277.14 14.542 Centre Distance Pass - MPS -33 - MPS -33 - MPS -33 6,222.56 772.88 6,222.56 711.62 4,295.45 12.615 Ellipse Separation Pass - MPS -33 - MPS -33 - MPS -33 6,697.56 940.81 6,697.56 837.69 4,407.61 9.123 Clearance Factor Pass - MPS -33 -MPS -33A -MPS -33A 5,875.33 910.24 5,875.33 870.34 4,146.14 22.811 Centre Distance Pass - M PS -33 - MPS -33A - MPS -33A 5,922.56 912.03 5,922.56 869.54 4,146.24 21.465 Ellipse Separation Pass - MPS -33 -MPS -33A -MPS -33A 6,472.56 1,107.62 6,472.56 1,034.80 4,126.30 15.209 Clearance Factor Pass - MPS -90 - MPS -90 - MPS -90 6,947.56 888.86 6,947.56 773.90 5,137.14 7.732 Clearance Factor Pass - MPS -90 - MPS -90 - MPS -90 7,097.56 870.35 7,097.56 760.85 5,186.67 7.949 Ellipse Separation Pass - MPS -90 -MPS -90 -MPS -90 7,148.27 869.06 7,148.27 762.02 5,201.13 8.119 Centre Distance Pass - MPU S-203 - MPU S-203 - MPU S-203 5,297.56 1,013.32 5,297.56 961.62 5,235.56 19.600 Clearance Factor Pass - MPU S-203 - MPU S-203PB1 - MPU S-203PB1 5,297.56 1,013.32 5,297.56 961.62 5,235.56 19.600 Clearance Factor Pass - MPU S-203- MPU S-203PB2 -MPU S-203PB2 5,297.56 1,013.32 5,297.56 961.62 5,235.56 19.600 Clearance Factor Pass - Plan: MPU S56 (MPU S-205) - MPU S-56 - MPU M -5f 5,297.56 817.07 5,297.56 746.42 5,778.06 11.565 Centre Distance Pass - 08 January, 2020 - 18:00 Page 5 of 9 COMPASS Hilcorp Alaska, LLC HALLIBURTON Milne Point Anticollision Report for Plan: MPU S-57 (MPU S-204) - MPU S-57 wp01 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Plan: MPU S-57 (MPU S-204) - MPU S-57 - MPU S-57 wp01 Scan Range: 5,297.56 to 13,631.62 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft 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 (usft) (usft) (usft) (usft) usft Plan MPU S-56 (MPU S-205) - MPU S-56 - MPU M-5( 13,222.56 920.21 13,222.56 633.15 14,221.31 3.206 Ellipse Separation Pass - Plan: MPU S-56 (MPU S-205) - MPU S-56 - MPU M-5( 13,272.56 922.68 13,272.56 634.09 14,221.31 3.197 Clearance Factor Pass - Proposal Plan: MPU S-206 - S-206 - UGNU#6 - S-206 6,347.56 372.81 6,347.56 325.95 5,434.61 7.956 Clearance Factor Pass - Proposal Plan: MPU S-206 - S-206 - UGNU#6 - S-206 6,572.56 287.99 6,572.56 266.50 5,473.26 13.404 Ellipse Separation Pass - Proposal Plan: MPU S-206 - S-206 - UGNU#6 - S-206 6,588.40 287.57 6,588.40 266.83 5,475.98 13.865 Centre Distance Pass - Proposal Plan: MPU S-207 - MPU S-207 - MPU S-207 7,397.56 328.42 7,397.56 276.31 6,007.15 6.303 Clearance Factor Pass - Proposal Plan: MPU S-207 - MPU S-207 - MPU S-207 7,572.56 263.25 7,572.56 233.62 6,042.87 8.883 Ellipse Separation Pass - Proposal Plan: MPU S-207 - MPU S-207 - MPU S-207 7,600.02 261.88 7,600.02 234.16 6,048.47 9.447 Centre Distance Pass - Proposal Plan: MPU S-208 - MPU S-208 - MPU S-208 8,097.56 308.54 8,097.56 253.25 6,555.41 5.580 Clearance Factor Pass - Proposal Plan: MPU S-208 - MPU S-208 - MPU S-208 8,247.56 252.87 8,247.56 217.06 6,586.03 7.061 Ellipse Separation Pass - Proposal Plan: MPU S-208 - MPU S-208 - MPU S-208 8,281.26 250.71 8,281.26 217.60 6,592.90 7.571 Centre Distance Pass - Proposal Plan: MPU S-209 - S-209 - MPU S-209 wp01 8,797.56 296.84 8,797.56 238.60 7,170.40 5.097 Clearance Factor Pass - Proposal Plan: MPU S-209 - S-209 - MPU S-209 wp01 8,947.56 249.53 8,947.56 209.64 7,201.01 6.256 Ellipse Separation Pass - Proposal Plan: MPU S-209 - S-209 - MPU S-209 wp01 8,962.47 249.10 8,962.47 210.21 7,204.05 6.405 Centre Distance Pass - Proposal Plan: MPU S-210 - MPU S-210 - MPU S-210 9,497.56 290.18 9,497.56 230.80 7,683.93 4.886 Clearance Factor Pass - Proposal Plan: MPU S-210 - MPU S-210 - MPU S-210 9,622.56 253.11 9,622.56 207.49 7,709.49 5.548 Ellipse Separation Pass - Proposal Plan: MPU S-210 - MPU S-210 - MPU S-210 9,644.14 252.23 9,644.14 208.12 7,713.91 5.718 Centre Distance Pass - Survey tool 12rQgram From To Survey/Plan Survey Tool (usft) (usft) 26.50 800.00 MPU S-57 wp01 3_Gyro-GC _Csg 800.00 5,297.56 MPU S-57wp01 3 MWD+IFR2+MS+Sag 5,297.56 13,631.62 MPU S-57 wp01 3_MWD+IFR2+MS+Sag 08 January, 2020 - 18:00 Page 6 of 9 COMPASS HALLIBURTON Anticollision Report for Plan: MPU S-57 (MPU S-204) - MPU S-57 wp01 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor= Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Hilcorp Alaska, LLC Milne Point 08 January, 2020 - 18:00 Page 7 of 9 COMPASS HALLIBURTON Project: Milne Point REFERENCE INFORMATION WELL DECAIlS:PImr MPU B-57 (MPU S-204) NAD 1927 (NADCON CONUS) Alaska Zone 04 Site: M Pt S Pad Co-ordinate (N/E) Reference: Wel Plan: MPU S-57 (MPU S-204). True North 36.30 Well: Plan:MPU S-57 (MPU S-204) V M-1(rVD) Reference: MPU S-57 M uiN RKB @ 62.8 -ft Measured DepM Reference: MPU S-57Aa-0uiN RKB @ 62 a -ft +N/ -S IE/ -W N0111mg Fed:ng L %H de Lo glmde Wellbore: MPU 857 CZIcuWBee Method: Mmimum cunawre 0.00 0.005999908.82 565567.71 70e 24' 36.716N 149° 27 57.973 W Plan: MPU S-57 wp01 SURVEY PROGRAM GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 0- 20sm-o6T00:o0:oo validated: Yes V-1- 26.50 To 13631.62 OepM Fmm Dopa, To Survey/Plan Tool CASINO DETAILS Ladder/S.F. Plots 26.50 800.00 MPU I I1.P MPU B-57) 3_GyroGO_Osg .z 800.00 5297.% MPU.:57,. (MPU 857) 3_MWD+IFR3+MS+Sag 5297.56 13631 62 MPU S-5 i01 (MPD S-57) 3 MWD+IFR2+MS+Sag TVD TVDSS MD Si. Nae m of 2 4112.80 4050.00 5297.56 9-5/8 9 5/8" x 12 1/4" 4102.80 4040.00 13631.62 6-5/8 6 5/8" x 8 l2" 180.00 � --MPS-23 I E f I�VB 1 X150.00 Id MPS -231_1 p l J O0 I. r' 120.00 MPS- H ;.rf-1?----- I 0.00 El 90.00- CU MPH-08APB7� Ij I I I U60.00--�---- 1J -! MPS -171_1 I o I I Im i 30.00 U I.. 0.00I i it 5400 5850 6300 6750 7200 7650 8100 8550 9000 9450 9900 10350 10800 11250 11700 12150 12600 13050 13500 Measured Depth (900 usfUin) 4.00' O- io 3.00 Co I j xx� I ILL c 0 22,00- CU Collision Risk Procedures Req. U) Collision Avoidance Req. 1.00 -_ No -Go Zone -Stop Drill ng j I i { NOERRORS 0.00 5400 5850 6300 6750 7200 7650 8100 8550 9000 9450 9900 10350 10800 11250 11700 12150 12600 13050 13500 Measured Depth (900 usf /in) TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: /+ U� }� POOL: Cl/It Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. 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 first 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) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140 _ Well Name: MILNE PT UNIT S-57 Program DEV Well bore seg ❑ I PTD#: 2200130 Company Hilcorp Alaska LLC Initial Class/Type DEV / PEND GeoArea 890 _ Unit 11328_ On/Off Shore On Annular Disposal ❑ Administration 1 Permit_fee attached_ - - - - - - - - _ - . - - - - - - - N_A_ . - - - Conductor set_ _ - - - - - - - - - - - - - - _ Engineering 2 Lease number appropriate_ _ . _ - _ _ - - Yes _ - - _ _ _ _ - - _ Surf Loc &-Top Prod Int lie in_A_D_L0380109, TD lies -in ------------------- 3 3 Unique well_nameandnumb_er - ------------------------ Yes------------------------------------------------------------------------ 9 5/8 casing will be fully cemented using- ES stage _collar -- - - - - - - - - - - - - - - - 4 Well -located in_a_defined_ pool ------- - - - - - _ _ Yes _ _ _ _ _ _ _ Milne Point Schrader Bluff Oil Pool (525140), governed by -CO 477, amended by CO 477.05. 5 Well -located proper distance from drilling unit -boundary ------ - - - Yes - - - - - - - CO 477.05 specifies:_ "There are no restrictions as to well spacing except that no pay shall_ - - - 6 Well located proper distance from other wells_ _ - _ - _ - _ _ - _ - Yes - - - be opened _in a well closer than. 500 feet from the exterior boundary of the_ affected area." 7 S ufficient acreage_avai[able in-dril_ling unit - - - - - - - - - - - - _ Yes - . _ _ _ - _ As planned, well conforms to spacing -requirements- - 8If_deviated, is -wellbore plat _included _ - - - - - Yes - - - - - 9 Operator only affected party - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - 10 Operator has_appropriate-bond in force _ _ _ Yes -- - - _ _ - - Appr Date 11 Permit can be issued without conservation order_ - - _ _ - - _ _ _ _ Yes - - - - Max form pressure =_1809 psi (8.6-ppg EMW)- Will drill with_8.9 - 9.5 ppg_mu_d_ Appr Date 12 Permit can be issued without administrativ-e_approval - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - -- - - - - - - -- - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - -- - - - - - - - - - - 13 Can permit be approved before 15-day_wa_it_ Yes MASP= 1398 psi will test BOPE to 3000 psi SFD 1/28/2020 31 -- - - - - - - - - - - - - - - - - - - - - - - - _ - - - - - - - - - - - - _ _ _ - - - _ -- - - - - - - - - _ - - _ - - - - - - - - -- - - - - - - 14 Well located within area and strata authorized by Injection Order# (put -10# in comments) -(For- NA_ - - . - - _ - - _ - _ 33 All wells -within 1/4_mile area_of review identified (For service well only) - _ - - - - _ - NA_ - - - Not expected on the pad ._ Rig has sensors and_alarms- - . - - - _ �15 16 Pre -produced injector. duration -of pre production less than 3 months -(For -service well only) _NA - - - - - - - - - - - - - - - - - - . - . - - - - - 17 Nonconven. gas conforms to AS31.05.0300,1-.A),(j.2.A-D) - - - - - - - - - - - - - - - - NA_ - - - - - - - - - - - - - - - - - - - - ..... . Geologic Engineering Public Completion will be a reverse circ Jet Pump . GIs Commissioner: Date: Commissioner: Date Commissi Da S Z zo C _.21V 7i 18 _Conductor string_ provided - - - - - - - - - - - - - - - - - - - - - - - - - _ - - - - - Yes _ . - . - - - Conductor set_ _ - - - - - - - - - - - - - - _ Engineering 19 I20 Surface casing -protects all -known_ USDWs - - - - - - - . - - - - - - - _ _ - - - - NA_ - - - - - NO aquifers...-permafrost_area. - - - - - - - - - - - - - - - - - - - - CMT -vol_ adequate to circul_ate_on conductor & surf_csg - . - - - _ - _ _ _ _ - - Yes 9 5/8 casing will be fully cemented using- ES stage _collar -- - - - - - - - - - - - - - - - 21 CMT_vol_adequate_to tie -in -long string to -surf csg- _ - - - - _ _ - - _ _ - - - _ - - - - Yes 9 5/8" casing will be topset in the SchraderBluff _sand (N) - - - - - 22 -CMT-will coverall known -productive horizons_ - - - - . - - - - - - - - - - Yes - - - - - - - slotted liner in -lateral- (6-5/8"). . 23 Casing designs adequate for C,_T, B &_permafrost - - _ - - - - - - - - - - - - - - - - - - Yes - - - - - - BTC ca_lcsprovided _ - _ - 24 Adequate tankage -or reserve pit - - - - - - - - - - - - - - - - - - - _ _ _ _ _ Yes . - - - 25 -If _a_ re -drill, has -a 1.0-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - - - - - - 26 Adequate wellbore separation_proposed- - - - - - - - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - Well path goes directly over (50 ft TVD)_existing_SB_ wells in -the OA/OB sand. 27 If-diverter required, does it meet_ regulations_ - - - - . - - _ - - - _ - - - - Yes - - - - - - - - - - Appr Date 28 Drilling fluid program schematic_&_ equip list adequate- _ - - - - - - - - - - - - - - - Yes - - - - - - - Max form pressure =_1809 psi (8.6-ppg EMW)- Will drill with_8.9 - 9.5 ppg_mu_d_ GLS 2/4/2020 29 BOPEs,_do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - Innovation rig has 13.5/8" BOPE_ 5000 psi WP - - - -------------------- 30 -B-OPE-press rating appropriate; test to -(put psig in comments)_ Yes - - - MASP= 1398 psi will test BOPE to 3000 psi 31 Choke_manifoldcomplies w/API_RP-53(May 84)_ - _ _ - _ - - _ Yes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 132 Work will occur without operation shutdown_ - _ - - - - - - - - - Yes - 33 Is presence_ of H2S gas_ probable - - - - - No_ - - - - Not expected on the pad ._ Rig has sensors and_alarms- - . - - - _ 34 Mechanical-cond-ition of wells within AOR verified (For service well only) - _ - _ - - - _ _ _ NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 35 Permit can be issued w/o hydrogen_ sulfide measures - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ H2S not anticipated from drilling of offset wells; however, rig will have H2S sensors and alarms._ _ _ _ _ _ _ _ Geology 36 Data -presented on- potential overpressure zones - - - _ _ Yes _ _ _ - - _ _ H2S mitigation discussed on p. -46 -and 48. -Only-normal reservoir pressure anticipated; however mud _ _ _ _ _ _ Appr Date 37 Seismic -analysis of shallow gas_zones_ - - - - - - - - - - - - - . - - - - - - - _ NA- _ - - . supplies will be available to increase mud weight to_1_ ppg above highest anticipated weight. - - - - - - SFD 1/28/2020 38 Seabed condition survey (if off_ -shore) NA_ - - - - Gas_ hydrates possible-based_on -drilling of offset wells._However, _mitigation_measures are discussed on 39 Contact -name/phone for weekly progress reports_ [exploratory only] _NA _ - - - - - - p.46. Wellbore breathing possible,_ discussed on p. 31._ Geologic Engineering Public Completion will be a reverse circ Jet Pump . GIs Commissioner: Date: Commissioner: Date Commissi Da S Z zo C _.21V 7i
