Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
219-116
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23567-01-00Well Name/No. MILNE PT UNIT K-44ACompletion StatusP&ACompletion Date4/20/2020Permit to Drill2191160Operator Hilcorp Alaska, LLCMD8077TVD6949Current StatusP&A6/4/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:ROP/ABG/DGR/EWR/ADR 2"/5" MD/TVD PB1, PB2NoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC12/18/20195579 8178 Electronic Data Set, Filename: MPU K-44APB1 LWD Final.las31694EDDigital DataC12/18/20195578 8148 Electronic Data Set, Filename: MPU K-44APB1 ADR Quadrants All Curves.las31694EDDigital DataC12/18/2019 Electronic File: MPU K-44A PB1 Final MD.cgm31694EDDigital DataC12/18/2019 Electronic File: MPU K-44A PB1 Final TVD.cgm31694EDDigital DataC12/18/2019 Electronic File: MPU K-44APB1_DSR.pdf31694EDDigital DataC12/18/2019 Electronic File: MPU K-44APB1_DSR.txt31694EDDigital DataC12/18/2019 Electronic File: MPU K-44A PB1 Final MD.emf31694EDDigital DataC12/18/2019 Electronic File: MPU K-44A PB1 Final TVD.emf31694EDDigital DataC12/18/2019 Electronic File: MPU_K-44APB1_Geosteering.dlis31694EDDigital DataC12/18/2019 Electronic File: MPU_K-44APB1_Geosteering.ver31694EDDigital DataC12/18/2019 Electronic File: MPU K-44A PB1 Final MD.pdf31694EDDigital DataC12/18/2019 Electronic File: MPU K-44A PB1 Final TVD.pdf31694EDDigital DataC12/18/2019 Electronic File: MPU K-44A PB1 Final MD.tif31694EDDigital DataC12/18/2019 Electronic File: MPU K-44A PB1 Final TVD.tif31694EDDigital Data0 0 2191160 MILNE PT UNIT K-44A PB1 LOG HEADERS31694LogLog Header Scans0 0 2191160 MILNE PT UNIT K-44A PB2 LOG HEADERS31695LogLog Header ScansC12/18/20195579 8077 Electronic Data Set, Filename: MPU K-44APB2 LWD Final.las31695EDDigital DataThursday, June 4, 2020AOGCCPage 1 of 3MPU K-44APB1 LWD Final.lasMPU K-44APB2LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23567-01-00Well Name/No. MILNE PT UNIT K-44ACompletion StatusP&ACompletion Date4/20/2020Permit to Drill2191160Operator Hilcorp Alaska, LLCMD8077TVD6949Current StatusP&A6/4/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYMud 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:4/20/2020Release Date:9/5/2019C12/18/20195578 8015 Electronic Data Set, Filename: MPU K-44APB2 ADR Quadrants All Curves.las31695EDDigital DataC12/18/2019 Electronic File: MPU K-44A PB2 Final MD.cgm31695EDDigital DataC12/18/2019 Electronic File: MPU K-44A PB2 Final TVD.cgm31695EDDigital DataC12/18/2019 Electronic File: MPU K-44APB2_DSR.pdf31695EDDigital DataC12/18/2019 Electronic File: MPU K-44APB2_DSR.txt31695EDDigital DataC12/18/2019 Electronic File: MPU K-44A PB2 Final MD.emf31695EDDigital DataC12/18/2019 Electronic File: MPU K-44A PB2 Final TVD.emf31695EDDigital DataC12/18/2019 Electronic File: MPU_K-44APB2_Geosteering.dlis31695EDDigital DataC12/18/2019 Electronic File: MPU_K-44APB2_Geosteering.ver31695EDDigital DataC12/18/2019 Electronic File: MPU K-44A PB2 Final MD.pdf31695EDDigital DataC12/18/2019 Electronic File: MPU K-44A PB2 Final TVD.pdf31695EDDigital DataC12/18/2019 Electronic File: MPU K-44A PB2 Final MD.tif31695EDDigital DataC12/18/2019 Electronic File: MPU K-44A PB2 Final TVD.tif31695EDDigital DataThursday, June 4, 2020AOGCCPage 2 of 3 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23567-01-00Well Name/No. MILNE PT UNIT K-44ACompletion StatusP&ACompletion Date4/20/2020Permit to Drill2191160Operator Hilcorp Alaska, LLCMD8077TVD6949Current StatusP&A6/4/2020UICNoComments:Compliance Reviewed By:Date:Thursday, June 4, 2020AOGCCPage 3 of 3M. Guhl6/4/2020 Note to File: MPU K-44A PB2, with a total depth of 8,077’ MD/ 6,949’ TVD, is considered the mainbore for this well. Data is labeled as PB2. M. Guhl 6/19/2020 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: _0 Service Stratigraphic Test 2.Operator Name:6.Date Comp., Susp., or Aband.: 3. Address: 7.Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: Top of Productive Interval: 9.Ref Elevations: KB: 17.Field / Pool(s): GL: 29.3' BF: 29.3' Total Depth: 10.Plug Back Depth MD/TVD: 18.Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19.DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22.Logs Obtained: 23. BOTTOM 7" L-80 6,787' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD N/AN/A SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 9-7/8" 176 sx STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 4/20/2020 3744' FSL, 2020' FEL, Sec 3, T12N, R11E, UM, AK 645' FNL, 1407' FWL, Sec 2, T12N, R11E, UM, AK Permit to Drill Number / Sundry: / - Milne Point Field / Kuparuk River Oil Pool 56.5' 5,431' MD / 4,813' TVD HOLE SIZE AMOUNT PULLED 50-029-23567-01-00 MPU K-44A 584535 6005880 N/A CEMENTING RECORD N/A SETTING DEPTH TVD 6006809 BOTTOM TOP 4,855' CASING WT. PER FT.GRADE N/A 587949 TOP SETTING DEPTH MD 5,480' (Cut) Per 20 AAC 25.283 (i)(2) attach electronic information DEPTH SET (MD) N/A PACKER SET (MD/TVD) 26# 7,725' Gas-Oil Ratio:Choke Size:Water-Bbl: PRODUCTION TEST N/A Date of Test: N/A Flow Tubing 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 N/A Previously Submitted with operations shutdown - ROP/ABG/DGR/EWR/ADR 2"/5" MD/TVD PB1, PB2 Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: October 22, 2020 October 5, 2020 ADL375133 / ADL375132 N/A 1,994' MD / 1,940' TVD 5,431' MD / 4,813' TVDN/A N/A 8,077' MD / 6,949' TVD WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 11:05 am, May 27, 2020 RBDMS HEW 5/29/2020 Abandonment Date 4/20/2020 HEW G 2019 MDG 2019 MDG DLB 06/01/2020 Abandoned gls 6/2/20 -- DSR-6/1/2020 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD 1,994' 1,940' Top of Productive Interval N/A N/A 5,734' 5,072' 7,549' 6,673' 7,658' 6,744' 7,750' 6,798' 7,956' 6,903' Kuparuk D 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Contact Email:cdinger@hilcorp.com Authorized Contact Phone: 777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: FORMATION TESTS Permafrost - Top Colville This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Permafrost - Base 29.GEOLOGIC MARKERS (List all formations and markers encountered): Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Kuparuk D HRZ Kalubik Formation at total depth: Kalubik GR Marker Wellbore Schematic, Drilling and Abandonment Reports, Definitive Directional Surveys, Csg and Cmt Report, OH Sidetrack Summary. Signature w/Date: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. INSTRUCTIONS Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). No NoSidewall Cores:Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2020.05.27 09:36:14 -08'00' Monty M Myers _____________________________________________________________________________________ Created By: CJD 5/26/2020 P&A Schematic Milne Point Unit Well: MPU K-44A P&A’d: 4-20-20 PTD: 219-116 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 78.6 / A-53 / Weld - Surface 80' 10-3/4" Surface 45.5 / L-80 / BTC 9.875 Surface 5,597’ 7" Intermediate 26 / L-80 / TXP 6.059 5,480’ 7,725’ JEWELRY DETAIL No. Top MD Item ID 1 7,554’ Cement Retainer WELL INCLINATION DETAIL 7” Window @ 7,609’ – 7,622’ MD GENERAL WELL INFO API: 50-029-23567-01-00 OPEN HOLE / CEMENT DETAIL Cond Cmt to surface 13-1/2” Cmt w/ 342 bbls (Lead) 120 bbls (Tail) Cmt to Surface 9-7/8” 38 bbls Inside 7” 15 bbs TREE & WELLHEAD Tree Seaboard 3-1/8”, 5K Wellhead well sidetracked to K-44B CIBP Activity Date Ops Summary 10/4/2019 Cont. changing out saver sub. Change out air slip inserts to 5";Pick up Bit, bit breaker, DM, TM, lift subs and floats for BHA via tool slide.;PJSM. M/U BHA, pick up motor and make up bit and DM collar. Measure RFO = 0.68"/7.01" = 34.92°. M/U TM, float, (2) flex collars and 1 HWDP. Shallow pulse test. Pick up drift and single in with (5) HWDP, Jars and (11) HWDP to 670.08'.;Daily hauled 105 bbls to G&I total = 1,721 bbls Hauled 0 bbls H2O from A-Pad reserve total = 0 bbls Hauled 130 bbls H2O from B-Pad Creek total = 3,640 bbls Lost 0 bbls to formation Total fluid lost section = 1,430 bbls 10/5/2019 Pick up, drift and single in the hole with 5" drill pipe from 670' to 5183'. PUW 163K, SOW 120K. Wash down from 5183' at 2 bpm/300 psi. Tag TOC at 5381' x 2 with 5K.;Circulate bottoms up while reciprocating pipe stage pumps up to 540 gpm/1725 psi.;Rig up, flood lines and purge air. PT casing to 2800 psi pumping down drill string and annulus - failed test. Bleed off. Pump a drill string volume and purge air. PT casing to 2800 psi for 30 minutes - good test. Pumped 5.4 bbls, bled back 4.9 bbls. Rig down, blow down choke/kill.;RIH and tag cement at 5381' Drill cement from 5381' to 5610' to get mud motor bend out of shoe. 540 gpm/1770 psi with 80 psi diff, 40 rpms/9,000 ft-lbs, WOB 8-10K. PUW 178K, SOW 125K, ROTW 144K.;Kick off sliding at 5610', observe formation over shakers at 5618'. Drill 20' of new hole to 5638', Initial ROP limited to 10fph increasing to 30 fph. WOB 0-10K, 540 gpm/1680 psi. PUW 174K, SOW 125K.;Rack one stand back and circulate bottoms up at 540 gpm/1720 psi - even mud weights 9.7 ppg in/out.;Rig up, fill lines and purge. Shut top rams. Perform FIT to 12.5 ppg EMW with 730 psi - good. Blow down lines, rig down.;RIH to TD at 5638'. Continue sidetracking well-bore drilling from 5638' to 5753' sliding as needed at 540 gpm/1880 psi, WOB 8-10K, 40 rpms/11Kft-lbs PUW 185K, SOW 125K, ROT 146K. Gain 2.72' C-C separation by 5657', and 11.75' C-C separation by projected survey at 5753'.;Circulate bottoms up at 540 gpm/1790 psi.40 rpms/10Kft-lbs, reciprocating pipe. Obtain SPR's.;POOH from 5753' to inside casing shoe at 5560', no indication of swabbing. Monitor well - static. Pump dry job. Continue to POOH to 670'. PUW 63K, SOW 63K.;Distance to WP #5: 2.4', 1.48'L, 1.9' R;Daily hauled 177 bbls to G&I total = 1,898 bbls Hauled 0 bbls H2O from A-Pad reserve total = 0 bbls Hauled 260 bbls H2O from B-Pad Creek total = 3,770bbls Hauled 130 bbls H2O from K-Pad lake, Total = 260 bbls Lost 0 bbls to formation Total fluid lost section = 1,430 bbls 10/6/2019 L/d BHA. Rack back 8 stands HWDP ant 1 jar stand. Rack back NM flex collars. L/D float, TM, and DM. Break bit, and L/D Mud motor.;Clean and clear rig floor. remove small BHA pieces from rig floor.;PJSM pick up RSS drilling BHA #2. Pick up Geo-Pilot, make up bit, DM collar, ADR, DGR/PWD, TM and IBS. Plug in and upload MWD. M/U float, stand of NM flex collars, float sub. Pick up 1st stand of HWDP and shallow pulse test.;RIH to 5548'; (2) stands HWDP, Jars stand, (5) stands HWDP and 5" drill pipe. Fill pipe and break in Geo-Pilot at 2623'. PUW 168K, SOW 120K. Calculated displacement.;Fill pipe. Wash and ream from 5,548' to 5,753' at 60 rpms/10.5Kft-lbs, 450 gpm/1235 psi. PUW 175K, SOW 124K, ROTW 143K.;Drill 9- 7/8" hole from 5753' to 6216', total 463' (AROP=93fph) staging up to 575 gpm/2020 psi, WOB 9-14, 120 rpms/13,5Kft-lbs. ECD's 10.2 ppg with 9.7 ppg mud. Max Gas 17U. PUW 200K, SOW 125K, ROTW 150K.;Drill 9-7/8" hole from 6216' to 6312', total 93' 575 gpm/2050 psi, WOB 3-8, 120 rpms/13ft- lbs. ECD's 10.3 ppg with 9.7 ppg mud. Max Gas 8U. PUW 210K, SOW 132K, ROTW 145K.;Trouble shoot Geo-Pilot: ABI pulsing up GTotal of 1.063 and not taking downlinked TF and defection command; TF locked at 45L. Attempt to reset tool with downlinked mode switch command without success. Reset tool with manual mode switch by cycling pumps. ABI within spec, and TF responding.;Drill 9-7/8" hole from 6312' to 6690', total 378' (AROP = 84fph) 550 gpm/1950 psi, WOB 15-18, 100 rpms/14ft-lbs. ECD's 10.2 ppg with 9.6 ppg mud. Max Gas 8U. PUW 233K, SOW 130K, ROTW 165K.;Distance to WP#5 (survey depth 6405): 11.08', 3.39'L, 10.55'R.;Daily hauled 346 bbls to G&I total = 2,244 bbls Hauled 0 bbls H2O from A-Pad reserve total = 0 bbls Hauled 130 bbls H2O from B-Pad Creek total = 3,900bbls Hauled 130 bbls H2O from K-Pad lake, Total = 130 bbls Lost 0 bbls to formation Total fluid lost section = 1,430 bbls n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: MP K-44A Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:1914444D MPU K-44A Drilling Spud Date: gpg ;RIH and tag cement at 5381' Drill 10/7/2019 Drill 9-7/8" hole from 6690' to 6944', total 254' (AROP = 73fph) 600 gpm/2300 psi, WOB 15, 110 rpms/16ft-lbs. ECD's 10.3 ppg with 9.55 ppg mud. Max Gas 12U. PUW 230K, SOW 140K, ROTW 168K.;CBU at 600 gpm/2250 psi, 60 rpms/13Kft-lbs, reciprocating pipe.;Attempt to POOH on elevators from 6883' to 6820', observe swabbing. BROOH from 6820' to 6312' at 550gpm/1920 psi, 60-100rpms/12Kft-lbs. PUW 225K, SOW 125K.;Cont. to BROOH from 6,312' to 5,802' at 550gpm/1920 psi, 80 rpms/12Kft-lbs. ECD's 10.58, max gas 652U. PUW 197K, SOW 117K, ROTW 153K.;POOH from 5,802' to 5,548'. observe 12K overpull as stabalizer/bit at casing shoe. PUW 197K, SOW 117K.;CBU at 575 gpm/1860 psi, 60 rpms/10Kft-lbs reciprocating pipe.;PJSM pull tripping nipple, install RCD bearing.;Service rig: grease/inspect crown, blocks and top drive. Check oil in top drive.;RIH on elevators from 5,548' to 6,820' with no issues. Wash down to 6,944' 400 gpm/1250 psi. No issues on trip.;Drill 9-7/8" hole from 6944' to 7170', total 226' (AROP = 50fph) 575 gpm/2370 psi, WOB 15-20, 80-100 rpms/15ft-lbs. Max Gas 370U. Begin holding back pressure while drilling, and trapping pressure on connections. Working up to CBHP of 10.8 ppg PUW 218K, SOW 130K, ROTW 165K.;Drill 9-7/8" hole from 7170' to 7581', total 411' (AROP = 69fph) 550 gpm/2545 psi, WOB 15-20, 80-100 rpms/18ft-lbs. Max Gas 425U. Hold back pressure while drilling and trapping on connection for a CBHP of 11.2 - 11.3 ppg EMW PUW 230K, SOW 130K, ROTW 162K. Top of HRZ logged at 7549'MD.;Distance to WP#5 (survey depth 7424'): 10.73', 2.54'L, 10.43'R.;Daily hauled 689 bbls to G&I total = 2,933 bbls Hauled 520 bbls H2O from B-Pad Creek total = 3,420 bbls Hauled 130 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 130 bbls from 6 mile lake, Total 130 bbls Lost 0 bbls to formation Total fluid lost section = 1,430 bbls 10/8/2019 Drill 9-7/8" hole from 7581' to 7736' MD/6789' TVD, total 155' (AROP = 78fph) 600 gpm/2950 psi, WOB 15-20, 80-100 rpm/18k tq on, Max Gas 601u. Hold back pressure while drilling and trapping on connection for a CBHP of 11.2 - 11.3 ppg EMW. P/U 233K, S/O 135K, ROT 162K.;Circulate and condition mud (Rot/Recip) @ 7736' MD (Intermediate TD). Circulate 3x btms up. 600 gpm, 2850 psi, 120 rpm, 15k tq.;Monitor well w/ 200 psi back psi for 10 min (10 ppg EMW). Pressure bled down to 164 over 10 min. Slowly increase MPD to ~625 psi w/ 9.55 MW (11.3 EMW) and hold while POOH on elevators F/ 7736' - T/ 6514' MD. Hole took proper displacement. 5-10k drag w/ several 25k bobbles before falling off.;TIH on elevators F/ 7514' - T/ 7736' without issue holding ~625 psi w/ MPD (11.3 EMW). Hole took proper displacement.;Break circulation and stage up to 585 gpm, 2640 psi, 80 rpm, 16k tq while holding ~260 w/ MPD (MWD showed 11.3 EMW). Weight up active system from 9.6 to 10.5 over 3x circulations. Monitor well via MPD no pressure buildup.;POOH on elevators from 7736' to 5548', following Beyond trip schedule holding dynamic pressure of 340 psi and static pressure 280 psi at 45 fpm. Observe intermittent 5-15K drag off off bottom to ~7300'. 25K overpull at 5771' = wipe through - clean.;Circulate and condition mud (Rot/Recip). Circulate 3x btms up at 580 gpm/2350 psi, holding back pressure to maintain ~11.55 ppg EMW for a CBHP of 11.3 ppg. PUW 168K, SOW 118K, ROTW 135K.;Service rig: Grease crown, blocks and top drive. Check oil in TD. SimOps : monitor well with MPD - no pressure buildup. Open tattle tall on RCD to verify well is static.;POOH laying down drill pipe from 5548' to 1542', following Beyond trip schedule holding initially 360 psi dynamic pressure down to 320 psi, and 280 psi static pressure at 80 fpm. Observe 30K overpull at 3400', went down with no issues, pulled back through with 5K.;Distance to WP#5: 12.02', 11.67'L, 2.87'R;Daily hauled 0 bbls to G&I total = 2,933 bbls Hauled 260 bbls H2O from B-Pad Creek total = 4,680 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 0 bbls from 6 mile lake, Total 130 bbls Lost 0 bbls to formation Total fluid lost section = 1,430 bbls 10/9/2019 Continue POOH F/ 1542' - T/ 747' MD laying down 5" drill pipe while maintaining 11.3 EMW CBHP w/ MPD (~280 psi static / ~320 psi dynamic). 15 bbl loss for total trip.;Bleed off MPD psi to 0 and monitor well (static). Verify static well visually via bleed off hose (confirmed static). Remove RCD head and install trip nipple. Blow down MPD system.;PJSM, POOH F/ 747' to MWD laying down all HWDP, jars, flex DC, Float sub and stab. Plug in and download MWD. B/O and L/D MWD/RSS. No notable damage to BHA. Bit graded - 1,1,CT,A,X,I,NO,TD.;Clean and clear rig floor of BHA components.;Drain stack. Pull wear ring, set test plug.;Bleed down accumulator. Open UPR doors and change out to 7" solid body rams. Re-energize accumulator.;Flood lines and purge air. Test UPR's on 7" test joint. 250/3500 psi. Rig down testing equipment. Blow down kill line.;Rig up Weatherford, change out elevators, M/U Volant, R/U power tongs. Dummy run hanger.;PJSM. Pick up shoe track, BakerLok to pin end of joint 4. Check floats - good. RIH with 7" 26#, L-80 TXP casing to 1,574'. Make up torque 14,750 ft-lbs. PUW 62K, SOW 60K, calculated displacement observed.;RIH with 7" 26#, L-80 TXP casing to 4,995'. Make up torque 14,750 ft-lbs. 60 fpm; ~10.9 ppg EMW on bottom surge as per Beyond running procedure. PUW 135K, SOW 11K, calculated displacement observed.;Daily hauled 57 bbls to G&I total = 3,333 bbls Hauled 130 bbls H2O from B-Pad Creek total = 4,810 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 0 bbls from 6 mile lake, Total 130 bbls Lost 15 bbls to formation Total fluid lost section = 15 bbls 10/10/2019 Cont. to RIH with 7" 26#, L-80 TXP casing from 4,995' to 5597'. Make up torque 14,750 ft-lbs. 45 fpm; ~10.9 ppg EMW max on bottom surge as per Beyond running procedure. PUW 145K, SOW 116K, calculated displacement observed.;Circulate annular volume staging pumps up to 8 bpm/250 psi in upstroke. Reciprocating pipe.;Cont. to RIH with 7" 26#, L-80 TXP casing from 5597' to 7131'. Make up torque 14,750 ft-lbs. 45 fpm; ~11.0 ppg EMW max on bottom surge as per Beyond running procedure. PUW 190K, SOW 139K, calculated displacement observed. 30k tag @ 6190' MD (wash past 4 bpm on 2nd attempt).;Circulate annular volume prior to HRZ staging pumps up to 6 bpm/330 psi in upstroke, reciprocating pipe.;Continue to RIH with 7", 26#, L- 80, TXP casing from 7131', set down 25K at 7,525'. Establish circulation at 4 bpm/275. Wash casing down from 7,525' to 7,696'. M/U hanger and landing joint. Cont. washing down to casing point of 7725'. PUW 210, SOW 140K.;Circulate hole clean staging pumps 6 bpm/330 psi, reciprocating pipe. Rig up cementers and prep for cement job.;Cement as per detail: Flood lines and PT 1500/4000 psi - good. Mix and pump 40 bbls of 11.0 ppg spacer at 3.4 bpm/304 psi, drop bottom plug, mix and pump 38 bbls of 15.8 ppg Class G cement at 3.5 bpm/640 psi. Drop top plug. Displace with 5 bbls water followed by 289.5 bbls.;(calc 287.9 bbls, 1/2 shoe track volume over) at 6 bpm/330 psi, stage rate down to 2 bpm once cement exits shoe. FCP 335 psi. Pressure up to 850 psi and hold for 5 minutes. Check floats - good. CIP at 19:00 psi. No losses throughout job.;R/D volant tool and weatherford handling equipment. Clean and clear rig floor.;Back out landing joint. M/U pack-off and set. RILDS, energize P-seals with plastic packing. Attempt to test Pack-off void - would not pressure up. BOLDS, pull pack-off. Lower body seal gauged, top neck seal also damaged. Redress packoff. SimOps: Install long mousehole while redressing packoff;Re-Install packoff. RILDS, energize P-seals and attempt to test pack-off, would not pressure up. Pull pack-off; seals in good condition. Wellhead rep mobilize another (used) pack-off to location, while attempting a third time with same results. Install different pack- off with same results.;Pull pack off and L/D landing joint. Contact Seaboard to troubleshoot packoff. Change out UPR's to 2-7/8" x 5.5" VBR's. Begin working on changing out saver sub. AOGCC witness notification sent for 10/11/19 BOP test.;Daily hauled 801 bbls to G&I total = 4,134 bbls Hauled 130 bbls H2O from B-Pad Creek total = 5070 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 0 bbls from 6 mile lake, Total 130 bbls Lost 15 bbls to formation Total fluid lost section = 15 bbls cement 7" casing g Open UPR doors and change out to 7" solid body rams. Drill 9-7/8" hole from 7581' to 7736' MD/ jp pg , mix and pump 38 bbls of 15.8 ppg Class G cement at 3.5 bpm/640 Drill 9-7/8" hole from 6690' to 6944', total 254' g Cont. washing down to casing point of 7725'. Cont. to RIH with 7" 26#, RIH with 7" casing 10/11/2019 Continue troubleshoot packoff issues with 11" 5M Seaboard thru bowl wellhead. Obtain measurements vs stack up schematic. Found lower external seal on packoff had been relocated on new packoff assemblies which placed seal across unused lockdown screws on are wellhead configuration.;Located old packoff and redressed. On 6th attempt we were able to successfully set, RILDS and test packoff 800/5000 w/ 5/15 min hold ea (good test). L/D landing jt. B/O packoff running tool. Test witnessed by Co Rep (Shane Barber).;R/U BOP test equipment. Flood lines and manifold. Shell test BOP stack 250/3500 psi.;R/U and L/D 5" NC50 DP out of derrick (6 stds) while waiting on AOGCC rep to arrive onsite.;Pick up 4" test joint. Set test plug. m/U test sub into top drive. Flood lines, purge air.;Test BOPE's 250/3500 psi on 3-1/2" and 4" test joints. Test gas alarms, flow paddle and alarms. Test witnessed by AOGCC rep Matt Herrera. No failures. Accumulator drawdown: Starting pressure 3000 psi, final 1450 psi. First 200 psi recharge 22 seconds, full recharge 81 seconds. (6) N2 at 2333 psi.;Rig down test joint and testing equipment. Blow down choke and kill lines. Install wear bushing.;L/D 29 stands of 5" drill pipe via mousehole.;Service rig: grease crown, blocks, top drive, iron roughneck. Perform derrick inspection.;Change out elevator inserts to 4". Pick up small BHA pieces from slide. Load collars and HWDP in shed. Break off TIW and dart from test joint.;M/U BHA. pick up Geo-Pilot and ADR collar. M/U bit. M/U ILS, Gamma, PWD, DM, TM, and IBS collars as per DD. Plug in and download.;Daily hauled 117 bbls to G&I total = 4,251 bbls Hauled 130 bbls H2O from B-Pad Creek total = 5070 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 0 bbls from 6 mile lake, Total 130 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls 10/12/2019 Finish downloading MWD. M/U BHA #3 (286.63' total length). 6-1/8" RSS geopilot, MWD, 2x flex DC's, 3x 4" HWDP w/ jars. 2 solid floats installed in BHA. Shallow pulse test MWD 200 gpm, 540 psi (test good).;PJSM, Single in hole F/ 286' - T/ 2044' w/ 4" HT38, 14#, S-135 dp out of shed (drift 2.35"). Sym Ops -LRS onsite @ 08:00. Freeze protect 10-3/4" x 7" annulus w/ 100 bbls diesel (2020' MD). 2 bpm, 500 ICP, 832 FCP. Shut in psi = 780.;Continue trip in hole out of derrick F/ 2044' - T/ 5300' MD. Break in Geo-Pilot @ 2736' as per DD staging up from 10 rpms to 80 rpms (2k tq), 200 gpm, 1130 psi. Downlink (success). 100k up, 75k dn. Calculated disp for trip.;Continue trip in hole F/ 5300' - T/ 7620' MD washing down last stand. No cmt encountered. Calculated disp for trip. 142k up, 96k dn, 2 bpm, 700 psi.;R/U and test 7" TXP BTC, 26#, L-80 casing to 3500 psi w/ 30 min hold (test good). Chart and record same. 2.7 bbls pumped, 2.7 bbls returned. 14 psi drop first 15 min, 0 psi drop last 15 min.;PJSM, Hang blocks, cut drilling line (14 wraps), ACCUM TM 13804. Check brake air gaps (within spec). Recalibrate block position & zero ton mile tracker.;Wash down from 7620', tag up on FC on depth at 7640'. Drill shoe track and 2' new hole from 7736' to 7738' at 60 rpms/7Kft-lbs, 200 gpm/1600 psi. Tag float shoe on depth. PUW 142K, SOW 96K, ROTW 113K. At 7738', hole packed off 600 psi increase and TD stalled (set limit 10Kft-lbs).;Work pipe, establishing circulation at 3/4 bpm with limiter set at 900 psi. Establish rotary ~ 1' off bottom with 20 rpms/7500 ft-lbs. Work pipe with non-rotating housing at the shoe, pulling 30K over. Observe pump pressure falling, stage pumps up to 2 bpm/540 psi. Slowly work pipe into shoe;fighting multiple pack-off with 10K over pulls, staging pumps up to 2.5 bpm as pressures fall/stabilize - no losses.;Circulate bottoms up staging pumps up to 250 gpm/2000 psi, 60 rpms/7500 ft-lbs reciprocating pipe from 7225' to 7683'. Start working pipe back to bottom at 7738'.;Cont. drilling total of 20' new hole from 7738' to 7756' ROP 0 -30 fph; adjusting parameters to attempt and increase ROP: from 250 gpm/2141 psi to 175 gpm/1220psi, 80rpms -120 rpms/6700ft-lbs, WOB 4-15Klbs. Displace to 10.0 ppg Baradril-N on the fly. PUW 165K, SOW 96K, ROTW 115K.;Circulate bottoms up 250 gpm/1900 psi, 60rpms/6000ft-lbs, racking back from 7756' to 7683'; Observe signs of packing off as bit enters shoe, slack off and slow pumps to 2 bpm to pull into shoe.;Rig up, flood lines and purge air. Perform FIT to 13.0 ppg EMW (1060psi) - good test. Pumped 1 bbls, bled back 1 bbls. Rig down and blow down lines.;Pull tripping nipple, install MPD RCD bearing.;Wash and ream BHA in casing attempting to clear debris from bit. Continue to wash and ream from 7683' to 7676' at 200 gpm/1330 psi, 60 rpms/6Kft-lbs.;Daily hauled 57 bbls to G&I total = 4,308 bbls Hauled 130 bbls H2O from B-Pad Creek total = 5200 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 0 bbls from 6 mile lake, Total 130 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls 10/13/2019 Continue drilling 6-1/8" production hole F/ 7756' - T/ 7848' MD / 6857' TVD. 250 gpm, 2330 psi on, 2320 psi off, 60-150 rpm, 7k tq, 10-130 diff psi, 3-18k wob, 160k up, 90k dn, 104k rot. Drilling Kulubik formation (shale). Varied parameters attempting to increase slow rop (20-50 fph ROP).;Pumped 30 bbls nut plug (6 ppb), condet sweep for possible bit balling. Yielded minimum change in ROP once clear of bit.;Continue drilling 6-1/8" production hole F/ 7848' - T/ 7884' MD. 250 gpm, 1950 psi, 125 rpm, 7k tq, 8k wob, 158K up, 84K dn, 105K rot. Varied parameters to attempt to increase slow rop. Max gas 43U. ECD 11.45 ppg EMW with 170 psi back pressure applied by MPD. Floats no holding, bleeding on conn.;Troubleshoot comms error with MWD, change out choke size in geospan to send downlinks.;Continue drilling 6-1/8" production hole F/ 7884' - T/ 7920' MD. 250 gpm, 1450 psi, 135 rpm, 7Kft-lbs, WOB 12, 163K up, 85K dn, 105K rot. Max gas 13U. Discontinue holding back pressure at 7900' due to floats not holding. Comms with MWD tool.;Continue drilling 6-1/8" production hole F/ 7920' - T/ 8026' MD. 250 gpm, 2150 psi, 135 rpm, 8Kft-lbs, WOB 8-20, 164K up, 82K dn, 109K rot. Max gas 11U. ECD 11.0 ppg. Pumped 8% lube sweep at 7973', observed 6K drop in weight as lube crossed bit, pumped 2nd 8% lube at 7994'.;ROP increased from 15-20 fph to 50-70 fph until sweep exited hole at 8025'.;Continue drilling 6-1/8" production hole F/ 8026' - T/ 8074' MD. 250 gpm, 1900 psi, 140 rpm, 8Kft-lbs, WOB 8-20, 164K up, 84K dn, 107K rot. Max gas 11U. ECD 11.0 ppg. Attempt to pump another lube pill with little success. ROP 15-50fph. Packed off and stalled out at 8074'.;Pick up and establish rotary 20 rpms/7Kft-lbs. Work pipe to establish circulation, stage pumps up with multiple pack-offs to 5 bpm/1500 psi.;Continue drilling 6-1/8" production hole from 8074' to 8116'. Initial ROP 40 fph falling to 15-20fph. 250 gpm, 1930 psi, 140 rpm, 7.9 Kft-lbs, WOB 8- 20, 164K up, 84K dn, 107K rot. Max gas 11U. ECD 11.0 ppg.;Distance to WP05: 9.5', 9.4' low, 1.4' left (survey depth 7982.6').;Daily hauled 575 bbls to G&I total = 4,883 bbls Hauled 0 bbls H2O from B-Pad Creek total = 5200 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 260 bbls from 6 mile lake, Total 390 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls pggppp gp p p ;Cont. drilling total of 20' new hole from 7738' to 7756' ROP r. Perform FIT to 13.0 ppg EMWrr Continue drilling 6-1/8" production hole F/ 7756' - T/ 7848' MD / FIT to 13 ppg gp (p) Drill shoe track and 2' new hole from 7736' to 7738' () g p ;Test BOPE's 250/3500 psi on 3-1/2" and 4" test joints. 10/14/2019 Continue drilling 6-1/8" production hole from 8116' to 8179' MD / 6990' TVD. 250 gpm, 1980 psi, 110-140 rpm, 7.9 Kft-lbs, WOB 8-22, 188K up, 83K dn, 107K rot. Max gas 36u. ECD 11.0 ppg. Packed off @ 8150' bit depth while backreaming during connection. 2000 psi, 12.5k tq stall.;Work pipe free with no pump and establish free rotation w/ 7.2k tq. Stop rotation and slowly pump out of hole F/ 8179' - T/ 7994' with significant packing off issues until 8050 where we were able to establish circulation 2 bpm, 490 psi.;Saw 62k overpull freeing pipe then consistent 10-20k drag. 180k up, 80k dn.;Continue pump out of hole F/ 7994' - T/ 7725' MD (shoe). Saw 30k overpull when upper string stabilizer pulled thru shoe. Only minor bobbles pulling remaining BHA up into shoe.;Circulate and condition mud 1.5x btms up @ 7725' MD. 250 gpm, 1830 psi, 60 rpm, 7.4k tq. 300% increase in cuttings at btms up. Initially saw very fine cuttings (sand/shale) @ btms up then became more coarse for another 40 bbls pumped.;Monitor well, static. Pull MPD bearing. Install trip riser.;POOH on elevators from 7610' to 6678', observe swabbing. pump out of hole at 3bpm/630 psi to 6335', correct hole fill while pumping. PUW 161K, SOW 92K.;Continue to POOH from 6020' to 5426' - still swabbing. Run back in hole to 6020' with correct displacement.;Circulate 50 bbls nut plug/condet sweep at 250 gpm/1460 psi, 60 rpms/5300 ft-lbs. No increase in cuttings.;POOH 60fpm for 10 stands, no signs of swabbing. Continue to POOH to 3760' with good displacement. Pump dry job. POOH to 3206' - calculated displacement. PUW 82K.;Continue to POOH from 3206' to 286'. PUW 43K, SOW 43K. Calculated displacement observed.;L/D BHA: monitor well, static. Rack back 3 jtns of HWDP/Jars, L/D float subs, XO's and IBS. Rack back flex collars. Plug in and read MWD tools. L/D TM, DM. Pull up and inspect ADR and Geo-Pilot. Break bit. Bit grade 1-1-NO-X-I-PR. No signs of damage to BHA.;M/U new BHA. M/U 5-bladed bit. C/O ILS, Gamma, PWD, DM, TM collars, IBS. Plug in and upload MWD.;Distance to WP05: 8.38', 7.98' low, 2.59' left (survey depth 8045.60').;Daily hauled 114 bbls to G&I total = 4,997 bbls Hauled 130 bbls H2O from B-Pad Creek total = 5330 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 260 bbls from 6 mile lake, Total 390 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls 10/15/2019 Continue with download MWD. M/U new floats (solid), 2x Flex DC's, XO, 3x jts 4" HWDP w/ jars (286' total length BHA). Shallow pulse test @ 200 gpm, 600 psi (test good).;RIH F/ 286' - T/ 6303' MD w/ 6-1/8" assy on 4" HT38 DP. Closed annular and psi up 60 psi on annulus to verify new floats were holding (floats held). Fill pipe every 25 stds. Observed gas climbing to 800u. Observed well (no gain, gas breaking out and crude).;Kelly up @ 6303' MD and circulate 1.5x btms up. Saw gas continually climb throughout 1st btms up with peak gas @ 2361u then slowly trending down to 200-300u. Staged up to 180 gpm, 975 psi w/ full returns. NGR fault displayed during cleanup cycle and dropped pump rate to 5 spm. Troubleshoot pump.;Shut down pumps and isolate power to Hi-Line. Pumps reset and ran without issue. Swapped over to gen power and had no issue. Finished cleanup cycle without any other issue.;Continue RIH on elevators F/ 6303' - T/ 7620' MD. Calc disp for trip.;PJSM, Monitor well (static). Remove trip nipple and install MPD rotating head. Flood lines and test same (test good). Baseline MPD system at drilling rate (25 psi surface friction).;Attempt to trip in from shoe. 3x 15k tag @ 7726' (shoe @ 7725'). P/U into shoe, establish parameters 163k up, 96k dn (w/ pumps), 151k up, 91k dn (w/ no pump). 175 gpm, 1070 psi, 60 rpm, 7.6k tq. Attempt to wash down from shoe. Obstruction @ 7726'-7728' then freed up. Work thru w/ pump/rot/20k.;Cont working down from 7728' to next obstruction @ 7741'-7743' w/ same parameters. Worked back up into shoe with same amount of trouble going up. Temporarily detained @ 7741' before freeing pipe coming up. Worked back down to 7761' MD with similar parameters encountering tight spots as before.;Work free and pull up to 7730' MD. Significant packoffs and inability to travel up or dn during tight spots noted. Tight spots did not change from each time we worked thru them. Max pull 40k over and 40k dn while working tight spots.;Discussed options with town engineer. Decision made to hold 11.5 EMW utilizing MPD while attempting to wash to btm. Wash dn to 7804' MD holding 11.5 EMW w/ MPD. 205 gpm, 1525 psi, 62 rpm, 7.8k tq. Stalled @ 11.5k tq @ 7804' MD. Begin working to free pipe @ 17:55 hrs.;PJSM Rack back stand to 7,803' MD. P/U working single. Work string F/ 7,803' to 7,800' MD ROT 155K, ROT SLK 70K W/ 1,500 PSI Press trapped in string, 20 RPM stall set at 12.7K. Cont. working string pulled 200K (40K over) without rotation. Tried no pumps and bleed down MPD to zero,;pulled to 200K, SLK to 70K, tried W/ 50 RPM, TRQ set 12.7K ROT SLK 70K, ROT 170K string stalling out at 7,999' MD. Jarred up 5 X and lost all progress but was able to SLK back down. Went to 50 RPM, TRQ set 13.4K Press set at 600 PSI, MPD 200 PSI, inching up pulling F/ 160K to 170K watching torque;stall with no Circ. Worked to 7,798' MD and stalled out, worked string F/ 70K to 170K to regain rotation. Work string back up to 7,798' lost 150 PSI to 450 PSI on string, TRQ 12.3K at 50 RPM, ROT 117K. Cont working pipe up to 7,790' MD W/ 50 RPM, TRQ set 13.7K ROT 125K, 200 PSI stand pipe,;MPD 160 PSI. Work string F/ 7,803' to 7,790' MD. 50 RPM, TRQ 10-13K, 200 PSI trapped in string, ROT 125K, ROT SLK 80K. Shut down and L/D working single. Kelley up and try to gain Rot. Set RPM at 50 W/ 13.7K stall, 200 PSI trapped Press.;Work string pulling to 170K, SLK 70K only gaining 2', Was able to get 50 RPM, TRQ 10.5K still packed off but had 4' of movement. P/U working single. No losses to formation. Circ. fluid through MPD and Top Drive at 21:00 and 23:00 to ensure no ice plugs.;PJSM Set RPM 50, TRQ limiter at 13.7K, trap 200 PSI, MPD 160 PSI. Working string F/ 7,803' to shoe at 7,725' MD. watching TRQ stall and intermittent flow at 200 PSI. Pulling 120K to 135K. Cont. to pull to 7,697' MD. Was able to get partial flow in 7" casing.;Rot and Reciprocate at 50-20 RPM, TRQ 8K, ROT 120K, ROT SLK 108K. CBU working string F/ 7,697' to 7,641' MD, Staging up pumps from 0.5 bpm to 3 bpm, 800 PSI. MPD 200 PSI, 10.5-10.9 ppg EMW. Max Gas at BU 732U. Circ. 2nd BU at 200 GPM, 1,150 PSI, 20 RPM, TRQ 8K, Max Gas 600U, MPD 200 PSI.;Attempt to down link MWD. Open Choke and attempt to down link cycling pumps. MWD is pulsing but tools are not reading data, Shut down and monitor well with MPD closed, gained 2 PSI over 10 Min. Open MPD by pass and monitor for 5 Min, well static.;Daily hauled 0 bbls to G&I total = 4,997 bbls Hauled 0 bbls H2O from B-Pad Creek total = 5330 bbls 10/16/2019 Monitor well (static). Pull RCD and install trip nipple. Pull wet out of hole F/ 7651 to 7212' MD. 163k up, 96k dn observed swabbing. Trip back to bottom from 7212' to 7712' MD.;Circulate nut plug / condet sweep surface to surface to clear debris from BHA. 40 bbls w/ 10 ppb nut plug. 250 gpm, 1300 psi, 20- 50 rpm, 8k tq. 50 units gas.;Monitor well (static). POOH F/ 7712' - T/ 286' MD. Pulled 1st 5 stds wet (no swabbing), pump dry job, B/D TDS.;Rack back HWDP w/ jars, 1 std NM Flex DC's, B/O and L/D floats (both floats stuck partially open due to nut plug on valve guide, clean and rebuild). Download. P/U MWD w/ upper part of Geo Pilot starting @ reference housing. Lost 12.22' GP + .85' bit) 13.07' total left in hole. Discuss with town.;PJSM P/U M/U BHA 5 Dumb Iron 6 1/8" Smith XR-PS Tri Cone, 4 3/4" Bit Sub, X/O, 2 Jts 4" HWDP, 4 3/4" Jars, 1 jnt 4" HWDP total 131.58'. One non ported float. 3 X 15 Jets in bit.;PJSM Service rig. Grease Crown, Blocks, Top Drive, Spinners, Iron Roughneck and inspect Drawworks.;PJSM RIH W/ BHA #5 on 4" 14# HT38 L-80 F/ 132' to 7,653' MD. No losses.;PJSM CBU Rot & Rec F/ 7,653' to 7,593' MD. Circ at 6 bpm, 1,100 PSI, 40 RPM, 6.7K TRQ, ROT 115K, P/U 150K, SLK 100K. Obtain parameters 20 RPM 6.7K TRQ, 40 RPM 6.8K TRQ, 60 RPM 7K TRQ. Max Gas 32U.;PJSM RIH F/ 7,653’ to 7,715’ MD. Wash down at 2 bpm, 380 PSI F/ 7,715’, took 7K weight at 7,730’ Cont to 7,755’ Press up to 540 PSI packed off, pulled 10K over to get free. Pulled to 7,715’ was able to get returns. Pump at 4 BPM, 630 PSI, 40 RPM, 6.7K TRQ, stall set 15K, ROT 104K, 38% F/O.;Start washing down working tight spots at 7,730’, 7,741’ & 7,755’. At 7,761’ saw slight packing off TRQ stall at 15K pulled 10K over to get free. Pulled up to 7,736’ no issue. Wash down working tight spots to 7,750’. Cont washing with minimal issue to 7,781’ MD. Adjust parameters to 20 RPM.;TRQ 7.6K, 4 BPM, 668 PSI, ROT 115K, 33.1% F/O. Tagged 7,792’ W/ 5K, Tagged at 7,796’ 2X W/ 5K down.;Rotate out at 20 RPM, 650 PSI, 9.5K TRQ, ROT P/U 122K, 33.1% F/O. Packed off at 7,770’ TRQ 12K, trapped 720 PSI in string. Cont. fighting out of hole W/ string packing off erratic 10 to 12K TRQ stall W/ 20 RPM to shoe at 7,725’ MD. Once in 7" Csg at 7,708' was able to achieve;good returns but 50 PSI increase in pump Press and 300-400 ft/lb increase in TRQ. Max Gas 835U.;PJSM Rot and Rec F/ 7,708’ to 7,647’ MD 5 BPM, 870 PSI, 20 RPM, TRQ 7.4K, 37.2% F/O ROT 112K. CBU Max Gas 815U. Saw only fines over Shakers at BU. Monitor well for 15 min, static.;PJSM POOH F/ 7,708' to 6,775' MD 20-40 ftm watching for swabbing. P/U 155K, SLK 95K. Pump Dry Job and Cont POOH F/ 6,775' to 5,523' MD. P/U 113K, SLK 83K. Blow down Geo Skid to clear any debris from nut plug sweeps.;Daily hauled 57 bbls to G&I total = 5,054 bbls Hauled 0 bbls H2O from B-Pad Creek total = 5330 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 130 bbls from 6 mile lake, Total 520 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls Continue drilling 6-1/8"production hole from 8116'to 8179' gp Significantgp p gg p p p packoffs and inability to travel up or dn during tight spots noted. Tight spots did not change from each time we worked thru them. 10/17/2019 Continue POOH F/5523' - T/ Surface. L/D 6-1/8" cleanout assy BHA. 6-1/8" Milltooth Bit showed 2 chipped cutters indicating good tag on fish. Hole took proper displacement for trip.;Clean and clear rig floor. Bring tools and equipment to rig floor. C/O inserts to 3.5" on hydraulic elevators.;M/U XO w/ TIW, Stage same. M/U perforated 3.5” tubing orange peel shoe (29.89' length) w/ 15 jts 3.5" EUE, 9.3#, L-80 tubing and 3.5" EUE X HT38 crossover (498.21' total length of cement stinger assy).;C/O inserts to 4" on elevators. RIH w/ 3.5" cmt stinger F/ 498' - T/ 7685' MD.;Obtain parameters - 4 bpm, 510 psi, 20 rpm, 6.9k tq. Attempt to wash down F/ 7685' tag up @7755' MD. Packed off, pulled 35k over to get free. Increase pump to 5 bpm, 690 psi and wash down staging in hole 10-15' at a time then pull back into shoe each time. Seemed to cleanup open hole section.;Tag @ 7766' w/ packoff and 30k overpull back up into shoe. Stage up pumps to 12.25 bpm, 2590 psi and pick up to 7710' MD. Circulated 2.5x btms up. Shakers unloaded @ btms up initially with fines became more coarse throughout 1st btms up and 1/2 of 2nd btms up before cleaning up. Sand/Shale.;Wash down @ 1/2 bpm F/ 7710 - T/ TOF @ 7795' without issue. Tag 2x w/ 5k TOF. 141k up, 95k dn.;PJSM Blow down Top Drive. P/U 4" working single. RIH to TOF at 7,795'. Kelly up W/ 5' pup and pump in sub to string. R/U Halliburton valves and cement line. Stage pumps up to 4.5 bpm 815 PSI packing off. Work drill string W/ 25K over SLK 20K to establish intermittent returns at 2 bpm 330 PSI.;PJSM Cont trying to get to 4 bpm W/ out success. Park string at 7,795'. Stage pumps up F/ 0.5 to 2 bpm 400 PSI to establish Circ. Shut down for 3 min and stage pumps up F/ 0.5 to 2 bpm 380 PSI with good returns. Attempt to get to 3 bpm, packed off at 2.9 bpm. Shut down and Press bled right down.;Waited for 3 min and started pumping at 1 bpm W/ immediate returns. Shut down for 1 min and started pumping at 1.5 bpm W/ immediate returns. At 1.5 bpm 300 PSI.;Stage up to 2 bpm 370 PSI. PJSM for cement job. Halliburton pump 5.5 bbls H2O at .75 bpm, 250 PSI. PT lines W/ 500 PSI low kick out, 5th gear stall 1,300 PSI, PT to 4,000 PSI for 3 min, good. Pump 5.5 bbls 11.2 ppg mud push to Halliburton. Line up W/ rig pumps and pump 24.5 bbls 11.2 ppg Mud Push at;1 bpm 220-240 PSI, 1.5 bpm ICP 330 PSI dropping to 280 PSI, 2 bpm FCP 280 PSI. Line up to Halliburton, pump 10.5 bbls 15.8 ppg (65 sks) 1.154 ft/sk G Neet at 1 bpm 190 PSI, 1.5 bpm 267 PSI, pump 5.5 bbls 11.2 ppg mud push at 1.5 bpm 56 PSI. Rig pumped 68 bbls 10.0 ppg mud at 1.25 bpm;caught Press at 17 bbls away 32 PSI. Saw slight Press increase F/ 60 PSI to 127 PSI falling off to 36 PSI at 27 bbls away. Return flow increased F/ 5% to 9%. Slowly increased rate to 1.7 bpm 62 PSI. At 49 bbls away saw slight Press spike to 320 PSI, Slowly walked pumps down to 0.5 bpm maintaining;80-100 PSI to 66.5 bbls away. Observed Press fall to 21 PSI till pumps off at 68 bbls leaving 2 bbls under displacement. FCP 21 PSI. CIP at 23:30. Verified no flow and well balanced.;PJSM L/D working single F/ 7,795' to 7,769' MD at 5 fpm. P/U 155K. POOH on elevators F/ 7,769' to 7,707' at 5 fpm well slightly swabbing. Stopped swabbing and was static while pulling F/ 7,707' to 7,636'. Fluid stared falling at 7,575' pulling 5 fpm. Cont. pulling on elevators F/ 7,575' to 7,392' MD;with fluid falling on back side. P/U 138K, SLK 94K.;Drop wiper ball and pump down string at 3 bpm staging up to 9 bpm 1,450 PSI. Dumped 23 bbls of looked to be mud push W/ 10.9 PH and 10.8 ppg MW at BU. Cont pumping for Surf to Surf but did not see wiper ball. Monitor well for 10 min, static.;PJSM POOH on elevators W/ 4" D.P. F/ 7,392' to 498' MD. P/U 39K, SLK 39K. No losses.;PJSM M/U X/O to 4" TIW. C/O Elevator inserts F/ 4" to 3.5".;Daily hauled 101 bbls to G&I total = 5,158 bbls Hauled 0 bbls H2O from B-Pad Creek total = 5330 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 130 bbls from 6 mile lake, Total 650 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls 10/18/2019 L/D 3.5" EUE cmt stinger string from 498' to surface. Inspect for residual cmt in string (none noted). B/O and L/D down orange peel shoe, clean same.;C/O handling equipment to 4". Bring tools to rig floor for upcoming BHA run.;PJSM, M/U 6-1/8" Mtr assy. 6-1/8" PDC (Hycalog 513), Sperry Drill mtr w/ 1.5° bend. M/U MWD and scribe same (160/481*360=119.75° RFO), Float sub (Non ported / Plunger), 2x NM Flex DC's, XO, 3x 4" HWDP w/ jars(SLB). Shallow pulse test (test good) 170 gpm, 670 psi. (Total Length BHA = 293.37').;RIH F/ 293' - T/ 7062' MD w/ 6-1/8" mtr assy on 4" HT38 dp out of derrick. Fill every 25 stds.;PJSM Cut 12 wraps 75' drilling line. Accumulated 14,714 ton miles. 2,406' left on reel. Check and adjust air brake gap. Grease Crown, Blocks and Top Drive. Disconnect Spinner Hydraulics due to bad roller bearing. Order parts.;Wait on cement. PJSM SIMOPS Replace Stucci fitting on service loop connection. Check traveling block wobble. Inspect J Box on Top Drive for Hydraulic oil. Un hang Blocks. Calibrate block position sensor. Perform housekeeping. Inspect hydraulic elevators found sensor needing repair.;Install manual elevators.;PJSM RIH 4" D.P. F/ 7,062' to 7,372' MD rabbit pipe F/ Derrick. (2.375" OD) P/U 146K, SLK 94K.;PJSM Obtain parameters. 210 GPM, 1,530 PSI, 20 RPM 7K TRQ, ROT 114K, P/U 146K, SLK 94K. Wash down at 126 GPM, 800 PSI F/ 7,372' to 7,625' MD at 3 ft/min. Saw some cement stringers W/ 200 PSI spikes in Press. Calc. TOC 7,575' MD.;Reciprocate pipe F/ 7,625' to 7,565' MD CBU at 168 gpm, 1,130 PSI, P/U 145K, SLK 97K 35% F/O. During BU had elevated PH 11.5, MW 10.8 ppg. Appeared to have lightly contaminated cement coming across shakers W/ constancy of green cement.;PJSM Wash down F/ 7,625' to 7,704' MD at 168 gpm, 800-850 PSI, 5 ft/min at 7,704' Press jumped to 1,200 PSI and set down 5K 2X. P/U 143K, SLK 99K.;Attempt to drill cement F/ 7,704' to 7,720' MD 200 gpm, 1,600 PSI, 20 RPM, TRQ 7.5 to 8K, 150 ROP. P/U 143K, SLK 99K. Initial WOB 5K tapering off to 2-3K. Stop drilling and discussed further operations W/ town. Decision was made to WOC.;Reciprocate F/ 7,720' to 7,681' MD CBU at 150 GPM, 975 PSI, P/U 145K, SLK 100K. At the shakers saw very firmed up cement cuttings coming over Shakers.;PJSM racked back one stand 4" D.P. to 7,686'. Installed FOV and found slight flow in string. Appeared floats were not holding. Made several attempts to cycle pumps and work string. It had slowed down the flow. Circ. a drill string volume and appeared to help, noticed slight cement at shakers.;Started rotating at 20 RPM, 6.7 to 7.5K TRQ, 180 GPM, 1,200 PSI and saw very firm cement at shakers. Appeared hole was slightly loaded up without rotation. WOC Work around the rig and housekeeping.;Daily hauled 92 bbls to G&I total = 5,250 bbls Hauled 130 bbls H2O from B-Pad Creek total = 5,460 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 0 bbls from 6 mile lake, Total 650 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls Continue POOH F/5523' - T/ Surface. L/D 6-1/8" cleanout assy BHA. 6 ;Attempt to drill cement F/ 7,704' to 7,720' gp j p p MD 200 gpm, 1,600 PSI, 20 RPM, TRQ 7.5 to 8K, 150 ROP. P/U 143K, SLK 99K. Initial W OB 5K tapering off to 2-3K. Stop drilling and discussed pg CIP at 23:30. Verified no flow and well balanced. 10/19/2019 Rot & Rec F/ 7,686' to 7,672' MD. Pump 20 bbl H2O pill to clear floats. Cycle pumps while going through floats. Spot H2O on backside. 150-250 GPM, 920- 1,810 PSI, P/U 145K, SLK 101K, ROT 117K.;PJSM Flood choke and kill lines. Rack back stand to 7,627' MD. Shut Annular and test floats to 500 PSI, good. Bleed and blow down choke.;Wash down F/ 7,627' tag TOC at 7,720' set down 5K 2X. 125 GPM, 700 PSI, P/E 154K, SLK 100K.;PJSM Drill cement F/ 7,720' to 7,727' MD 150 GPM, 1870 PSI, 20 RPM, TRQ 7K, WOB 2-4K. Observed Press increase 870-1,300 PSI stacking WT 8K at Shoe 7,725' MD. Work through Shoe multiple times variating parameters 200 GPM, 1,340 PSI, 80 RPM, TRQ 7K. After multiple passes TRQ and Press;cleaned up slightly. Stared drilling on plug to 7,730' MD.;Slide drill F/ 7,730' to 7,750' MD at 10 FPM, 200 GPM, 1,415 PSI, TRQ 1.8K, WOB 0-7K, P/U 154K, SLK 100K. Packed off at 7,750' working pipe multiple times and unable to establish Circ or ROT. Pulled 25K over SLK 15K to establish rotary W/ out stall at 10K limit. P/U 5K over ROT WT.;Cont. working to shoe with slight flow at .25 bpm. Was able to pull back into shoe without over pull. P/U 154K, SLK 101K, ROT 117K.;PJSM CBU 2X 265 GPM, 2,117 PSI, 50 RPM, TRQ 7.5K, ROT 114K, P/U 154K, SLK 101K. Observed slight fines at shakers.;PJSM Monitor well, static. POOH on elevators F/ 7,680' to 293' MD Pull initial 10 stands no swabbing. Pump dry job, did not work. POOH wet. P/U 154K, SLK 94K, No losses. Rack back jars and HWDP.;PJSM Rack back FC, L/D ILS and Float Sub, down load MWD. Rack back MWD & LWD tools in Derrick. Milk motor and L/D 6 1/8" Bit 0-1-CT-S-E-I-NO-HP.;PJSM Grease Crown, Blocks, Top Drive. Clean and clear rig floor. C/U manual elevators to hydraulic 4".;PJSM Make up Baker 7" CBP Baker K-1 Mech 12.13' to X/O 3.5" IF to HT 38 13.54'. RIH W/ 4" D.P. to 7,630' MD P/U 149K, SLK 95K at 60-80 FPM as per Baker Rep onsite. No losses.;PJSM Set CBP at 7,630' MD. P/U 95K, SLK 150K. Start W/ 10 RPM TRQ set at 7K. Set 12 wraps in string W/ 6.7K TRQ. Set down 5K, P/U 20K over set lower slips. SLK down 20K. Pull over 30K W/ upper slips set. SLK down 30K, Pull 40K, SLK 40K.;Pull 40K over. SLK to 125K ROT at 15 RPM W/ 15 Wraps to pull out of CBP Set at 7,628' top of CBP. Rack Back one stand to 7,593' MD.;PJSM R/U FOV and Head Pin to drill string. R/U test Equip and hose. Flood choke and kill lines working air out. Shut upper rams and test 7" Csg to 3,500 PSI for 30 Min on chart. R/D blow down test equip. Pumped 3.2 bbls, bled back 3.2 bbls.;Daily hauled 114 bbls to G&I total = 5,364 bbls Hauled 130 bbls H2O from B-Pad Creek total = 5,590 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 0 bbls from 6 mile lake, Total 650 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls 10/20/2019 POOH F/ 7593' - T/ surface. Laydown CIBP running tool. Hole took proper displacement.;Clean and clear rig floor. Bring tools to floor and prep for whipstock run.;PJSM, M/U 6.125" window mill, 6" lower mill, flex jt, 6.151" upper mill, XO, 1jt 4" HWDP, XO, Float (non port plunger). M/U Gen II (BOT) whipstock assy (#H15010006). Carry scribe and M/U MWD. 413/468x360=317.69° RFO. 35k lug whipstock, 4 pins anchor=14,260 lb shear. M/U XO, 8jt 4" HWDP.;319.19' Total length for milling assy. 17.63' Total length of whipstock assy w/ anchor. Shallow pulse test (test good).;PJSM RIH W/ 4" D.P. F/ 320' to 7,482' MD. P/U 143K, SLK 96K. Fill every 2,500'.;PJSM Kelly up, pump rate at 250 GPM, 950 PSI, P/U 144K, SLK 94K. Orientate 31° LHS. Wash down and tag at 7,628' MD holding 31° LHS. Set down 15K and shear set Anchor. Pulled 15K over ensure anchor set, slacked back down and tagged 1' higher at 7,627' MD. Putting TOW 7,609' BOW 7,622'.;Work string W/ 10K over pull and 20K down to ensure anchor was set. Set down 38K to shear brass whipstock bolt. No over pull observed. Set and tag top of slide at 7,609' MD.;PJSM Start milling operations as per Baker Rep onsite. 250 GPM, 1,460 PSI, 80-100 RPM, TRQ 7K, F/O 43%, TRQ limit set at 9.5K. Start milling TOW at 7,609' WOB 100-200 lb watching TRQ variate F/ 6.8 - 8.5K W/ intermittent stalls to 7,612' MD 2-3 FPH.;At 7,615' increase RPM to 100 RPM, WOB 1K, ROP 2-3 FPH. TRQ 3- 9.1K. F/ 7,620 to 7,626' 100 RPM, WOB 1-2K, 2-3 FPH TRQ smoothing out 6.9 - 8K. At 7,626' to 7,631' TRQ 8K WOB 3-4K. F/ 7,631' to 7,638' WOB 4-7K, TRQ 7K full gauge upper mill passing out of BOW, no issue.;F/ 7,638' to 7,645' 100 RPM, 250 GPM, 1,450 PSI, TRQ 7K, WOB 8K. ROT off bottom F/ 7,645' to 7,606' W/ 1-2K drag. Shut down rotary and worked string down W/ 1K drag to 7,645'. Work string up saw 10K bobble at 7,626'. Turned pumps off and worked mills through window SLK 98K, P/U 158K.;saw 5K bobble at 7,624'. Dressed up area F/ 7,621' to 7,628' W/ 200 GPM, 1,080 PSI, 100 RPM, TRQ 6.6 -7K ROT 114K, SLK 110K. Worked string down no pumps no rotary F/ 7,594. to 7,642' with no drag. Pulled up with 1K drag and no sign of bobble at 7,624'. TOW 7,609’ BOW 7,622’ MD Recovered 90# Metal.;Drilled new formation F/ 7622' - T/ 7645' (23').;Daily hauled 57 bbls to G&I total = 5,421 bbls Hauled 130 bbls H2O from B-Pad Creek total = 5,590 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 130 bbls from 6 mile lake, Total 780 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls Daily Metal 90#, Total 90#. 10/21/2019 PJSM, Circulate and condition 1.5x btms up Rot/Recip @ 7590'-7527' MD. 250 gpm, 1450 psi, 20 rpm, 6.5k tq. Pump 45 bbls 10.1 ppg / 300 vis sweep - On time w/ 200% increase.;B/D TDS. Perform 12 ppg EMW (FIT). R/U head pin w/ test equipment. Flood choke and kill lines. Shut upper pipe rams. Pump rate .7 bpm. Psi up to 700 psi (3/4 bbl pumped). Bled off 45 psi over 10 min (Good test). 3/4 bbl bled back. R/D test equipment. Chart and record same.;Monitor well (Static). POOH F/ 7590' - T/ 7276' MD. Pulled wet (good displacement). Pump dry job and B/D TDS.;Service rig - Grease traveling equipment, wash pipe, IBOP's, Drawworks and Iron Roughneck. Check oil inTDS (Good). Inspect "J" box on TDS (good).;Continue POOH F/ 7276' to surface. Racked back all 4" dp. B/O and L/D excess HWDP along with milling assy. Starter mill 1/16" under, Upper mill full gauge. Hole took proper displacement.;PJSM, M/U 6.125" HDBS MM55 5 blade PDC (.3835 TFA), 1.5° mtr (5/6-8.3 stg - Non Ported float), MWD, Float (non ported plunger), 2x NM Flex, XO, 2x HWDP, Jars, 1x HWDP. Total length BHA = 293.03' MD. Pump thru MWD to warm tool / Download.;Shallow hole test MWD 250 GPM, 830 PSI. Good detection.;PJSM RIH BHA #8 W/ 4" D.P. Ht 38 F/ 293' to 7,438' MD. P/U 144K, SLK 92K Filling every 2,500'. No losses.;PJSM Grease Crown, Remove Desiccant packs F/ J Box and seal up W/ silicone and duct tape.;PJSM Drain RCD, remove trip riser and install RCD bearing as per Beyond Rep onsite. Fill lines and and check for leaks, good. Monitor well, static.;PJSM Wash down F/ 7,438' to 7,595' MD 250 GPM, 1,925 PSI. P/U 148K, SLK 89K. Calibrate MPD Choke to rig watch. Simulate connections W/ rig crew and MPD to ensure good communication and understanding of operation. MPD holding 560 PSI W/ pumps off and 160 PSI W/ pumps on at 250 GPM, 1,925 PSI.;Orientate tool face 30° LHS W/ MPD holding 160 PSI for 11.5 ppg EMW.;SPR at 7,595' W/ MPD 11.5 ppg EMW. MP #1 32- 617 PSI, 48- 837 PSI MPD 283 PSI. MP #2 32- 604 PSI, 48- 824 PSI MPD 276 PSI.;With MPD holding 160 PSI EMW 11.5 ppg pumps off. Attempt to go through window W/ 30° LHS P/U 153K, SLK 86K tagged up 3X setting down 5K at 7,614' MD. Bled off MPD to zero and checked tools face. Attempted again adjusting tool face F/ 25° to 35° LHS 4X setting down 7-10K at 7,614' MD.;Tried rocking string 3X setting down 6K at 7,614' MD. Oriented 155° ROHS and was able to pass through window clean to 7,624' MD.;Wash down F/ 7,624' to 7,640' MD 174 GPM, 1,140 PSI. After MWD surveys showed inconclusive data as far as hole orientation. Discussion was made W/ town to drill head to determine well geometry. Slide drill to 7,644' MD. 250 GPM, 2,278 PSI.;Daily hauled 0 bbls to G&I total = 5,421 bbls Hauled 0 bbls H2O from B-Pad Creek total = 5,590 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 130 bbls from 6 mile lake, Total 910 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls Daily Metal 55#, Total 165# gp of slide at 7,609' MD.;PJSfM Start milling operations as per Baker Rep onsite. 250 GPM, 1,460 PSI,pp gp gp 80-100 RPM, TRQ 7K, F/O 43%, TRQ limit set at 9.5K. Start milling TOW at 7,609' WOB 100-200 pp . M/U Gen II (BOT) p whipstock assy (#H15010006). Carry scribe and M/U MWD. 10/22/2019 QC survey package and baseline. Original svy @ 7551' , 46.43° Inc / New svy @ 7551' showed .4 lower. Interpolate svy @ btm of slide @ 7622' (50.79° Inc - .4° variance = 49.68°). Drill ahead in new hole sliding 70° LOHS, 250 gpm, 2150 psi, 1-2k WOB, control drilling 50 fph F/ 7645' - T/ 7667' MD.;P/U to 7665' and obtain survey. Survey depth @ 7622' showed 47.55° Inc. Inclination indicates we exited lower side of casing with milling assy. 2.13° drop from interpolated svy @ 7622' (base of whipstock). Sperry MWD (David Booth) verified tool configuration was correct from whipstock run.;Discuss plan forward with drilling engineer. Continue drilling ahead gaining separation.;Cont Sliding from 7667' to 7763' MD, 260 GPM, 1250 PSI, 40 rpm, TQ 7.5k, WOB 2- 10K, PUW 154K, SOW 89K, Rot 107K, holding 160 psi back pressure w/MPD f/11.5 PPG MW.;Encountered multiple pack offs between 7710'-7733'. Packed off and stalled out @ 7633'-7625'. Work and free pipe with 20K over pull. All issues occurred while sliding.;Work pipe and CBU while holding 170 psi back pressure. 260 GPM, 2210 PSI, 60 RPM, Tq 7.2K, PUW 154K, SOW 89K Rot 107K. Hole unloaded Shales and fines at Btm Up.;Drill from 7763' to 7860' Feather into ROP while sliding starting @ 10 fph staging to 50 fph Max ROP. slight pack offs at 1st but cleaned up. Rotate out slides starting @ 15 fph staging up 75 fph Max ROP. Obtained optimal Control Drilling parameters @ 50 FPH ROP Sliding and 75 FPH ROP Rotating.;PJSM Slide & Rot 6.125" Production Hole F/ 7,680' to 8,001' MD ( 6,920' TVD) total 321' (AROP 53.5') 260 GPM, 2,340 PSI, 60 RPM, TRQ 7.5K, WOB 2-6K. P/U 149K, SLK 85K, ROT 109K. Max Gas 947U. MPD 100 PSI pumps on,pumps off 560 PSI 11.5 ppg EMW W/ 10.1 ppg MW.;Rotary drill 75 fpf max, slide drill 35 fph max. Set TRQ limit 10.9K, Press limit 2,600 PSI. Keeping close eye in Diff Press around 50-180PSI. Feather WOB. Saw slight Press spikes but not packing off. At 7,468' MD saw max Gas 485U at BU.;Perform check shots for MWD at 7,936'.;PJSM Slide & Rot 6.125" Production Hole F/ 8,001' to 8,078' MD ( 6,949' TVD) total 77' (AROP 14') 260 GPM, 2,340 PSI, 60 RPM, TRQ 7.5K, WOB 2-6K. P/U 154K, SLK 85K, ROT 107K. Max Gas 114U. MPD 100 PSI pumps on,pumps off 560 PSI 11.5 ppg EMW W/ 10.1.ppg MW.;Rotary drill 75 fpf max, slide drill 35 fph max. Encountering torque and hard spots while drilling ahead. Perform check shots for MWD at 7,998' & 8,061' MD.;Sliding 20-21 ft to 7874’. Motor output 15.38° per 100/ft. Doglegs on surveys about 4.8°.Cut back to 14-15 slides. Motor output 13.98° per 100/ft. Dogleg dropped to 3.75° by 7950’. We are ahead about 1.5° dogleg to land at 8510’ MD. Plan called for 3.59° but builds above reduced the dogleg required.;Sliding cut back to 10ft slides to come in closer to plan at 8510’. Distance to WP07 9.29', 7,47' High, 5.51' Left.;While drilling ahead W/ rotary at 8,078' encountered pack off and stall . Working drill string F/ 8,078' to 8,074' unable to rotate and Circ. Cycling pump Press up to 2,000 PSI and trapping 10.5K TRQ working string W/ 10-30K overpull. MPD holding ~500 PSI back Press.;Daily hauled 171 bbls to G&I total = 5,592 bbls Hauled 0 bbls H2O from B-Pad Creek total = 5,590 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 130 bbls from 6 mile lake, Total 1,040 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls Daily Metal 75#, Total 240# 10/23/2019 Continue attempt to free pipe and gain circulation. Work pipe from 8078' to 8074'. Unable to establish rotation or circulation. Attempt multiple methods to free pipe before jarring.;Begin jarring on string Staging up from 184k (30k over) to 250k( 95k over). Hold pressure on back side with MPD periodically, and 2350 psi on drill string periodically. Jars hitting good but no pipe movement. Mobilize BOT fishing and AK E-line for back off ops.;Discuss options. Due to tool joint 25' above rotary, perform a blind back off on the 3 1/2" IF connection below the HT-38 Jars. Using 10K target range, start with 2 LH Wrap @ 4K working Tq down. Work up to 7 wraps and 8K Tq down string and see back off. PU and establish rotation and circulation.;Rack back 1 stand to 8064'. Rotate 100 rpm, 12 bpm, 2360 psi, 6.2k Tq, PUW 150, SOW 80k, Rot 1.3k, pumping 20 bbls 10.1 ppg, 240 vis sweep around.;No substantial change in return cuttings on entire circulation. Sweep back on time with no substantial change. No running shales ect. Hole appeared to be clean prior to sticking.;POOH from 8001' to 7,500', checking every connection for proper TQ. Pulled clean through window.;PJSM Remove RCD Bearing and strip off stand. Install trip nipple. Monitor well, static.;PJSM Inspect Derrick crown to ground after jarring operations. Everything looked good. Service rig. Grease Crown, Blocks and Top Drive.;PJSM Cont. POOH F/ 7,500' to backed off 4" HT 38 D.P. Left 3 Jnts 4" D.P. and BHA #8 estimated (386.71') TOF at ~7,691' MD. Checking TRQ every connection. All tight. Correct Disp.;PJSM P/U M/U Fishing BHA HT 38 cut lip sub, Circ Sub (Rupture 2,800 PSI) 6 ea 4 3/4" DC, 4 3/4" Cobalt Energizer and X/O Sub (200.3') as per Baker Rep onsite. Drift 4 3/4" DC W/ 1.95" OD Drift.;PJSM RIH W/ 4" D.P. F/ 200' to 7,534' MD. Correct Disp.P/U 154K, SLK 98K.;CBU washing down F/ 7,534' to 7,598' MD 320 GPM, 1,350 PSI, 20 RPM, TRQ 7.4K. F/O 47%. P/U 145K, SLK 98, ROT 111K No Gas seen at surface and shakers clean.;RIH W/O pumps F/ 7,598' to 7,660' MD Start pumping at 1 bPM, 350 PSI, Tag TOF at 7,692' P/U 145, SLK 98. Check space out for running ELine, good.;Put 10.5K TRQ in string and work TRQ down to engage fish W/ HT 38 cut lip as per Baker Rep onsite. P/U 20K over to ensure fish on. Release TRQ out of string.;Set down 10-15K down and pulled over 50-60K to try and fire Jars. Jars would not fire. Work string setting down 43K ( 55K) and over pulling 40 to 80K over (194K to 234K) to get jars to fire. Jarring W/ 30K (59K) down and pulling;F/ 80 to 100K (234K to 255K) over W/ and W/O pump Press 600 PSI to 1,000 PSI several times. Intermittently straight pulling 146K over (300K) with no movement. Blow down Top Drive. Perform Derrick inspection.;Daily hauled 57 bbls to G&I total = 5,649 bbls Hauled 0 bbls H2O from B-Pad Creek total = 5,590 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 130 bbls from 6 mile lake, Total 1,170 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls Daily Metal 0, Total 240# leave BHA fish unable to rotate and yp ggg Work up to 7 wraps and 8K Tq down string and see back off. PU and establish rotation and circulation.;Ra gg q g Left.;While drilling ahead W/ rotary at 8,078' encountered pack off and stall jgp yg gg Left 3 Jnts 4" D.P. and BHA #8 estimated (386.71') TOF at 10/24/2019 Jarring W/ 30K (59K) down and pulling F/ 80 to 100K (234K to 255K) over W/ and W/O pump Press 600 PSI to 1,000 PSI several times. Intermittently straight pulling 188K over (322K) with no movement.;Blow down Top Drive. Perform Derrick inspection. Inspect welds on Cradle and Derrick, good.;PJSM Spot Pollard Eline unit and P/U tools and Equip to rig floor.;Work 6K left hand torque in drill string. (5.25 Wraps) Lock rotary table and set slips. L/D 4" single. R/U Eline sheave in elevators. M/U ELine head, CCL and String Shot W 560 Grain 7 strands. 1.5' to middle pack off.;PJSM RIH W/ String Shot and locate collars. space out and fire string shot at 7,910' and bottom at 7,913' WLM in between 4 3/4" NM FC in the BHA. POOH verify string shot went off. P/U M/U Single Jnt 4" D.P. P/U string W/ top drive brake on 3.5K TRQ on string. SLK 97K.;Put 1 wrap left handed in string to 6K TRQ. P/U drill string free of TRQ. P/U 140K, SLK 97K. Original up weight 154K lost 14K string weight.;Unsure where string backed out. Set TRQ limiter to 10K and rotate working down torque into string W 10K down and 10K over pull. Let out trapped trq. P/U 185K and set down in slips W/ 31K in tension. L/D single and blow down top drive.;PJSM R/U Pollard ELine tools and Equip. RIH W/ 1.75" Drill Collar Severing Tool. Fire shot at 7,879' WLM at collar between the 2 jnts 4" HWDP. Leaving 1 Jnt 4" HWDP, Jars, 1 4" HWDP and 3 Jnts 4" D.P. to fish. String did not jump at surface. POOH W/ Eline, Tool did fire. R/D tools and Equip.;PJSM Work string trying to get jars to fire. Work string W/ 30K (59K) down and pulling F/ 80 to 171K (234K to 326K) over W/ and W/O pump Press 600 PSI to 1,500 PSI several times. During attempts was as able to get 4 bpm Circ but packed off when adjusted to 6 bpm. Was able to stage up to 3 bpm.;490 PSI for 208 bbls almost 1.5 BU. Max Gas 371U. Lost Circ. during working string trying to get jars to fire. Worked 11K TRQ in string W/ 1,500 PSI working string to try establish Circ. unable. Decission was made to attempt to back off between D.P. above Jars. Blow down top drive. M/U 5' Pup;below working single.;PJSM Work 6K left hand torque in string W/ 5.25 wraps working string F/ 80K to 140K. Set string in compression W/ 21K in slips. Break out top drive and L/D single.;PJSM R/U ELine sheave and tools. RIH W/ CCl and 3’ String Shot 2' F/ CCL to center of String Shot (560 Grain 7 strands) 175 ft/min. Made 3 passes at 40 ft/min. correlation correction 2.5’. Set string shot at 7,754’ WLM at tool joint. In between 2nd and 3rd Jnt of 4” D.P. above BHA.;No visual indication on rig floor. Saw line jump in unit. POOH W/ ELine. Visual at surface String Shot fired.;P/U M/U Single Jnt 4" D.P. P/U string W/ top drive brake on 6K TRQ on string P/U 165K, SLK 110K. Put .25 wrap left handed in string to 6K TRQ. Work TRQ down W/ 80K down and 150K up. Put another .75 wraps for a total of 6 wraps P/U lost 2.2K TRQ and string weight 121K, SLK 89K.;Original up weight 154K lost 33K string weight. Unsure where string backed out.;Set TRQ limiter to 10.5K and rotate 15 RPM 5.1K TRQ, working down torque into string W 10K down and 10K over pull. Let out trapped trq. P/U 30K over and SLK 30K. Work 6K left hand torque in string W/ 6 wraps working string F/ 80K to 125K.;Set string in compression W/ 21K in slips due to tool joint placement. Break out top drive and L/D single. Blow down Top Drive.;PJSM M/U Sheave and Eline in elevators. Pollard redress their head and M/U string shot. SIMOPS Perform monthly inspection on MP #2 and agitator.;Daily hauled 0 bbls to G&I total = 5,649 bbls Hauled 0 bbls H2O from B-Pad Creek total = 5,590 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 0 bbls Hauled 0 bbls from 6 mile lake, Total 1,170 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls Daily Metal 0, Total 240# 10/25/2019 RIH W/ CCl and 2’ String Shot 2' F/ CCL to center of String Shot (560 Grain 7 strands) 175 ft/min. Made 2 passes at 75 & 40 ft/min. no correlation correction. Set string shot at 7692’ WLM at crew in sub. No visual indication on rig floor. Saw line jump in unit. POOH W/ ELine.;Visual at surface String Shot fired.;P/U M/U Single Jnt 4" D.P. P/U string W/ top drive brake on 6K TRQ on string P/U 165K, SLK 110K. Put 1 wrap left handed in string to 6K TRQ. Work TRQ down W/ 80K down and 140K up. Will working TRQ down P/U lost 3K TRQ and string weight 119K, SLK 89K.;Original up weight 154K lost 35K string weight. Unsure where string backed out. Set TRQ limiter to 11.1K and rotate 15 RPM 5.1K TRQ, working down torque into string W 10K down and 10K over pull. Let out trapped trq. P/U 30K over and SLK 30K.;Trap 5K right hand TRQ in string W/ 10K in slips. Break out single and L/D. Blow down Top Drive. R/U Pollard sheave and tools. RIH W/ 1.75" Drill Collar Severing Tool to 7,698' MD 6' below screw in sub. POOH. Tool fired.;M/U single. P/U W/ 30K over pull. Attempted to Circ. at 0.5 bpm packed off W/ 500 PSI. Set TRQ to 12K and work TRQ down. Pipe free at 7,698' W/ 20K over pull and saw 100K of drag for 40' (7,658' MD). Press dropped on drill string and started pumping at 4 bpm, 750 PSI. P/U 154K, SLK 98K.;POOH F/ 7,638' to 7,590' MD No issue going through window. (BOW 7,622' TOW 7,609') P/U 154K, SLK 98K.;CBU at 7,590' MD. 12 bpm, 2,370 PSI, P/U 136K, SLK 88K. Nothing seen at shakers.;PJSM Blow down top drive. Slip and cut 82' 13 wraps. Accum TM 14,714. 2,406' on reel. Check brake gaps. Inspect and Grease Crown, Top Drive and check oil level.;PJSM POOH W/ 4" D.P. F/ 7,590' to 200' MD. No losses.;PJSM L/D fishing BHA as per Baker Rep onsite. Cut 4" D.P. length 6', widest flare on cut 4.5". Circ Sub was sheared and was unable to back out screw in sub from cut joint.;PJSM P/U 4" test jnt and pull Wear Bushing. Install test plug. M/U to 4" test jnt Side entry, 4" TIW, Dart, and test sub to top drive. Flood lines. Attempted to drain stack and had issue W/ annular valves. Had to Circ out mud W/ H2O.;PJSM Perform BOPE test W/ 3.5" & 4" to 250 PSI low and 3,500 PSI high for 5 Min. Tested Choke Manifold 1-15, 5" Dart, 5" TIW, Upper and lower IBOP, Mez Kill, HCR and manual Choke and Kill, manual and Super Choke, Upper and lower VRB Rams (2,875" X 5.5") Blind Rams, Annular W/ 3.5" test Jnt.;Koomey draw drown Initial System 3,000 PSI, Manifold 1,500 PSI, Annular 1,425 PSI, after System 1,575 PSI, Man 1,575 PSI, Annular 1,400 PSI. 200 PSI increase 24 Sec, full charge 80 sec. Nitrogen 6 bottle average 2,400 PSI. Test H2S 10-20 ppm, LEL 20- 40%, PVT high/ low level alarms.;Witnessed waived by AOGCC Rep Jeff Jones.;Daily hauled 622 bbls to G&I total = 6,271 bbls Hauled 0 bbls H2O from B-Pad Creek total = 5,590 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 0 bbls Hauled 0 bbls from 6 mile lake, Total 1,170 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls Daily Metal 0, Total 240# 10/26/2019 Cont. R/D test Equip. Pull test plug. Blow down Choke and Kill lines.;Service rig. Grease top drive and inspect Drawworks. Check oil in top drive. Perform weekly inspection on Iron Roughneck.;Inspect upper annular valve for blockage. May have minor debris. Set wear ring and RILDS. L/D test joint.;P/U M/U Baker 7" K-1 Cast Iron Cement Retainer 12.47' as per Baker Rep onsite.;RIh W/ CIBP W/ 4" D.P. F/ 13' to 7,524' MD 60-90 ft/min as per Baker. P/U 77K, SLK 68K. Checking TRQ in each connection, good. No losses.;P/U working single to space out at 7,554' MD. Set CICR as per Baler Rep onsite. P/U 143K, SLK 98K, ROT 117K. 15 RPM, TRQ 7K. Attempt to establish injection rate at 0.5 bpm Press. climbed to 1,000 PSI. Shut down and L/D Single.;PJSM for cement job. Halliburton pumped 5 bbls H2O at 2 bpm 475 psi, Low Pres test 1,108 PSI, high 2,508 PSI. Rig pumped 13.8 BBLS 11 PPG CLEAN SPACER at 4 BPM 650 PSI, HAL pumped 15 BBLS 15.8 PPG G Premium 75 SKS 1.154 Y, 4.974 GPS @ 3 BPM 820 PSI, 5 BBLS H2O at 3 BPM 100 PSI.;Rig pump 6.2 BBLS OF Clean Spacer at 3 BPM 60 PSI, pump 60 BBLS 10.1 PPG mud at 6 BPM 720 PSI FCP 690 PSI. CIP at 18:25. Calc. TOC 7,161' MD.;PJSM R/D cement lines. L/D working single, POOH on elevators at 20 fpm F/ 7,535' to 6,971' MD.;Drop wiper ball and Circ. at 9 bpm, 900 PSI for 2X BU. Dumped 8 bbls of interface Mud Push at BU. Blow Down top drive.;WOC to achieve 500 PSI in 5.5 Hrs. SIMOPS R/U and flush annular valve W/ charge pumps clearing debris out. PM Tuggers, Catwalk wench and Iron Roughneck. Clean drip pan.;PJSM M/U Test Equip. Fluid pack lines and purge air from system.;PJSM Test 7" Csg and cement plug at TOC 7,161'Press up to 1,500 PSI for 30 min on chart. Pumped 1.45 bbls, bled back 1.45 bbls. R/D test Equip. Blow down lines.;PJSM Displace 10.0 ppg mud W/ 25 bbls 11.0 ppg 235 Vis sweep and 235 bbls 8.5 ppg Seawater taking return overboard at 336 GPM, ICP 1,500 PSI FCP 950 PSI. P/U 139K, SLK 96K. Monitor well for 10 min, static.;PJSM POOH laying down 4" D.P. F/ 6,971' to 4,900' MD. P/U 105K, SLK 84K, Calc Disp.;Daily hauled 171 bbls to G&I total = 6,442 bbls Hauled 0 bbls H2O from B-Pad Creek total = 5,590 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 0 bbls Hauled 0 bbls from 6 mile lake, Total 1,170 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls Daily Metal 0, Total 240# p . Set CICR as per Baler Rep onsite. gg g p p M Test 7" Csg and cement plug at TOC 7,161'Press up to 1,500 PSI for 30 min on chart. P g F/ 13' to 7,524' MD ppp gg HAL pumped 15 BBLS 15.8 PPG G Premium 75 SKS 1.154 Y, 4.974 GPS @ 3 yp g p Baker 7" K-1 Cast Iron Cement Retainer 12.47' 10/27/2019 Cont L/D 4" D.P. F/ 4,900' to 1,175' MD. P/U 52K, SLK 49K.;RIH 4" F/ Derrick F/ 1,175' to 3,965' MD. P/U 86K, SLK 74K.;POOH L/D 4" D.P. F/ 3,965' to K- 1 running Assy. L/D running Assy as per Baker Rep onsite.;P/U 5" jnt and pull wear ring. P/U 3.5" EUE jnt and dummy run tubing hanger. Swapped out hanger to new hanger due to questionable threads on original. Ensure hanger seated in well head properly as per NOS onsite.;PJSM P/U R/U Weatherford Power Tongs, slips, 3.5" elevators and prep Pipe Shed for running 3.5" Kill String.;PJSM RIH 3.5" 9.3# L-80 8rd EUE Tubing to 2,478' MD. P/U 52K, SLK 50K. P/U M/U Hanger and install control line plugs, dummy penetrator and TWC. Drain Stack and land Hanger 16K landed weight. NOS verified Hanger landed RILDS. 3.5" Kill String at 2,507' MD. L/D 3.5" Landing Jnt.;PJSM L/D Weatherford tools and Equip. Use soap and H2O to flush surface lines, Kelly Hose, Choke Manifold and Kill line. Blow down all lines. SIMOPS Clean Pits, start moving mud products and misc to F Pad.;PJSM Remove Mouse Hole, clean flow box and remove MPD hard lines. Pull Riser and install RCD cap.;PJSM Drain stack and remove Kill and Choke lines. Remove drip pan and hoses. N/D BOPE and set on pedestal. Remove MPD and DSA F/ cellar. SIMOPS Cont. Pit cleaning. Rebuild pop off on MP #2. Lay matt boards and herculite on F-116.;PJSM Install dry hole try. Test Tree. Freeze Protect Well.;Daily hauled 788 bbls to G&I total = 7,230 bbls Hauled 0 bbls H2O from B-Pad Creek total = 5,590 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 0 bbls Hauled 130 bbls from 6 mile lake, Total 1,300 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls Daily Metal 0, Total 240# Activity DateO Ops Summary 4/16/2020 PJSM Blow down H2O & steam. Disconnect interconnects. Remove cutting box. Swap to cold start @ 08:30. Peak truck on location @ 10:00. Install Jeep on Gen Mod. Jack up Pipe Shed, Mud Mod, Gen Mod and Cattle Chute. Stage on S Pad. Walk Sub off S-56. Spin 90° & install rear tires. Remove rear tow bar. Install front tow bar. Move Gen and Mud Mod to K Pad. Haul Mat boards to K Pad.,PJSM Move Sub, Catwalk and Pipe Shed to K Pad. SIMOPS P/U Herculite and clean up around S-56.,PJSM Spot MPD Head and Well Tree in cellar area. Spot Sub over K-44B. Spot Pipe Skate and Pipe Shed. Set Mats for Mud & Gen Mod.,PJSM Spot Gen & Mud Mod. Set outriggers on Sub. Start rigging up lines and inner connects. Stage Office camp, Break Shack, Enviro Vac and Peak Shop. Reassemble MP'S. Steam whip in cellar box to thaw. Swap to Gen power at 05:00. R/U safe out stairs, rooftops and landings.,Daily fluid hauled to G&I 301 bbls total = 301 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 0 bbls total = 0 bbls Daily Fluid lost 0 bbls total production = 0 bbls 4/17/2020 PJSM Scope up Derrick, bridle down. Cont assemble MP's. Work on rig acceptance checklist. Welder work on Top Drive fixing crack on ceadle body. Weld hole and cracks in cutting Box. Replace Ethernet switches on every Mod. C/O pipe spinners in Iron Roughneck (FH-80). Cont bring misc loads F/ S Pad.,PJSM N/D Tree as per NOS rep onsite. SIMOPS Cont. welding around rig. Move H2O around all Pits.,PJSM Remove Bell Nipple Prep and install bolts for MPD head. INstall 11" X 13 5.8" DSA. Remove companion flanges ogg Choke and Kill lines. Remove bolts F/ spacer spool on bottom of BOP Stack. SIMOPS Set MPD Choke House. Cont welding on Top Drive cradle. C/O Ethernet switches due to inference with the Drawworks.. Spot cutting box. Cont working on rig acceptance.,Rig accepted at 18:00. PJSM Set BOP Stack on DSA/ Wellhead. Trq bolts. R/U Choke and Kill lines. Install companion flanges on IA and OA. Set MPD head on Stack. Open MPD clamp and remove plug. Attach chain binders to Stack and disconnect Bridge Cranes. Hook up Koomey lines and energize.,SIMOPS Bring on 580 bbls 9.5 ppg LSND Mud. Cont work on rig acceptance. Load 5" D.P. in Pipe Shed. Remove Master Bushing & install split. Bring up 4" handling Equip to rig floor. No internet on rig.,PJSM C/O lower rams to 7" and replace rubber for blind rams. SIMOPS Cont load and process 5" D.P.,Daily fluid hauled to G&I 0 bbls total = 301 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 650 bbls total = 650 bbls Daily Fluid lost 0 bbls total production = 0 bbls 4/18/2020 PJSM C/O stud bolts on MPD head due to being to long. Install Drip Pan and drain hoses. Install 4" MPD hard lines and trip tank lines. SIMOPS Cont load and process 5" D.P.,PJSM Install MPD test plug. Finish hooking up MPD lines. Flood Stack through choke and attempt to test MPD head. Found leak on MPD flange, re tighten. Test to 300 PSI 5 min, 1,200 PSI 5 min, good. Remove test plug and install modified riser. SIMOPS Cont processing D.P.,PJSM P/U 5" test donut and mark out where Annular and Upper rams sit. M/U 5" Dart. 2 ea 5" FOSV & side entry sub. L/D P/U 3.5" test Jnt M/U 4" Dart, 4" FOSV & side entry sub. Mark Annular and upper rams sit. L/D. Trq Top Drive test sub. P/U 5" test Jnt and flood lines. Shell test to 2,500 PSI, good.,PJSM Perform BOPE test W/ 3.5" & 5" to 250 PSI low and 3,500 PSI high for 5 Min. Tested Choke Manifold 1-15, 5" Dart, 2 ea 5" TIW, Upper and lower IBOP, Mez Kill, HCR and manual Choke and Kill, manual and Super Choke to 2,500 PSI, Upper VRB Rams (2,875" X 5.5") F/P Blind Rams, Annular W/ 3.5" test Jnt. Koomey draw drown Initial System 3,000 PSI, Manifold 1,400 PSI, Annular 1,475 PSI, after.,System 1,150 PSI, Man 1,450 PSI, Annular 1,425 200 PSI increase 28 Sec, full charge 106 sec. Nitrogen 6 bottle average 2,333 PSI. Test H2S 10-20 ppm, LEL 20-40%, PVT high/ low level alarms. Witnessed waived by AOGCC Rep Guy Cook.,PJSM Break down test Jnts and R/D testing Equip.,PJSM NOS rep onsite pull CTS and remove BPV.,PJSM P/U M/U 3.5" 8 rd EUE landing Jnt to Hanger. M/U X/O, Head Pin and HP hose to stand pipe manifold. NOS BOLDS. Unseat Hanger st 69K, P/U 55K. Stage up pumps to 10 bpm ICP 400 PSI FCP 560 PSI. Displace 92 bbls Diesel W/ 140 bbls fresh water.,PJSM Pull Hanger to rig floor, L/D. L/D 3.5" landing joint and Circ Equip.,PJSM R/U Weatherford Tongs and 3.5" Equip. POOH L/D 3.5" kill string F/ 2,478'to surface.,PJSM L/D Weatherford tongs and 3.5" handling Equip.,PJSM Install mouse hole. Drain Stack. P/U 7" Test jnt and set test plug. R/U testing Equip. Fill Stack and purge air. Unable to keep test joint full. Pull landing joint leaving test plug and check height, good. Run test Jnt and make it to test plug. Function 7" lower rams. Fill lines still not holding. Pull landing Jnt and test plug. Drain Stack. Inspect test plug.,Daily fluid hauled to G&I 57 bbls total = 358 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 190 bbls total = 840 bbls Daily Fluid lost 0 bbls total production = 0 bbls n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: MP K-44A Milne Point Hilcorp Energy Company Composite Report , AK Contractor AFE #: AFE $: Job Name: Spud Date: g() g Remove Bell Nipple Prep and install bolts for MPD head. gp ,Rig accepted at 18:00. PJSM y M Perform BOPE test W/ Spot Sub over K-44B. BOPE t test 4/19/2020 PJSM NOS rep onsite. Cont press up and seat test plug due to well head not being level. Purge air out of line. Test 7" lower rams to 250 PSI low and 3,500 PSI high 5 min ea. on chart.,PJSM Use blocks to pull test plug. Set Wear Ring as per NOS rep onsite. (11" ID) C/O Elevators to 4". Swap to Gen power at 07:30 due to production operation issues.,PJSM P/U M/U Baker Multi String Cutter, 6.125" Stab and X/O as per Baker rep onsite. Single in hole W/ 4" D.P. HT38 to 5,461' MD. P/U 107K SLK 87K. (Drift 2.35" OD).,PJSM Attempt to locate 7" collar around 5,461' MD. No indication of collar found. Set at 5,480' MD. Break Cric 4.5 bpm 800 PSI 60 RPM, TRQ 4.3K. P/U 107K, SLK 87, ROT 97. Start cutting 7" Csg after 6 min saw Press drop to 650 PSI and TRQ bobble. Press Cont to drop to 300 PSI W/ communication to OA. CBU at same rate. Monitor well for 10 min, static.,PJSM POOH rack back 4" D.P. F/ 5,480' and L/D Baker Multi String Cutter assy as per Baker rep onsite.,PJSM M/U Wear Ring puller BOLDS and pull Wear Ring as per NOS onsite.,PJSM C/O 5" elevators to 7" side door elevators.,PJSM Install 7" X 4.5" IF X/O and head pin on 7" landing Jnt. M/U Pack Off running tool. Pull Pack Off as per NOS Rep onsite. Remove running tool and M/U landing Jnt to 7" Hanger. Install swing, LoTrq and HP line to landing jnt. Saw slight out of balance W/ flow coming F/ top of 7" Csg.,PJSM Break Circ at 4 bpm ICP 280 PSI W/ fresh water taking returns down drag chain to the cutting box. Stage up to 7 bpm FCP 60 PSI. Pumped and dumped total of 365 bbls. Saw about 100 bbls of Diesel and rotten mud at surface. Circ til 8.4 ppg was in and out. Monitor well for 10 min, static.,PJSM Pull landing Jnt and Hanger free at 142K with no over pull. Pull landing Jnt and Hanger to rig floor. P/U 146K SLK 127K L/D as per NOS rep onsite. Start POOH L/D 7" Csg to pipe shed using Weatherford tongs F/ 5,440' to 3,500' MD. (46 Jnts). No losses.,PJSM Cont POOH L/D to pipe shed 7" Csg F/ 3,500' to cut Jnt (18.94') Total Jnts laid down including cut Jnt 136. No losses.,PJSM R/D Weatherford tongs and Equip. C/O Elevators to 5" Hydraulic elevators. Stage Baker CIBP and tools on rig floor.,PJSM C/O HT38 Saver Sub to NC50 Saver Sub on Top Drive. Internet is still out on the rig.,Daily fluid hauled to G&I 275 bbls total = 633 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 600 bbls total = 1,440 bbls Daily Fluid lost 0 bbls total production = 0 bbls 4/20/2020 PJSM Cont C/O HT38 to NC50 Saver Sub on Top Drive. C/O Grabber dies and bell guide. Clean and clear rig floor.,PJSM Service rig. Grease Crown, Top Drive, Blocks, Drawworks, Spinners, Cobra Heads and Iron Roughneck. Check oil in Top Drive. Swap to High Line power@ 07:30.,PJSM Drain Stack and install long wear ring. (Lgth 26" 10" ID) as per NOS onsite. RILDS.,PJSM P/U M/U Baker N-1 CIBP assy 12.25' Single in hole W/ 5" HWDP to 510' MD at 90 ft/min. No losses. P/U 57K SLK 57K.,Cont RIH W/ singles 5" NC50 D.P. F/ 510' to 5,455' MD at 90 ft/min. P/U 155K SLK 127K. Putting 1 turn to left every 1,000' as per Baker Rep. No losses.,PJSM Set CIBP as per Baker Rep on site. Top of plug @ 5,455' MD. P/U 155K SLK 127K ROT 139K.,PJSM Displace fresh water to 9.5 ppg LSND Mud. Pump 50 bbls 175 Vis sweep and 489 bbld 9.5 ppg LSND at 12 bpm ICP 250 PSI FCP 575 PSI. Shut down and rack back 1 stand to 5,400' MD.,PJSM R/U Head Pin and HP hose. Flood Choke and Kill lines. Test 10 3/4" Csg to 2,700 PSI for 30 min on chart, good. Pumped and bled back 5 bbls. Blow down lines and R/D test Equip.,PJSM Pump dry job and blow down Top Drive. POOH racking back 5" D.P & 5" HWDP F/ 5,400' to K-1 running tool. L/D running assy as per Baker rep.,PJSM P/U M/U 9.75" Window Mill, 9.5" Lower Mill, 5.813" Flex Joint, 9.875" Upper Mill, 2 ea 5.813" Pup Jnt. Scribe 180° off bolt hole (high side) on 9.75" Window Mill carry scribe to top of pup Jnt. Verified by MWD, DD, Baker Rep and CO Rep. Leave hanging in Derrick. P/U 9.563" Bottom Trip Anchor ( 3 pin 19.8K shear) & 10.75" Gen II Whipstock and set in rotary table. M/U Whipstock to Window MIll W/ 45K shear Bolt.,M/U 6.75" DM Collar, 6.75" TM Collar and 6.75" Float Sub (Port Float). Perform RFO F/ Scribe to DM Collar checked by Baker, DD, MWD and Co Rep onsite. RFO 6.12" / 6.74" = 326.88°.,PJSM P/U M/U 1 jnt 5" HWDP, 2 ea 6.5" Extreme Magnets RIH W/ 5" HWDP to 620' MD. Perform shallow hole test 500 GPM, 830 PSI, good.,PJSM RIH Whipstock BHA W/ 5" D.P. F/ 620' to 5,422' MD. Filled at 3,300' MD. Run speed 90 ft/min.,PJSM Break Circ. at 450 GPM 850 PSI. MWD Inc reads in 6° increments. P/U 162K, SLK 130. Orientate to 23° R. Slack down and set at 5,456' MD. Set down 30K anchor set. P/U 10K over good set. Slack down 48K and shear bolt. TOW 5,431' BOW 5,451' MD. L/D Single and kelly up on full stand. Start milling at 5,451' MD 450 GPM 860 PSI 60 RPM TRQ 6K.,Daily fluid hauled to G&I 859 bbls total = 1,492 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 0 bbls total = 1,440 bbls Daily Fluid lost 0 bbls total production = 0 bbls g ,PJSM Attempt to locate 7" collar around 5,461' MD. No indication of collar found. Set at 5,480' MD Mill window for sidetrack to K-44B g Set CIBP as per Baker Rep on site. Top of plug @ 5,455' MD. ppg gp p () P/U M/U Baker Multi String Cutter, 6.125" Stab and X/O as per Baker rep onsite. gpp pyj U M/U 9.75" Window Mill, 9.5" Lower Pull landing Jnt and Hanger to rig floor. p Slack down and set at 5,456' MD. Set down 30K anchor set. P/U 10K over good set. Slack down 48K and shear bolt. TOW 5,431' BOW 5,451' MD. L/D Single and kelly up on full stand. Start milling at 5,451' MD 450 GPM gg Start POOH L/D 7" Csg to pipe shed cut 7" at 5480ft ! "# "#$# % "#&$'(( #) "#&$'(( #) *+,, # -. ! . !' % . /0 . . 1. 1 . !" ! "2%.## !$%%&'( )* + 3. !" .,- . / , " . !$%%&'( )* + 2 . 0 . " . 4 . # - " 5. . "123)45 + , "123), -,-, + . *,4-*,. 6( 70 77 1 1# 3 %. %. 6 3. 23. 768'1 78' # & 4 % . (&(( (&(( ' ((% 88(&"3 %8 %9%&(2 21&9(12 %6 .(&(( (&(( 3(:2%;99&%3(, " 1:"8; (&(9 0 1 9:; <% 32 9/; 3 9:; !" "% " 3 !<<2("8 1="'=2("1 "'&%% 8(&1 %3 "'&9389((98 #2 .0 . % . 3 !" "&( . 0 . 2< 9/0; 9 ; 78' 9 ; 9:; 768'1 9 ; /=2.% %%(&(( 3%&3"(&(((&((2'&9( < 9 ; # 3 / 91 ; / 9 ; ""=%=2("1 9>0>* ?/ 7 ((9@A* ?#B/ 7"23&9( 18&2' *) +(9=28=2("' 9>0/*C 2// 7 (8" A**C D# / 7%19&' % %%(&(( 0/*C 2// 7)"+) (9=21=2("' 9>0/*C 2// 7 (8" A**C D# / 7% '"(&(( 3 3('& ( !"0/*C 2// 7)""(=9(=2("1 9>0/*C 2// 7 (8" A**C D# / 73 32'&1( 8 ( %&'( !"0/*C 2// 7)2 "(=" =2("1 " 9 ; > 9:; ? 9:; 768'1 9 ; 78' 9 ; /0 9 ; /0 9 ; " 23 9; " 6 3 9; 0 9; 9:8@; / 2'&9( (&(( (&(( 2'&9( (&(( (&(( 21&9( ' ((% 88(&"3 %8 %9%&(2 (&(( (&(( ,4C*,4 "23&9( (&99 9%&(3 "23&9( (&2 (&"33"&3( ' ((% 88(& " %8 %9%&"8 (&99 (&22 9>0>* ?/ 7)"+ 2"3&%% (&" 9%&(3 2"3&%% (&% (&98"'"&1% ' ((% 88(&32 %8 %9%&91 (&2" (&%( 9>0>* ?/ 7)"+ 9" &21 (&" 9%&(3 9" &21 (&39 (&%22%8&'1 ' ((% 88(&1" %8 %9%&%9 (&(( (&'8 9>0>* ?/ 7)"+ (2&3( (&(1 9%&(3 (2&3( (&88 (&'29 3&"( ' ((% 88"&(' %8 %9%&'9 (&(' (&82 9>0>* ?/ 7)"+ 18&2' (& ( 9%&(3 18&2' "&2" (&8% 2&'' ' ((% 88"&91 %8 %9%&8' (&92 "&"9 9>0>* ?/ 7)"+ %19&' (& " 9%&(3 %19&'9 "&33 "&2 %98&(9 ' ((% 88"&1% %8 %9'&2 (&(" "&' 9>0/*C 2// 7)2+ '83&'" (&99 %1&'1 '83&'( 2&"8 "&'3'92&(( ' ((% 882&93 %8 %9'&'' (&"1 2&"% 9>0/*C 2// 7)2+ 38"&3" 9&%" '2&(( 38"&' 9&'3 & 32'&( ' ((% 889&81 %8 %91& 2 9&98 %&2" 9>0/*C 2// 7)2+ 839&21 9&32 %1&1( 839&( '& 3 1& 18"3& ' ((% 88'&3% %8 % & (&23 "(&31 9>0/*C 2// 7)2+ 13(&% '& '(&"8 1'1&81 "(&33 "'&1%1" &21 ' ((% 81"&"9 %8 %%"&8% 2&8( "1&(1 9>0/*C 2// 7)2+ # -. ! . !' % . /0 . . 1. 1 . !" ! "2%.## !$%%&'( )* + 3. !" .,- . / , " . !$%%&'( )* + 2 . 0 . " 9 ; > 9:; ? 9:; 768'1 9 ; 78' 9 ; /0 9 ; /0 9 ; " 23 9; " 6 3 9; 0 9; 9:8@; / " (' &'% 3&"1 %1&29 " ('9&9 "'& " 2'&%1" ((3&3 ' ((% 81'&83 %8 %'"& 2 (&8" 21&82 9>0/*C 2// 7)2+ " "%8&1( 1&12 % &21 " "%'&%9 2 &"' 98&2%" "((&19 ' ((% 1( &3' %8 %32&11 9&(( 9&(9 9>0/*C 2// 7)2+ " 2%9&9" "9&8% %"&31 " 2 8&1( 9%&1( %9&3 " "19&9( ' ((% 1"'&'8 %8 %88&9% &2( '(&1 9>0/*C 2// 7)2+ " 9 '&"1 " &(3 3& % " 991&( %(& 2 3(&8(" 289& ' ((% 19"&98 %8 '(%&29 "&"% 8"&(% 9>0/*C 2// 7)2+ " "&( "3&2% %3&3% " 9(&98 '%&32 1"&"1" 93 &38 ' ((% 1 '&12 %8 '2%& % & "( &%1 9>0/*C 2// 7)2+ " %9'&2% "1&82 %'&%" " %2(&' 82&"3 ""'&'(" '%&( ' ((% 1'9&' %8 '%(&'3 2&39 "99&23 9>0/*C 2// 7)2+ " '9(&93 2"&'' % &9 " '(8&'' "("&"( " &(2" %%9&(' ' ((% 182&88 %8 '33&83 2&"2 "' &%2 9>0/*C 2// 7)2+ " 32 &28 29&28 %9&8% " '1%& "22&"% "39&(1" '91&8 ' ((' (( &2' %8 3('&3( "&3 "13&88 9>0/*C 2// 7)2+ " 8"8&99 29&"' % &"" " 38"&83 " 9&1' 2(9&(8" 32'&23 ' ((' (2'& ( %8 39'& (&"3 292&99 9>0/*C 2// 7)2+ " 1"9&9% 23&%8 '(&2" " 8'3&32 "'%&8% 293&99" 8"2&"2 ' ((' ( 8&'1 %8 33(& 9 %& ( 23(&12 9>0/*C 2// 7)2+ 2 (('&%8 28&%2 '3&'9 " 1%(&(2 "8%&(% 23'&'%" 81 & 2 ' ((' ('8&99 %8 8(1&% 9&83 9"9&33 9>0/*C 2// 7)2+ 2 "((&88 9(&"9 3 &81 2 (92&2' "11&8( 92(&9 " 13'&'' ' ((' (89&%' %8 8%9&(% &" 9%1&3 9>0/*C 2// 7)2+ 2 "1%&99 92&'3 3%&38 2 ""2&83 2"2&2 9'3&1 2 (%3&23 ' ((' (1'&% %8 1((&%( 2&39 (8&1% 9>0/*C 2// 7)2+ 2 281&18 9 &18 3 &1 2 "1"&%( 22%&%3 "8&1"2 "9%&1( ' ((' ""(& % %8 1%"&9" 2& 1 '"&'9 9>0/*C 2// 7)2+ 2 98 &"3 9%&"9 3%&38 2 2'8&'( 291&2 3"&2'2 2"9&(( ' ((' "2 &3" %8% ((9& 1 (&% %"%&39 9>0/*C 2// 7)2+ 2 38&33 9%&(2 3%&39 2 9 '&(2 2%2&'2 %29&1%2 21(& 2 ' ((' "98&'8 %8% (%'&(2 (&"2 %3(&(1 9>0/*C 2// 7)2+ 2 %39&"' 99& ( 3%&1% 2 2 &(8 2'%&'( %3%& (2 9'8& 8 ' ((' "%2&2% %8% "(3&92 "&32 '29&"% 9>0/*C 2// 7)2+ 2 ''3&93 99&9% 3'&"8 2 %(2&3% 238&(8 '2%&3(2 3&"% ' ((' "'%&21 %8% "%3& 3 (&" '3 &18 9>0/*C 2// 7)2+ 2 3'"&8% 99&9( 3'& ( 2 %8"&3( 21(&98 '3'&"92 %2'&"( ' ((' "38&"3 %8% 2(3&3% (&" 32'&88 9>0/*C 2// 7)2+ 2 8%'&%1 99&" 3'&"% 2 ''(&1% 9(2&3( 32'&%%2 '(%&9% ' ((' "1"&(% %8% 2%8&(9 (&22 338&38 9>0/*C 2// 7)2+ 2 1%2&28 99&"9 3'&9" 2 3 "&(8 9"%&"% 333&9%2 '8%& 8 ' ((' 2( &(3 %8% 9(8&'8 (&(1 89"&(1 9>0/*C 2// 7)2+ 9 ( &%3 92&18 3'&1" 2 8"8& 92'&8( 82'&922 3'2&8 ' ((' 2"'&28 %8% 9%3&%" (&91 88"& 2 9>0/*C 2// 7)2+ 9 "91&%8 92&81 3'&%" 2 818&"8 998&'8 83'&%12 8 2&%8 ' ((' 228&39 %8% (3&' (&2% 199&(3 9>0/*C 2// 7)2+ 9 29 &(8 92&9( 3'&'' 2 133&31 9%(& 1 12'&""2 122&"1 ' ((' 2 "&"( %8% %3&(2 (&'9 189&13 9>0/*C 2// 7)2+ 9 928&'3 9"&8 3'&83 9 (%3&1% 9'"&11 13%&((9 ((2&9% ' ((' 2%9&"% %8% %(%&33 (&%( " (9 &"8 9>0/*C 2// 7)2+ 9 22&1" 92&"" 3%&1 9 "93&81 939&32 " (29&%(9 (82&21 ' ((' 2'%& 9 %8% %% &"9 (&'( " (8 &(8 9>0/*C 2// 7)2+ 9 %"3&(8 9 &"' 3%&%' 9 2"'&3 98'& ( " (39&919 "'"&" ' ((' 238&'' %8% '(9&83 2&"1 " "9%&%% 9>0/*C 2// 7)2+ 9 '"2&( 9 &9" 3'&28 9 21%&2% 911&91 " "2%&2"9 291&'% ' ((' 212&2 %8% '%%&%9 (& % " "88&18 9>0/*C 2// 7)2+ 9 3(%&83 9 &" 3'&'2 9 932&89 ""&3' " "3'&%"9 9"3&29 ' ((' 9(%&"1 %8% 3('&'1 (&23 " 2 "&3 9>0/*C 2// 7)2+ 9 31'&81 99&88 33&99 9 8&28 29&29 " 22'&""9 912&'8 ' ((' 9"3&22 %8% 3%'&"% (&%2 " 212&' 9>0/*C 2// 7)2+ 9 81 & 2 99&8 33& 2 9 %21&23 9%&"" " 231&" 9 39&'3 ' ((' 921&3( %8% 8(1&(9 (&(3 " 9 '&1' 9>0/*C 2// 7)2+ 9 188&2 9 &2" 3'&'3 9 '(3&(9 '&88 " 99(&9(9 %%"& 9 ' ((' 9 2&(% %8% 8'(&(% (&'( " 911& 9>0/*C 2// 7)2+ (82&%2 9 &9' 33&"1 9 '8 &19 %8&81 " 982&(99 '21&99 ' ((' 9% &' %8% 1""&' (&9% " %2&% 9>0/*C 2// 7)2+ "33&2( 92&11 3%&3 9 3'9&32 3"&"' " 99&(39 3(8&"2 ' ((' 9'3& 1 %8% 1'2&%9 "&'8 " %(%&(9 9>0/*C 2// 7)2+ 2''&98 92&'2 3%&18 9 898&'8 82&13 " 31&129 389&(8 ' ((' 931&82 %8' ((1&2 (& " %%9&9 9>0/*C 2// 7)2+ 9'3&2' 9"&31 3'&1( 9 12 &( 1%&%8 " %92&"19 8'8& ' ((' 919&(2 %8' ('"&9% (&1' " '(3&"( 9>0/*C 2// 7)2+ '(&8 92&%3 3'& 3 ((9&2 %(3&(' " %8(&'89 1 3&' ' ((' (%&(% %8' "(1&3" (&83 " '%'&19 9>0/*C 2// 7)2+ %%%&'% 99&'( 3%&38 (82&'8 %"1& 3 " '9(&19 (23&(8 ' ((' "8&(9 %8' "%1&8" "&"' " 3(8&'8 9>0/*C 2// 7)2+ '%(&2" 99&"( 3'&"2 "'"&'' %92&(1 " '8"&9' "('&(' ' ((' 9"&22 %8' 2"(&(1 (&%' " 3'(&'3 9>0/*C 2// 7)2+ 3 &3 99&% 3'&%" 2 (&'' % &98 " 39"&8" "8%&(' ' ((' &(8 %8' 2'(&91 (&%2 " 8"2&%1 9>0/*C 2// 7)2+ # -. ! . !' % . /0 . . 1. 1 . !" ! "2%.## !$%%&'( )* + 3. !" .,- . / , " . !$%%&'( )* + 2 . 0 . " 9 ; > 9:; ? 9:; 768'1 9 ; 78' 9 ; /0 9 ; /0 9 ; " 23 9; " 6 3 9; 0 9; 9:8@; / 898&39 9 &29 3'&88 9"8&'8 %%'& 9 " 382&8( 2'9&(8 ' ((' %'&3" %8' 9""&2 (&33 " 8' &11 9>0/*C 2// 7)2+ 199&29 9 &9% 33&8% 91'&3' %'8&(8 " 89 &3% 9 "&"' ' ((' '8&1 %8' 9'9&(% (&%1 " 1"8&2( 9>0/*C 2// 7)2+ % (23&9% 99&3' 3'& 3 &3 %31&8( " 88'&"9 "1&" ' ((' 8"&2 %8' " &21 "&(% " 13(&81 9>0/*C 2// 7)2+ % "2(&11 9 &9 3'&13 %%2&92 %1"&8% " 193&"' 1'&32 ' ((' 19&83 %8' '%&"3 (&3( 2 (29&9" 9>0/*C 2// 7)2+ % 2"2&"9 92&32 3'&"2 '28&21 '(9&%' " 18'&"2 %32&'1 ' ((' %('&"9 %8' %"9&11 "&8% 2 (39&' 9>0/*C 2// 7)2+ % 9(1&88 92&2 3'&"( 3"(&3% '"'&"' 2 (93&(8 '%%&"% ' ((' %"1&9" %8' %' &8( (& 1 2 "2'&" 9>0/*C 2// 7)2+ % ( &39 99&"' 3%&31 31(&%3 '28&'" 2 (8'&38 39 &13 ' ((' %92&92 %8' '" &9' (&11 2 "33&98 9>0/*C 2// 7)2+ % 11& " 99&(1 3%&%" 8'1&8' ' "& 9 2 "9'&1" 8" &2' ' ((' % %&3" %8' '' &99 (&"8 2 221&"2 9>0/*C 2// 7)2+ % %%(&(( 99&"8 3%&'2 1"2&29 ' 8&92 2 "'9&'1 8%'&'9 ' ((' %%2&1( %8' '1"&(9 (&2" 2 2%'&33 9>0/*C 2// 7)2+ % '"(&(( 9"&9% 3'&9 1'2&1' '%'&(1 2 "1 &3' 1(3&9' ' ((' %'"&(2 %8' 322&(" 9&"2 2 288&8( 9>0/*C 2// 7)9+ % '%3&'9 21&1( 3'&1' % ((9&1 ''"&'1 2 2"8&93 1 8&9 ' ((' %''&81 %8' 3 %&%% 9&"2 2 9"9&(' 9>0/*C 2// 7)9+ % 32(&38 2'& 3 31&"' % (%1&'( ''3&81 2 2 3&% % (( &(( ' ((' %39& 2 %8' 33 &' %&'3 2 9 2&8% 9>0/*C 2// 7)9+ % 33(&"9 2 &9( 8(& 8 % "( &"8 '3"&' 2 2'8&9%% ( 8&%8 ' ((' %33& ( %8' 31%& " &% 2 9'9&1% 9>0/*C 2// 7)9+ % 89 &3% 2"&11 82&%% % "'9&'( '3%& " 2 219& 3% "(8&(( ' ((' %8"& % %8' 82(& 8 9&31 2 981&22 9>0/*C 2// 7)9+ % 813&'' "1&98 82&'1 % 222& % '38&2' 2 9"%&%(% "''&8% ' ((' %8 &%' %8' 8 2& 8 &"% 2 ""&23 9>0/*C 2// 7)9+ % 1'"&39 "%&2% 89&% % 289&'( '8(&%3 2 99 & 9% 228&(( ' ((' %83&(3 %8' 8'"&93 '& ' 2 9(&"8 9>0/*C 2// 7)9+ ' (2%&2 ""&3 8%&%2 % 9 %&9% '82&(" 2 9 1&"3% 281&3% ' ((' %88&'8 %8' 83'&"( %&%3 2 &89 9>0/*C 2// 7)9+ ' (88&8% 1&(9 1(&"1 % (3&1" '82&%( 2 9'(&'2% 9%2&9" ' ((' %81&9( %8' 883&% & ' 2 %'&( 9>0/*C 2// 7)9+ ' "%9&(" '&"8 1(&1 % 3"&%( '82& 9 2 9'1&""% "%&1( ' ((' %81&99 %8' 81'&(9 & 2 ' &2% 9>0/*C 2// 7)9+ ' 2"9&(1 '& 8 1(&38 % %9"&22 '82&99 2 93%&39% 3%&'2 ' ((' %81&9( %8' 1(2&'% (&%( 2 3(&' 9>0/*C 2// 7)9+ ' 233&9% '&1( 1"&%8 % %1%&( '82&"3 2 989&22% %91& ' ((' %81&29 %8' 1"(&" (&'3 2 33&8' 9>0/*C 2// 7)9+ ' 9 &91 8&11 88&18 % ''"& 9 '82&"% 2 912& 8% '(%&89 ' ((' %81&92 %8' 1"1& ( 9&"' 2 8'&89 9>0/*C 2// 7)9+ ' (%&2" ""& % 8 &9" % 32"&28 '82&8 2 (9&2 % ''%&'8 ' ((' %1(&"2 %8' 19(&"% &2' 2 13& 9 9>0/*C 2// 7)9+ ' ''& 3 "9&'" 8"& 1 % 38"&(8 '8 &%" 2 "'& 2% 32%& 8 ' ((' %1"&1 %8' 1 9&9" 9&'' 2 %"(&'" 9>0/*C 2// 7)9+ ' %9 &%9 "'&2" 8 &( % 8 '&8 '8'&'8 2 99&31% 31"&2 ' ((' %1 &9" %8' 1'(&'% 9&1 2 %23&18 9>0/*C 2// 7)9+ ' %18&"( "8&38 89&88 % 1(3& 3 '88&'1 2 %2&31% 8%"&83 ' ((' %1'&% %8' 131&'9 &( 2 % '&81 9>0/*C 2// 7)9+ ' ''"&2 2"&'' 82&23 % 1''&3" '1"&9 2 3 & %% 1""&"" ' ((' %11& 9 %83 (("&2% &'% 2 %'8&%9 9>0/*C 2// 7)9+ ' 32 &'( 2 &%1 8(&%" ' (2 &13 '1%&(1 2 11&(%% 1'1&93 ' ((' '(9& ' %83 (2%&8( &3% 2 %19&21 9>0/*C 2// 7)9+ ' 388&%9 23&"3 31&1% ' (82& 1 '11&89 2 %2'&% ' (2'&81 ' ((' '(8&%" %83 (%9&2 &(% 2 '2"&"" 9>0/*C 2// 7)9+ ' 8%2&%% 21&81 82&"2 ' "98&39 3( &%3 2 %%'&3 ' (89&"9 ' ((' '"9&%1 %83 (89&98 &%% 2 '%"&% 9>0/*C 2// 7)9+ ' 1"9& " 9"&19 8"&%( ' "1(&1 3(1&(9 2 %83&'8' "9%&9 ' ((' '"8& ( %83 "" &23 9&91 2 '82&'9 9>0/*C 2// 7)9+ ' 138& 3 9 &(9 82& 3 ' 2 %&%2 3"9&1' 2 '22&3%' "81&12 ' ((' '29&32 %83 " 1&23 9&99 2 3"3&89 9>0/*C 2// 7)9+ 3 ( 2&33 9'&1( 82&9% ' 213&88 3"8&81 2 '%1&39' 2 2&28 ' ((' '21&(3 %83 "8'&"1 & ' 2 3% &88 9>0/*C 2// 7)9+ 3 "('&"9 91&89 8"&1' ' 9 3&%' 32 &2' 2 '18&'8' 21"&1' ' ((' '9 &88 %83 22%&(8 &' 2 319&1% 9>0/*C 2// 7)9+ 3 "'1&%3 2&"3 8"& 9 ' 91%& 9 39(&23 2 391&8'' 991&89 ' ((' ' "&9' %83 2''&"8 9&39 2 89%&9 9>0/*C 2// 7)9+ 3 299&'% 2&(( 8(&"' ' 2&11 393&" 2 382&2%' 983&91 ' ((' ' 8&3" %83 9(8& 1 "&9% 2 838&"2 9>0/*C 2// 7)9+ 3 213& 1 9&9 38&81 ' 81&19 3 %&(" 2 82 &8(' 9 &99 ' ((' '%3&(3 %83 9%(&1 2& 1 2 12"&21 9>0/*C 2// 7)9+ 3 9'"&93 9& ( 33&"3 ' %9'&93 3% &"" 2 8'3&3"' 8(&33 ' ((' '''&'% %83 919&3 "&8% 2 1'%&"" 9>0/*C 2// 7)9+ 3 2 &3 "&8 33&98 ' %89&(( 3'9&%' 2 1(1&%'' %23& ( ' ((' '3'&%3 %83 9%& 8 2& 3 9 ((8&(" 9>0/*C 2// 7)9+ 3 88&'8 9&1 38&99 ' '21&8 332&3" 2 1%2&"(' %3 &2 ' ((' '8'&2( %83 33&1" 9& 9 (%"& 1 9>0/*C 2// 7)9+ # -. ! . !' % . /0 . . 1. 1 . !" ! "2%.## !$%%&'( )* + 3. !" .,- . / , " . !$%%&'( )* + 2 . 0 . " 9 ; > 9:; ? 9:; 768'1 9 ; 78' 9 ; /0 9 ; /0 9 ; " 23 9; " 6 3 9; 0 9; 9:8@; / 3 %%"&3" '& 9 38&3 ' '3 &2' 38"&'( 2 11%&12' '"8&'' ' ((' '1%&%8 %83 %2"&'2 9&18 9 (1'&" 9>0/*C 2// 7)9+ 3 '"%&11 1&3 38&(9 ' 3"3&2( 31"&29 9 ( 2&33' ''"&'( ' ((' 3(%&3% %83 %'8&9% %&2" 9 " 9&12 9>0/*C 2// 7)9+ 3 '31&28 %9&93 33&"8 ' 3%'&% 8("&88 9 (1"&"3' 3((&1 ' ((' 3"'&1 %83 '"'&'2 %&89 9 "19& % 9>0/*C 2// 7)9+ 3 3('& ( % &88 3'&81 ' 332& 8('&8" 9 ""2&%8' 3"'&8 ' ((' 322&"" %83 '93&18 %&'9 9 2"%& 2 9>0/*C 2// 7)9+ 3 32'&1( % &98 3'&39 ' 38 &9( 8"(&'2 9 "28&8'' 328&3( ' ((' 32'&"" %83 '% &2" 2&%2 9 292&"9 9>0/*C 2// 7) + 3 31%&3' %'& 2 33&23 ' 829& ( 829&93 9 "8 &(8' 3'3&8( ' ((' 391& 8 %83 3(1&28 9&(9 9 288&8( 9>0/*C 2// 7) + 3 8%3&1' %1&%1 38&2" ' 8%'&9% 89 &%' 9 29%&'9' 8((&3% ' ((' 3%"&2% %83 3'(&'1 %&2' 9 9 "&%" 9>0/*C 2// 7) + 3 12(& '2&"9 38&(9 ' 88'&38 8 %&8( 9 281&(9' 89"&"8 ' ((' 3'9&(1 %83 8"9&1% &(3 9 91'&(9 9>0/*C 2// 7) + 3 182&'" ' &33 3'&(' ' 1" &%' 8%8&23 9 9 9&2"' 8%8&1' ' ((' 33'&"8 %83 8'3&11 %&"" 9 %"&'2 9>0/*C 2// 7) + 8 ( %&'( ''& % 3%&38 ' 1 (&%8 832&29 9 918&8'' 88 &18 ' ((' 31(&33 %83 129& ' 2&3( 9 %(8&18 9>0/*C 2// 7) + 8 "38&(( ''& % 3%&38 ' 119& 8 1(2&(% 9 %"'&%"' 193&88 ' ((' 82"&1" %88 ( (&3' (&(( 9 '9(&9' -E4.4. ! AB ! A A Benjamin Hand Digitally signed by Benjamin Hand Date: 2019.11.05 10:02:46 -09'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2019.11.05 12:33:44 -09'00' ! "# "#$# % "#&$'(( #) "#&$'(( #) *+,, # -. ! . !' % . /0 . . 1. 1 . !" ! "2%.## !$%%&'( )* + 3. !" .,- . / , " . !$%%&'( )* + 2 . 0 . " . 4 . # - " 5. . 12"3)45 + , 12"3), -,-, + . *,4-*,. 6( 70 77 1 1# 3 %. %. 6 3. 23. 768'1 78' # & 4 % . (&(( (&(( ' ((% 88(&13 %8 %9%&(" "2&9(12 %6 .(&(( (&(( 3(:"%;99&%3(, 1 2:18; (&(9 0 1 9:; <% 32 9/; 3 9:; !" "% " 3 !<<"(18 2=1'="(12 1'&%% 8(&2 %3 1'&9389((98 #2 .0 . % . 3 !" 1&( . > 0 . 2< 9/0; 9 ; 78' 9 ; 9:; 768'1 9 ; /=2.3 %%1&31 3%&31(&(((&(("'&9( < 9 ; # 3 / 91 ; / 9 ; 11=%="(12 9?0?* @/ 7 ((9A B* @#>/ 71"3&9( 28&"' *) +(9="8="(1' 9?0/*C "// 7 (81 B**C D# / 7%29&' % %%(&(( 0/*C "// 7)1+) (9="2="(1' 9?0/*C "// 7 (81 B**C D# / 7% '1(&(( 3 %%1&31 !10/*C "// 7)1 1(=9(="(12 9?0/*C "// 7 (81 B**C D# / 73 '(2&(( 8 (1'&(% !"0/*C "// 7)9 1(=13="(12 " 9 ; > 9:; ? 9:; 768'1 9 ; 78' 9 ; /0 9 ; /0 9 ; " 23 9; " 6 3 9; 0 9; 9:8@; / "'&9( (&(( (&(( "'&9( (&(( (&(( "2&9( ' ((% 88(&13 %8 %9%&(" (&(( (&(( ,4C*,4 1"3&9( (&99 9%&(3 1"3&9( (&" (&1331&3( ' ((% 88(& 1 %8 %9%&18 (&99 (&"" 9?0?* @/ 7)1+ "13&%% (&1 9%&(3 "13&%% (&% (&981'1&2% ' ((% 88(&3" %8 %9%&92 (&"1 (&%( 9?0?* @/ 7)1+ 91 &"2 (&1 9%&(3 91 &"2 (&39 (&%""%8&'2 ' ((% 88(&21 %8 %9%&%9 (&(( (&'8 9?0?* @/ 7)1+ ("&3( (&(2 9%&(3 ("&3( (&88 (&'"9 3&1( ' ((% 881&(' %8 %9%&'9 (&(' (&8" 9?0?* @/ 7)1+ 28&"' (& ( 9%&(3 28&"' 1&"1 (&8% "&'' ' ((% 881&92 %8 %9%&8' (&9" 1&19 9?0?* @/ 7)1+ %29&' (& 1 9%&(3 %29&'9 1&33 1&" %98&(9 ' ((% 881&2% %8 %9'&" (&(1 1&' 9?0/*C "// 7)"+ '83&'1 (&99 %2&'2 '83&'( "&18 1&'3'9"&(( ' ((% 88"&93 %8 %9'&'' (&12 "&1% 9?0/*C "// 7)"+ 381&31 9&%1 '"&(( 381&' 9&'3 & 3"'&( ' ((% 889&82 %8 %92& " 9&98 %&"1 9?0/*C "// 7)"+ 839&"2 9&3" %2&2( 839&( '& 3 2& 2813& ' ((% 88'&3% %8 % & (&"3 1(&32 9?0/*C "// 7)"+ 23(&% '& '(&18 2'2&82 1(&33 1'&2%21 &"2 ' ((% 821&19 %8 %%1&8% "&8( 12&(2 9?0/*C "// 7)"+ # -. ! . !' % . /0 . . 1. 1 . !" ! "2%.## !$%%&'( )* + 3. !" .,- . / , " . !$%%&'( )* + 2 . 0 . " 9 ; > 9:; ? 9:; 768'1 9 ; 78' 9 ; /0 9 ; /0 9 ; " 23 9; " 6 3 9; 0 9; 9:8@; / 1 (' &'% 3&12 %2&"9 1 ('9&9 1'& 1 "'&%21 ((3&3 ' ((% 82'&83 %8 %'1& " (&81 "2&8" 9?0/*C "// 7)"+ 1 1%8&2( 2&2" % &"2 1 1%'&%9 " &1' 98&"%1 1((&29 ' ((% 2( &3' %8 %3"&22 9&(( 9&(9 9?0/*C "// 7)"+ 1 "%9&91 19&8% %1&32 1 " 8&2( 9%&2( %9&3 1 129&9( ' ((% 21'&'8 %8 %88&9% &"( '(&2 9?0/*C "// 7)"+ 1 9 '&12 1 &(3 3& % 1 992&( %(& " 3(&8(1 "89& ' ((% 291&98 %8 '(%&"9 1&1% 81&(% 9?0/*C "// 7)"+ 1 1&( 13&"% %3&3% 1 9(&98 '%&3" 21&121 93 &38 ' ((% 2 '&2" %8 '"%& % & 1( &%2 9?0/*C "// 7)"+ 1 %9'&"% 12&8" %'&%1 1 %"(&' 8"&13 11'&'(1 '%&( ' ((% 2'9&' %8 '%(&'3 "&39 199&"3 9?0/*C "// 7)"+ 1 '9(&93 "1&'' % &9 1 '(8&'' 1(1&1( 1 &("1 %%9&(' ' ((% 28"&88 %8 '33&83 "&1" 1' &%" 9?0/*C "// 7)"+ 1 3" &"8 "9&"8 %9&8% 1 '2%& 1""&1% 139&(21 '92&8 ' ((' (( &"' %8 3('&3( 1&3 123&88 9?0/*C "// 7)"+ 1 818&99 "9&1' % &11 1 381&83 1 9&2' "(9&(81 3"'&"3 ' ((' ("'& ( %8 39'& (&13 "9"&99 9?0/*C "// 7)"+ 1 219&9% "3&%8 '(&"1 1 8'3&3" 1'%&8% "93&991 81"&1" ' ((' ( 8&'2 %8 33(& 9 %& ( "3(&2" 9?0/*C "// 7)"+ " (('&%8 "8&%" '3&'9 1 2%(&(" 18%&(% "3'&'%1 82 & " ' ((' ('8&99 %8 8(2&% 9&83 919&33 9?0/*C "// 7)"+ " 1((&88 9(&19 3 &82 " (9"&"' 122&8( 9"(&9 1 23'&'' ' ((' (89&%' %8 8%9&(% &1 9%2&3 9?0/*C "// 7)"+ " 12%&99 9"&'3 3%&38 " 11"&83 "1"&" 9'3&2 " (%3&"3 ' ((' (2'&% %8 2((&%( "&39 (8&2% 9?0/*C "// 7)"+ " "82&28 9 &28 3 &2 " 121&%( ""%&%3 18&21" 19%&2( ' ((' 11(& % %8 2%1&91 "& 2 '1&'9 9?0/*C "// 7)"+ " 98 &13 9%&19 3%&38 " "'8&'( "92&" 31&"'" "19&(( ' ((' 1" &31 %8% ((9& 2 (&% %1%&39 9?0/*C "// 7)"+ " 38&33 9%&(" 3%&39 " 9 '&(" "%"&'" %"9&2%" "2(& " ' ((' 198&'8 %8% (%'&(" (&1" %3(&(2 9?0/*C "// 7)"+ " %39&1' 99& ( 3%&2% " " &(8 "'%&'( %3%& (" 9'8& 8 ' ((' 1%"&"% %8% 1(3&9" 1&3" '"9&1% 9?0/*C "// 7)"+ " ''3&93 99&9% 3'&18 " %("&3% "38&(8 '"%&3(" 3&1% ' ((' 1'%&"2 %8% 1%3& 3 (&1 '3 &28 9?0/*C "// 7)"+ " 3'1&8% 99&9( 3'& ( " %81&3( "2(&98 '3'&19" %"'&1( ' ((' 138&13 %8% "(3&3% (&1 3"'&88 9?0/*C "// 7)"+ " 8%'&%2 99&1 3'&1% " ''(&2% 9("&3( 3"'&%%" '(%&9% ' ((' 121&(% %8% "%8&(9 (&"" 338&38 9?0/*C "// 7)"+ " 2%"&"8 99&19 3'&91 " 3 1&(8 91%&1% 333&9%" '8%& 8 ' ((' "( &(3 %8% 9(8&'8 (&(2 891&(2 9?0/*C "// 7)"+ 9 ( &%3 9"&28 3'&21 " 818& 9"'&8( 8"'&9"" 3'"&8 ' ((' "1'&"8 %8% 9%3&%1 (&92 881& " 9?0/*C "// 7)"+ 9 192&%8 9"&82 3'&%1 " 828&18 998&'8 83'&%2" 8 "&%8 ' ((' ""8&39 %8% (3&' (&"% 299&(3 9?0/*C "// 7)"+ 9 "9 &(8 9"&9( 3'&'' " 233&32 9%(& 2 2"'&11" 2""&12 ' ((' " 1&1( %8% %3&(" (&'9 289&23 9?0/*C "// 7)"+ 9 9"8&'3 91&8 3'&83 9 (%3&2% 9'1&22 23%&((9 (("&9% ' ((' "%9&1% %8% %(%&33 (&%( 1 (9 &18 9?0/*C "// 7)"+ 9 ""&21 9"&11 3%&2 9 193&82 939&3" 1 ("9&%(9 (8"&"2 ' ((' "'%& 9 %8% %% &19 (&'( 1 (8 &(8 9?0/*C "// 7)"+ 9 %13&(8 9 &1' 3%&%' 9 "1'&3 98'& ( 1 (39&929 1'1&1 ' ((' "38&'' %8% '(9&83 "&12 1 19%&%% 9?0/*C "// 7)"+ 9 '1"&( 9 &91 3'&"8 9 "2%&"% 922&92 1 1"%&"19 "92&'% ' ((' "2"&" %8% '%%&%9 (& % 1 188&28 9?0/*C "// 7)"+ 9 3(%&83 9 &1 3'&'" 9 93"&89 11&3' 1 13'&%19 913&"9 ' ((' 9(%&12 %8% 3('&'2 (&"3 1 " 1&3 9?0/*C "// 7)"+ 9 32'&82 99&88 33&99 9 8&"8 "9&"9 1 ""'&119 92"&'8 ' ((' 913&"" %8% 3%'&1% (&%" 1 "2"&' 9?0/*C "// 7)"+ 9 82 & " 99&8 33& " 9 %"2&"3 9%&11 1 "32&1 9 39&'3 ' ((' 9"2&3( %8% 8(2&(9 (&(3 1 9 '&2' 9?0/*C "// 7)"+ 9 288&" 9 &"1 3'&'3 9 '(3&(9 '&88 1 99(&9(9 %%1& 9 ' ((' 9 "&(% %8% 8'(&(% (&'( 1 922& 9?0/*C "// 7)"+ (8"&%" 9 &9' 33&12 9 '8 &29 %8&82 1 98"&(99 '"2&99 ' ((' 9% &' %8% 211&' (&9% 1 %"&% 9?0/*C "// 7)"+ 133&"( 9"&22 3%&3 9 3'9&3" 31&1' 1 99&(39 3(8&1" ' ((' 9'3& 2 %8% 2'"&%9 1&'8 1 %(%&(9 9?0/*C "// 7)"+ "''&98 9"&'" 3%&28 9 898&'8 8"&23 1 32&2"9 389&(8 ' ((' 932&8" %8' ((2&" (& 1 %%9&9 9?0/*C "// 7)"+ 9'3&"' 91&32 3'&2( 9 2" &( 2%&%8 1 %9"&129 8'8& ' ((' 929&(" %8' ('1&9% (&2' 1 '(3&1( 9?0/*C "// 7)"+ '(&8 9"&%3 3'& 3 ((9&" %(3&(' 1 %8(&'89 2 3&' ' ((' (%&(% %8' 1(2&31 (&83 1 '%'&29 9?0/*C "// 7)"+ %%%&'% 99&'( 3%&38 (8"&'8 %12& 3 1 '9(&29 ("3&(8 ' ((' 18&(9 %8' 1%2&81 1&1' 1 3(8&'8 9?0/*C "// 7)"+ '%(&"1 99&1( 3'&1" 1'1&'' %9"&(2 1 '81&9' 1('&(' ' ((' 91&"" %8' "1(&(2 (&%' 1 3'(&'3 9?0/*C "// 7)"+ 3 &3 99&% 3'&%1 " (&'' % &98 1 391&81 18%&(' ' ((' &(8 %8' "'(&92 (&%" 1 81"&%2 9?0/*C "// 7)"+ # -. ! . !' % . /0 . . 1. 1 . !" ! "2%.## !$%%&'( )* + 3. !" .,- . / , " . !$%%&'( )* + 2 . 0 . " 9 ; > 9:; ? 9:; 768'1 9 ; 78' 9 ; /0 9 ; /0 9 ; " 23 9; " 6 3 9; 0 9; 9:8@; / 898&39 9 &"9 3'&88 918&'8 %%'& 9 1 38"&8( "'9&(8 ' ((' %'&31 %8' 911&" (&33 1 8' &22 9?0/*C "// 7)"+ 299&"9 9 &9% 33&8% 92'&3' %'8&(8 1 89 &3% 9 1&1' ' ((' '8&2 %8' 9'9&(% (&%2 1 218&"( 9?0/*C "// 7)"+ % ("3&9% 99&3' 3'& 3 &3 %32&8( 1 88'&19 12&1 ' ((' 81&" %8' 1 &"2 1&(% 1 23(&82 9?0/*C "// 7)"+ % 1"(&22 9 &9 3'&23 %%"&9" %21&8% 1 293&1' 2'&3" ' ((' 29&83 %8' '%&13 (&3( " ("9&91 9?0/*C "// 7)"+ % "1"&19 9"&3" 3'&1" '"8&"2 '(9&%' 1 28'&1" %3"&'2 ' ((' %('&19 %8' %19&22 1&8% " (39&' 9?0/*C "// 7)"+ % 9(2&88 9"&" 3'&1( 31(&3% '1'&1' " (93&(8 '%%&1% ' ((' %12&91 %8' %' &8( (& 2 " 1"'&1 9?0/*C "// 7)"+ % ( &39 99&1' 3%&32 32(&%3 '"8&'1 " (8'&38 39 &23 ' ((' %9"&9" %8' '1 &9' (&22 " 133&98 9?0/*C "// 7)"+ % 22& 1 99&(2 3%&%1 8'2&8' ' 1& 9 " 19'&21 81 &"' ' ((' % %&31 %8' '' &99 (&18 " ""2&1" 9?0/*C "// 7)"+ % %%(&(( 99&18 3%&'" 21"&"9 ' 8&9" " 1'9&'2 8%'&'9 ' ((' %%"&2( %8' '21&(9 (&"1 " "%'&33 9?0/*C "// 7)"+ % '1(&(( 91&9% 3'&9 2'"&2' '%'&(2 " 12 &3' 2(3&9' ' ((' %'1&(" %8' 3""&(1 9&1" " "88&8( 9?0/*C "// 7)9+ % '%3&'9 "2&2( 3'&2' % ((9&2 ''1&'2 " "18&93 2 8&9 ' ((' %''&82 %8' 3 %&%% 9&1" " 919&(' 9?0/*C "// 7)9+ % 3"(&38 "'& 3 32&1' % (%2&'( ''3&82 " " 3&% % (( &(( ' ((' %39& " %8' 33 &' %&'3 " 9 "&8% 9?0/*C "// 7)9+ % 33(&19 " &9( 8(& 8 % 1( &18 '31&' " "'8&9%% ( 8&%8 ' ((' %33& ( %8' 32%& 1 &% " 9'9&2% 9?0/*C "// 7)9+ % 89 &3% "1&22 8"&%% % 1'9&'( '3%& 1 " "29& 3% 1(8&(( ' ((' %81& % %8' 8"(& 8 9&32 " 982&"" 9?0/*C "// 7)9+ % 823&'' 12&98 8"&'2 % """& % '38&"' " 91%&%(% 1''&8% ' ((' %8 &%' %8' 8 "& 8 &1% " 11&"3 9?0/*C "// 7)9+ % 2'1&39 1%&"% 89&% % "89&'( '8(&%3 " 99 & 9% ""8&(( ' ((' %83&(3 %8' 8'1&93 '& ' " 9(&18 9?0/*C "// 7)9+ ' ("%&" 11&3 8%&%" % 9 %&9% '8"&(1 " 9 2&13% "82&3% ' ((' %88&'8 %8' 83'&1( %&%3 " &89 9?0/*C "// 7)9+ ' (88&8% 2&(9 2(&12 % (3&21 '8"&%( " 9'(&'"% 9%"&91 ' ((' %82&9( %8' 883&% & ' " %'&( 9?0/*C "// 7)9+ ' 1%9&(1 '&18 2(&2 % 31&%( '8"& 9 " 9'2&11% 1%&2( ' ((' %82&99 %8' 82'&(9 & " ' &"% 9?0/*C "// 7)9+ ' "19&(2 '& 8 2(&38 % %91&"" '8"&99 " 93%&39% 3%&'" ' ((' %82&9( %8' 2("&'% (&%( " 3(&' 9?0/*C "// 7)9+ ' "33&9% '&2( 21&%8 % %2%&( '8"&13 " 989&""% %92& ' ((' %82&"9 %8' 21(&1 (&'3 " 33&8' 9?0/*C "// 7)9+ ' 9 &92 8&22 88&28 % ''1& 9 '8"&1% " 92"& 8% '(%&89 ' ((' %82&9" %8' 212& ( 9&1' " 8'&89 9?0/*C "// 7)9+ ' (%&"1 11& % 8 &91 % 3"1&"8 '8"&8 " (9&" % ''%&'8 ' ((' %2(&1" %8' 29(&1% &"' " 23& 9 9?0/*C "// 7)9+ ' ''& 3 19&'1 81& 2 % 381&(8 '8 &%1 " 1'& "% 3"%& 8 ' ((' %21&2 %8' 2 9&91 9&'' " %1(&'1 9?0/*C "// 7)9+ ' %9 &%9 1'&"1 8 &( % 8 '&8 '8'&'8 " 99&32% 321&" ' ((' %2 &91 %8' 2'(&'% 9&2 " %"3&28 9?0/*C "// 7)9+ ' %28&1( 18&38 89&88 % 2(3& 3 '88&'2 " %"&32% 8%1&83 ' ((' %2'&% %8' 232&'9 &( " % '&82 9?0/*C "// 7)9+ ' ''1&" "1&'' 8"&"3 % 2''&31 '21&9 " 3 & %% 211&11 ' ((' %22& 9 %83 ((1&"% &'% " %'8&%9 9?0/*C "// 7)9+ ' 3" &'( " &%2 8(&%1 ' (" &23 '2%&(2 " 22&(%% 2'2&93 ' ((' '(9& ' %83 ("%&8( &3% " %29&"2 9?0/*C "// 7)9+ ' 388&%9 "3&13 32&2% ' (8"& 2 '22&89 " %"'&% ' ("'&82 ' ((' '(8&%1 %83 (%9&" &(% " '"1&11 9?0/*C "// 7)9+ ' 8%"&%% "2&82 8"&1" ' 198&39 3( &%3 " %%'&3 ' (89&19 ' ((' '19&%2 %83 (89&98 &%% " '%1&% 9?0/*C "// 7)9+ ' 219& 1 91&29 81&%( ' 12(&2 3(2&(9 " %83&'8' 19%&9 ' ((' '18& ( %83 11 &"3 9&92 " '8"&'9 9?0/*C "// 7)9+ ' 238& 3 9 &(9 8"& 3 ' " %&%" 319&2' " '""&3%' 182&2" ' ((' '"9&3" %83 1 2&"3 9&99 " 313&89 9?0/*C "// 7)9+ 3 ( "&33 9'&2( 8"&9% ' "23&88 318&82 " '%2&39' " "&"8 ' ((' '"2&(3 %83 18'&12 & ' " 3% &88 9?0/*C "// 7)9+ 3 1('&19 92&89 81&2' ' 9 3&%' 3" &"' " '28&'8' "21&2' ' ((' '9 &88 %83 ""%&(8 &' " 329&2% 9?0/*C "// 7)9+ 3 1'2&%3 "&13 81& 9 ' 92%& 9 39(&"3 " 392&8'' 992&89 ' ((' ' 1&9' %83 "''&18 9&39 " 89%&9 9?0/*C "// 7)9+ 3 "99&'% "&(( 8(&1' ' "&22 393&1 " 38"&"%' 983&92 ' ((' ' 8&31 %83 9(8& 2 1&9% " 838&1" 9?0/*C "// 7)9+ 3 "23& 2 9&9 38&82 ' 82&29 3 %&(1 " 8" &8(' 9 &99 ' ((' '%3&(3 %83 9%(&2 "& 2 " 2"1&"2 9?0/*C "// 7)9+ 3 9'1&93 9& ( 33&13 ' %9'&93 3% &11 " 8'3&31' 8(&33 ' ((' '''&'% %83 929&3 1&8% " 2'%&11 9?0/*C "// 7)9+ 3 " &3 1&8 33&98 ' %89&(( 3'9&%' " 2(2&%'' %"3& ( ' ((' '3'&%3 %83 9%& 8 "& 3 9 ((8&(1 9?0/*C "// 7)9+ 3 88&'8 9&2 38&99 ' '"2&8 33"&31 " 2%"&1(' %3 &" ' ((' '8'&"( %83 33&21 9& 9 (%1& 2 9?0/*C "// 7)9+ # -. ! . !' % . /0 . . 1. 1 . !" ! "2%.## !$%%&'( )* + 3. !" .,- . / , " . !$%%&'( )* + 2 . 0 . " 9 ; > 9:; ? 9:; 768'1 9 ; 78' 9 ; /0 9 ; /0 9 ; " 23 9; " 6 3 9; 0 9; 9:8@; / 3 %%1&31 '& 9 38&3 ' '3 &"' 381&'( " 22%&2"' '18&'' ' ((' '2%&%8 %83 %"1&'" 9&28 9 (2'&1 9?0/*C "// 7)9+ 3 '(2&(( 2&98 38&1( ' 31"&'' 32(&19 9 (93&%'' '%3&(' ' ((' 3( &%2 %83 %'9&1' %&"" 9 198&'( 9?0/*C "// 7) + 3 ' "&(1 8&91 33& ( ' 39 &92 32%& 1 9 ('1&8%' '38&32 ' ((' 31(&19 %83 %83&98 9&'1 9 1'9& 9?0/*C "// 7) + 3 3( &%' %"&88 3'&1" ' 33 &(8 8('& 2 9 1(8&88' 318& 8 ' ((' 3"1&3% %83 '9 &"8 3& 8 9 "11&3% 9?0/*C "// 7) + 3 3'8&13 %3&(( 3 &23 ' 81(&'" 812&%( 9 1%2&"8' 3%%&(" ' ((' 39%&9" %83 '8 &%9 '&' 9 "'9&81 9?0/*C "// 7) + 3 8"2&82 '(&(' 3 &'1 ' 8 "&89 899&91 9 "1(&(3' 383&"9 ' ((' 3 2&31 %83 39%&1% &28 9 91'& 9 9?0/*C "// 7) + 3 82"& 8 '"&2 3%&%8 ' 83"&3( 8 3& % 9 "'9&""' 813&1( ' ((' 3' & % %83 388&19 &8( 9 931& 9 9?0/*C "// 7) + 3 2%(&3 '%&(% 3%&33 ' 828&" 8'(& ( 9 919&2%' 8 "&' ' ((' 333&28 %83 898&31 9&'9 9 "9&32 9?0/*C "// 7) + 8 (1'&(% ''&2 3 &"1 ' 2" &81 83%&8' 9 931&%3' 8'2&"1 ' ((' 32 &(8 %83 82'&1 9&'" 9 89& 9?0/*C "// 7) + 8 (33&(( ''&2 3 &"1 ' 2 8&'8 821&1" 9 "%&%9' 829&(8 ' ((' 8(2&2% %83 2 2&29 (&(( 9 %92&%( -E4.4. ! B> ! B B Benjamin Hand Digitally signed by Benjamin Hand Date: 2019.11.05 10:04:42 -09'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2019.11.05 12:34:40 -09'00' TD Shoe Depth: PBTD: Jts. 2 189 Yes X No X Yes No 45 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes X No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg)Rate (bpm):Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? Yes X No Reciprocated?X Yes No % Returns during job Cement returns to surface? Yes X No Spacer returns?Yes X No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: Class G 176 1.21 24.50RKB 24.95 Hanger 10 3/4 TXP Seaboard 0.45 24.95 24.50 7,640.57 28.45 Pup Joint 7 26.0 L-80 TXP BTC 3.50 28.45 1.30 7,641.87 7,640.57 Casing 7 26.0 L-80 TXP BTC 7,612.12 Float Collar 7 3/4 26.0 TXP BTC Antelope L-80 TXP BTC 81.49 7,723.36 7,641.87 www.wellez.net WellEz Information Management LLC ver_04818br 3.5 Type of Shoe:Bullnose Casing Crew:Weatherford (2) on shoe jnt and FC jnt 1 on every joint to 7073' 1 on every joint from 5990 -5870 (across 10-3/4" shoe) 7,724.977,736.00 7,622.00 CEMENTING REPORT Csg Wt. On Slips:175 LSND Casing 7 26.0 0 Rig 15.8 38 Bump press Calculation - gauge hole Bump Plug? 19:00 10/10/2019 6,987 18.5 10.5 6 100 335FIRST STAGE11Tuned 40 DWC own Hole Solutio 1.61 7,724.97 7,723.36 Csg Wt. On Hook:210 Type Float Collar:Conventional No. Hrs to Run: Setting Depths Component Size Wt.Grade THD Make Length Bottom Top S Barber / C Montague Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.MP K-44A Date Run 10-Oct-19 LSND OK Remarks: CASING RECORD County State Alaska Supv. 7,640.57 Floats Held 26.7 38 0 38 294.5/292.9 850 Rotate Csg Recip Csg Ft. Min.PPG10.5 Shoe @ 7724.97 FC @ Top of Liner WELLHEAD SMB -22MakeType Serial No.Seaboard 26.7 Test head to 5000 PSIG 15 MIN Casing (Or Liner) Detail Shoe 7 3/4 26.0 Y Size 11 W.P.5000 7" casing report PB1 PB2 TD 8,178' MD / 6,993' TVD 8,077' MD / 6,948' TVD KOP 7,609' TOW N/A Well P&A'd Date 10/20/2019 N/A Well P&A'd PTD: 219-116 / API: 50-029-23567-01-00 MPU K-44A OH Sidetrack Summary THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU K -44A Permit to Drill Number: 219-116 Sundry Number: 320-113 Dear Mr. Myers: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1 G Daniel T. Seamount, Jr. Commissioner DATED this day of March, 2020. RECEIVE® STATE OF ALASKA MAR 11 2020 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC LU /1i11i LJ.GVV 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 13 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ r Perforate New Pool E]Re-enterSusp Well ElAlter Casing ElOther: u.fe C 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 219-116 6. API Number: ' 3. Address: 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 50-029-23567-01-00 8. Well Name and Number: 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? N/A MPU K -44A Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9. Property Designation (Lease Number): 10. Field/Pool(s): ' Milne Point Field / Kuparuk River Oil Pool ADL375133! ADL375132 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Z 7 P 5� Plugs (MD): Junk (MD): 8,078' 6,949' 7,161' 6,388' -WA- 7,161' 7,698' (TOF) Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' N/A N/A Surface 5,597' 10-3/4" 5,597' 4,952' 3,580psi 2,090psi Intermediate 1 7,725' 7" 7,725' 6,78T 7,240psi 5,41 Opel Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 3-1/2" L-80 2,50T Packers and SSSV Type: N/A Packers and SSSV MD (ft) and ND (R): N/A 12. Attachments: Proposal Summary ❑ Wellbore schematic 13. Well Class after proposed work: Sketch Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ Detailed Operations Program Q BOP 14. Estimated Date for 3/31/2020 15. Well Status after proposed work: fur ❑ OIL ❑ WINJ ❑ WDSPL Suspended Commencing Operations: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Date: 16. Verbal Approval: ❑ Op Shutdown ❑ Abandoned Commission Representative: GINJ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Monty Myers Contact Name: Joe Engel Authorized Title: Drilling Manager Contact Email: eD a hilcor .CORI Contact Phone: 777-8395 � Authorized Signature: Date: COMMISSION USE ONLY Condftions of approval: Notify Commission so that a representative may witness Sundry Number: -113 ,,_J/ Plug Integrity ❑ BOP Test V7 Mechaniccaal Integrity Test ❑ Location Clearance ❑ Other: „�( 3J �[7 SOS- .60v Post Initial Injection MIT Req'd? Yes ❑ No ❑ � Subsequent Form Required: ! Q •' 0 T Spacing Exception Required? Yes ❑ No APPROVED BY ILO Approved by: COMMISSIONER THE COMMISSION Date: 3 [Z-5 iG 2,30,/ .i/a6/'� �` 1 1 I A'�� Submit Form and Form 10-403 Revised 412017 (/Y Approvedapplication i-Oi f 2 '_YL -'111N ate of approval/�/�� Attachments i3Duplicate P&A and setup for RD Well: MPU K -44A Date: 03-15-2020 Well Name: MPU K -44A API Number: 50-029-23567-01-00 Current Status: Ops Shutdown Pad: K -Pad Estimated Start Date: April 2, 2020 Rig: Innovation Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Cody Dinger Permit to Drill Number: 219-116 First Call Engineer: Joe Engel (907) 777-8395 (0) (805) 235-6265 (M) Second Call Engineer: Ian Toomey (907) 777-8434 (0) (907) 903-3987 (M) AFE Number: Job Type: P&A and setup for RD Brief Well Summary: The parent well, K-44 was drilled in 2016 and worked over in May 2019. In September 2019, the well was sidetracked as K -44A with the intent of drilling a lateral in the Kup C. 7" casing was top set in the Kalubik. Two attempts were made to drill the 6-1/8" lateral, however due to hole conditions the well was plugged back in the 7", 7" was pressure tested to 1500 psi for 30 min, and the well entered operational shutdown. Hydrocarbon bearing zones were never penetrated Notes Regarding Wellbore Condition: The 7" casing was cemented back to a TOC of 7,161' MD. 7" casing was pressure tested to 1500 psi on 10/27/2019 for 30 minutes, operation covered under PTD 219-116 Objective: K -44A is to be officially abandoned and pr fined for a sidPtrark_ Pull 3-1/2" Kill string. Pressure Test 7" Casing. ut aC ndFuasing. Run 10-3/4" CIBP to top of 7" casing cut. RWO Procedure: 1. MIRU the Innovation rig. 2. Check for pressure and if 0 psi pull BPV If needed, bleed off any residual pressure off tubing and casing. If needed, kill well prior to pulling BPV. �t 3. Install TWC. (�) -7 It �q AS 6M ► + -t 4. ND the tree. NU 13-5/8" BOP tack with 2-7/8" x 5" VBR's in the upper and lower pipe ram cavities. Si)L f„- 5 est BOPE to 250/30Q6 psi v+iith 3-1/2" and 5" test joint. 3 a. Notify AOGCC N hours in advance of BOP test. i3 1-17 L� b. Confirm test pressures per the Sundry Conditions of approval. c. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 6. Pull the TWC. 7. Circulate out freeze protect, taking returns to tiger tank 8. RU to pull 3-1/2" killstring 9. MU landing joint, BOLDS and unseat the tubing hanger • PU Weight when running = 52klb on Innovation October 2019 10. Pull the tubing hanger to the rig floor and lay down 11. POOH laying down 3-1/2" killstring • Send all completion equipment to be cleaned for reuse 12. Install wear ring 2 ze" Jz✓ 13. RU and Pressure Test 7" casingt '' z o�vu psi for 30 minutes, chart test 14. MU and RIH with mechanical multi string cutter BHA on 4" drill pipe 15. Cut 7" casing at -5560' MD 7 U P&A and setup for RD Well: MPU K -44A Date: 03-15-2020 • Confirm measurements of casing cut, 10-3/4" CIBP length, 10-3/4" whipstock length and 10-3/4" casing tally to ensure future window will not be milled across a casing connection 16. Close annular and attempt to establish circulation through 7" cut 17. POOH and lay down cutting BHA • Inspect cutter for cut confirmation/quality 18. BOLDS of 7" hanger 19. MU 7" Landing Joint or Spear and engage 7" hanger 20. Pull 7" hanger free and to rig floor, lay down same 21. Lay down cut 7" casing joints • Send full joints to be cleaned, inspected, and reused 22. PU and MU 10-3/4" CIBP 23. RIH with CIBP and set on top of 7" casing cut -5560' MD 24. Displace well to 9.5 ppg LSND mud 25. Pressure test 10-3/4" casing t/ 2700 psi for 30 min, chart test. • Save chart for upcoming FIT/ 0,41 r4 s7,z..x<s/p2-- • AOGCC regulation is 50% of burst, 5210 / 2 = 2605 psi, test pressure is 2700 psi 26. TOOH and lay down CIBP running tool 27. Continue to work on PTD for sidetrack, K -44B Attachments: 1. Current schematic 2. Proposed schematic 3. Blank MOC form 4. BOPE schematic Milne Point Unit Well: MPU K 44A Current Schematic Last Completed: Future Hilaury.als�ka. LLt: PTD: 219-116 Ling. KB Elev.: 63.1'/ GL El0w.:29X 20' Tree Wellhead TREE & WELLHEAD CASING DETAIL [i4 .tM Cmt to surface 13-1/2" Cmt w/ 342 bb1s (Lead)120 bbis (Tail) Cmt to Surface 9-7/8" 1 38 bbis � Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 78.6/A-53/Weld - Surface 80' 10-3/4" Surface 45.5 / L-80 / B7C 9.794 Surface 5,597' 7" Intermediate 26/L-80/TXP 6.059 Surface 7,725' TUBING DETAIL 10.3/4" 3-1/2" Tubing 9.3/L-80/EUE Brd 1 2.867 1 Surf 1 2,507' 5557, 1 �@ IS(w if JEWELRY DETAIL OPEN HOLE / CEMENT DETAIL Cond Cmt to surface 13-1/2" Cmt w/ 342 bb1s (Lead)120 bbis (Tail) Cmt to Surface 9-7/8" 1 38 bbis Inside7" I 15bbs WELL INCLINATION DETAIL 7" Window @ 7,609'-7,622' MD 7" GENERAL WELL INFO API: 50-029-23567-01-00 TOF @ 7,6W MD 1 TD = 8,077 (MD(/ TD = 6,949'(IVD) PBTD = 7,161' (MD( / PBTD - 6,W(TVD) Created By: CJD 10/29/2019 n IFlaorn Alneln. LLI: ong. KB Elev.: 63.176L Eley.: 293' ESQ.. @ gbh' i' aBP @* 4553 MD 10-3/4- . or IOtT@ f5,560'I.1D 7" TOF @ 7,698' MD L—j TD - 8,077 (MD) / TD = 6,949'(M) PBTD - 7,161' ( MD) / PBTD - 6,388'(TVD) Proposed Schematic TREE & WELLHEAD CASING DETAIL Milne Point Unit Well: MPU K -44A Last Completed: N/A PTD: 219-116 Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 78.6/A-53/Weld - Surface 80' 10-3/4" 7" Surface Intermediate 45.5 / L-80 / BTC 26/L-80/TXP 9.794 Surface 6.059 Surface 5,597' 7,725' TUBING DEIAIL 3-1/2" Tubing 9.3 / L-80 / EUE 11 2.867 Surf 2,SOi JEWELRY DETAIL nPFN HOLE / CEMENT DETAIL Cond Cmttosurface 13-1/2" Cmt w/ 342 bbls (Lead)120 bbis (Tail) Cmt to Surface 8" 38 bbls Inside 7" 15 bbs WELL INCLINATION DETAIL 7" Window @ 7,609'-7,622' MD GENERAL WELL INFO API: 50-029-23567-01-00 Created By: CID 10/29/2019 n Ililr�arp AI.A.0 1.1.1: Milne Point Unit K -44B Kuparuk Producer Drilling Procedure _ 10 -- F= I I Ili I I" V,e:l NIP,-, b: 44r M. Proposed Schematic LBSII'O Oeted Faiwr Sepbaar03-0 0". SK PTCI. T5D TD=7flS)tIVq!TD=7,J2 WfTV01 PSTD=7;9®• Ihq! PSTD=] 13017101 Page 8 _.__._....___________________________..__._. ------ TREE & WELLHEAD __---_-____________ M. Tree1 Sepbaar03-0 0". SK TOO STMS 171E"x1' x•1 C.25'OPaJ WelWead 2 700 STA0Ir-2.719"x 1'$ir cLw/0um vGLV 2.61" -------------------------------- TBD __-___._---._._____.________________.______-.. CASING DETAII 2.305' 4 Size I TypeWJI' Cpm Drift 10 LIM—'NeN SLIM Tap am 21' Cardudar 78. I Surlam I 89' 103;'4" 1 SurF 4S.SJL-80 BTC I 9.794 I Sudam I 5.59'1' 7' I.wrewipte 26/1-00/w 6.059 7.597' 'I TBD TUBING DETAIL M Mir I Tubin 9.3 Ld0 COLBrd 1 2867 1 S.d I z7.= JEWELRYDETAIL Na. Tww M. ID 1 TOO STMS 171E"x1' x•1 C.25'OPaJ 2.441" 2 700 STA0Ir-2.719"x 1'$ir cLw/0um vGLV 2.61" 2 TBD 3-V3, *I Nipple-M0Im' 2.305' 4 IBD Balton Dbchar8elkutl 5 7BD Partrd D.hsm 14 tl 6 70D Pu 3: PMP59EPM=93FLCM7I6 I TBD Pump2: PMPS30Pk%XD91FLEX4711S E 72D Pump 1: PMPS98PI.LSE020GINP911119 9 TBD Gas Sepamror.53BG91WM CFCB M TBD 0 crr imdem3ukf�03081155PJ'A9Ptii 11 TBO lvxer iardem Seok G5030B 1155B,•'AB FZcA 12 TBD Mczar: 13 TBD I Senear CeM.Ider. WELL INCLINATION DETAIL 7.Ord. IS 15547 hiD ._____________________________________________----------- _ GENERAL WELLINFO 1 API: 50029]3551-02-00 H Hilcorp Alaska, LLC x lcorp Changes to Approved Rig Workover Sundry Procedure Date: 3.16.2020 Subject: Changes to Approved Sundry for MPU K -44A Abandonment File #: Any modifications to the approved MPU K -44A sundry will be documented and approved below. Changes to an approved sundry will be communicated to and approved by the AOGCC prior to implementation. Approval: Prepared: Date Manager Date Engineer Date Innovation Rig BOP Schematic Its 11111� �; 9-518" DBL D Seal \ Casing 13-518' NOM 9-5/8" BTC Btm x 10.5"A SA Pin Top W/ Primary Seal _-13-5/8' 5M Control Technology Annular BOP S 0 13-5/8' 5M Control o Technology Double Ram 13-5/8" 5M Control Technology Single Ram 13-5/8"x 5M "-----11" x 5M �2-1/16' x 5M 13-5/8" x 5M \— x 5M 20" Casing -5/8" Casing Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re - drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status of"Suspended." M& Step I Task Responsible 1The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and b initial it on both copies of the Form 10-403 (AOGCC's and operator's dd--���� copies). 3/ 1 / /a.0 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial en 1i1 f it on both copies of the Form 10-403 (AOGCC's and operator's copies). 3 Instead, check the "Suspended" box and initial that change. ✓ Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 Whth en e Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. M& 11 Hilrorp Alaska_ I.TA. DATE 12/18/2019 D,_. . a Oudean Hilcorp Alaska, LLL GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 CD: HALLIBURTON FINAL LWD LOGS 30 OCT 2019 MPU K -44A PB1 MP U K -44A P B2 _Log Viewers 31694 31695 12/18;20191 Cl: 9 .. 1 Z/18,+'201911:D0 .. 1Z1V2C11911: DD.. 219116 RF °FcCF/V -9pccc,9F0 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 STATE OF ALASKA ALAS, A OIL AND GAS CONSERVATION COMMIboION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Ll Plug Perforations U Fracture Stimulate Ll Pull Tubing Li Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑✓ Stratigraphic ❑ Exploratory ❑ Service ❑ 219-116 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, 6. API Number: AK 99503 50-029-23567-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL375133 / ADL375132 MPU K -44A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): ROP/ABG/DGR/EWR/ADR 2"/5" MD ABG/DGR/EWR/ADR 2"/5" TVD PB1/PB2 Milne Point Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8,077' feet Plugs measured 7,161' (TOC) feet true vertical 6,949' feet Junk measured 7,698' (TOF) feet Effective Depth measured 7,161' feet Packer measured 7,554' (CIBP) feet ' true vertical 6,391' feet true vertical 6,676' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' N/A N/A Surface 5,597' 10-3/4" 5,597' 4,952' 3,580 psi 2,090' psi Intermediate 7,725' 7" 7,725' 6,787' 7,240 psi 5,410' psi Production Liner 11116— I V E Perforation depth Measured depth N/A feet NOV IV Y 12 2019 True Vertical depth N/A feet AOGCPTubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / L-80 / EUE 8rd 2,507' MD 344' TVD Packers and SSSV (type, measured and true vertical depth) N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A Subsequent to operation: N/A 14. Attachments (required per 20 AAc 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations E Exploratory ❑ Development ❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑� Def. Surveys Only 16. Well Status after work: Oil Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Authorized Name: Monty Myers Contact Name: Cody Dinger Authorized Title: A Drilling Manager Contact Email: cdingerCaDhilcorp.com /� `ll / 4 �Zbl Authorized Signature: G„ Date: Contact Phone: 777-8389 r� �`I'� � `I A 11��( -1SDMS_L�NOV 1 3 2019 Form 10-404 Revised 4/2017 Submit Original Only Milne Point Unit Well: MPU K -44A Schematic Last Completed: Future H17corp Alaska. LLC PTD: 219-116 Orig. KB Bev.: 63.1'/ GL Elev.: 29.3' ti 20' H cemeMrr @ X616 { IG -3/4 - Al) (�j 1 @ 7,161 MD i TOF @ 7,6W 4' MD TD = 8,077 (MD) / TD = 6,949'(fVD) PBTD = 7,161' (MD) J PBTD= 6,3W(TVD) TREE & WELLHEAD Tree Seaboard 3-1/8", SK Wellhead CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 78.6 / A-53 / Weld - Surface 80' 10-3/4" Surface 45.5 / L-80 / BTC 9.794 Surface 5,597' 7" Intermediate 26 / L-80 / TXP 6.059 Surface 7,725' TUBING DETAIL 3-1/2" 1 Tubing 1 9.3 / L-80 / EUE 8rd 1 2.867 1 Surf 1 2,507' JEWELRY DETAIL No. Top MD Item ID 1 7,554' 1 Cement Retainer OPEN HOLE / CEMENT DETAIL Cond Cmt to surface 13-1/2" Cmt w/ 342 bbls (Lead) 120 bbls (Tail) Cmt to Surface 9-7/8" 38 bbls Inside 7" 15 bbs WELL INCLINATION DETAIL 7" Window @ 7,609'-7,622' MD GENERAL WELL INFO API: 50-029-23567-01-00 Created By: CJD 10/29/2019 Hilcorp Energy Company Composite Report Well Name: MP K -44A Field: County/State: , Alaska (LAT/LONG): :vation (RKB): API #: Spud Date: Job Name: 1914444D MPU K -44A Drilling Contractor Innovation AFE #: AFE $: Activity Date: Ops Summary 10/4./2019 Cont. changing out saver sub. Change out air slip inserts to 5"; Pick up Bit, bit breaker, DM, TM, lift subs and floats for BHA via tool slide.;PJSM. M/U BHA, pick up motor and make up bit and DM collar. Measure RFO = 0.68'/7.01" = 34.92°. M/U TM, float, (2) flex collars and 1 HWDP. Shallow pulse test. Pick up drift and single in with (5) HWDP, Jars and (11) HWDP to 670.08'.; Daily hauled 105 bbls to G&I total = 1,721 bbls Hauled 0 bbls H2O from A -Pad reserve total = 0 bbls Hauled 130 bbls H2O from B -Pad Creek total = 3,640 bbls Lost 0 bbls to formation Total fluid lost section = 1,430 bbls 10/5/2019 Pick up, drift and single in the hole with 5" drill pipe from 670' to 5183'. PUW 163K, SOW 120K. Wash down from 5183' at 2 bpm/300 psi. Tag TOC at 5381' x 2 with 5K.;Circulate bottoms up while reciprocating pipe stage pumps up to 540 gpm/1725 psi.;Rig up, flood lines and purge air. . PT casino to 28QO 9_§J_ pumping down drill string and annulus - failed test. Bleed off. Pump a drill string volume and purge air. PT casing to 2800 psi for 30 minutes - good test. Pumped 5.4 bbls, bled back 4.9 bbls. Rig down, blow down choke/klll.;RIH and tag cement at 5381' Drill cement from 5381' to 5610' to get mud motor bend $ A! out of shoe. 540 gpm/1770 psi with 80 psi diff, 40 rpms/9,000 ft -lbs, WOB 8-10K. PUW 178K, SOW 125K, ROTW 144K.;Kick off sliding at 5610', observe formation over shakers at 5618'. Drill 20' of new hole to 5638', Initial ROP limited to 10fph increasing to 30 fph. WOB 0-10K, 540 gpm/1680 psi. PUW 174K, \� SOW 125K.; Rack one stand back and circulate bottoms up at 540 gpm/1720 psi - even mud weights 9.7 ppg in/out.;Rig up, fill lines and purge. Shut top rams. Perform FIT to 12.5 ppg EMW with 730 psi - good. Blow down lines, rig down.;RIH to TD at 5638'. Continue sidetracking well -bore drilling from 5638' to 5753' sliding as needed at 540 gpm/1880 psi, WOB 8-10K, 40 rpms/11 Kft-lbs PUW 185K, SOW 125K, ROT 146K. Gain 2.72' C -C separation by 5657', and 11.75' C -C separation by projected survey at 5753'.; Circulate bottoms up at 540 gpm/1790 psi.40 rpms/10Kft-Ibs, reciprocating pipe. Obtain SPR's.;POOH from 5753' to inside casing shoe at 5560', no indication of swabbing. Monitor well -static. Pump dryjob. Continue to POOH to 670'. PUW 63K, SOW 63K.;Distance to WP #5: 2.4', 1.481, 1.9' R;Daily hauled 177 bbls to G&I total = 1,898 bbls Hauled 0 bbls H2O from A -Pad reserve total = 0 bbls Hauled 260 bbls H2O from B -Pad Creek total = 3,770bbis Hauled 130 bbls H2O from K -Pad lake, Total = 260 bbls Lost 0 bbls to formation Total fluid lost section = 1,430 bbls 10/6/2019 Ud BHA. Rack back 8 stands HWDP ant 1 jar stand. Rack back NM flex collars. UD float, TM, and DM. Break bit, and UD Mud motor.;Clean and clear rig floor. remove small BHA pieces from rig floor.;PJSM pick up RSS drilling BHA #2. Pick up Geo -Pilot, make up bit, DM collar, ADR, DGR/PWD, TM and IBS. Plug in and upload MWD. M/U float, stand of NM flex collars, float sub. Pickup 1st stand of HWDP and shallow pulse test.;RIH to 5548'; (2) stands HWDP, Jars stand, (5) stands HWDP and 5" drill pipe. Fill pipe and break in Geo -Pilot at 2623'. PUW 168K, SOW 120K. Calculated displacement.; Fill pipe. Wash and ream from 5,548' to 5,753' at 60 rpms/10.5Kft-Ibs, 450 gpm/1235 psi. PUW 175K, SOW 124K, ROTW 143K.; Drill 9-7/8" hole from 5753' to 6216', total 463' (AROP=93fph) staging up to 575 gpm/2020 psi, WOB 9-14,120 rpms/13,5Kft-lbs. ECD's 10.2 ppg with 9.7 ppg mud. Max Gas 17U. PUW 200K, SOW 125K, ROTW 150K.; Drill 9-7/8" hole from 6216' to 6312', total 93' 575 gpm/2050 psi, WOB 3-8, 120 rpms/13ft-lbs. ECD's 10.3 ppg with 9.7 ppg mud. Max Gas 8U. PUW 210K, SOW 132K, ROTW 145K.;Trouble shoot Geo -Pilot: ABI pulsing up GTotal of 1.063 and not taking downlinked TF and defection command; TF locked at 45L. Attempt to reset tool with down]inked mode switch command without success. Reset tool with manual mode switch by cycling pumps. ABI within spec, and TF responding.; Drill 9-7/8" hole from 6312' to 6690', total 378' (AROP = 84fph) 550 gpm/1950 psi, WOB 15-18, 100 rpms/14ft- Ibs. ECD's 10.2 ppg with 9.6 ppg mud. Max Gas 8U. PUW 233K, SOW 130K, ROTW 165K.; Distance to WP#5 (survey depth 6405): 11.08', 3.39'L, 10.55'R.; Daily hauled 346 bbls to G&I total = 2,244 bbls Hauled 0 bbls H2O from A -Pad reserve total = 0 bbls Hauled 130 bbls H2O from B -Pad Creek total = 3,900bbis Hauled 130 bbls H2O from K -Pad lake, Total = 130 bbls Lost 0 bbls to formation Total fluid lost section = 1,430 bbls 10/7/2019 Drill 9-7/8" hole from 6690' to 6944', total 254' (AROP = 73fph) 600 gpm/2300 psi, WOB 15, 110 rpms/16ft-lbs. ECD's 10.3 ppg with 9.55 ppg mud. Max Gas 12U. PUW 230K, SOW 140K, ROTW 168K.;CBU at 600 gpm/2250 psi, 60 rpms/13Kft-lbs, reciprocating pipe.;Attempt to POOH on elevators from 6883' to 6820', observe swabbing. BROOH from 6820' to 6312' at 550gpm/1920 psi, 60-100rpms/12Kft-lbs. PUW 225K, SOW 125K.;Cont. to BROOH from 6,312' to 5,802' at 550gpm/1920 psi, 80 rpms/12Kft-lbs. ECD's 10.58, max gas 652U. PUW 197K, SOW 117K, ROTW 153K.;POOH from 5,802' to 5,548', observe 12K overpull as stabalizer/bit at casing shoe. PUW 197K, SOW 117K.;CBU at 575 gpm/1860 psi, 60 rpms/10Kft-lbs reciprocating pipe.;PJSM pull tripping nipple, install RCD bearing.; Service rig: grease/inspect crown, blocks and top drive. Check oil in top drive.;RIH on elevators from 5,548' to 6,820' with no issues. Wash down to 6,944'400 gpm/1250 psi. No issues on trip.; Drill 9-7/8" hole from 6944' to 7170', total 226' (AROP = 50fph) 575 gpm/2370 psi, WOB 15-20, 80-100 rpms/15ft-lbs. Max Gas 370U. Begin holding back pressure while drilling, and trapping pressure on connections. Working up to CBHP of 10.8 ppg PUW 218K, SOW 130K, ROTW 165K.; Drill 9-7/8" hole from 7170' to 7581', total 411' (AROP = 69fph) 550 gpm/2545 psi, WOB 15-20,80-100 rpms/18ft-lbs. Max Gas 425U. Hold back pressure while drilling and trapping on connection for a CBHP of 11.2 -11.3 ppg EMW PUW 230K, SOW 130K, ROTW 162K. Top of HRZ logged at 7549'M D.; Distance to WP#5 (survey depth 7424'): 10.73', 2.541, 10.43'R.;Daily hauled 689 bbls to G&I total = 2,933 bbls Hauled 520 bbls H2O from B-Pad Creek total = 3,420 bbls Hauled 130 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 130 bbls from 6 mile lake, Total 130 bbls Lost 0 bbls to formation Total fluid lost section = 1,430 bbls 10/8/2019 Drill 9-7/8" hole from 7581' to 7736' MD/6789' TVD, total 155' (AROP = 78fph) 600 gpm/2950 psi, WOB 15-20, 80-100 rpm/18k tq on, Max Gas 601 u. Hold back pressure while drilling and trapping on connection for a CBHP of 11.2 - 11.3 ppg EMW. P/U 233K, S/O 135K, ROT 162K.;Circulate and condition mud (Rot/Recip) @ 7736' MD (Intermediate TD). Circulate 3x btms up. 600 gpm, 2850 psi, 120 rpm, 15k tq.;Monitor well w/ 200 psi back psi for 10 min (10 ppg EMW). Pressure bled down to 164 over 10 min. Slowly increase MPD to —625 psi w/ 9.55 MW (11.3 EMW) and hold while POOH on elevators F/ 7736' - T/ 6514' MD. Hole took proper displacement. 5-10k drag w/ several 25k bobbles before falling off.;TIH on elevators F/ 7514' - T/ 7736' without issue holding —625 psi w/ MPD (11.3 EMW). Hole took proper displacement.; Break circulation and stage up to 585 gpm, 2640 psi, 80 rpm, 16k tq while holding —260 w/ MPD (MWD showed 11.3 EMW). Weight up active system from 9.6 to 10.5 over 3x circulations. Monitor well via MPD no pressure buildup.;POOH on elevators from 7736' to 5548', following Beyond trip schedule holding dynamic pressure of 340 psi and static pressure 280 psi at 45 fpm. Observe intermittent 5-15K drag off off bottom to 7300'. 25K overpull at 5771' = wipe through - clean.; Circulate and condition mud (Rot/Recip). Circulate 3x btms up at 580 gpm/2350 psi, holding back pressure to maintain 11.55 ppg EMW for a CBHP of 11.3 ppg. PUW 168K, SOW 118K, ROTW 135K.;Service rig: Grease crown, blocks and top drive. Check oil in TD. SimOps : monitor well with MPD - no pressure buildup. Open tattle tall on RCD to verify well is static.; POOH laying down drill pipe from 5548' to 1542', following Beyond trip schedule holding initially 360 psi dynamic pressure down to 320 psi, and 280 psi static pressure at 80 fpm. Observe 30K overpull at 3400', went down with no issues, pulled back through with 5K.;Distance to WP#5: 12.02', 11.671, 2.87'R;Daily hauled 0 bbls to G&I total = 2,933 bbls Hauled 260 bbls H2O from B-Pad Creek total = 4,680 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 0 bbls from 6 mile lake, Total 130 bbls Lost 0 bbls to formation Total fluid lost section = 1,430 bbls 10/9/2019 Continue POOH F/ 1542'- T/ 747' MD laying down 5" drill pipe while maintaining 11.3 EMW CBHP w/ MPD (-280 psi static / —320 psi dynamic). 15 bbl loss for total trip.;Bleed off MPD psi to 0 and monitor well (static). Verify static well visually via bleed off hose (confirmed static). Remove RCD head and install trip nipple. Blow down MPD system.;PJSM, POOH F/ 747' to MWD laying down all HWDP, jars, flex DC, Float sub and stab. Plug in and download MWD. B/O and UD MWD/RSS. No notable damage to BHA. Bit graded - 1,1,CT,A,X,I,NO,TD.;Clean and clear rig floor of BHA components.; Drain stack. Pull wear ring, set test plug.;Bleed down accumulator. Open UPR doors and change out to 7" solid body rams. Re-energize accumulator.; Flood lines and purge air. Test UPR's on 7" test joint. 250/3500 psi. Rig down testing equipment. Blow down kill Iine.;Rig up Weatherford, change out elevators, M/U Volant, R/U power tongs. Dummy run hanger.;PJSM. Pick up shoe track, BakerLok to pin end of joint 4. Check floats - good. RIH with 7" 26#, L-80 TXP casing to 1,574'. Make up torque 14,750 ft-lbs. PUW 62K, SOW 60K, calculated displacement observed.;RIH with 7" 26#, L-80 TXP casing to 4,995'. Make up torque 14,750 ft-lbs. 60 fpm; —10.9 ppg EMW on bottom surge as per Beyond running procedure. PUW 135K, SOW 11 K, calculated displacement observed.;Daily hauled 57 bbls to G&I total = 3,333 bbls Hauled 130 bbls H2O from B-Pad Creek total = 4,810 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 0 bbls from 6 mile lake, Total 130 bbls Lost 15 bbls to formation Total fluid lost section = 15 bbl 10/10/2019 Cont. to RIH with 7" 26#, L-80 TXP casing from 4,995' to 5597'. Make up torque 14,750 ft-lbs. 45 fpm; —10.9 ppg EMW max on bottom surge as per Beyond running procedure. PUW 145K, SOW 116K, calculated displacement observed.;Circulate annular volume staging pumps up to 8 bpm/250 psi in upstroke. Reciprocating pipe.;Cont. to RIH with 7" 26#, L-80 TXP casing from 5597' to 7131'. Makeup torque 14,750 ft-lbs. 45 fpm; --11.0 ppg EMW max on bottom surge as per Beyond running procedure. PUW 190K, SOW 139K, calculated displacement observed. 30k tag @ 6190' MD (wash past 4 bpm on 2nd attempt).;Circulate annular volume prior to HRZ staging pumps up to 6 bpm/330 psi in upstroke, reciprocating pipe.;Continue to RIH with 7", 26#, L-80, TXP casing from 7131', set down 25K at 7,525'. Establish circulation at 4 bpm/275. Wash casing down from 7,525' to 7,696'. M/U hanger and landing joint. Cont. washing down to casing point of 7725'. PUW 210, SOW 140K.;Circulate hole clean staging pumps 6 bpm/330 psi, reciprocating pipe. Rig up cementers and prep for cement job.;Cement as per detail: Flood lines and PT 1500/4000 psi - good. Mix and pump 40 bbls of 11.0 ppg spacer at 3.4 bpm/304 psi, drop bottom plug, mix and pump 38 bbls of 15.8 ppg Class G cement at 3.5 bpm/640 psi. Drop top plug. Displace with 5 bbis water followed by 289.5 bbls.;(calc 287.9 bbls, 1/2 shoe track volume over) at 6 bpm/330 psi, stage rate down to 2 bpm once cement exits shoe. FCP 335 psi. Pressure up to 850 psi and hold for 5 minutes. Check floats - good. CIP at 19:00 psi. No losses throughout job.;R/D volant tool and weatherford handling equipment. Clean and clear rig floor.;Back out landing joint. M/U pack-off and set. RILDS, energize P-seals with plastic packing. Attempt to test Pack -off void - would not pressure up. BOLDS, pull pack-off. Lower body seal gauged, top neck seal also damaged. Redress packoff. SimOps: Install long mousehole while redressing packoff;Re- Install packoff. RILDS, energize P-seals and attempt to test pack-off, would not pressure up. Pull pack-off; seals in good condition. Wellhead rep mobilize another (used) pack-off to location, while attempting a third time with same results. Install different pack- off with same results.;Pull pack off and L/D landing joint. Contact Seaboard to troubleshoot packoff. Change out UPR's to 2-7/8" x 5.5" VBR's. Begin working on changing out saver sub. AOGCC witness notification sent for 10/11/19 BOP test.;Daily hauled 801 bbls to G&I total = 4,134 bbls Hauled 130 bbls H2O from B-Pad Creek total = 5070 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 0 bbls from 6 mile lake, Total 130 bbls Lost 15 bbls to formation Total fluid lost section = 15 bbls 10/11/2019 Continue troubleshoot packoff issues with 11" 5M Seaboard thru bowl wellhead. Obtain measurements vs stack up schematic. Found lower external seal on packoff had been relocated on new packoff assemblies which placed seal across unused lockdown screws on are wellhead configuration.; Located old packoff and redressed. On 6th attempt we were able to successfully set, RILDS and test packoff 800/5000 w/ 5/15 min hold ea (good test). UD landing jt. B/O packoff running tool. Test witnessed by Co Rep (Shane Barber).;R/U BOP test equipment. Flood lines and manifold. Shell test BOP stack 250/3500 psi.;R/U and UD 5" NC50 DP out of derrick (6 stds) while waiting on AOGCC rep to arrive onsite.;Pick up 4" test joint. Set test plug. m/U test sub into top drive. Flood lines, purge air.;Test BOPE's 250/3500 psi on 3-1/2" and 4" test joints. Test gas alarms, flow paddle and alarms. Test witnessed by AOGCC rep Matt Herrera. No failures. Accumulator drawdown: Starting pressure 3000 psi, final 1450 psi. First 200 psi recharge 22 seconds, full recharge 81 seconds. (6) N2 at 2333 psi.;Rig down test joint and testing equipment. Blow down choke and kill lines. Install wear bushing.;UD 29 stands of 5" drill pipe via mousehole.;Service rig: grease crown, blocks, top drive, iron roughneck. Perform derrick inspection.; Change out elevator inserts to 4". Pick up small BHA pieces from slide. Load collars and HWDP in shed. Break off TIW and dart from test joint.;M/U BHA. pick up Geo-Pilot and ADR collar. M/U bit. M/U ILS, Gamma, PWD, DM, TM, and IBS collars as per DD. Plug in and download.;Daily hauled 117 bbls to G&I total = 4,251 bbis Hauled 130 bbls H2O from B-Pad Creek total = 5070 bbis Hauled 0 bbis H2O from K-Pad lake, Total = 130 bbis Hauled 0 bbis from 6 mile lake, Total 130 bbls Lost 0 bbis to formation Total fluid lost section = 0 bbls 10/12/2019 Finish downloading MWD. M/U BHA #3 (286.63' total length). 6-1/8" RSS geopilot, MWD, 2x flex DC's, 3x 4" HWDP w/ jars. 2 solid floats installed in BHA. Shallow pulse test MWD 200 gpm, 540 psi (test good).;PJSM, Single in hole F/ 286'- T/ 2044'w/ 4" HT38, 14#, 5-135 dp out of shed (drift 2.35"). Sym Ops - LRS onsite @ 08:00. Freeze protect 10-3/4" x 7" annulus w/ 100 bbis diesel (2020' MD). 2 bpm, 500 ICP, 832 FCP. Shut in psi = 780.;Continue trip in hole out of derrick F/ 2044' - T/ 5300' MD. Break in Geo-Pilot @ 2736' as per DD staging up from 10 rpms to 80 rpms (2k tq), 200 gpm, 1130 psi. Downlink (success). 100k up, 75k dn. Calculated disp for trip.;Continue trip in hole F/ 5300' - T/ 7620' MD washing down last stand. No cmt encountered. Calculated disp for trip. 142k up, 96k dn, 2 bpm, 700 psi.;R/U and test 7" TXP BTC, 26#, L-80 casing to 3500 psi w/ 30 min hold (test good). Chart and record same. 2.7 bbls pumped, 2.7 bbls returned. 14 psi drop first 15 min, 0 psi drop last 15 min.;PJSM, Hang blocks, cut drilling line (14 wraps), ACCUM TM 13804. Check brake air gaps (within spec). Recalibrate block position & zero ton mile tracker.;Wash down from 7620', tag up on FC on depth at 7640'. Drill shoe track and 2' new hole from 7736' to 7738' at 60 rpms/7Kft-lbs, 200 gpm/1600 psi. Tag float shoe on depth. PUW 142K, SOW 96K, ROTW 113K. At 7738', hole packed off 600 psi increase and TD stalled (set limit 10Kft-Ibs).;Work pipe, establishing circulation at 3/4 bpm with limiter set at 900 psi. Establish rotary — 1' off bottom with 20 rpms/7500 ft-lbs. Work pipe with non-rotating housing at the shoe, pulling 30K over. Observe pump pressure falling, stage pumps up to 2 bpm/540 psi. Slowly work pipe into shoe;fighting multiple pack-off with 10K over pulls, staging pumps up to 2.5 bpm as pressures fall/stabilize - no losses.; Circulate bottoms up staging pumps up to 250 gpm/2000 psi, 60 rpms/7500 ft-lbs reciprocating pipe from 7225' to 7683'. Start working pipe back to bottom at 7738'.;Cont. drilling total of 20' new hole from 7738' to 7756' ROP 0 -30 fph; adjusting parameters to attempt and increase ROP: from 250 gpm/2141 psi to 175 gpm/1220psi, 80rpms -120 rpms/6700ft-lbs, WOB 4-15KIbs. Displace to 10.0 ppg Baradril-N on the fly. PUW 165K, SOW 96K, ROTW 115K.;Circulate bottoms up 250 gpm/1900 psi, 60rpms/6000ft-lbs, racking back from 7756' to 7683'; Observe signs of packing off as bit enters shoe, slack off and slow pumps to 2 bpm to pull into shoe.; Rig up, flood lines and purge air. Perform FIT to 13.0 ppg EMW (1060psi) -good test. Pumped 1 bbls, bled back 1 bbls. Rig down and blow down Iines.;Pull tripping nipple, install MPD RCD bearing.;Wash and ream BHA in casing attempting to clear debris from bit. Continue to wash and ream from 7683' to 7676' at 200 gpm/1330 psi, 60 rpms/6Kft-lbs.;Daily hauled 57 bbls to G&I total = 4,308 bbls Hauled 130 bbis H2O from B-Pad Creek total = 5200 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 0 bbis from 6 mile lake, Total 130 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls 10/13/2019 Continue drilling 6-1/8" production hole F/ 7756'- T/ 7848' MD / 6857' TVD. 250 gpm, 2330 psi on, 2320 psi off, 60-150 rpm, 7k tq, 10-130 diff psi, 3-18k wob, 160k up, 90k dn, 104k rot. Drilling Kulubik formation (shale). Varied parameters attempting to increase slow rop (20-50 fph ROP).; Pumped 30 bbls nut plug (6 ppb), condet sweep for possible bit balling. Yielded minimum change in ROP once clear of bit.;Continue drilling 6-1/8" production hole F/ 7848'- T/ 7884' MD. 250 gpm, 1950 psi, 125 rpm, 7k tq, 8k wob, 158K up, 84K dn, 105K rot. Varied parameters to attempt to increase slow rop. Max gas 43U. ECD 11.45 ppg EMW with 170 psi back pressure applied by MPD. Floats no holding, bleeding on conn.;Troubleshoot comms error with MWD, change out choke size in geospan to send downlinks.;Continue drilling 6-1/8" production hole F/ 7884'- T/ 7920' MD. 250 gpm, 1450 psi, 135 rpm, 7Kft-lbs, WOB 12, 163K up, 85K dn, 105K rot. Max gas 13U. Discontinue holding back pressure at 7900' due to floats not holding. Comms with MWD tool.;Continue drilling 6-1/8" production hole F/ 7920'- T/ 8026' MD. 250 gpm, 2150 psi, 135 rpm, 8Kft-lbs, WOB 8-20, 164K up, 82K dn, 109K rot. Max gas 11 U. ECD 11.0 ppg. Pumped 8% lube sweep at 7973', observed 6K drop in weight as lube crossed bit, pumped 2nd 8% lube at 7994'.;ROP increased from 15-20 fph to 50-70 fph until sweep exited hole at 8025'.;Continue drilling 6-1/8" production hole F/ 8026'- T/ 8074' MD. 250 gprn, 1900 psi, 140 rpm, 8Kft-lbs, WOB 8-20, 164K up, 84K dn, 107K rot. Max gas 11 U. ECD 11.0 ppg. Attempt to pump another lube pill with little success. ROP 15-50fph. Packed off and stalled out at 8074'.;Pick up and establish rotary 20 rpms/7Kft-lbs. Work pipe to establish circulation, stage pumps up with multiple pack-offs to 5 bpm/1500 psi.;Continue drilling 6-1/8" production hole from 8074' to 8116'. Initial ROP 40 fph falling to 15-20fph. 250 gpm, 1930 psi, 140 rpm, 7.9 Kft-lbs, WOB 8-20, 164K up, 84K dn, 107K rot. Max gas 11 U. ECD 11.0 ppg.;Distance to WP05: 95, 9.4' low, 1.4' left (survey depth 7982.6').;Daily hauled 575 bbis to G&I total = 4,883 bbls Hauled 0 bbis H2O from B-Pad Creek total = 5200 bbis Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbis Hauled 260 bbls from 6 mile lake, Total 390 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbis 1 011 4/2 01 9 Continue drilling 6-1/8" production hole from 8116' to 8179' MD / 6990' TVD. 250 gpm, 1980 psi, 110-140 rpm, 7.9 Kft-lbs, WOB 8-22, 188K up, 83K dn, 107K rot. Max gas 36u. ECD 11.0 ppg. Packed off @ 8150' bit depth while backreaming during connection. 2000 psi, 12.5k tq stall.;Work pipe free with no pump and establish free rotation w/ 7.2k tq. Stop rotation and slowly pump out of hole F/ 8179' - T/ 7994' with significant packing off issues until 8050 where we were able to establish circulation 2 bpm, 490 psi.;Saw 62k overpull freeing pipe then consistent 10-20k drag. 180k up, 80k dn.;Continue pump out of hole F/ 7994' - T/ 7725' MD (shoe). Saw 30k overpull when upper string stabilizer pulled thru shoe. Only minor bobbles pulling remaining BHA up into shoe.;Circulate and condition mud 1.5x btms up @ 7725' MD. 250 gpm, 1830 psi, 60 rpm, 7.4k tq. 300% increase in cuttings at btms up. Initially saw very fine cuttings (sand/shale) @ btms up then became more coarse for another 40 bbls pumped.;Monitor well, static. Pull MPD bearing. Install trip riser.;POOH on elevators from 7610' to 6678', observe swabbing. pump out of hole at 3bpm/630 psi to 6335', correct hole fill while pumping. PUW 161 K, SOW 92K.;Continue to POOH from 6020' to 5426'- still swabbing. Run back in hole to 6020' with correct displacement.;Circulate 50 bbls nut plug/condet sweep at 250 gpm/1460 psi, 60 rpms/5300 ft -lbs. No increase in cuttings.;POOH 60fpm for 10 stands, no signs of swabbing. Continue to POOH to 3760' with good displacement. Pump dry job. POOH to 3206'- calculated displacement. PUW 82K.;Continue to POOH from 3206' to 286'. PUW 43K, SOW 43K. Calculated displacement observed.; UD BHA: monitor well, static. Rack back 3 jtns of HWDP/Jars, UD float subs, XO's and IBS. Rack back flex collars. Plug in and read MWD tools. UD TM, DM. Pull up and inspect ADR and Geo -Pilot. Break bit. Bit grade 1 -1 -NO -X -1 -PR. No signs of damage to BHA.;M/U new BHA. M/U 5 -bladed bit. C/O ILS, Gamma, PWD, DM, TM collars, IBS. Plug in and upload MWD.;Distance to WP05: 8.38', 7.98' low, 2.59' left (survey depth 8045.60').; Daily hauled 114 bbls to G&I total = 4,997 bbls Hauled 130 bbls H2O from B -Pad Creek total = 5330 bbls Hauled 0 bbls H2O from K -Pad lake, Total = 130 bbls Hauled 260 bbls from 6 mile lake, Total 390 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls 10/15/2019 Continue with download MWD. M/U new floats (solid), 2x Flex DC's, XO, 3x jts 4" HWDP w/ jars (286' total length BHA). Shallow pulse test @ 200 gpm, 600 psi (test good).;RIH F/ 286- T/ 6303' MD w/ 6-1/8" assy on 4" HT38 DP. Closed annular and psi up 60 psi on annulus to verify new floats were holding (floats held). Fill pipe every 25 stds. Observed gas climbing to 800u. Observed well (no gain, gas breaking out and crude).; Kelly up @ 6303' MD and circulate 1.5x btms up. Saw gas continually climb throughout 1st btms up with peak gas @ 2361 u then slowly trending down to 200-300u. Staged up to 180 gpm, 975 psi w/ full returns. NGR fault displayed during cleanup cycle and dropped pump rate to 5 spm. Troubleshoot pump.;Shut down pumps and isolate power to Hi - Line. Pumps reset and ran without issue. Swapped over to gen power and had no issue. Finished cleanup cycle without any other issue.;Continue RIH on elevators F/6303' -T/7620' MD. Calc disp for trip.;PJSM, Monitor well (static). Remove trip nipple and install MPD rotating head. Flood lines and test same (test good). Baseline MPD system at drilling rate (25 psi surface friction).;Attempt to trip in from shoe. 3x 15k tag @7726' (shoe @7725'). P/U into shoe, establish parameters 163k up, 96k do (w/ pumps), 151 k up, 91 k do (w/ no pump). 175 gpm, 1070 psi, 60 rpm, 7.6k tq. Attempt to wash down from shoe. Obstruction @ 7726'-7728' then freed up. Work thru w/ pump/rot/20k.;Cont working down from 7728' to next obstruction @ 7741'-7743' w/ same parameters. Worked back up into shoe with same amount of trouble going up. Temporarily detained @ 7741' before freeing pipe coming up. Worked back down to 7761' MD with similar parameters encountering tight spots as before.;Work free and pull up to 7730' MD. Significant packoffs and inability to travel up or do during tight spots noted. Tight spots did not change from each time we worked thru them. Max pull 40k over and 40k do while working tight spots.; Discussed options with town engineer. Decision made to hold 11.5 EMW utilizing MPD while attempting to wash to btm. Wash do to 7804' MD holding 11.5 EMW w/ MPD. 205 gpm, 1525 psi, 62 rpm, 7.8k tq. Stalled @ 11.5k tq @ 7804' MD. Begin working to free pipe @ 17:55 hrs.;PJSM Rack back stand to 7,803' MD. P/U working single. Work string F/ 7,803' to 7,800' MD ROT 155K, ROT SLK 70K W/ 1,500 PSI Press trapped in string, 20 RPM stall set at 12.7K. Cont. working string pulled 200K (40K over) without rotation. Tried no pumps and bleed down MPD to zero,;pulled to 200K, SLK to 70K, tried W/ 50 RPM, TRQ set 12.7K ROT SLK 70K, ROT 170K string stalling out at 7,999' MD. Jarred up 5 X and lost all progress but was able to SLK back down. Went to 50 RPM, TRQ set 13.4K Press set at 600 PSI, MPD 200 PSI, inching up pulling F/ 160K to 170K watching torque;stall with no Circ. Worked to 7,798' MD and stalled out, worked string F/ 70K to 170K to regain rotation. Work string back up to 7,798' lost 150 PSI to 450 PSI on string, TRQ 12.3K at 50 RPM, ROT 117K. Cont working pipe up to 7,790' MD W/ 50 RPM, TRQ set 13.7K ROT 125K, 200 PSI stand pipe,;MPD 160 PSI. Work string F/ 7,803' to 7,790' MD. 50 RPM, TRQ 10-13K, 200 PSI trapped in string, ROT 125K, ROT SLK 80K. Shut down and UD working single. Kelley up and try to gain Rot. Set RPM at 50 W/ 13.7K stall, 200 PSI trapped Press.;Work string pulling to 170K, SLK 70K only gaining 2', Was able to get 50 RPM, TRQ 10.5K still packed off but had 4' of movement. P/U working single. No losses to formation. Circ. fluid through MPD and Top Drive at 21:00 and 23:00 to ensure no ice plugs.;PJSM Set RPM 50, TRQ limiter at 13.7K, trap 200 PSI, MPD 160 PSI. Working string F/ 7,803' to shoe at 7,725' MD. watching TRQ stall and intermittent flow at 200 PSI. Pulling 120K to 135K. Cont. to pull to 7,697' MD. Was able to get partial flow in 7" casing.;Rot and Reciprocate at 50-20 RPM, TRQ 8K, ROT 120K, ROT SLK 108K. CBU working string F/ 7,697' to 7,641' MD, Staging up pumps from 0.5 bpm to 3 bpm, 800 PSI. MPD 200 PSI, 10.5-10.9 ppg EMW. Max Gas at BU 7320. Circ. 2nd BU at 200 GPM, 1,150 PSI, 20 RPM, TRQ 8K, Max Gas 6000, MPD 200 PSI.;Attempt to down link MWD. Open Choke and attempt to down link cycling pumps. MWD is pulsing but tools are not reading data, Shut down and monitor well with MPD closed, gained 2 PSI over 10 Min. Open MPD by pass and monitor for 5 Min, well static.;Daily hauled 0 bbls to G&I total = 4,997 bbls Hauled 0 bbls H2O from B -Pad Creek total = 5330 bbls Hauled 0 bbls H2O from K -Pad lake Total = 130 bbls 10/16/2019 Monitor well (static). Pull RCD and install trip nipple. Pull wet out of hole F/ 7651 to 7212' MD. 163k up, 96k do observed swabbing. Trip back to bottom from 7212' to 7712' MD.;Circulate nut plug / condet sweep surface to surface to clear debris from BHA. 40 bbls w/ 10 ppb nut plug. 250 gpm, 1300 psi, 20-50 rpm, 8k tq. 50 units gas.;Monitor well (static). POOH F/ 7712'- T/ 286' MD. Pulled 1 st 5 stds wet (no swabbing), pump dry job, B/D TDS.;Rack back HWDP wl jars, 1 std NM Flex DC's, B/O and UD floats (both floats stuck partially open due to nut plug on valve guide, clean and rebuild). Download. P/U MWD w/ upper part of Geo Pilot starting @ reference housing. Lost 12.22' GP + .85' bit) 13.07' total left in hole. Discuss with town.;PJSM P/U M/U BHA 5 Dumb Iron 6 1/8" Smith XR-PS Tri Cone, 4 3/4" Bit Sub, X/O, 2 Jts 4" HWDP, 4 3/4" Jars, 1 jnt 4" HWDP total 131.58'. One non ported float. 3 X 15 Jets in bit.;PJSM Service rig. Grease Crown, Blocks, Top Drive, Spinners, Iron Roughneck and inspect Drawworks.;PJSM RIH W/ BHA #5 on 4" 14# HT38 L-80 F/ 132' to 7,653' MD. No losses.;PJSM CBU Rot & Rec F/ 7,653' to 7,593' MD. Circ at 6 bpm, 1,100 PSI, 40 RPM, 6.7K TRQ, ROT 115K, P/U 150K, SLK 100K. Obtain parameters 20 RPM 6.71K TRQ, 40 RPM 6.8K TRQ, 60 RPM 7K TRQ. Max Gas 32U.;PJSM RIH F/ 7,653' to 7,715' MD. Wash down at 2 bpm, 380 PSI F/ 7,715', took 7K weight at 7,730' Cont to 7,755' Press up to 540 PSI packed off, pulled 10K over to get free. Pulled to 7,715' was able to get returns. Pump at 4 BPM, 630 PSI, 40 RPM, 6.7K TRQ, stall set 15K, ROT 104K, 38% F/O.;Start washing down working tight spots at 7,730', 7,741'& 7,755'. At 7,761' saw slight packing off TRQ stall at 15K pulled 10K over to get free. Pulled up to 7,736' no issue. Wash down working tight spots to 7,750'. Cont washing with minimal issue to 7,781' MD. Adjust parameters to 20 RPM.;TRQ 7.6K, 4 BPM, 668 PSI, ROT 115K, 33.1 % F/O. Tagged 7,792'W/ 5K, Tagged at 7,796'2X W/ 5K down.;Rotate out at 20 RPM, 650 PSI, 9.51K TRQ, ROT P/U 122K, 33.1% F/O. Packed off at 7,770' TRQ 12K, trapped 720 PSI in string. Cont. fighting out of hole W/ string packing off erratic 10 to 12K TRQ stall W/ 20 RPM to shoe at 7,725' MD. Once in 7" Csg at 7,708' was able to achieve;good returns but 50 PSI increase in pump Press and 300-400 ft/lb increase in TRQ. Max Gas 835U.;PJSM Rot and Rec F/ 7,708' to 7,647' MD 5 BPM, 870 PSI, 20 RPM, TRQ 7.4K, 37.2% F/O ROT 112K. CBU Max Gas 815U. Saw only fines over Shakers at BU. Monitor well for 15 min, static.;PJSM POOH F/ 7,708' to 6,775' MD 20-40 ftm watching for swabbing. P/U 155K, SLK 95K. Pump Dry Job and Cont POOH F/ 6,775' to 5,523' MD. P/U 113K, SLK 83K. Blow down Geo Skid to clear any debris from nut plug sweeps.;Daily hauled 57 bbis to G&I total = 5,054 bbls Hauled 0 bbls H2O from B -Pad Creek total = 5330 bbls Hauled 0 bbls H2O from K -Pad lake, Total = 130 bbls Hauled 130 bbls from 6 mile lake, Total 520 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls 10/17/2019 Continue POOH F/5523'- T/ Surface. UD 6-118" cleanout assy BHA. 6-1/8" Milltooth Bit showed 2 chipped cutters indicating good tag on fish. Hole took proper displacement for trip.;Clean and clear rig floor. Bring tools and equipment to rig floor. C/O inserts to 3.5" on hydraulic elevators.;M/U XO w/ TIW, Stage same. M/U perforated 3.5" tubing orange peel shoe (29.89' length) w/ 15 jts 3.5" EUE, 9.3#, L-80 tubing and 3.5" EUE X HT38 crossover (498.21' total length of cement stinger assy).;C/O inserts to 4" on elevators. RIH w/3.5" cmt stinger F/ 498'-T/ 7685' MD.;Obtain parameters - 4 bpm, 510 psi, 20 rpm, 6.9k tq. Attempt to wash down F/ 7685' tag up @7755' MD. Packed off, pulled 35k over to get free. Increase pump to 5 bpm, 690 psi and wash down staging in hole 10-15' at a time then pullback into shoe each time. Seemed to cleanup open hole section.;Tag @ 7766' w/ packoff and 30k overpull backup into shoe. Stage up pumps to 12.25 bpm, 2590 psi and pick up to 7710' MD. Circulated 2.5x btms up. Shakers unloaded @ btms up initially with fines became more coarse throughout 1st btms up and 1/2 of 2nd btms up before cleaning up. Sand/Shale.;Wash down @ 1/2 bpm F/7710 - T/ TOF @7795' without issue. Tag 2x w/ 5k TOF. 141k up, 95k dn.;PJSM Blow down Top Drive. P/U 4" working single. RIH to TOF at 7,795'. Kelly up W/ 5' pup and pump in sub to string. R/U Halliburton valves and cement line. Stage pumps up to 4.5 bpm 815 PSI packing off. Work drill string W/ 25K over SLK 20K to establish intermittent returns at 2 bpm 330 PSI.;PJSM Cont trying to get to 4 bpm W/ out success. Park string at 7,795'. Stage pumps up F1 0.5 to 2 bpm 400 PSI to establish Circ. Shut down for 3 min and stage pumps up F/ 0.5 to 2 bpm 380 PSI with good returns. Attempt to get to 3 bpm, packed off at 2.9 bpm. Shut down and Press bled right down.;Waited for 3 min and started pumping at 1 bpm W/ immediate returns. Shut down for 1 min and started pumping at 1.5 bpm W/ immediate returns. At 1.5 bpm 300 PSI.;Stage up to 2 bpm 370 PSI. PJSM for cement job. Halliburton pump 5.5 bbls H2O at .75 bpm, 250 PSI. PT lines W/ 500 PSI low kick out, 5th gear stall 1,300 PSI, PT to 4,000 PSI for 3 min, good. Pump 5.5 bbls 11.2 ppg mud push to Halliburton. Line up W/ rig pumps and pump 24.5 bbls 11.2 ppg Mud Push at;1 bpm 220-240 PSI, 1.5 bpm ICP 330 PSI dropping to 280 PSI, 2 bpm FCP 280 PSI. Line up to Halliburton, pump 10.5 bbls 15.8 ppg (65 sks) 1.154 ft/sk G Neet at 1 bpm 190 PSI, 1.5 bpm 267 PSI, pump 5.5 bbls 11.2 ppg mud push at 1.5 bpm 56 PSI. Rig pumped 68 bbls 10.0 ppg mud at 1.25 bpm;caught Press at 17 bbls away 32 PSI. Saw slight Press increase F/ 60 PSI to 127 PSI falling off to 36 PSI at 27 bbls away. Return flow increased F/ 5% to 9%. Slowly increased rate to 1.7 bpm 62 PSI. At 49 bbls away saw slight Press spike to 320 PSI, Slowly walked pumps down to 0.5 bpm inaintaining;80-100 PSI to 66.5 bbls away. Observed Press fall to 21 PSI till pumps off at 68 bbls leaving 2 bbls under displacement. FCP 21 PSI. CIP at 23:30. Verified no flow and well balanced.;PJSM UD working single F/ 7,795' to 7,769' MD at 5 fpm. P/U 155K. POOH on elevators F/ 7,769' to 7,707' at 5 fpm well slightly swabbing. Stopped swabbing and was static while pulling F/ 7,707' to 7,636'. Fluid stared falling at 7,575' pulling 5 fpm. Cont, pulling on elevators F/ 7,575to 7,392' MD;with fluid falling on back side. P/U 138K, SLK 94K.;Drop wiper ball and pump down string at 3 bpm staging up to 9 bpm 1,450 PSI. Dumped 23 bbls of looked to be mud push W/ 10.9 PH and 10.8 ppg MW at BU. Cont pumping for Surf to Surf but did not see wiper ball. Monitor well for 10 min, static.;PJSM POOH on elevators W/ 4" D.P. F/ 7,392' to 498' MD. P/U 39K, SLK 39K. No losses.;PJSM M/U X/O to 4" TIW. C/O Elevator inserts F/ 4" to 3.5".; Daily hauled 101 bbls to G&I total = 5,158 bbls Hauled 0 bbls H2O from B-Pad Creek total = 5330 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 130 bbls from 6 mile lake, Total 650 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls 10/18/2019 UD 3.5" EUE cmt stinger string from 498' to surface. Inspect for residual cmt in string (none noted). B/O and UD down orange peel shoe, clean same.;C/O handling equipment to 4". Bring tools to rig floor for upcoming BHA run.; PJSM, M/U 6-1/8" Mtr assy. 6-1/8" PDC (Hycalog 513), Sperry Drill mtr w/ 1.5° bend. M/U MWD and scribe same (160/481"360=119.75° RFO), Float sub (Non ported / Plunger), 2x NM Flex DC's, XO, 3x 4" HWDP w/jars(SLB). Shallow pulse test (test good) 170 gpm, 670 psi. (Total Length BHA = 293.37').;RIH F/ 293'- T/ 7062' MD w/ 6-1/8" mtr assy on 4" HT38 dp out of derrick. Fill every 25 stds.;PJSM Cut 12 wraps 75' drilling line. Accumulated 14,714 ton miles. 2,406' left on reel. Check and adjust air brake gap. Grease Crown, Blocks and Top Drive. Disconnect Spinner Hydraulics due to bad roller bearing. Order parts.;Wait on cement. PJSM SIMOPS Replace Stucci fitting on service loop connection. Check traveling block wobble. Inspect J Box on Top Drive for Hydraulic oil. Un hang Blocks. Calibrate block position sensor. Perform housekeeping. Inspect hydraulic elevators found sensor needing repair.;Install manual elevators.;PJSM RIH 4" D.P. F/ 7,062' to 7,372' MD rabbit pipe F/ Derrick. (2.375" OD) P/U 146K, SLK 94K,;PJSM Obtain parameters. 210 GPM, 1,530 PSI, 20 RPM 7K TRQ, ROT 114K, P/U 146K, SLK 94K. Wash down at 126 GPM, 800 PSI F/ 7,372' to 7,625' MD at 3 ft/min. Saw some cement stringers W/ 200 PSI spikes in Press. Calc. TOC 7,575' MD,;Reciprocate pipe F/ 7,625' to 7,565' MD CBU at 168 gpm, 1,130 PSI, P/U 145K, SLK 97K 35% F/O. During BU had elevated PH 11.5, MW 10.8 ppg. Appeared to have lightly contaminated cement coming across shakers W/ constancy of green cement.;PJSM Wash down F/ 7,625' to 7,704' MD at 168 gpm, 800-850 PSI, 5 ft/min at 7,704' Press jumped to 1,200 PSI and set down 5K 2X. P/U 143K, SLK 99K.;Attempt to drill cement F/ 7,704' to 7,720' MD 200 gpm, 1,600 PSI, 20 RPM, TRQ 7.5 to 8K, 150 ROP. P/U 143K, SLK 99K. Initial WOB 5K tapering off to 2-3K. Stop drilling and discussed further operations W/ town, Decision was made to WOC.;Reciprocate F/ 7,720' to 7,681' MD CBU at 150 GPM, 975 PSI, P/U 145K, SLK 100K. At the shakers saw very firmed up cement cuttings coming over Shakers.;PJSM racked back one stand 4" D.P. to 7,686'. Installed FOV and found slight flow in string. Appeared floats were not holding. Made several attempts to cycle pumps and work string. It had slowed down the flow. Circ. a drill string volume and appeared to help, noticed slight cement at shakers.;Started rotating at 20 RPM, 6.7 to 7.5K TRQ, 180 GPM, 1,200 PSI and saw very firm cement at shakers. Appeared hole was slightly loaded up without rotation. WOC Work around the rig and housekeeping.; Daily hauled 92 bbls to G&I total = 5,250 bbis Hauled 130 bbls H2O from B-Pad Creek total = 5,460 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 0 bbls from 6 mile lake, Total 650 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls 10/19/2019 Rot & Rec F/ 7,686' to 7,672' MD. Pump 20 bbl H2O pill to clear floats. Cycle pumps while going through floats. Spot H2O on backside. 150-250 GPM, 920- 1,810 PSI, P/U 145K, SLK 101 K, ROT 117K.;PJSM Flood choke and kill lines. Rack back stand to 7,627' MD. Shut Annular and test floats to 500 PSI, good. Bleed and blow down choke.;Wash down F/ 7,627' tag TOC at 7,720' set down 5K 2X. 125 GPM, 700 PSI, P/E 154K, SLK 100K.;PJSM Drill cement F/ 7,720' to 7,727' MD 150 GPM, 1870 PSI, 20 RPM, TRQ 7K, WOB 2-4K. Observed Press increase 870-1,300 PSI stacking WT 8K at Shoe 7,725' MD. Work through Shoe multiple times variating parameters 200 GPM, 1,340 PSI, 80 RPM, TRQ 7K. After multiple passes TRQ and Press;cleaned up slightly. Stared drilling on plug to 7,730' MD.;Slide drill F/ 7,730' to 7,750' MD at 10 FPM, 200 GPM, 1,415 PSI, TRQ 1.8K, WOB 0-7K, P/U 154K, SLK 100K. Packed off at 7,750' working pipe multiple times and unable to establish Circ or ROT. Pulled 25K over SLK 15K to establish rotary W/ out stall at 10K limit. P/U 5K over ROT WT.;Cont. working to shoe with slight flow at .25 bpm. Was able to pull back into shoe without over pull. P/U 154K, SLK 101 K, ROT 117K.;PJSM CBU 2X 265 GPM, 2,117 PSI, 50 RPM, TRQ 7.5K, ROT 114K, P/U 154K, SLK 101 K. Observed slight fines at shakers.;PJSM Monitor well, static. POOH on elevators F/ 7,680' to 293' MD Pull initial 10 stands no swabbing. Pump dry job, did not work. POOH wet. P/U 154K, SLK 94K, No losses. Rack back jars and HWDP.;PJSM Rack back FC, L/D ILS and Float Sub, down load MWD. Rack back MWD & LWD tools in Derrick. Milk motor and L/D 6 1/8" Bit 0-1-CT-S-E-1- NO-HP.;PJSM Grease Crown, Blocks, Top Drive. Clean and clear rig floor. C/U manual elevators to hydraulic 4".;PJSM Make up Baker 7" CBP Baker K-1 Mech 12.13' to X/O 3.5" IF to HT 38 13.54'. RIH W/ 4" D.P. to 7,630' MD P/U 149K, SLK 95K at 60-80 FPM as per Baker Rep onsite. No losses.;PJSM Set CBP at 7,630' MD. P/U 95K, SLK 150K. Start W/ 10 RPM TRQ set at 7K. Set 12 wraps in string W/ 6.7K TRQ. Set down 5K, P/U 20K over set lower slips. SLK down 20K. Pull over 30K W/ upper slips set. SLK down 30K, Pull 40K, SLK 40K.;Pull 40K over. SLK to 125K ROT at 15 RPM W/ 15 Wraps to pull out of CBP Set at 7,628' top of CBP. Rack Back one stand to 7,593' MD.;PJSM R/U FOV and Head Pin to drill string. R/U test Equip and hose. Flood choke and kill lines working air out. Shut upper rams and test 7" Csg to 3,500 PSI for 30 Min on chart. R/D blow down test equip. Pumped 3.2 bbis, bled back 3.2 bbls.;Daily hauled 114 bbis to G&I total = 5,364 bbls Hauled 130 bbls H2O from B-Pad Creek total = 5,590 bbis Hauled 0 bbis H2O from K-Pad lake, Total = 130 bbis Hauled 0 bbis from 6 mile lake, Total 650 bbis Lost 0 bbis to formation Total fluid lost section = 0 bbis 10/20/2019 POOH F/ 7593' - T/ surface. Laydown CIBP running tool. Hole took proper displacement.; Clean and clear rig floor. Bring tools to floor and prep for whipstock run.;PJSM, M/U 6.125" window mill, 6" lower mill, flex jt, 6.151" upper mill, XO, ljt 4" HWDP, XO, Float (non port plunger). M/U Gen II (BOT) whipstock assy (#H15010006). Carry scribe and M/U MWD. 413/468x360=317.69° RFO. 35k lug whipstock, 4 pins anchor=14,260 Ib shear. M/U XO, 8jt 4" HWDP.;319.19' Total length for milling assy. 17.63' Total length of whipstock assy w/ anchor. Shallow pulse test (test good).;PJSM RIH W/ 4" D.P. F/ 320' to 7,482' MD. P/U 143K, SLK 96K. Fill every 2,500'.;PJSM Kelly up, pump rate at 250 GPM, 950 PSI, P/U 144K, SLK 94K. Orientate 31° LHS. Wash down and tag at 7,628' MD holding 31 ° LHS. Set down 15K and shear set Anchor. Pulled 15K over ensure anchor set, slacked back down and tagged 1' higher at 7,627' MD. Putting TOW 7,609' BOW 7,622'.;Work string W/ 10K over pull and 20K down to ensure anchor was set. Set down 38K to shear brass whipstock bolt. No over pull observed. Set and tag top of slide at 7,609' MD.;PJSM Start milling operations as per Baker Rep onsite. 250 GPM, 1,460 PSI, 80-100 RPM, TRQ 7K, F/O 43%, TRQ limit set at 9.5K. Start milling TOW at 7,609' WOB 100-200 Ib watching TRQ variate F/ 6.8 - 8.5K W/ intermittent stalls to 7,612' MD 2-3 FPH.;At 7,615' increase RPM to 100 RPM, WOB 1 K, ROP 2-3 FPH. TRQ 3- 9.1 K. F/ 7,620 to 7,626' 100 RPM, WOB 1-2K, 2-3 FPH TRQ smoothing out 6.9 - 8K. At 7,626' to 7,631' TRQ 8K WOB 3-4K. F/ 7,631' to 7,638' WOB 4-7K, TRQ 7K full gauge upper mill passing out of BOW, no issue.;F/ 7,638' to 7,645' 100 RPM, 250 GPM, 1,450 PSI, TRQ 7K, WOB 8K. ROT off bottom F/ 7,645' to 7,606'W/ 1-2K drag, Shut down rotary and worked string down W/ 1 K drag to 7,645'. Work string up saw 10K bobble at 7,626'. Turned pumps off and worked mills through window SLK 98K, P/U 158K.;saw 5K bobble at 7,624'. Dressed up area F/ 7,621' to 7,628'W/ 200 GPM, 1,080 PSI, 100 RPM, TRQ 6.6 -7K ROT 114K, SLK 110K. Worked string down no pumps no rotary F/ 7,594. to 7,642' with no drag. Pulled up with 1 K drag and no sign of bobble at 7,624'. TOW 7,609' BOW 7,622' MD Recovered 90# Metal.;Drilled new formation F/ 7622'- T/ 7645' (23').;Daily hauled 57 bbls to G&I total = 5,421 bbis Hauled 130 bbis H2O from B-Pad Creek total = 5,590 bbis Hauled 0 bbis H2O from K-Pad lake, Total = 130 bbis Hauled 130 bbis from 6 mile lake, Total 780 bbis Lost 0 bbis to formation Total fluid lost section = 0 bbls Daily Metal 90#, Total 90#. 10/21/2019 PJSM, Circulate and condition 1.5x btrns up Rot/Recip @ 7590'-7527' MD. 250 gpm, 1450 psi, 20 rpm, 6.5k tq. Pump 45 bbis 10.1 ppg / 300 vis sweep - On time w/ 200% increase.;B/D TDS. Perform 12 ppg EMW (FIT). R/U head pin w/ test equipment. Flood choke and kill lines. Shut upper pipe rams. Pump rate 7 bpm. Psi up to 700 psi (314 bbl pumped). Bled off 45 psi over 10 min (Good test). 3./4 bbl bled back. R/D test equipment. Chart and record same.;Monitor well (Static). POOH F/ 7590' - T/ 7276' MD. Pulled wet (good displacement). Pump dry job and B/D TDS.;Service rig - Grease traveling equipment, wash pipe, IBOP's, Drawworks and Iron Roughneck. Check oil inTDS (Good). Inspect "J" box on TDS (good).;Continue POOH F/ 7276' to surface. Racked back all 4" dp. B/O and L/D excess HWDP along with milling assy. Starter mill 1/16" under, Upper mill full gauge. Hole took proper displacement.; PJSM, M/U 6.125" HDBS MM55 5 blade PDC (.3835 TFA), 1.5° mtr (5/6-8.3 stg - Non Ported float), MWD, Float (non ported plunger), 2x NM Flex, XO, 2x HWDP, Jars, 1x HWDP. Total length BHA = 293.03' MD. Pump thru MWD to warm tool / Download.; Shallow hole test MWD 250 GPM, 830 PSI. Good detection.;PJSM RIH BHA #8 W/ 4" D.P. Ht 38 F/ 293' to 7,438' MD. P/U 144K, SLK 92K Filling every 2,500'. No Iosses.;PJSM Grease Crown, Remove Desiccant packs F/ J Box and seal up W/ silicone and duct tape.;PJSM Drain RCD, remove trip riser and install RCD bearing as per Beyond Rep onsite. Fill lines and and check for leaks, good. Monitor well, static.;PJSM Wash down F/ 7,438' to 7,595' MD 250 GPM, 1,925 PSI. P/U 148K, SLK 89K. Calibrate MPD Choke to rig watch. Simulate connections W/ rig crew and MPD to ensure good communication and understanding of operation. MPD holding 560 PSI W/ pumps off and 160 PSI W/ pumps on at 250 GPM, 1,925 PSI.;Orientate tool face 30° LHS W/ MPD holding 160 PSI for 11.5 ppg EMW.;SPR at 7,595'W/ MPD 11.5 ppg EMW. MP #1 32- 617 PSI, 48- 837 PSI MPD 283 PSI. MP #2 32- 604 PSI, 48- 824 PSI MPD 276 PSI.;With MPD holding 160 PSI EMW 11.5 ppg pumps off. Attempt to go through window W/ 30° LHS P/U 153K, SLK 86K tagged up 3X setting down 5K at 7,614' MD. Bled off MPD to zero and checked tools face. Attempted again adjusting tool face F/ 25° to 35° LHS 4X setting down 7-10K at 7,614' MD.;Tried rocking string 3X setting down 6K at 7,614' MD. Oriented 155° ROHS and was able to pass through window clean to 7,624' MD.;Wash down F/ 7,624' to 7,640' MD 174 GPM, 1,140 PSI. After MWD surveys showed inconclusive data as far as hole orientation. Discussion was made W/ town to drill head to determine well geometry. Slide drill to 7,644' MD. 250 GPM, 2,278 PSI.;Daily hauled 0 bbis to G&I total = 5,421 bbis Hauled 0 bbis H2O from B-Pad Creek total = 5,590 bbis Hauled 0 bbis H2O from K-Pad lake, Total = 130 bbis Hauled 130 bbls from 6 mile lake, Total 910 bbis Lost 0 bbis to formation Total fluid lost section = 0 bbis Daily Metal 55#, Total 165# 10/22/2019 QC survey package and baseline. Original svy @ 7551' , 46.43° Inc / New svy @ 7551' showed .4 lower. Interpolate svy @ btm of slide @ 7622' (50.79° Inc - A' variance = 49.68°). Drill ahead in new hole sliding 70° LOHS, 250 gpm, 2150 psi, 1-2k WOB, control drilling 50 fph F/ 7645'- T/ 7667' MD.; P/U to 7665' and obtain survey. Survey depth @ 7622' showed 47.55° Inc. Inclination indicates we exited lower side of casing with milling assy. 2.13° drop from interpolated svy @ 7622' (base of whipstock). Sperry MWD (David Booth) verified tool configuration was correct from whipstock run.;Discuss plan forward with drilling engineer. Continue drilling ahead gaining separation.; Cont Sliding from 7667' to 7763' MD, 260 GPM, 1250 PSI, 40 rpm, TQ 7.5k, WOB 2-10K, PUW 154K, SOW 89K, Rot 107K, holding 160 psi back pressure w/MPD f/11.5 PPG MW.; Encountered multiple pack offs between 7710'-7733'. Packed off and stalled out @ 7633'-7625'. Work and free pipe with 20K over pull. All issues occurred while sliding.;Work pipe and CBU while holding 170 psi back pressure. 260 GPM, 2210 PSI, 60 RPM, Tq 7.2K, PUW 154K, SOW 89K Rot 107K. Hole unloaded Shales and fines at Btm Up.;Drill from 7763' to 7860' Feather into ROP while sliding starting @ 10 fph staging to 50 fph Max ROP. slight pack offs at 1st but cleaned up. Rotate out slides starting @ 15 fph staging up 75 fph Max ROP. Obtained optimal Control Drilling parameters @ 50 FPH ROP Sliding and 75 FPH ROP Rotating.;PJSM Slide & Rot 6.125" Production Hole F/ 7,680' to 8,001' MD ( 6,920' TVD) total 321' (AROP 53.5') 260 GPM, 2,340 PSI, 60 RPM, TRO 7.5K, WOB 2-6K. P/U 149K, SLK 85K, ROT 109K. Max Gas 947U. MPD 100 PSI pumps on,pumps off 560 PSI 11.5 ppg EMW W/ 10.1 ppg MW.;Rotary drill 75 fpf max, slide drill 35 fph max. Set TRQ limit 10.9K, Press limit 2,600 PSI. Keeping close eye in Diff Press around 50-180PS1. Feather WOB. Saw slight Press spikes but not packing off. At 7,468' MD saw max Gas 485U at BU.;Perform check shots for MWD at 7,936'.;PJSM Slide & Rot 6.125" Production Hole F/ 8,001' to 8,078' MD ( 6,949' TVD) total 77' (AROP 14') 260 GPM, 2,340 PSI, 60 RPM, TRQ 7.5K, WOB 2-6K. P/U 154K, SLK 85K, ROT 107K. Max Gas 114U. MPD 100 PSI pumps on,pumps off 560 PSI 11.5 ppg EMW W/ 10.1.ppg MW.;Rotary drill 75 fpf max, slide drill 35 fph max. Encountering torque and hard spots while drilling ahead. Perform check shots for MWD at 7,998' & 8,061' MD.;Sliding 20-21 ft to 7874'. Motor output 15.38° per 100/ft. Doglegs on surveys about 4.8°.Cut back to 14-15 slides. Motor output 13.98° per 100/ft. Dogleg dropped to 3.75° by 7950'. We are ahead about 1.5° dogleg to land at 8510' MD. Plan called for 3.59° but builds above reduced the dogleg required.;Sliding cut back to 10ft slides to come in closer to plan at 8510'. Distance to WP07 9.29', 7,47' High, 5.51' Left.;While drilling ahead W/ rotary at 8,078' encountered pack off and stall . Working drill string F/ 8,078' to 8,074' unable to rotate and Circ. Cycling pump Press up to 2,000 PSI and trapping 10.5K TRQ working string W/ 10-30K overpull. MPD holding --500 PSI back Press.;Daily hauled 171 bbls to G&I total = 5,592 bbls Hauled 0 bbls H2O from B-Pad Creek total = 5,590 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 130 bbls from 6 mile lake, Total 1,040 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls Daily Metal 75#, Total 240# 10/23/2019 Continue attempt to free pipe and gain circulation. Work pipe from 8078' to 8074'. Unable to establish rotation or circulation. Attempt multiple methods to free pipe before jarring.;Begin jarring on string Staging up from 184k (30k over) to 250k( 95k over). Hold pressure on back side with MPD periodically, and 2350 psi on drill string periodically. Jars hitting good but no pipe movement. Mobilize BOT fishing and AK E-line for back off ops.;Discuss options. Due to tool joint 25' above rotary, perform a blind back off on the 3 1/2" IF connection below the HT-38 Jars. Using 10K target range, start with 2 LH Wrap @ 4K working Tq down. Work up to 7 wraps and 8K Tq down string and see back off. PU and establish rotation and circulation.; Rack back 1 stand to 8064'. Rotate 100 rpm, 12 bpm, 2360 psi, 6.2k Tq, PUW 150, SOW 80k, Rot 1.3k, pumping 20 bbls 10.1 ppg, 240 vis sweep around.; No substantial change in return cuttings on entire circulation. Sweep back on time with no substantial change. No running shales ect. Hole appeared to be clean prior to sticking.; POOH from 8001' to 7,500', checking every connection for proper TQ. Pulled clean through window.;PJSM Remove RCD Bearing and strip off stand. Install trip nipple. Monitor well, static.;PJSM Inspect Derrick crown to ground after jarring operations. Everything looked good. Service rig. Grease Crown, Blocks and Top Drive.;PJSM Cont. POOH F/ 7,500' to backed off 4" HT 38 D.P. Left 3 Jnts 4" D.P. and BHA #8 estimated (386.71') TOF at 7,691' MD. Checking TRQ every connection. All tight. Correct Disp.;PJSM P/U M/U Fishing BHA HT 38 cut lip sub, Circ Sub (Rupture 2,800 PSI) 6 ea 4 3/4" DC, 4 3/4" Cobalt Energizer and X/O Sub (2003) as per Baker Rep onsite. Drift 4 3/4" DC W/ 1.95" OD Drift.;PJSM RIH W/ 4" D.P. F/ 200' to 7,534' MD. Correct Disp.P/U 154K, SLK 98K.;CBU washing down F/ 7,534' to 7,598' MD 320 GPM, 1,350 PSI, 20 RPM, TRQ 7.4K. F/O 47%. P/U 145K, SLK 98, ROT 111 K No Gas seen at surface and shakers clean.;RIH W/O pumps F/ 7,598' to 7,660' MD Start pumping at 1 bPM, 350 PSI, Tag TOF at 7,692' P/U 145, SLK 98. Check space out for running ELine, good.;Put 10.5K TRQ in string and work TRQ down to engage fish W/ HT 38 cut lip as per Baker Rep onsite. P/U 20K over to ensure fish on. Release TRQ out of string.;Set down 10-15K down and pulled over 50-60K to try and fire Jars. Jars would not fire. Work string setting down 43K ( 55K) and over pulling 40 to 80K over (194K to 234K) to get jars to fire. Jarring W/ 30K (59K) down and pulling; F/ 80 to 100K (234K to 255K) over W/ and W/O pump Press 600 PSI to 1,000 PSI several times. Intermittently straight pulling 146K over (300K) with no movement. Blow down Top Drive. Perform Derrick inspection.; Daily hauled 57 bbls to G&I total = 5,649 bbls Hauled 0 bbls H2O from B-Pad Creek total = 5,590 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 130 bbls Hauled 130 bbls from 6 mile lake, Total 1,170 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls Daily Metal 0, Total 240# 10/24/2019 Jarring W/ 30K (59K) down and pulling F/80 to 100K (234K to 255K) over W/ and W/O pump Press 600 PSI to 1,000 PSI several times. Intermittently straight pulling 188K over (322K) with no movement,;Blow down Top Drive. Perform Derrick inspection. Inspect welds on Cradle and Derrick, good.;PJSM Spot Pollard Eline unit and P/U tools and Equip to rig floor.;Work 6K left hand torque in drill string. (5.25 Wraps) Lock rotary table and set slips. UD 4" single. R/U Eline sheave in elevators. M/U ELine head, CCL and String Shot W 560 Grain 7 strands. 1.5' to middle pack off.;PJSM RIH W/ String Shot and locate collars. space out and fire string shot at 7,910' and bottom at 7,913' WLM in between 4 3/4" NM FC in the BHA. POOH verify string shot went off. P/U M/U Single Jnt 4" D.P. P/U string W/ top drive brake on 3.5K TRQ on string. SLK 97K.; Put 1 wrap left handed in string to 6K TRQ. P/U drill string free of TRQ. P/U 140K, SLK 97K. Original up weight 154K lost 14K string weight.;Unsure where string backed out. Set TRQ limiter to 10K and rotate working down torque into string W 10K down and 10K over pull. Let out trapped trq. P/U 185K and set down in slips W/ 31 K in tension. UD single and blow down top drive.;PJSM R/U Pollard ELine tools and Equip. RIH W/ 1.75" Drill Collar Severing Tool. Fire shot at 7,879' WLM at collar between the 2 jnts 4" HWDP. Leaving 1 Jnt 4" HWDP, Jars, 1 4" HWDP and 3 Jnts 4" D.P. to fish. String did not jump at surface. POOH W/ Eline, Tool did fire. R/D tools and Equip.;PJSM Work string trying to get jars to fire. Work string W/ 30K (59K) down and pulling F/ 80 to 171 K (234K to 326K) over W/ and W/O pump Press 600 PSI to 1,500 PSI several times. During attempts was as able to get 4 bpm Circ but packed off when adjusted to 6 bpm. Was able to stage up to 3 bpm.;490 PSI for 208 bbls almost 1.5 BU. Max Gas 371 U. Lost Circ. during working string trying to get jars to fire. Worked 11 K TRQ in string W/ 1,500 PSI working string to try establish Circ. unable. Decission was made to attempt to back off between D.P. above Jars. Blow down top drive. M/U 5' Pup;below working single.;PJSM Work 6K left hand torque in string W/ 5.25 wraps working string F/ 80K to 140K. Set string in compression W/ 21 K in slips. Break out top drive and UD single.;PJSM R/U ELine sheave and tools. RIH W1 CCI and 3' String Shot 2' F/ CCL to center of String Shot (560 Grain 7 strands) 175 ft/min. Made 3 passes at 40 ft/min. correlation correction 2.5'. Set string shot at 7,754' WLM at tool joint. In between 2nd and 3rd Jnt of 4" D.P. above BHA.;No visual indication on rig floor. Saw line jump in unit. POOH W/ ELine. Visual at surface String Shot fired.;P/U M/U Single Jnt 4" D.P. P/U string W/ top drive brake on 6K TRQ on string P/U 165K, SLK 110K. Put .25 wrap left handed in string to 6K TRQ. Work TRQ down W/ 80K down and 150K up. Put another .75 wraps for a total of 6 wraps P/U lost 2.2K TRQ and string weight 121 K, SLK 89K.;Original up weight 154K lost 33K string weight. Unsure where string backed out.;Set TRQ limiter to 10.5K and rotate 15 RPM 5.1 K TRQ, working down torque into string W 10K down and 10K over pull. Let out trapped trq. P/U 30K over and SLK 30K. Work 6K left hand torque in string W/ 6 wraps working string F/ 80K to 125K.;Set string in compression W/ 21 K in slips due to tool joint placement. Break out top drive and UD single. Blow down Top Drive.;PJSM M/U Sheave and Eline in elevators. Pollard redress their head and M/U string shot. SIMOPS Perform monthly inspection on MP #2 and agitator.;Daily hauled 0 bbls to G&I total = 5,649 bbls Hauled 0 bbls H2O from B-Pad Creek total = 5,590 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 0 bbls Hauled 0 bbls from 6 mile lake, Total 1,170 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls Daily Metal 0, Total 240# 10/25/2019 RIH W/ CCI and 2' String Shot 2' F/ CCL to center of String Shot (560 Grain 7 strands) 175 ft/min. Made 2 passes at 75 & 40 ft/min. no correlation correction. Set string shot at 7692' WLM at crew in sub. No visual indication on rig floor. Saw line jump in unit. POOH W/ ELine.;Visual at surface String Shot fired.;P/U M/U Single Jnt 4" D.P. P/U string W/ top drive brake on 6K TRQ on string P/U 165K, SLK 110K. Put 1 wrap left handed in string to 6K TRQ. Work TRQ down W/ 80K down and 140K up. Will working TRQ down P/U lost 3K TRQ and string weight 119K, SLK 89K.;Original up weight 154K lost 35K string weight. Unsure where string backed out. Set TRQ limiter to 11.1 K and rotate 15 RPM 5.1 K TRQ, working down torque into string W 10K down and 10K over pull. Let out trapped trq. PIU 30K over and SLK 30K.;Trap 5K right hand TRQ in string W/ 10K in slips. Break out single and UD. Blow down Top Drive. R/U Pollard sheave and tools. RIH W/ 1.75" Drill Collar Severing Tool to 7,698' MD 6' below screw in sub. POOH. Tool fired.;M/U single. P/U W/ 30K over pull. Attempted to Circ. at 0.5 bpm packed off W/ 500 PSI. Set TRQ to 12K and work TRQ down. Pipe free at 7,698'W/ 20K over pull and saw 100K of drag for 40' (7,658' MD). Press dropped on drill string and started pumping at 4 bpm, 750 PSI. P/U 154K, SLK 98K.;POOH F/ 7,638' to 7,590' MD No issue going through window. (BOW 7,622' TOW 7,609') P/U 154K, SLK 98K.;CBU at 7,590' MD. 12 bpm, 2,370 PSI, P/U 136K, SLK 88K. Nothing seen at shakers.;PJSM Blow down top drive. Slip and cut 82' 13 wraps. Accum TM 14,714. 2,406' on reel. Check brake gaps. Inspect and Grease Crown, Top Drive and check oil level.;PJSM POOH W/ 4" D.P, F/ 7,590' to 200' MD. No losses.;PJSM UD fishing BHA as per Baker Rep onsite. Cut 4" D.P. length 6', widest flare on cut 4.5". Circ Sub was sheared and was unable to back out screw in sub from cut joint.;PJSM P/U 4" test jnt and pull Wear Bushing. Install test plug. M/U to 4" test jnt Side entry, 4" TIW, Dart, and test sub to top drive. Flood lines. Attempted to drain stack and had issue W/ annular valves. Had to Circ out mud W/ H2O.;PJSM Perform BOPE test W/ 3.5" & 4" to 250 PSI low and 3,500 PSI high for 5 Min. Tested Choke Manifold 1-15, 5" Dart, 5" TIW, Upper and lower IBOP, Mez Kill, HCR and manual Choke and Kill, manual and Super Choke, Upper and lower VRB Rams (2,875" X 5.5") Blind Rams, Annular W/ 3.5" test Jnt.;Koomey draw drown Initial System 3,000 PSI, Manifold 1,500 PSI, Annular 1,425 PSI, after System 1,575 PSI, Man 1,575 PSI, Annular 1,400 PSI. 200 PSI increase 24 Sec, full charge 80 sec. Nitrogen 6 bottle average 2,400 PSI. Test H2S 10-20 ppm, LEL 20-40%, PVT high/ low level alarms.;Witnessed waived by AOGCC Rep Jeff Jones.;Daily hauled 622 bbls to G&I total = 6,271 bbls Hauled 0 bbls H2O from B-Pad Creek total = 5,590 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 0 bbls Hauled 0 bbls from 6 mile lake, Total 1,170 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls Daily Metal 0, Total 240# 10/26/2019 Cont. R/D test Equip. Pull test plug. Blow down Choke and Kill lines.;Service rig. Grease top drive and inspect Drawworks. Check oil in top drive. Perform weekly inspection on Iron Roughneck.; Inspect upper annular valve for blockage. May have minor debris. Set wear ring and RILDS. UD test joint.;P/U M/U Baker 7" K-1 Cast Iron Cement Retainer 12.47' as per Baker Rep onsite.;Rlh W/ CIBP W/ 4" D.P. F/ 13' to 7,524' MD 60-90 f 1min as per Baker. P/U 77K, SLK 68K. Checking TRQ in each connection, good. No Iosses.;P/U working single to space out at 7,554' MD. Set CICR as per Baler Rep onsite. P/U 143K, SLK 98K, ROT 117K. 15 RPM, TRQ 7K. Attempt to establish injection rate at 0.5 bpm Press. climbed to 1,000 PSI. Shut down and UD Single.;PJSM for cement job. Halliburton pumped 5 bbls H2O at 2 bpm 475 psi, Low Pres test 1,108 PSI, high 2,508 PSI. Rig pumped 13.8 BBLS 11 PPG CLEAN SPACER /a at 4 BPM 650 PSI, HAL pumped 15 BBLS 15.8 PPG G Premium 75 SKS 1.154 Y. 4-974 GPS @ 3 RPM 820 PSI, 5 BBLS H2O at 3 BPM 100 PSI.;Rig pump 6.2 BBLS OF Clean Spacer at 3 BPM 60 PSI, pump 60 BBLS 10.1 PPG mud at 6 BPM 720 PSI FCP 690 PSI. CIP at 18:25. Calc. TOC 7,161' MD.;PJSM R/D cement lines. UD working single, POOH on elevators at 20 fpm F/ 7,535' to 6,971' MD.;Drop wiper ball and Circ. at 9 bpm, 900 PSI for 2X BU. Dumped 8 bbls of interface Mud Push at BU. Blow Down top drive.;WOC to achieve 500 PSI in 5.5 Hrs. SIMOPS R/U and flush annular valve W/ charge pumps clearing debris out. PM Tuggers, Catwalk wench and Iron Roughneck. Clean drip pan.;PJSM M/U Test Equip. Fluid pack lines and purge air from system.;PJSM Test 7" Csg and cement plug at TOC 7,161'Press up to 1,500 PSI for 30 min on chart. Pumped 1.45 bbls, bled back 1.45 bbls. R/D test Equip. Blow down Iines.;PJSM Displace 10.0 ppg mud W/ 25 bbis 11.0 ppg 235 Vis sweep and 235 bbls 8.5 ppg Seawater taking return overboard at 336 GPM, ICP 1,500 PSI FCP 950 PSI. P/U 139K, SLK 96K. Monitor well for 10 min, static.;PJSM POOH laying down 4" D.P. FI 6,971' to 4,900' MD. P/U 105K, SLK 84K, Calc Disp.;Daily hauled 171 bbls to G&I total = 6,442 bbls Hauled 0 bbls H2O from B-Pad Creek total = 5,590 bbls Hauled 0 bbls H2O from K-Pad lake, Total = 0 bbls Hauled 0 bbls from 6 mile lake, Total 1,170 bbls Lost 0 bbls to formation Total fluid lost section = 0 bbls Daily Metal 0, Total 240# 10/27/2019 Cont UD 4" D.P. F/ 4,900' to 1,175' MD. P/U 52K, SLK 49K.;RIH 4" F/ Derrick F/ 1,175' to 3,965' MD. P/U 86K, SLK 74K.;POOH UD 4" D.P. F/ 3,965' to K-1 running Assy. UD running Assy as per Baker Rep onsite.;P/U 5" jnt and pull wear ring. P/U 3.5" EUE jnt and dummy run tubing hanger. Swapped out hanger to new hanger due to questionable threads on original. Ensure hanger seated in well head properly as per NOS onsite.;PJSM P/U R/U Weatherford Power Tongs, slips, 3.5" elevators and prep Pipe Shed for running 3.5" Kill String.;PJSM RIH 3.5" 9.3# L-80 8rd EUE Tubing to 2,478' MD. P/U 52K, SLK 50K. P/U M/U Hanger and install control line plugs, dummy penetrator and TWC. Drain Stack and land Hanger 16K landed weight. NOS verified Hanger landed RILDS. 3.5" Kill String at 2,507' MD. UD 3.5" Landing Jnt.;PJSM UD Weatherford tools and Equip. Use soap and H2O to flush surface lines, Kelly Hose, Choke Manifold and Kill line. Blow down all lines. SIMOPS Clean Pits, start moving mud products and misc to F Pad.;PJSM Remove Mouse Hole, clean flow box and remove MPD hard lines. Pull Riser and install RCD cap.;PJSM Drain stack and remove Kill and Choke lines. Remove drip pan and hoses. N/D BOPE and set on pedestal. Remove MPD and DSA F/ cellar. SIMOPS Cont. Pit cleaning. Rebuild pop off on MP #2. Lay matt boards and herculite on F-116.;PJSM Install dry hole try. Test Tree. Freeze Protect Well.; Daily hauled 788 bbls to G&I total = 7,230 bbis Hauled 0 bbis H2O from B-Pad Creek total = 5,590 bbis / S f� Hauled 0 bbis H2O from K-Pad lake, Total = 0 bbls � Li Hauled 130 bbis from 6 mile lake, Total 1,300 bbis v Lost 0 bbis to formation Total fluid lost section = 0 bbls Daily Metal 0, Total 240# Hilcorp Alaska, LLC Milne Point M Pt K Pad MPU K-44AP131 MPU K-44APB1 500292356770 Bp►erry Drilling Definitive Survey Report 05 November, 2019 HALLIBURTON Sperry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU K44 Project: Milne Point TVD Reference: MPU K-44AActual RKB @ 55.60usft (Innovation) Site: M Pt K Pad MD Reference: MPU K-44AActual RKB @ 55.60usft (Innovation) Well: MPU K-44 North Reference: True Wellbore: MPU K-44APB1 Survey Calculation Method: Minimum Curvature Design: MPU K44APB1 Database: NORTH US + CANADA Project Milne Point, ACT, MILNE POINT Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well MPU K-44 Well Position +N/ -S 0.00 usft Northing: 6,005,880.17 usft Latitude: +E/ -W 0.00 usft Easting: 584,535.02 usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: Magnetics Design Audit Notes: MPU K44APB1 Model Name Sample Date Declination Dip Angle BGGM2018 9/16/2019 16.55 80.5 MPU K-44APB1 70° 25'33.570 N 149° 18' 40.034 W 29.30 usft Field Strength (nT) 57,416.37830038 Version: 1.0 Phase: ACTUAL Tie On Depth: 5,550.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction Vertical (usft) (usft) (usft) (°) TVD TVDSS 26.30 0.00 0.00 75.71 Easting Survey Program Date 11/5/2019 (usft) (I (I From To (usft) (usft) (ft) (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 127.30 498.26 MPK-44 Interp (MPK-44) 3_MWD _lnterp Azi+Sag H003Mb: Interpolated azimuth + sag correction 03/28/2016 593.64 5,550.00 MPK-44 MWD+IFR2+MS+sag (1) (MPK- 3_MWD+IFR2+MS+Sag H081 Ma: IIFR dec & multi -station analysis + sag 03/29/2016 5,610.00 7,706.40 MPU K-44APB1 MWD+IFR2+MS+Sag (1 3_MWD+IFR2+MS+Sag H081 Ma: 11 FIR dec & multi -station analysis + sag 10/30/2019 7,726.90 8,045.60 MPU K-44APB1 MWD+IFR2+MS+Sag (2 3_MWD+IFR2+MS+Sag H081 Ma: IIFR dec & multi -station analysis + sag 10/14/2019 Survey 11/5/2019 12:51:50PM Page 2 COMPASS 5000.15 Build 91 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 26.30 0.00 0.00 26.30 -29.30 0.00 0.00 6,005,880.17 584,535.02 0.00 0.00 UNDEFINED 127.30 0.33 35.07 127.30 71.70 0.24 0.17 6,005,880.41 584,535.18 0.33 0.22 3_MWD_Interp Azi+Sag (1) 217.55 0.14 35.07 217.55 161.95 0.54 0.38 6,005,880.72 584,535.39 0.21 0.50 3_MWD_Interp Azi+Sag (1) 314.29 0.14 35.07 314.29 258.69 0.73 0.52 6,005,880.91 584,535.53 0.00 0.68 3_MWD_InlerpAzi+Sag(1) 402.70 0.09 35.07 402.70 347.10 0.88 0.62 6,005,881.06 584,535.63 0.06 0.82 3_MWD_InterpAzi+Sag(1) 498.26 0.40 35.07 498.26 442.66 1.21 0.85 6,005,881.39 584,535.86 0.32 1.13 3_MWD_InterpAzi+Sag(1) 593.64 0.41 35.07 593.63 538.03 1.77 1.24 6,005,881.95 584,536.24 0.01 1.64 3_MWD+IFR2+MS+Sag (2) 687.61 0.33 59.69 687.60 632.00 2.18 1.67 6,005,882.37 584,536.66 0.19 2.15 3_MWD+IFR2+MS+Sag (2) 781.71 3.51 62.00 781.64 726.04 3.67 4.44 6,005,883.89 584,539.42 3.38 5.21 3_MWD+IFR2+MS+Sag (2) 873.29 3.72 59.90 873.04 817.44 6.47 9.49 6,005,886.75 584,544.44 0.27 10.79 3_MWD+IFR2+MS+Sag (2) 970.54 6.44 60.18 969.89 914.29 10.77 16.95 6,005,891.13 584,551.85 2.80 19.09 3_MWD+IFR2+MS+Sag (2) 11/5/2019 12:51:50PM Page 2 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU K-44 Project: Milne Point TVD Reference: MPU K-44AActual RKB @ 55.60usft (Innovation) Site: M Pt K Pad MD Reference: MPU K-44AActual RKB @ 55.60usft (Innovation) Well: MPU K-44 North Reference: True Wellbore: MPU K-44APB1 Survey Calculation Method: Minimum Curvature Design: MPU K-44APB1 Database: NORTH US + CANADA Survey 1115/2019 12:51:50PM Page 3 COMPASS 5000.15 Build 91 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (`) (1) (usft) (usft) (usft) (usft) (ft) (ft) (`/100') (ft) Survey Tool Name 1,064.65 7.19 59.23 1,063.34 1,007.74 16.41 26.59 6,005,896.87 584,561.42 0.81 29.82 3_MWD+IFR2+MS+Sag (2) 1,158.90 9.92 54.29 1,156.53 1,100.93 24.16 38.25 6,005,904.76 584,572.99 3.00 43.03 3_MWD+IFR2+MS+Sag (2) 1,253.31 13.85 51.79 1,248.90 1,193.30 35.90 53.74 6,005,916.68 584,588.35 4.20 60.94 3_MWD+IFR2+MS+Sag (2) 1,346.19 14.07 47.45 1,339.04 1,283.44 50.42 70.80 6,005,931.38 584,605.23 1.15 81.05 3_MWD+IFR2+MS+Sag (2) 1,441.04 17.25 57.75 1,430.38 1,374.78 65.72 91.19 6,005,946.92 584,625.45 4.44 104.59 3_MWD+IFR2+MS+Sag (2) 1,536.25 19.82 56.51 1,520.64 1,465.04 82.17 116.60 6,005,963.64 584,650.67 2.73 133.27 3_MWD+IFR2+MS+Sag (2) 1,630.37 21.66 54.34 1,608.66 1,553.06 101.10 144.02 6,005,982.88 584,677.87 2.12 164.52 3_MWD+IFR2+MS+Sag (2) 1,724.28 23.28 53.85 1,695.44 1,639.84 122.15 173.09 6,006,004.26 584,706.70 1.74 197.88 3_MWD+IFR2+MS+Sag (2) 1,818.33 23.16 54.11 1.,781.87 1,726.27 143.96 203.08 6,006,026.40 584,736.44 0.17 232.33 3_MWD+IFR2+MS+Sag (2) 1,913.35 27.58 60.21 1,867.72 1,812.12 165.85 237.33 6,006,048.69 584,770.43 5.40 270.92 3_MWD+IFR2+MS+Sag (2) 2,006.58 28.52 67.63 1,950.02 1,894.42 185.05 276.65 6,006,068.33 584,809.54 3.87 313.77 3_MWD+IFR2+MS+Sag (2) 2,100.88 30.13 74.89 2,032.26 1,976.66 199.80 320.34 6,006,083.56 584,853.05 4.14 359.74 3_MWD+IFR2+MS+Sag (2) 2,195.33 32.67 75.78 2,112.87 2,057.27 212.24 367.94 6,006,096.54 584,900.50 2.73 408.95 3_MWD+IFR2+MS+Sag (2) 2,289.98 34.98 74.94 2,191.50 2,135.90 225.57 418.91 6,006,110.45 584,951.31 2.49 461.63 3_MWD+IFR2+MS+Sag (2) 2,384.17 35.13 75.78 2,268.60 2,213.00 239.24 471.26 6,006,124.71 585,003.49 0.54 515.73 3_MWD+IFR2+MS+Sag (2) 2,478.77 35.02 75.73 2,346.02 2,290.42 252.62 523.95 6,006,138.68 585,056.02 0.12 570.09 3_MWD+IFR2+MS+Sag (2) 2,573.16 33.40 75.95 2,424.08 2,368.48 265.60 575.40 6,006,152.25 585,107.32 1.72 623.15 3_MWD+IFR2+MS+Sag (2) 2,667.37 33.35 76.18 2,502.75 2,447.15 278.08 625.70 6,006,165.29 585,157.47 0.14 674.98 3_MWD+IFR2+MS+Sag (2) 2,761.85 33.30 76.40 2,581.70 2,526.10 290.38 676.13 6,006,178.17 585,207.75 0.14 726.88 3_MWD+IFR2+MS+Sag (2) 2,856.59 33.14 76.15 2,660.95 2,605.35 302.70 726.55 6,006,191.05 585,258.03 0.22 778.78 3_MWD+IFR2+MS+Sag (2) 2,952.28 33.13 76.31 2,741.08 2,685.48 315.15 777.35 6,006,204.07 585,308.68 0.09 831.09 3_MWD+IFR2+MS+Sag (2) 3,044.57 32.98 76.91 2,818.44 2,762.84 326.80 826.32 6,006,216.28 585,357.51 0.39 881.42 3_MWD+IFR2+MS+Sag (2) 3,139.58 32.89 76.51 2,898.18 2,842.58 338.68 876.59 6,006,228.73 585,407.64 0.25 933.07 3_MWD+IFR2+MS+Sag (2) 3,234.08 32.30 76.66 2,977.79 2,922.19 350.49 926.11 6,006,241.10 585,457.02 0.63 983.97 3_MWD+IFR2+MS+Sag (2) 3,328.67 31.84 76.87 3,057.95 3,002.35 361.99 975.00 6,006,253.15 585,505.77 0.50 1,034.18 3_MWD+IFR2+MS+Sag (2) 3,422.91 32.11 75.94 3,137.89 3,082.29 373.72 1,023.50 6,006,265.43 585,554.13 0.60 1,084.08 3_MWD+IFR2+MS+Sag (2) 3,517.08 34.16 75.56 3,216.74 3,161.14 386.40 1,073.39 6,006,278.66 585,603.87 2.19 1,135.55 3_MWD+IFR2+MS+Sag (2) 3,612.04 34.31 76.28 3,295.25 3,239.65 399.39 1,125.21 6,006,292.24 585,655.53 0.45 1,188.98 3_MWD+IFR2+MS+Sag (2) 3,705.87 34.14 76.62 3,372.83 3,317.23 411.76 1,176.51 6,006,305.19 585,706.69 0.27 1,241.74 3_MWD+IFR2+MS+Sag (2) 3,796.89 33.88 77.33 3,448.28 3,392.68 423.23 1,226.11 6,006,317.22 585,756.15 0.52 1,292.64 3_MWD+IFR2+MS+Sag (2) 3,894.42 33.84 77.42 3,529.27 3,473.67 435.11 1,279.14 6,006,329.70 585,809.03 0.07 1,346.96 3_MWD+IFR2+MS+Sag (2) 3,988.24 34.21 76.67 3,607.03 3,551.43 446.88 1,330.30 6,006,342.05 585,860.05 0.60 1,399.44 3_MWD+IFR2+MS+Sag (2) 4,082.52 34.36 77.19 3,684.93 3,629.33 458.89 1,382.03 6,006,354.64 585,911.64 0.35 1,452.54 3_MWD+IFR2+MS+Sag (2) 4,177.20 32.99 75.74 3,763.72 3,708.12 471.16 1,433.07 6,006,367.49 585,962.53 1.68 1,505.03 3_MWD+IFR2+MS+Sag (2) 4,266.38 32.62 75.98 3,838.68 3,783.08 482.97 1,479.92 6,006,379.82 586,009.24 0.44 1,553.34 3_MWD+IFR2+MS+Sag (2) 4,367.26 31.79 76.90 3,924.04 3,868.44 495.58 1,532.19 6,006,393.02 586,061.35 0.96 1,607.10 3_MWD+IFR2+MS+Sag (2) 4,460.84 32.57 76.47 4,003.24 3,947.64 507.06 1,580.68 6,006,405.05 586,109.71 0.87 1,656.93 3_MWD+IFR2+MS+Sag (2) 4,555.65 33.60 75.78 4,082.68 4,027.08 519.47 1,630.93 6,006,418.03 586,159.81 1.16 1,708.68 3_MWD+IFR2+MS+Sag (2) 4,650.21 33.10 76.12 4,161.66 4,106.06 532.09 1,681.36 6,006,431.22 586,210.09 0.56 1,760.67 3_MWD+IFR2+MS+Sag (2) 4,744.74 33.54 76.51 4,240.66 4,185.06 544.38 1,731.81 6,006,444.08 586,260.39 0.52 1,812.59 3_MWD+IFR2+MS+Sag (2) 1115/2019 12:51:50PM Page 3 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU K-44 Project: Milne Point TVD Reference: MPU K-44AActual RKB @ 55.60usft (Innovation) Site: M Pt K Pad MD Reference: MPU K-44AActual RKB @ 55.60usft (Innovation) Well: MPU K-44 North Reference: True Wellbore: MPU K-44API31 Survey Calculation Method: Minimum Curvature Design: MPU K-44APB1 Database: NORTH US + CANADA Survey 7,488.68 43.94 78.33 6,629.84 6,574.24 772.71 2,952.10 6,006,686.20 587,477.91 3.44 3,051.49 3_MWD+IFR2+MS+Sag (3) 11/5/2019 12:51:50PM Page 4 COMPASS 5000.15 Build 91 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1 (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,838.73 34.23 76.88 4,318.68 4,263.08 556.43 1,782.80 6,006,456.71 586,311.24 0.77 1,864.99 3_MWD+IFR2+MS+Sag (2) 4,933.23 34.35 77.85 4,396.76 4,341.16 568.08 1,834.75 6,006,468.94 586,363.05 0.59 1,918.20 3_MWD+IFR2+MS+Sag (2) 5,027.35 33.76 76.44 4,474.74 4,419.14 579.80 1,886.13 6,006,481.24 586,414.29 1.05 1,970.89 3_MWD+IFR2+MS+Sag (2) 5,120.99 34.34 76.97 4,552.32 4,496.72 591.85 1,937.16 6,006,493.87 586,465.17 0.70 2,023.31 3_MWD+IFR2+MS+Sag (2) 5,212.13 32.72 76.12 4,628.29 4,572.69 603.56 1,986.12 6,006,506.13 586,513.99 1.85 2,073.64 3_MWD+IFR2+MS+Sag (2) 5,309.88 32.24 76.10 4,710.75 4,655.15 616.16 2,037.08 6,006,519.31 586,564.80 0.49 2,126.14 3_MWD+IFR2+MS+Sag (2) 5,404.73 33.16 75.79 4,790.57 4,734.97 628.61 2,086.78 6,006,532.32 586,614.36 0.99 2,177.38 3_MWD+IFR2+MS+Sag (2) 5,499.41 33.09 75.51 4,869.86 4,814.26 641.43 2,136.91 6,006,545.71 586,664.33 0.18 2,229.12 3_MWD+IFR2+MS+Sag (2) 5,550.00 33.18 75.62 4,912.23 4,856.63 648.32 2,163.69 6,006,552.90 586,691.03 0.21 2,256.77 3_MWD+IFR2+MS+Sag (2) 5,610.00 31.35 76.34 4,962.96 4,907.36 656.09 2,194.76 6,006,561.02 586,722.01 3.12 2,288.80 3_MWD+IFR2+MS+Sag (3) 5,657.63 29.90 76.96 5,003.94 4,948.34 661.69 2,218.37 6,006,566.89 586,745.55 3.12 2,313.06 3_MWD+IFR2+MS+Sag (3) 5,720.78 26.47 79.16 5,059.60 5,004.00 667.89 2,247.54 6,006,573.42 586,774.64 5.67 2,342.85 3_MWD+IFR2+MS+Sag (3) 5,770.13 24.30 80.48 5,104.18 5,048.58 671.64 2,268.35 6,006,577.40 586,795.41 4.54 2,363.95 3_MWD+IFR2+MS+Sag (3) 5,834.75 21.99 82.55 5,163.60 5,108.00 675.41 2,293.47 6,006,581.45 586,820.48 3.79 2,389.22 3_MWD+IFR2+MS+Sag (3) 5,897.66 19.38 82.69 5,222.45 5,166.85 678.26 2,315.50 6,006,584.56 586,842.48 4.15 2,411.27 3_MWD+IFR2+MS+Sag (3) 5,961.73 15.25 83.54 5,283.60 5,228.00 680.57 2,334.43 6,006,587.07 586,861.37 6.46 2,430.18 3_MWD+IFR2+MS+Sag (3) 6,025.24 11.74 85.52 5,345.35 5,289.75 682.01 2,349.17 6,006,588.68 586,876.10 5.57 2,444.83 3_MWD+IFR2+MS+Sag (3) 6,088.85 9.03 90.19 5,407.91 5,352.31 682.50 2,360.62 6,006,589.30 586,887.54 4.46 2,456.04 3_MWD+IFR2+MS+Sag (3) 6,153.01 6.18 90.94 5,471.50 5,415.90 682.43 2,369.11 6,006,589.33 586,896.03 4.44 2,464.25 3_MWD+IFR2+MS+Sag (3) 6,213.09 6.48 90.78 5,531.22 5,475.62 682.33 2,375.73 6,006,589.30 586,902.65 0.50 2,470.64 3_MWD+IFR2+MS+Sag (3) 6,277.35 6.90 91.58 5,595.04 5,539.44 682.17 2,383.22 6,006,589.23 586,910.14 0.67 2,477.86 3_MWD+IFR2+MS+Sag (3) 6,344.39 8.99 88.98 5,661.43 5,605.83 682.15 2,392.48 6,006,589.32 586,919.40 3.16 2,486.83 3_MWD+IFR2+MS+Sag (3) 6,405.21 11.45 84.31 5,721.28 5,665.68 682.84 2,403.24 6,006,590.12 586,930.15 4.26 2,497.43 3_MWD+IFR2+MS+Sag (3) 6,466.47 13.61 81.49 5,781.08 5,725.48 684.51 2,416.42 6,006,591.94 586,943.31 3.66 2,510.61 3_MWD+IFR2+MS+Sag (3) 6,534.53 16.21 84.04 5,846.84 5,791.24 686.68 2,433.79 6,006,594.31 586,960.65 3.94 2,527.98 3_MWD+IFR2+MS+Sag (3) 6,598.10 18.78 83.88 5,907.47 5,851.87 688.69 2,452.79 6,006,596.54 586,979.63 4.04 2,546.89 3_MWD+IFR2+MS+Sag (3) 6,661.24 21.66 82.27 5,966.71 5,911.11 691.34 2,474.45 6,006,599.43 587,001.25 4.65 2,568.53 3_MWD+IFR2+MS+Sag (3) 6,724.60 24.59 80.51 6,024.97 5,969.37 695.09 2,499.05 6,006,603.46 587,025.80 4.75 2,593.29 3_MWD+IFR2+MS+Sag (3) 6,788.53 27.17 79.95 6,082.49 6,026.89 699.83 2,526.54 6,006,608.51 587,053.24 4.05 2,621.11 3_MWD+IFR2+MS+Sag (3) 6,852.55 29.89 82.12 6,138.73 6,083.13 704.57 2,556.74 6,006,613.59 587,083.38 4.55 2,651.54 3_MWD+IFR2+MS+Sag (3) 6,913.41 31.93 81.50 6,190.94 6,135.34 709.03 2,587.68 6,006,618.40 587,114.27 3.39 2,682.63 3_MWD+IFR2+MS+Sag (3) 6,978.47 34.03 82.47 6,245.52 6,189.92 713.96 2,622.75 6,006,623.72 587,149.27 3.33 2,717.83 3_MWD+IFR2+MS+Sag (3) 7,042.77 36.90 82.35 6,297.88 6,242.28 718.89 2,659.73 6,006,629.07 587,186.19 4.46 2,754.88 3_MWD+IFR2+MS+Sag (3) 7,106.13 39.83 81.96 6,347.56 6,291.96 724.26 2,698.68 6,006,634.88 587,225.08 4.64 2,793.95 3_MWD+IFR2+MS+Sag (3) 7,169.57 42.17 81.43 6,395.43 6,339.83 730.27 2,739.86 6,006,641.36 587,266.18 3.73 2,835.34 3_MWD+IFR2+MS+Sag (3) 7,233.65 42.00 80.16 6,442.99 6,387.39 737.14 2,782.25 6,006,648.71 587,308.49 1.35 2,878.12 3_MWD+IFR2+MS+Sag (3) 7,297.49 43.34 78.89 6,489.93 6,434.33 745.01 2,824.80 6,006,657.07 587,350.94 2.49 2,921.29 3_MWD+IFR2+MS+Sag (3) 7,361.37 43.40 77.17 6,536.37 6,480.77 754.11 2,867.71 6,006,666.65 587,393.74 1.85 2,965.11 3_MWD+IFR2+MS+Sag (3) 7,424.74 41.84 77.38 6,583.00 6,527.40 763.56 2,909.56 6,006,676.57 587,435.48 2.47 3,008.01 3_MWD+IFR2+MS+Sag (3) 7,488.68 43.94 78.33 6,629.84 6,574.24 772.71 2,952.10 6,006,686.20 587,477.91 3.44 3,051.49 3_MWD+IFR2+MS+Sag (3) 11/5/2019 12:51:50PM Page 4 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU K-44 Project: Milne Point TVD Reference: MPU K-44AActual RKB @ 55.60usft (Innovation) Site: M Pt K Pad MD Reference: MPU K-44AActual RKB @ 55.60usft (Innovation) Well: MPU K-44 North Reference: True Wellbore: MPU K-44AP131 Survey Calculation Method: Minimum Curvature Design: MPU K-44AP131 Database: NORTH US + CANADA Survey Checked By: Chelsea Wright D-20`9 ;`05. 3344 o9Wl Approved By: Benjamin Hand ht eigilly :201 .11.05yB02.46- 9'00' 11/05/2019 ea�e:zo,9.,,.05,0:o�:<b-osnu Date: 11/5/2019 12:51:50PM Page 5 COMPASS 5000.15 Build 91 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,551.71 46.43 78.74 6,674.26 6,618.66 781.60 2,995.92 6,006,695.58 587,521.62 3.98 3,096.14 3_MWD+IFR2+MS+Sag (3) 7,615.99 49.74 78.03 6,717.20 6,661.60 791.23 3,042.77 6,006,705.75 587,568.35 5.21 3,143.92 3_MWD+IFR2+MS+Sag (3) 7,679.28 53.37 77.18 6,756.54 6,700.94 801.88 3,091.17 6,006,716.94 587,616.62 5.83 3,193.45 3_MWD+IFR2+MS+Sag (3) 7,706.40 54.88 76.89 6,772.44 6,716.84 806.81 3,112.58 6,006,722.11 587,637.98 5.63 3,215.42 3_MWD+IFR2+MS+Sag (3) 7,726.90 54.38 76.73 6,784.30 6,728.70 810.62 3,128.86 6,006,726.11 587,654.21 2.52 3,232.13 3_MWD+IFR2+MS+Sag (4) 7,795.76 56.42 7727 6,823.40 6,767.80 823.37 3,184.08 6,006,739.48 587,709.28 3.03 3,288.80 3_MWD+IFR2+MS+Sag (4) 7,857.96 59.59 78.21 6,856.35 6,800.75 834.56 3,235.63 6,006,751.25 587,760.69 5.26 3,341.51 3_MWD+IFR2+MS+Sag (4) 7,920.44 62.13 78.03 6,886.78 6,831.18 845.80 3,289.03 6,006,763.09 587,813.95 4.07 3,396.03 3_MWD+IFR2+MS+Sag (4) 7,982.61 64.77 76.06 6,914.56 6,858.96 858.27 3,343.21 6,006,776.18 587,867.99 5.11 3,451.62 3_MWD+IFR2+MS+Sag (4) 8,045.60 66.45 75.78 6,940.58 6,884.98 872.23 3,398.86 6,006,790.77 587,923.46 2.70 3,508.98 3_MWD+IFR2+MS+Sag (4) 8,178.00 66.45 75.78 6,993.48 6,937.88 902.05 3,516.51 6,006,821.91 588,040.76 0.00 3,630.36 PROJECTED to TD Checked By: Chelsea Wright D-20`9 ;`05. 3344 o9Wl Approved By: Benjamin Hand ht eigilly :201 .11.05yB02.46- 9'00' 11/05/2019 ea�e:zo,9.,,.05,0:o�:<b-osnu Date: 11/5/2019 12:51:50PM Page 5 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt K Pad MPU K-44APB2 MPU K-44APB2 500292356771 Sperry Drilling Definitive Survey Report 05 November, 2019 HALLIBURTON Sperry Drilling .w. Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU K-44 Project: Milne Point TVD Reference: MPU K-44AActual RKB @ 55.60usft (Innovation) Site: M Pt K Pad MD Reference: MPU K-44AActual RKB @ 55.60usft (Innovation) Well: MPU K-44 North Reference: True Wellbore: MPU K-44APB2 Survey Calculation Method: Minimum Curvature Design: MPU K-44APB2 Database: NORTH US + CANADA roject Milne Point, ACT, MILNE POINT ap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level eo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point ap Zone: Alaska Zone 04 Using geodetic scale factor Well MPU K-44 Well Position +N/ -S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore MPU K-44APB2 Magnetics Model Name Sample Date BGGM2018 9/16/2019 Design MPU K-44APB2 Audit Notes: Left in hole Version: 1.0 Phase: Vertical Section: Depth From (TVD) (usft) 26.30 6,005,880.17 usft Latitude: 584,535.02 usft Longitude: 0.00 usft Ground Level: Declination 16.55 Dip Angle 80.94 ACTUAL Tie On Depth: +N/ -S +E/ -W (usft) (usft) 0.00 0.00 7,5f Directic (°) 75.71 70° 25'33.570 N 149° 18'40.034 W 29.30 usft Field Strength (nT) 57,416.37830038 Survey Program Date 11/5/2019 From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 127.30 498.26 MPK-44 Interp (MPK-44) 3_MWD_Interp Azi+Sag H003Mb: Interpolated azimuth + sag correction 03/28/2016 593.64 5,550.00 MPK-44 MWD+IFR2+MS+sag (1) (MPK- 3_MWD+IFR2+MS+Sag H081 Ma: IIFR dec & multi -station analysis + sag 03/29/2016 5,610.00 7,551.71 MPU K-44APB1 MWD+IFR2+MS+Sag (1 3_MWD+IFR2+MS+Sag H081 Ma: IIFR dec & multi -station analysis + sag 10/30/2019 7,609.00 8,016.05 MPU K-44APB2 MWD+IFR2+MS+Sag (3 3_MWD+IFR2+MS+Sag H081 Ma: IIFR dec & multi -station analysis + sag 10/17/2019 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 26.30 0.00 0.00 26.30 -29.30 0.00 0.00 6,005,880.17 584,535.02 0.00 0.00 UNDEFINED 127.30 0.33 35.07 127.30 71.70 0.24 0.17 6,005,880.41 584,535.18 0.33 0.22 3_MWD_InterpAzi+Sag(1) 217.55 0.14 35.07 217.55 161.95 0.54 0.38 6,005,880.72 584,535.39 0.21 0.50 3_MWD_InterpAzi+Sag(1) 314.29 0.14 35.07 314.29 258.69 0.73 0.52 6,005,880.91 584,535.53 0.00 0.68 3_MWD_InterpAzi+Sag (1) 402.70 0.09 35.07 402.70 347.10 0.88 0.62 6,005,881.06 584,535.63 0.06 0.82 3_MWD_InterpAzi+Sag(1) 498.26 0.40 35.07 498.26 442.66 1.21 0.85 6,005,881.39 584,535.86 0.32 1.13 3_MWD_InterpAzi+Sag(1) 593.64 0.41 35.07 593.63 538.03 1.77 1.24 6,005,881.95 584,536.24 0.01 1.64 3_MWD+IFR2+MS+Sag (2) 687.61 0.33 59.69 687.60 632.00 2.18 1.67 6,005,882.37 584,536.66 0.19 2.15 3_MWD+IFR2+MS+Sag (2) 781.71 3.51 62.00 781.64 726.04 3.67 4.44 6,005,883.89 584,539.42 3.38 5.21 3_MWD+IFR2+MS+Sag (2) 873.29 3.72 59.90 873.04 817.44 6.47 9.49 6,005,886.75 584,544.44 0.27 10.79 3_MWD+IFR2+MS+Sag (2) 970.54 6.44 60.18 969.89 914.29 10.77 16.95 6,005,891.13 584,551.85 2.80 19.09 3_MWD+IFR2+MS+Sag (2) 11/5/2019 12:56:01PM Page 2 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU K-44 Project: Milne Point TVD Reference: MPU K-44AActual RKB @ 55.60usft (Innovation) Site: M Pt K Pad MD Reference: MPU K-44AActual RKB @ 55.60usft (Innovation) Well: MPU K-44 North Reference: True Wellbore: MPU K-44APB2 Survey Calculation Method: Minimum Curvature Design: MPU K-44APB2 Database: NORTH US + CANADA Survey 4,744.74 33.54 76.51 4,240.66 4,185.06 544.38 1,731.81 6,006,444.08 586,260.39 0.52 1,812.59 3_MWD+IFR2+MS+Sag (2) 11/512019 12:56:01PM Page 3 COMPASS 5000.15 Build 91 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,064.65 7.19 59.23 1,063.34 1,007.74 16.41 26.59 6,005,896.87 584,561.42 0.81 29.82 3_MWD+IFR2+MS+Sag(2) 1,158.90 9.92 54.29 1,156.53 1,100.93 24.16 38.25 6,005,904.76 584,572.99 3.00 43.03 3_MWD+IFR2+MS+Sag (2) 1,253.31 13.85 51.79 1,248.90 1,193.30 35.90 53.74 6,005,916.68 584,588.35 4.20 60.94 3_MWD+IFR2+MS+Sag (2) 1,346.19 14.07 47.45 1,339.04 1,283.44 50.42 70.80 6,005,931.38 584,605.23 1.15 81.05 3_MWD+IFR2+MS+Sag (2) 1,441.04 17.25 57.75 1,430.38 1,374.78 65.72 91.19 6,005,946.92 584,625.45 4.44 104.59 3_MWD+IFR2+MS+Sag (2) 1,536.25 19.82 56.51 1,520.64 1,465.04 82.17 116.60 6,005,963.64 584,650.67 2.73 133.27 3_MWD+IFR2+MS+Sag (2) 1,630.37 21.66 54.34 1,608.66 1,553.06 101.10 144.02 6,005,982.88 584,677.87 2.12 164.52 3_MWD+IFR2+MS+Sag (2) 1,724.28 23.28 53.85 1,695.44 1,639.84 122.15 173.09 6,006,004.26 584,706.70 1.74 197.88 3_MWD+IFR2+MS+Sag (2) 1,818.33 23.16 54.11 1,781.87 1,726.27 143.96 203.08 6,006,026.40 584,736.44 0.17 232.33 3_MWD+IFR2+MS+Sag (2) 1,913.35 27.58 60.21 1,867.72 1,812.12 165.85 237.33 6,006,048.69 584,770.43 5.40 270.92 3_MWD+IFR2+MS+Sag (2) 2,006.58 28.52 67.63 1,950.02 1,894.42 185.05 276.65 6,006,068.33 584,809.54 3.87 313.77 3_MWD+IFR2+MS+Sag (2) 2,100.88 30.13 74.89 2,032.26 1,976.66 199.80 320.34 6,006,083.56 584,853.05 4.14 359.74 3_MWD+IFR2+MS+Sag(2) 2,195.33 32.67 75.78 2,112.87 2,057.27 212.24 367.94 6,006,096.54 584,900.50 2.73 408.95 3_MWD+IFR2+MS+Sag (2) 2,289.98 34.98 74.94 2,191.50 2,135.90 225.57 418.91 6,006,110.45 584,951.31 2.49 461.63 3_MWD+IFR2+MS+Sag (2) 2,384.17 35.13 75.78 2,268.60 2,213.00 239.24 471.26 6,006,124.71 585,003.49 0.54 515.73 3_MWD+IFR2+MS+Sag(2) 2,478.77 35.02 75.73 2,346.02 2,290.42 252.62 523.95 6,006,138.68 585,056.02 0.12 570.09 3_MWD+IFR2+MS+Sag (2) 2,573.16 33.40 75.95 2,424.08 2,368.48 265.60 575.40 6,006,152.25 585,107.32 1.72 623.15 3_MWD+IFR2+MS+Sag (2) 2,667.37 33.35 76.18 2,502.75 2,447.15 278.08 625.70 6,006,165.29 585,157.47 0.14 674.98 3_MWD+IFR2+MS+Sag (2) 2,761.85 33.30 76.40 2,581.70 2,526.10 290.38 676.13 6,006,178.17 585,207.75 0.14 726.88 3_MWD+IFR2+MS+Sag (2) 2,856.59 33.14 76.15 2,660.95 2,605.35 302.70 726.55 6,006,191.05 585,258.03 0.22 778.78 3_MWD+IFR2+MS+Sag (2) 2,952.28 33.13 76.31 2,741.08 2,685.48 315.15 777.35 6,006,204.07 585,308.68 0.09 831.09 3_MWD+IFR2+MS+Sag (2) 3,044.57 32.98 76.91 2,818.44 2,762.84 326.80 826.32 6,006,216.28 585,357.51 0.39 881.42 3_MWD+IFR2+MS+Sag (2) 3,139.58 32.89 76.51 2,898.18 2,842.58 338.68 876.59 6,006,228.73 585,407.64 0.25 933.07 3_MWD+IFR2+MS+Sag (2) 3,234.08 32.30 76.66 2,977.79 2,922.19 350.49 926.11 6,006,241.10 585,457.02 0.63 983.97 3_MWD+IFR2+MS+Sag (2) 3,328.67 31.84 76.87 3,057.95 3,002.35 361.99 975.00 6,006,253.15 585,505.77 0.50 1,034.18 3_MWD+IFR2+MS+Sag (2) 3,422.91 32.11 75.94 3,137.89 3,082.29 373.72 1,023.50 6,006,265.43 585,554.13 0.60 1,084.08 3_MWD+IFR2+MS+Sag (2) 3,517.08 34.16 75.56 3,216.74 3,161.14 386.40 1,073.39 6,006,278.66 585,603.87 2.19 1,135.55 3_MWD+IFR2+MS+Sag (2) 3,612.04 34.31 76.28 3,295.25 3,239.65 399.39 1,125.21 6,006,292.24 585,655.53 0.45 1,188.98 3_MWD+IFR2+MS+Sag (2) 3,705.87 34.14 76.62 3,372.83 3,317.23 411.76 1,176.51 6,006,305.19 585,706.69 0.27 1,241.74 3_MWD+IFR2+MS+Sag (2) 3,796.89 33.88 77.33 3,448.28 3,392.68 423.23 1,226.11 6,006,317.22 585,756.15 0.52 1,292.64 3_MWD+IFR2+MS+Sag (2) 3,894.42 33.84 77.42 3,529.27 3,473.67 435.11 1,279.14 6,006,329.70 585,809.03 0.07 1,346.96 3_MWD+IFR2+MS+Sag (2) 3,988.24 3421 76.67 3,607.03 3,551.43 446.88 1,330.30 6,006,342.05 585,860.05 0.60 1,399.44 3_MWD+IFR2+MS+Sag (2) 4,082.52 34.36 77.19 3,684.93 3,629.33 458.89 1,382.03 6,006,354.64 585,911.64 0.35 1,452.54 3_MWD+IFR2+MS+Sag (2) 4,177.20 32.99 75.74 3,763.72 3,708.12 471.16 1,433.07 6,006,367.49 585,962.53 1.68 1,505.03 3_MWD+IFR2+MS+Sag (2) 4,266.38 32.62 75.98 3,838.68 3,783.08 482.97 1,479.92 6,006,379.82 586,009.24 0.44 1,553.34 3_MWD+IFR2+MS+Sag (2) 4,367.26 31.79 76.90 3,924.04 3,868.44 495.58 1,532.19 6,006,393.02 586,061.35 0.96 1,607.10 3_MWD+IFR2+MS+Sag (2) 4,460.84 32.57 76.47 4,003.24 3,947.64 507.06 1,580.68 6,006,405.05 586,109.71 0.87 1,656.93 3_MWD+IFR2+MS+Sag (2) 4,555.65 33.60 75.78 4,082.68 4,027.08 519.47 1,630.93 6,006,418.03 586,159.81 1.16 1,708.68 3_MWD+IFR2+MS+Sag (2) 4,650.21 33.10 76.12 4,161.66 4,106.06 532.09 1,681.36 6,006,431.22 586,210.09 0.56 1,760.67 3_MWD+IFR2+MS+Sag (2) 4,744.74 33.54 76.51 4,240.66 4,185.06 544.38 1,731.81 6,006,444.08 586,260.39 0.52 1,812.59 3_MWD+IFR2+MS+Sag (2) 11/512019 12:56:01PM Page 3 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU K-44 Project: Milne Point TVD Reference: MPU K-44AActual RKB @ 55.60usft (Innovation) Site: M Pt K Pad MD Reference: MPU K-44AActual RKB @ 55.60usft (Innovation) Well: MPU K-44 North Reference: True Wellbore: MPU K-44API32 Survey Calculation Method: Minimum Curvature Design: MPU K-44AP132 Database: NORTH US + CANADA Survey 11/5/2019 12:56:01PM Page 4 COMPASS 5000.15 Build 91 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,838.73 34.23 76.88 4,318.68 4,263.08 556.43 1,782.80 6,006,456.71 586,311.24 0.77 1,864.99 3_MWD+IFR2+MS+Sag (2) 4,933.23 34.35 77.85 4,396.76 4,341.16 568.08 1,834.75 6,006,468.94 586,363.05 0.59 1,918.20 3_MWD+IFR2+MS+Sag (2) 5,027.35 33.76 76.44 4,474.74 4,419.14 579.80 1,886.13 6,006,481.24 586,414.29 1.05 1,970.89 3_MWD+IFR2+MS+Sag (2) 5,120.99 34.34 76.97 4,552.32 4,496.72 591.85 1,937.16 6,006,493.87 586,465.17 0.70 2,023.31 3_MWD+IFR2+MS+Sag (2) 5,212.13 32.72 76.12 4,628.29 4,572.69 603.56 1,986.12 6,006,506.13 586,513.99 1.85 2,073.64 3_MWD+IFR2+MS+Sag (2) 5,309.88 32.24 76.10 4,710.75 4,655.15 616.16 2,037.08 6,006,519.31 586,564.80 0.49 2,126.14 3_MWD+IFR2+MS+Sag(2) 5,404.73 33.16 75.79 4,790.57 4,734.97 628.61 2,086.78 6,006,532.32 586,614.36 0.99 2,177.38 3_MWD+IFR2+MS+Sag (2) 5,499.41 33.09 75.51 4,869.86 4,814.26 641.43 2,136.91 6,006,545.71 586,664.33 0.18 2,229.12 3_MWD+IFR2+MS+Sag (2) 5,550.00 33.18 75.62 4,912.23 4,856.63 648.32 2,163.69 6,006,552.90 586,691.03 0.21 2,256.77 3_MWD+IFR2+MS+Sag (2) 5,610.00 31.35 76.34 4,962.96 4,907.36 656.09 2,194.76 6,006,561.02 586,722.01 3.12 2,288.80 3_MWD+IFR2+MS+Sag (3) 5,657.63 29.90 76.96 5,003.94 4,948.34 661.69 2,218.37 6,006,566.89 586,745.55 3.12 2,313.06 3_MWD+IFR2+MS+Sag (3) 5,720.78 26.47 79.16 5,059.60 5,004.00 667.89 2,247.54 6,006,573.42 586,774.64 5.67 2,342.85 3_MWD+IFR2+MS+Sag (3) 5,770.13 24.30 80.48 5,104.18 5,048.58 671.64 2,268.35 6,006,577.40 586,795.41 4.54 2,363.95 3_MWD+IFR2+MS+Sag (3) 5,834.75 21.99 82.55 5,163.60 5,108.00 675.41 2,293.47 6,006,581.45 586,820.48 3.79 2,389.22 3_MWD+IFR2+MS+Sag (3) 5,897.66 19.38 82.69 5,222.45 5,166.85 678.26 2,315.50 6,006,584.56 586,842.48 4.15 2,411.27 3_MWD+IFR2+MS+Sag (3) 5,961.73 15.25 83.54 5,283.60 5,228.00 680.57 2,334.43 6,006,587.07 586,861.37 6.46 2,430.18 3_MWD+IFR2+MS+Sag (3) 6,025.24 11.74 85.52 5,345.35 5,289.75 682.01 2,349.17 6,006,588.68 586,876.10 5.57 2,444.83 3_MWD+IFR2+MS+Sag (3) 6,088.85 9.03 90.19 5,407.91 5,352.31 682.50 2,360.62 6,006,589.30 586,887.54 4.46 2,456.04 3_MWD+IFR2+MS+Sag (3) 6,153.01 6.18 90.94 5,471.50 5,415.90 682.43 2,369.11 6,006,589.33 586,896.03 4.44 2,464.25 3_MWD+IFR2+MS+Sag (3) 6,213.09 6.48 90.78 5,531.22 5,475.62 682.33 2,375.73 6,006,589.30 586,902.65 0.50 2,470.64 3_MWD+IFR2+MS+Sag (3) 6,277.35 6.90 91.58 5,595.04 5,539.44 682.17 2,383.22 6,006,589.23 586,910.14 0.67 2,477.86 3_MWD+IFR2+MS+Sag (3) 6,344.39 8.99 88.98 5,661.43 5,605.83 682.15 2,392.48 6,006,589.32 586,919.40 3.16 2,486.83 3_MWD+IFR2+MS+Sag (3) 6,405.21 11.45 84.31 5,721.28 5,665.68 682.84 2,403.24 6,006,590.12 586,930.15 4.26 2,497.43 3_MWD+IFR2+MS+Sag (3) 6,466.47 13.61 81.49 5,781.08 5,725.48 684.51 2,416.42 6,006,591.94 586,943.31 3.66 2,510.61 3_MWD+IFR2+MS+Sag (3) 6,534.53 16.21 84.04 5,846.84 5,791.24 686.68 2,433.79 6,006,594.31 586,960.65 3.94 2,527.98 3_MWD+IFR2+MS+Sag (3) 6,598.10 18.78 83.88 5,907.47 5,851.87 688.69 2,452.79 6,006,596.54 586,979.63 4.04 2,546.89 3_MWD+IFR2+MS+Sag (3) 6,661.24 21.66 82.27 5,966.71 5,911.11 691.34 2,474.45 6,006,599.43 587,001.25 4.65 2,568.53 3_MWD+IFR2+MS+Sag (3) 6,724.60 24.59 80.51 6,024.97 5,969.37 695.09 2,499.05 6,006,603.46 587,025.80 4.75 2,593.29 3_MWD+IFR2+MS+Sag (3) 6,788.53 27.17 79.95 6,082.49 6,026.89 699.83 2,526.54 6,006,608.51 587,053.24 4.05 2,621.11 3_MWD+IFR2+MS+Sag (3) 6,852.55 29.89 82.12 6,138.73 6,083.13 704.57 2,556.74 6,006,613.59 587,083.38 4.55 2,651.54 3_MWD+IFR2+MS+Sag (3) 6,913.41 31.93 81.50 6,190.94 6,135.34 709.03 2,587.68 6,006,618.40 587,114.27 3.39 2,682.63 3_MWD+IFR2+MS+Sag (3) 6,978.47 34.03 82.47 6,245.52 6,189.92 713.96 2,622.75 6,006,623.72 587,149.27 3.33 2,717.83 3_MWD+IFR2+MS+Sag (3) 7,042.77 36.90 82.35 6,297.88 6,242.28 718.89 2,659.73 6,006,629.07 587,186.19 4.46 2,754.88 3_MWD+IFR2+MS+Sag (3) 7,106.13 39.83 81.96 6,347.56 6,291.96 724.26 2,698.68 6,006,634.88 587,225.08 4.64 2,793.95 3_MWD+IFR2+MS+Sag (3) 7,169.57 42.17 81.43 6,395.43 6,339.83 730.27 2,739.86 6,006,641.36 587,266.18 3.73 2,835.34 3_MWD+IFR2+MS+Sag (3) 7,233.65 42.00 80.16 6,442.99 6,387.39 737.14 2,782.25 6,006,648.71 587,308.49 1.35 2,878.12 3_MWD+IFR2+MS+Sag (3) 7,297.49 43.34 78.89 6,489.93 6,434.33 745.01 2,824.80 6,006,657.07 587,350.94 2.49 2,921.29 3_MWD+IFR2+MS+Sag (3) 7,361.37 43.40 77.17 6,536.37 6,480.77 754.11 2,867.71 6,006,666.65 587,393.74 1.85 2,965.11 3_MWD+IFR2+MS+Sag (3) 7,424.74 41.84 77.38 6,583.00 6,527,40 763.56 2,909.56 6,006,676.57 587,435.48 2.47 3,008.01 3_MWD+IFR2+MS+Sag (3) 7,488.68 43.94 78.33 6,629.84 6,574.24 772.71 2,952.10 6,006,686.20 587,477.91 3.44 3,051.49 3_MWD+IFR2+MS+Sag (3) 11/5/2019 12:56:01PM Page 4 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU K-44 Project: Milne Point ND Reference: MPU K-44AActual RKB @ 55.60usft (Innovation) Site: M Pt K Pad MD Reference: MPU K-44AActual RKB @ 55.60usft (Innovation) Well: MPU K-44 North Reference: True Wellbore: MPU K-44APB2 Survey Calrulatinn Method: Minimum Curvature Design: MPU K-44APB2 Database: NORTH US + CANADA Survey Checked By: Chelsea Wright pa9e`.azo,99,",`o5;z ;tea Wright Approved By: Benjamin Hand DateI20199110510'M4]-09'e0ndDate: 11/05/2019 11/5/2019 12:56:01PM Page 5 COMPASS 5000.15 Build 91 Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,551.71 46.43 78.74 6,674.26 6,618.66 781.60 2,995.92 6,006,695.58 587,521.62 3.98 3,096.14 3_MWD+IFR2+MS+Sag (3) 7,609.00 49.38 78.10 6,712.66 6,657.06 790.13 3,037.56 6,006,704.59 587,563.16 5.22 3,138.60 3_MWD+IFR2+MS+Sag (4) 7,642.01 48.31 77.40 6,734.39 6,678.79 795.41 3,061.85 6,006,710.13 587,587.38 3.61 3,163.44 3_MWD+IFR2+MS+Sag (4) 7,704.56 52.88 76.12 6,774.08 6,718.48 806.49 3,108.88 6,006,721.75 587,634.28 7.48 3,211.75 3_MWD+IFR2+MS+Sag (4) 7,768.17 57.00 74.97 6,810.62 6,755.02 819.50 3,159.28 6,006,735.32 587,684.53 6.64 3,263.81 3_MWD+IFR2+MS+Sag (4) 7,829.89 60.06 74.61 6,842.83 6,787.23 833.31 3,210.07 6,006,749.71 587,735.15 4.98 3,316.43 3_MWD+IFR2+MS+Sag (4) 7,892.48 62.94 75.58 6,872.70 6,817.10 847.45 3,263.22 6,006,764.45 587,788.13 4.80 3,371.43 3_MWD+IFR2+MS+Sag (4) 7,950.74 65.05 75.77 6,898.24 6,842.64 860.40 3,313.95 6,006,777.98 587,838.71 3.63 3,423.79 3_MWD+IFR2+MS+Sag (4) 8,016.05 66.94 74.21 6,924.81 6,869.21 875.86 3,371.57 6,006,794.08 587,896.14 3.62 3,483.44 3_MWD+IFR2+MS+Sag (4) 8,077.00 66.94 74.21 6,948.68 6,893.08 891.12 3,425.53 6,006,809.95 587,949.93 0.00 3,539.50 PROJECTED to TD Checked By: Chelsea Wright pa9e`.azo,99,",`o5;z ;tea Wright Approved By: Benjamin Hand DateI20199110510'M4]-09'e0ndDate: 11/05/2019 11/5/2019 12:56:01PM Page 5 COMPASS 5000.15 Build 91 Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Thursday, October 17, 2019 9:14 AM To: Joseph Engel Cc: Cody Dinger; Mack Myers Subject: RE: HAK MPU K -44A (PTD:219-116) Update Joe, Sounds like you just lost the steering section of the assembly... so no sources lost. Go ahead and set kickoff plug and treat as normal PB section. Thanks for the update. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guy.schwartz@alaska.gov). From: Joseph Engel <jengel@hilcorp.com> Sent: Thursday, October 17, 2019 9:10 AM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Cody Dinger <cdinger@hilcorp.com>; Mack Myers <mmyers@hilcorp.com> Subject: HAK MPU K -44A (PTD:219-116) Update Guy — I wanted to give you an update on K -44A. 7" casing was set and cemented at 7725' MD. While drilling 6-1/8" hole section the decision was made to POOH due to failed floats and low ROP at 8179' MD. When RIH with the second RSS BHA, we encountered packoffs, becamse stuck at —7,803' MD, were able to get free and the decision was made again to POOH. When laying down the BHA we found that the RSS had parted —12' up from the bit, leaving a fish in the hole. We ran in with a tri cone bit and tagged TOF at 7796' MD. Our plan forward is to RIH with cement stinger, pump cement from 7796 to 7575' MD (150' inside the 7" shoe), MU a motor BHA, kick off and sidetrack the existing 6-1/8" hole and drill to the same approved target. Please let me know if we need to submit a sundry or if you have any questions. Thank you for your time. -Joe Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 1 Anchorage ( 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 V 0 a 411151 GOVERNOR MIKE DUNLEAVY Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU K -44A Permit to Drill Number: 219-116 Sundry Number: 319-491 Dear Mr. Myers: 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 Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1 Je rice Chair DATED this 1 day of November, 2019. 1BDMS! L" Nov 0 5 2019 RECEIVED STATE OF ALASKA OCT 3 0 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS' 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑✓ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 219-116 3. Address: 6. API Number: 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 50-029-23567-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑Q MPU K -44A 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL375133 / ADL375132 Milne Point Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,078' 6,949' 7,161' 6,388' N/A 7,161' 7,698' (TOF) Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' N/A N/A Surface 5,597' 10-3/4" 5,597' 4,952' 3,580psi 2,090psi Intermediate 7,725' 7" 7,725' 6,787' 7,240psi 5,410psi Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 3-1/2" L-80 7,725' Packers and SSSV Type: N/A Packers and SSSV MD (ft) and TVD (ft): N/A 12. Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service ❑ 14. Estimated Date for 10/24/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Yes Date: 10/25/2019 Commission Representative: Guy Schwartz GINJ ❑ Op Shutdown Q Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Monty Myers Contact Name: Joe Engel Authorized Title: Drilling Manager Contact Email: 2Cl el hIICOr .00171 Contact Phone: 777-8395 � / Authorized Signature: Date: W • 7-1. 7J g COMMISSION USE ONLY Conditions of approval: Notify n so that a represen a ,ve may witness Sundry Number: 34 ' b 1 Plug Integrity ❑ BOP Test El Mechanical Integrity Test ❑ Location ❑ /Clearance j Other: �4 JQ�- ! O ^t C.J�•T'�-c-� Gear l �lJ� ��i./`� CnU L ,44 o z Z (b Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes No Subsequent Form Required:/,) -- L{ ©If 0 5 2019 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 1 /0- J l ' I ` i Submit Form and Form 10-40�Rev,0.17 A application is valid for 12 months rtachments in Duplicate If�4L rDrIq Ifilcorp Alaska, LLC Well Update Well: MPU K -44A Date: 10/28/19 Well Name: MPU K -44A API Number: 50-029-23567-00-00 Current Status: RDMO Estimated Start Date: 10/25/2019 Rig: Innovation Reg. Approval Req'd? 10-403: Ops Shutdown Date Reg. Approval Rec'vd: 10/25/2019 Regulatory Contact: Cody Dinger 777-8389 Permit to Drill Number: 219-116 First Call Engineer: Joe Engel (907) 777-8395 (0) (805)235-6265 (M) Brief Well Summary: While drilling ahead in the 6-1/8" sidetracked hole section, the drilling BHA became stuck at the bit at 8078' MD / 6949' TVD. Attempts to jar the BHA free were unsuccessful. Verbal approval to 0 suspend operations as per the below plan was received on 10.25.19. Email Attached. Notes Regarding Wellbore: • 7" Window: 7609-7622' MD • Top Kup D: 7,956' MD • No Hydrocarbon bearing zone had been penetrated in this hole section Work performed: • 4" Drill pipe severed at 7,698' MD • Cement retainer set at 7,554' MD • Attempt to establish injection rate to cement beneath retainer, pressure up to 1000psi, no injection • Pumped 15bbl 15.8ppg Class G cement on top of cement retainer • Calc TOC 7,161' MD • PT cement t. 1500psi 30 min as per AOGCC • Run 3.5" killstring t/ 2,478' MD. • Freeze protect well. • RDMO Attnrhmontc 1. Actual Schematic 2. Verbal Approval Email Milne Point Unit Well: MPU K -44A Proposed Schematic Last Completed: Future Hilcorp Alaska, LLC PTD: 219-116 Orig. KB Elm: 63.1'/ G L Elev.: 29.3' 20• 10-3/4- 7' 7. TREE & WELLHEAD Tree I Seaboard 3-1/8", SK Wellhead CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 78.6 / A-53 / Weld - Surface 80' 10-3/4" Surface 45.5 / L-80 / BTC 9.794 Surface 5,597' 7" Intermediate 26 / L-80 /TXP 6.059 Surface 7,725' TUBING DETAIL 3-1/2" 1 Tubing 9.3 / L-80 / EUE 8rd 1 2.867 1 Surf 1 2,507' JEWELRY DETAIL No. Top MD Item ID 1 7,554' Cement Retainer OPEN HOLE / CEMENT DETAIL Cond Cmt to surface 13-1/2" Cmt w/ 342 bbls (Lead) 120 bbls (Tail) Cmt to Surface 9-7/8" 38 bbls Inside 7" 1S bbs WELL INCLINATION DETAIL 7" Window @ 7,609' —7,622' MD GENERAL WELL INFO API: 50-029-23567-01-00 TOF @ 7,698' ` MD J\ C�, a AA TD = 8,078 (M D) ( TD = 6,949 (TVD) PBTD = 7,161' (MD) J PBTD = 6,3W(TVD) Created By: CJD 10/29/2019 Schwartz, Guy L (CED) From: Joseph Engel <jengel@hilcorp.com> Sent: Friday, October 25, 2019 4:06 PM To: Schwartz, Guy L (CED) Cc: Mack Myers; Cody Dinger Subject: RE: [EXTERNAL] RE: HAK MPU K -44A (PTD: 219-116) Update Thank you, Guy. We will add the PT to the plan forward. Have a good weekend. 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 From: Schwartz, Guy L (CED) [mailto:guy.schwartz@alaska.gov] Sent: Friday, October 25, 2019 3:56 PM To: Joseph Engel <jengel@hilcorp.com> Cc: Mack Myers <mmyers@hilcorp.com>; Cody Dinger <cdinger@hilcorp.com> Subject: [EXTERNAL] RE: HAK MPU K -44A (PTD: 219-116) Update Joe, You have verbal approval to move off well as proposed. Submit a 10-403 sundry with "Operation Shutdown" checked off. After 60 days if not re-entering submit a 10-404 report detailing all operations in leu of the 10-407. Also test the cement plug to 1500 psi before leaving well. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.Qov). From: Joseph Engel <jengel@hilcorp.com> Sent: Thursday, October 24, 2019 4:19 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Mack Myers <mmyers@hilcorp.com>; Cody Dinger <cdinger@hilcorp.com> Subject: HAK MPU K -44A (PTD: 219-116) Update Guy — Following up from our phone conversat—a, while drilling ahead in our 6-1/8" sidetr.,K section we became stuck at the bit at —8078' MD / 6949' TVD. Attempts to jar the BHA over the last 24 hrs have been unsuccessful. We will sever drill pipe, putting TOF somewhere around 7700-7900' MD. See rough sketch attached. We would like to set a cement retainer above the window, — 7600' MD, pump cement below (-5-10 bbl) and leave 5-10 bbl of cement on top of the retainer and shut down operations on K -44A until we can come up with a plan forward and return. Please give me a call if you have any questions. Thank you for your time. -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 cant' out such virus and other checks as it considers appropriate. Schwartz, Guy L (CED) From: Joseph Engel <jengel@hilcorp.com> Sent: Thursday, October 17, 2019 9:10 AM To: Schwartz, Guy L (CED) Cc: Cody Dinger; Mack Myers Subject: HAK MPU K -44A (PTD:219-116) Update Guy — I wanted to give you an update on K -44A. 7" casing was set and cemented at 7725' MD. While drilling 6-1/8" hole section the decision was made to POOH due to failed floats and low ROP at 8179' MD. When RIH with the second RSS BHA, we encountered packoffs, becamse stuck at 7,803' MD, were able to get free and the decision was made again to POOH. When laying down the BHA we found that the RSS had parted —12' up from the bit, leaving a fish in the hole. We ran in with a tri cone bit and tagged TOF at —7796' MD. Our plan forward is to RIH with cement stinger, pump cement from 7796 to 7575' MD (150' inside the 7" shoe), MU a motor BHA, kick off and sidetrack the existing 6-1/8" hole and drill to the same approved target. Please let me know if we need to submit a sundry or if you have any questions. Thank you for your time. -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. Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Thursday, October 17, 2019 9:14 AM To: Joseph Engel Cc: Cody Dinger; Mack Myers Subject: RE: HAK MPU K -44A (PTD:219-116) Update Joe, Sounds like you just lost the steering section of the assembly... so no sources lost. Go ahead and set kickoff plug and treat as normal PB section. Thanks for the update. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Joseph Engel <jengel@hilcorp.com> Sent: Thursday, October 17, 2019 9:10 AM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Cody Dinger <cdinger@hilcorp.com>; Mack Myers <mmyers@hilcorp.com> Subject: HAK MPU K -44A (PTD:219-116) Update Guy — I wanted to give you an update on K -44A. 7" casing was set and cemented at 7725' MD. While drilling 6-1/8" hole section the decision was made to POOH due to failed floats and low ROP at 8179' MD. When RIH with the second RSS BHA, we encountered packoffs, becamse stuck at —7,803' MD, were able to get free and the decision was made again to POOH. When laying down the BHA we found that the RSS had parted -12' up from the bit, leaving a fish in the hole. We ran in with a tri cone bit and tagged TOF at 7796' MD. Our plan forward is to RIH with cement stinger, pump cement from 7796 to 7575' MD (150' inside the 7" shoe), MU a motor BHA, kick off and sidetrack the existing 6-1/8" hole and drill to the same approved target. Please let me know if we need to submit a sundry or if you have any questions. Thank you for your time. -Joe Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 ( 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 9201111 1 Walk 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, Kuparuk River Oil Pool, MPU K -44A Hilcorp Alaska, LLC Permit to Drill Number: 219-116 Surface Location: 3744' FSL, 2020' FEL, SEC. 3, T12N, RI IE, UM, AK Bottomhole Location: 269' FNL. 2321' FEL. SEC. 2. R1 IE. UM. AK Dear Mr. Myers: Enclosed is the approved application for the permit to redrill 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, -4a� Daniel T. Seamount, Jr. Commissioner DATED this S day of September, 2019. STATE OF ALASKA A� SKA OIL AND GAS CONSERVATION COMM—SION PERMIT TO DRILL 20 AAC 25.005 v' � AUG 3 0 2919 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1c. Specify ifwefl.is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑� Service - Winj ❑ Single Zone FZI 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. 0220315244 -j 017-03,13W4.+ MPU K -44A 3. Address: 6. Proposed Depth: %*'PB, 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 9,677' TVD: 7,118' Milne Point Field Kuparuk Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation:, Surface: 3744' FSL, 2020' FEL, Sec 3, T12N, R11 E, UM, AK ' ADL375133 / ADL375132 Top of Productive Horizon: 8. DNR Approval Number. 13. Approximate Spud Date: 551' FNL, 1811' FWL, Sec 2, T12N, R11 E, UM, AK N/A 9/22/2019 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 269' FNL, 2321' FEL, Sec 2, T12N, R11 E, UM, AK 5320 551' to nearest unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 55.8' 15. Distance to Nearest Well Open Surface: x-584535 y- 6005880 Zone -4 GL / BF Elevation above MSL (ft): 29.3' to Same Pool: 1,700'to MPK-13 16. Deviated wells: Kickoff depth: 5600 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 89 degrees Downhole: 3151 Surface: 2918 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) 9-7/8" 7" 26# L-80 TXP 7,553' Surface Surface 7,553' 6,676' L - 214.7 ft3 6-1/8" 4-1/2" 12.6# L-80 TXP 2,277' 7,400' 6,572' 9,677' 7,118' 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): 8,370' 7,376' 8,140' 8,140' 7,151' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 20" N/A 80' 80' Surface 5,597' 10-3/4" 1570 sx 5,597' 4,952' Intermediate 8,361' 7-5/8" 225 sx 8,361' 7,367' Production Liner Perforation Depth MD (ft): 8071 - 8128', 8144' - 8154' Perforation Depth TVD (ft): 7082' - 7139', 7154' - 7164' Hydraulic Fracture planned? Yes ❑ No ❑✓ 20. Attachments: Property Plat O 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 @I h11COr .COm Authorized Title: Drilling Manager Contact Phone: 777-8395 Authorized Signature: Date: g - p//9 Commission Use Only Permit to Drill API umber: 150- Permit Approval See cover letter for other Number: — (j D 7_9 – 35 0 — Q Q Date: 5 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: 5C)o l+s� 092 i /c'_5 Samples req'd: Yes ❑ No3r Mud log req'd: Yes ❑ No e–u H2S measures: Yes N/No ❑ Directional svy req'd: Yes QZ No ❑ 13-H P -flee o A Spacing exception req'd: Yes ❑ No C� Inclination -only svy req'd: Yes ❑ No [� �` ^ tom. Post initial injection MIT req'd: Yes ❑ No ❑ f c k e.r e.� J'35 APPROVED BY Cr by: COMMISSIONER THE COMMISSION Date: �5/\pproved - F66 10r4p Ji�ev�s¢ � I017 0 This peri � is valid for t f t e a e a proval per 20 AAC 25.00 ) Submit Form and Attachments in Du licate Hilcorp Alaska, LLC Milne Point Unit (MPU) K -44A Sidetrack Drilling Program Version 1 August 29, 2019 nilrorp Alaska, I.I.0 Contents 1.0 Well Summary.................................................................................................................................2 2.0 Management of Change Information............................................................................................3 3.0 Tubular Program: ........................................................................................................................... 4 4.0 Drill Pipe Information: ................................................................................................................... 4 5.0 Internal Reporting Requirements..................................................................................................5 6.0 Current & Proposed Wellbore Schematic.....................................................................................6 7.0 Drilling / Completion Summary.....................................................................................................9 8.0 Mandatory Regulatory Compliance / Notifications...................................................................10 9.0 MIRU, Reservoir Abandonment & Sidetrack Preparation.......................................................12 10.0 Intermediate Hole Section Summary...........................................................................................13 11.0 Drill 9-7/8" Intermediate Hole Section........................................................................................14 12.0 Run & Cement 7" Intermediate Casing......................................................................................18 13.0 Production Hole Section Summary..............................................................................................23 14.0 Drill 6-1/8" Production Lateral....................................................................................................24 15.0 Run 4-1/2" Slotted Liner Completion..........................................................................................27 16.0 Run 3-1/2" ESP Completion.........................................................................................................31 17.0 RDMO............................................................................................................................................32 18.0 Innovation Rig BOP Schematic....................................................................................................33 19.0 Days vs Depth.................................................................................................................................34 20.0 Formation Tops & Information...................................................................................................35 21.0 Anticipated Drilling Hazards.......................................................................................................36 22.0 Innovation Rig Layout..................................................................................................................37 23.0 FIT Procedure................................................................................................................................38 24.0 Innovation Choke Manifold Schematic.......................................................................................39 25.0 Casing Design Information...........................................................................................................40 26.0 9-7/8" & 6-1/8" Hole Section MASP............................................................................................41 27.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................43 28.0 Surface Plat (As Built) (NAD 27).................................................................................................44 ff Ililcoq Alaska, LLC 1.0 Well Summary Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Well K -44A Pad Milne Point `K' Pad Planned Completion Type 4-1/2" Slotted Liner / 3-1/2" ESP Target Reservoir(s) Ku aruk C Planned Well TD, MD / TVD 9,677' MD / 7,118' TVD PBTD, MD / TVD +9,634' MD / 7,118' TVD Surface Location (Governmental) 3744' FSL, 2020' FEL, Sec 3, T12N, RI 1E, UM, AK Surface Location (NAD 27 — Zone 4) X=584535.02, Y=6005880.1 Top of Productive Horizon (Governmental) 551' FNL, 1811' FWL, Sec 2, T12N, RI 1E, UM, AK TPH Location (NAD 27) X= 588352.81, Y= 6006908.6 BHL (Governmental) 269' FNL, 2321' FEL, Sec 2, T12N, RI 1E, UM, AK BHL (NAD 27) X=589496.9, Y=6007204 AFE Number 1914444 AFE Pre -Drill 7 AFE Drilling Das 10 AFE Completion Days 2 AFE Pre -Drill Amount $1,189,171 AFE Drilling Amount $2,461,450 AFE Completion Amount $738,677 AFE Facility Amount $330,000 Maximum Anticipated Pressure (Surface) 2,918 psi Maximum Anticipated Pressure (Downhole/Reservoir) 3,151 si Work String 5" 19.5# NC50 4" 14# HT38 KB Elevation above MSL: 26.5 + 29.3 ft = 55.8 ft AMSL GL Elevation above MSL: 29.3 ft AMSL BOP Equipment 13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams Page 2 llilcorp Alaska. LIX 2.0 Management of Change Information 10 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure ]a Hilcorp Alaska, LLC Hilcorp Changes to Approved Permit to Drill Date: 8/3012019 Subject: Changes to Approved Permit to Drill for MPU K -44A File #: MPU K -44A Drilling and Completion Program Any modifications to MPU K -44A Drilling & Completion Program will be documented and approved below. Changes to an approved APD will be approved in advance to the AOGCC. Sec page Date Procedure Change Approved B'Y Approved BY Approval: Prepared: Page 3 Drilling Manager Date Drilling Engineer Date Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Hileorp Alaska, LLC 3.0 Tubular Program: Hole O iau) 1D (in) Drift Conn Wt Gr�Lde Conn Burst Collapse Tension Section i . 'n) in OD in(#/ft) si)(k-lbs) (psi)(psi)(k-lbs) 9-7/8" 5" 4.276" Cond 20" 19.5 5-135 NC50 78.6 A-53 Weld 6-1/8" 4" 3.34" 2.5625" 13.5" 10-3/4" 9.95 9.794 11.75 45.5 L-80 BTC 5210 2470 1040 9-7/8" 7" 6.276 6.151 7.656 26 L-80 TXP 7240 ` 5410 604 6-1/8" 4-1/2" 3.968 3.833 45.00 12.6 L-80 TXP 8430 7500 288 All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). 4.0 Drill Pipe Information: 1WT-- OD (in) ID (in) TJ ID TJ OD Grade Conn Burst Collapse Tension Section i . 'n) #/ ° si)(k-lbs) 9-7/8" 5" 4.276" 3.25" 6.625" 19.5 5-135 NC50 31,032 34,136 560klb 6-1/8" 4" 3.34" 2.5625" 4.875" 14 5-135 XT39 18,500 22,200 403 4" 3.34 2.5625 4.875 14 5-135 HT38 12,200 17,700 403 Page 4 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Ilileorp Alaska, LLC 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on WellEz. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area — this will not save the data entered, and will navigate to another data entry. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. • Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Detailed Daily Plan Forwards • Distributed to jengelghilcop.com and mmyers(khilcop.com 5.3 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hileorp.com, mmyers(c�r�,hilcorp.com jenael@hilcorp.com and cdinger@hilcorp.com 5.4 Intranet Home Page Morning Update • Submit a short operations update each morning by lam on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 5.5 EHS Incident Reporting • Health and safety: Notify EHS field coordinator. • Environmental: Drilling Environmental coordinator • Notify Drilling Manager & Drilling Engineer • Submit Hilcorp Incident report to contacts above within 24 hrs 5.6 Casing Tally • Send final "As -Run" Casing tally to mmy rs2hilcoM.com, jengelghilcorp.com and cdinger cghilcorp.com 5.7 Casing and Cmt report • Send casing and cement report for each string of casing to mmyers@a,hilcorp.com, jengel@hilcorp.com and edinger@hilcorp.com 5.8 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmyers@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 jengel@hilcoM.com Completion Engineer Ian Toomey 907.777.8434 907.903.3987 itoomev@hilcorp.com Geologist Radu Girbacea 907.777.8324 907.230.9490 rgirbacea@hilcorp.com Reservoir Engineer Almas Aitkulov 907.777.8475 979.739.3133 aaitkulov@hilcorp.com Drlg Environmental Coord Keegan Fleming 907.777.8477 907.350.9439 kfleming@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 cajones@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 1 509.768.8196 cdinger@hilcorp.com Page 5 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Ililcorp Alaska, TAX 6.0 Current & Proposed Wellbore Schematic Milne Point Unit Well: I`APU K-44 S C H E M AT l'>. Last Completed: 6/16/2019 IIiL,•r,, 11a1m. 1.1 r. PTLD: 216-038 0rig.K&Elev.:8.i'/GLeev.:293 TREE & WELLHEAD -T-Tree Seaboar 2-9/16-_9 K "� Seaboard 16 3/4' 3M x 11" 5M Multibowl w/11" x 2-7f B' Tbg % EUE Brd tvelttread Tap and Bottom wrth 4" CRM "H" BPV p�Ie. zea 3/8" NPr central lime- 4- 1/2" EUE x I ST XO on pup_ 1"314. CfliP�flts7 CASING DETAIL Size Type �W Grade/ Conn Drift ID Top 1 20' Conductor 78.6 J A-53 /Weld - Surface w Ifr3r4 su fce 45.5 L-80 BTC 9.794 1 Su :e 5,59 7.5/6 Production 29.7 L-80 BIC -M 6.750 Su - ce 8,361 TUBING DETAIL 2-7/8" 1 Tubing 1 65 / L-80 / EUE OF2.441 Suri 7.43T JEWELRY DETAIL No. Top MD roam 10 1 194 STAR1 Camco 2-7121" x 1 51 eRRww 0.25 DPOV 2.441 2 7,165' STA02 Camco 2.7/8"xi"9i9e o w/Dumaw GLV 2.441" 3 7,282' 2-7/3'XN Nipple- WN ID 2.205" 2.205" 4 7,332' Bolt on Discharge Head - 5 7,333' Ported Discharge Head - 6 7,334 Pump 3: PMR 538PM5)9 93 FLEX47 HS - 7 7,356 Pump 2: PMP 538PMSXD 93 FLEX47 HS - B 7,378' Pump 1: PMP 538PNISXD 20 GINPSHH H6 - 9 7,3a7 Gas Separator 5380HVVM WCFER - 10 7,391 Upper Tandem Seal: GSB3DB H6 A8 PFSA 11 7,396 LoNar Tandem Seal: GS53DB H6 397AS PPFSA 12 7,405' Motor. MIR 562XP - Re -Rated to 297 HP/2,825 V/ 64 A 13 7,433' Sensor/ Centralizer Zenith E7 455175C w/ Discharge PSI -Rtm Ey 7,437' OPEN HOLE / CEMENT DETAIL g g Cond Crratosurface 13- Crrtt W[342 bbl5 LP 120 bWS Cmt Su e 9-7 Crnt %Vj 56 M Class G Perf from 8,144' to 8,154'/Attempt to squeeze io bbls of 15.= &MCtass G =thru Rk& no success WELL INCLINATION DETAIL 3 KOP @ 789' Max We Angle = 35_i deg_ @ 2,391' MD ):511 PERFORATION DETAIL Sands I Top (MD) fl= (MD) I Top (TVD) OM (TVD) Size/SPF/Status Me. C-1 I 8,071 5,2ZF 1 7,082 1 7,2W 1 +? 1 3-3 8' 1 ispri Open Kul. B-7 8,144' 8,154' I 7,154' I 7,164' I iC 33/a° i lllspt( Isa4ated GENERAL WELL INFO 71-18' A M, TD= 8,3M (MD) /TD=7,376 (IVD} PBTD=8,14' (MD)/PM D--7,15Y(TVD) Page 6 APE 50-029-23567-04400 Drilled and Cased, Kill Sting Inmiled by DoVon 14 -4/1 2016 CoffOatiDn and Perforation by ASR S-513116 ESP Swap by ASR 1-6/16/2059 71-18' A M, TD= 8,3M (MD) /TD=7,376 (IVD} PBTD=8,14' (MD)/PM D--7,15Y(TVD) Page 6 Ilileorp Alaska, LLC Orig KB EW.: (.1'/ GL B era.: 29 3 CIEPAetS3 TOC@ T0WPo Cmct Pl=irty ,§Ti71 TREE & WELLHEAD Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Milne Paint Unit Well: MPU K-44 Last Completed: 6/16/2019 PTD: 216-034 Tree Sea nt 2-9 1 , SK f Grade/ Conn Seaboard i6 3/4" 3M x 11" 5M Muhibowl w/3.1" x 2-7/8" Tbg HWr EUE 8rd LVelfl*ad I Top and Bottom ttidh 4" CIW "H" BPV profile. Zea 3/8" M7 control lanes. 4- Conductor V2" EUE x 162 XO on pup. - Sur`ace 86' i(Y-3 4 Su ce z+ i 9.794 Su ce Wit% 7-5 Pro ucbon 29.7 L -8o BTC -M n 7 F 8,361 1,7 's - tit •. TCC;EtSGy7 t►S,g;R�' f "'� CIEPAetS3 TOC@ T0WPo Cmct Pl=irty ,§Ti71 TREE & WELLHEAD Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Milne Paint Unit Well: MPU K-44 Last Completed: 6/16/2019 PTD: 216-034 Tree Sea nt 2-9 1 , SK f Grade/ Conn Seaboard i6 3/4" 3M x 11" 5M Muhibowl w/3.1" x 2-7/8" Tbg HWr EUE 8rd LVelfl*ad I Top and Bottom ttidh 4" CIW "H" BPV profile. Zea 3/8" M7 control lanes. 4- Conductor V2" EUE x 162 XO on pup. CASING DETAIL Size Type f Grade/ Conn Drift ID Top 3 20' Conductor 78.61 A-53/Weld - Sur`ace 86' i(Y-3 4 Su ce 45-5 L-60 STC 9.794 Su ce 5,54 7-5 Pro ucbon 29.7 L -8o BTC -M 6.750 Surrace 8,361 TUBING DETAIL 2-7/8" 1 Tubing I 6.5 j L-80 / EUE &d 1 2.441 Surf 7jt3T JEWELRY DETAIL tom. 1 Top MD Item ID 6,150 C Iran Sn ge ug CIBP 2 7,471' Cement Retainer 3 8,140' 1 Cement Retainer TOC,g 7.753 Qnaa FeairQ .'. Ytit Sad 71/8" TD= 83M IN" /TD=7,37$ (7VDp P81D= A11lV (K0 / PBiD--7,152 M Page 7 Is OPEN HOLE / CEMENT DETAIL Conti Cmt to surface 13-2/2' Cmt w/342 bbls (Leadl 126 bbis as Cmt to Surface 9-7/8 Cmt%v156_ 8 55G 6 Perf from ,144'to S154/Attempt to squeeze 16 bbls of 15-8 =Class G=thrugW , no success WELL INCLINATION DETAIL KOP @ 789• "1 Max Hale Angle = 35-1 deg @ 2r'91' MD L-)' PERFORATION DETAIL Sands Top (MD) B= (MD) Top MID) fin[TVD) FT Size /sPf/Status Kul. C-1 8,671' 8,12 7,082 7,2391 57 S-3 81 bspffsqueezed Kul. 5.7 8,144` 8,154' 7,15d' 7,154" SQ 1 3-3J8" / iDspf/ Isolated GENERAL WELL INFO API: SD -029 -23567 -CG -DO Drilled and Cased, KI Strang Inst3IJed by Doyon 14 -4i1 ZD16 Completon- Perforation birASR 1-51316 ESP Swap by ASR 1-6/1612019 Ililcorp Alaska, I.M. Orifi. K9 Eleu: B.1'1 GL Elev.: 293 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Milne Point Unit Well: I'OPU K -44A Proposed Schematic Last Completed: Future PTD: TBD TD=9,R'(MD)/TD=7,131rW a} Para= 9,672' (MD) / PBfD=7,118 rW TREE & WELLHEAD Tree I Sea 3-1/r, , 5K Wellhead CASING DETAIL Size Type W Grade/ Conn Drift ID Top STA#1Camco 3 x V Sideoocket �w 0.25 DPOV 20, Conductor 78.6 J A-53 / Weld - Surface 8d 10-314- Surface 45.5 L-80 BTC 9.794 Su ce 597' 6 Interco late 26 1 L-80 i TXP 6.059 Su[e --T 553 4- S ott Lrncr --1-267—L--B-5 / TxP 3.833 7,400 Gas Separator. 535GSHVV M P. X FER TUBING DETAIL 3-112" 1 Tubirg 1 9.3 J L-80 / EUE and 1 2.867 1 Surf I ±7,3D0 JEWELRY DETAIL No. TCp MD ttem iD 1 _ 94 STA#1Camco 3 x V Sideoocket �w 0.25 DPOV Z _7,M' STA#2 Carrico 3-1/2' x 1"Sido[ket, w/DumnYV GLV 3 ±7,1W 3-1/e XN Pkpple - 4 ±7,178' Bott on Dlsdsarge Head 5 ±7,= Ported Discharge Head 6 ±7,19a Pump 3: PMP 538PMSXD 93 FLEX47 HS 7 Pump 2: PMP 538PMSM 93 FLEX47 HS B Pump is PMP 538PMSM 20 GINPSHH H6 9 ±7,220` Gas Separator. 535GSHVV M P. X FER 10 _ Upper Tandem Seal: G58308 H6 SEs,AB PFSA 11 ±7,24LY Lower Tandem Seal: GSB3DB H6 WAB PFSA 12 _Motor. MTR 562xP - 13 ±7,300 I Sensor/ Centralizer. Zenith OPEN HOLE/ CEMENT DETAIL CorI Cmttosu e 13-1 2' Cmtw 342 V015 Lea 1120 tIS Tai i Cmt to Surface 9.7/8" 214.8ft3 WELL INCLINATION DETAI L Max Hole Angle= 89 deg. @ 3,941' MD GENERAL WELL INFO API: 50-025-23 557-01-00 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Hilcorp Alaska, LLC, 7.0 Drilling / Completion Summary MPU K -44A is to be a sidetracked producer with the Kuparuk C as the target. The parent well, K-44 was drilled in 2016 and worked over in May 2019. After an increase in water cut and decrease in oil rate, the decision was made to sidetrack the well. The reservoir is planned to be abandoned and the well prepared for the sidetrack with the Innovation rig in September 2019 (operations submitted on a separate sundry). Current wellbore schematic is attached. '0 The Innovation Rig will be used to sidetrack and complete the wellbore. Drilling operations are expected to commence approximately September 22, 2019. The existing 10-3/4" surface casing will be used and a pressure test conducted prior to drilling the sidetrack. The directional plan for this sidetrack will include two hole sections. The intermediate 9-7/8" hole will drop and then build to 89° inclination and land in the upper Kalubik, 7" casing will then be ran and cemented. A 6-1/8" production hole lateral section will then be drilled in the Kuparuk C, and a 4-1/2" slotted liner will be ran. The well completed with a 3- 1/2" ESP completion. All waste & mud generated during drilling operations will be hauled to the Milne Point G&I facility on `B" pad. A separate sundry notice has been submitted to cover reservoir abandonrwnt and wellbore preparation for the sidetrack. The aforementioned sundry will cover the following operations: 3 l et — 3 5S 1. MIRU the Innovation Rig. Test BOPE 2. Pull ESP completion 3. Set Cement retainer and cement squeeze existing perforations 4. Set CIBP at 6,150' MD, cut and pull 7-5/8" casing 5. Pump KOP, Tag KOP with cement stinger and POOH General sequence of operations pertaining to this approved drilling procedure: Z3'7S7 1. RIH with Kick off BHA, PT 10-3/4" asing V-344" psi Q-2-) 2. Kick off and drill 9-7/8" Intermediate ho e sec ion o 7,552' MD Run 7" and cement 4. Drill 6-1/8" production hole t/ 9,677' MD 5. Run 4-1/2" slotted liner 6. Run 3-1/2" ESP Completion 7. N/D BOP, N/U tree, RDMO P) Reservoir Evaluation Plan Intermediate: No Mud Logging, LWD: GR & Res Production: No Mud Logging, LWD: GR & Res, Azimuthal Res (For Geo Steering) Page 9 0 llileorp Alaska, LLC Milne Point Unit K -44A Kuparuk Producer Drilling Procedure 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with all AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2) week intervals during the drilling and completion of K -44A. Ensure to provide AOGCC 24 hrs notice prior to testing BOPS. • The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 10/10 min (annular—To 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements". • Ensure both AOGCC approved drilling permit is posted on the rig floor and in Co Man office. Variance Requests: • There are no variance requests at this time. Page 10 Ilileorp Alaska, LII Summary of BOP Equipment and Test Requirements Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Hole Section Equipment Test Pressure(psi) • 13-5/8" x 5M Control Technology Inc Annular BOP • 13-5/8" x 5M Control Technology Inc Double Gate Initial Test: 250/3500 o Blind ram in bottom cavity (Annular 2500 psi) • Mud cross w/ 3" x 5M side outlets 9-7/8" & 6-1/8" a 13-5/8" x 5M Control Technology Single ram • 3-1/8" x 5M Choke Line Subsequent Tests: • 3-1/8" x 5M Kill line 250/3500 • 3-1/8" x 5M Choke manifold (Annular 2500 psi) • Standpipe, floor valves, etc Primary closing unit: Control Technology Inc. (CTI), 6 station, 3000 psi, 220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is electric triplex pump on a different electrical circuit and emergency pressure is provided by bottled nitrogen The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: • Well control event (BOPS utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPS. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Additional requirements may be stipulated on APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: jim.regg@alaska.gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guy. schwartz@alaska.og_v Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: Victoria.loepp@alaska.gov Mel Rixse / Petroleum Engineer / (0): 907-793-1231 / (C): 907-907-223-3605 / Email: melvin.rixse@alaskA.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotifhtml Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 11 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Hilcorp Alaska, LLC 9.0 MIRU, Reservoir Abandonment & Sidetrack Preparation 9.1 Rig Orientation on K-44: *Not to Scale 1 ' I ~ ~1 I i 1 i � ( � I c, I I 2 ■ 5■ s . I I I s■ K-44 13 ■ to • i 17 ■ 18 • I � 21 ■ 27 ° I 25 ■ 30 • 33 ■ 34 • I 37 ■ 38 • I 43 • I K -PAD I I 9.2 Reservoir abandonment was completed with Innovation. A separate sundry was submitted to the AOGCC (Sundry #XA summary of sundry operations is below: 3i`t-3S- • MIRU Innovation, Test BOPE • Pull 2-7/8" ESP completion • RIH with cement retainer, set cement retainer, squeeze cement into the existing perforation, pullout of the cement retainer and place cement on top of the cement retainer • RIH and set CIBP at 6150' MD • Cut the 7-5/8" casing at 6100' MD • POOH laying down 7-5/8" casing • RIH, tag CIBP and pump balance cement kickoff plug • WOC, Tag with Stinger, POOH 9.3 Abandonment and sidetrack preparations under the sundry were performed on a 1 week BOPE test cycle. Once operations are covered by PTD, the BOPE test cycle is 2 weeks, from the most recent test. • Ensure 5" test joint was used on previous test Page 12 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure 11ileorp Alaska, LIX 10.0 Intermediate Hole Section Summary Depths of Interest (MD/TVD) Directional BHA Drilling Notes Casing & Cement 10/3/4" Shoe wp04 Bit MW Casing 5,597 / 4,952 — I �" ` ` '' %' 9-7/8" 9.5 ppg LSND 7" 26# TXP to Surface Inc 500' Above Drop to 10° at 6,242 HRZ, add black Colville Build to 50° at 7,552 RSS products Centralizers 7" x 8-1/2" Bowspring 5,800 / 5,130 GeoPilot 7600 (PESI) Azi 1/jt to TOC Turn to 90° by 6,064 Increase MW Turn to 78° by 7,475 t/ 10.5 at TD MWD/LWD HRZ Gamma / Res / PWD 7,480 / 6,627 MPD Install RCD 500' Above HRZ Cement TD Drillpipe CBHP Target: 1 Stage 11.3 PPG 7,552 / 6,676 5" NC50 38.25 bbl 15.8ppg Class EMW @ Top G HRZ (Super CBL & Microbond) TOOH: Offset TOC Req: 500' Above TD swab to 11.3 ppg EMW Page 13 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Ililcorp Alaska, LLC 11.0 Drill 9-7/8" Intermediate Hole Section 11.1 Pick up 9-7/8" Motor BHA • Motor BHA will be used ensure kick off and drill enough full gauge OH for the RSS BHA • Motor and MWD 11.2 TIH t/ TOC of KOP, — 5,497'MD • TOC already tagged during well prep operations with cement stinger, confirm prior tag depth • Note tag depth Iga Z) fms h 11.3 R/U and test casingtL3�Orpsi for 30 min. Ensure to record colume/pressure and plot on FIT graph. AOGCC regulation is 50% of burst = 5210 / 2 = 2605 psi, test pressure isi.'`'/°�" 11.4 Managed Pressure Drilling will be used on the intermediate and production hole sections. Prior ep to drilling out the shoe track, verify all rig crew member are familiar with operation. If needed, tK install RCD bearing element and perform practice connections to familiarize crews with its operations. 11.5 11.6 Drill down to 10-3/4" shoe and drill 20' of new hole 11.7 POOH t./ casing shoe 11.8 Perform FIT t/ 12.5 ppg EMW • If 12.5 EMW is not obtained, call and discuss with drilling engineer 11.9 RIH to bottom and kick off well bore • Drill — 150' to 200' of new hole • Confirm kick off with MWD Surveys, have gyro ready if magnetic interference is present • Ensure enough new hole is drilled to bury RSS BHA 11.10 CBU x 1-2, OWFF 11.11 POOH LD BHA 11.12 MU 9-7/8" RSS BHA • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure MWD is RX and operational. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. • Drill pipe will be 5" 19.5# S-135, NC50 • Run x2 Solid Plunger Floats for MPD Page 14 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Hilcorp Alaska, LII 11.13 Intermediate hole section mud program summary: • Density: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. • Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. • Rheology: Ensure 6 rpm is >9.875 (hole diameter) for sufficient hole cleaning, YP as low as possible • Inhibition: 3% KCl will be used for handling clay cuttings. Watch MBT levels, dilute as necessary to maintain. Increase KCl % if needed • Run the centrifuge continuously while drilling the production hole, this will help with solids removal and minimize sand content and LGS to maintain fluid properties and quality of the mud system. • PVT will be used throughout the drilling phase. Remote monitoring stations will be available at the driller's console, Co Man office, & Toolpusher office. System Type: 9.5 — 10.8 ppg 3% KCl Inhibited LSND WBM Pronerties: 11.14 RIH w/ 9-7/8" directional assembly on 5" DP from the derrick. • Shallow test MWD to confirm tool communication 11.15 Once on bottom, displace wellbore to 9.5ppg 3% KCL LSND 11.16 Drill 9-7/8" Hole to — 500' MD above HRZ, 6,980' MD • RPM: 120+ • Flow Rate: 600 GPM (200 ft/min Annular Velocity) • Ensure shaker screens are set up to handle this flow rate, shakers running slightly wet to maximize solids removal efficiency. Check for holes on screens on every connection. • WOB as needed • Pump tandem high visc high weight / low visc low weight sweeps to aid in hole cleaning Page 15 Density Plastic MBT PH Section Yield Point LGS HPHT Viscosit Intermediate 9.5 — 10.5 15-25 15-20 <6% <20 <1 1.0 9-10 11.14 RIH w/ 9-7/8" directional assembly on 5" DP from the derrick. • Shallow test MWD to confirm tool communication 11.15 Once on bottom, displace wellbore to 9.5ppg 3% KCL LSND 11.16 Drill 9-7/8" Hole to — 500' MD above HRZ, 6,980' MD • RPM: 120+ • Flow Rate: 600 GPM (200 ft/min Annular Velocity) • Ensure shaker screens are set up to handle this flow rate, shakers running slightly wet to maximize solids removal efficiency. Check for holes on screens on every connection. • WOB as needed • Pump tandem high visc high weight / low visc low weight sweeps to aid in hole cleaning Page 15 rlileorp Alaska, LLC Milne Point Unit K -44A Kuparuk Producer Drilling Procedure • Take MWD surveys every stand • Monitor hole cleaning indicators: PUW, pump pressure and ECD. Make wiper trips or backream connections if necessary 11.17 CBU x2, perform short trip to shoe if necessary • RPM: 120+ • Flow Rate: 600 GPM (200 ft/min Annular Velocity) • Alternate reciprocation depths to avoid troughing/ledging 11.18 Increase black productions for Shale stability. MW will remain at 9.5 ppg unless otherwise noted with drilling ECDs • If needed, increase MW with pre sheared spike fluid, in .3 ppg per circulation, this is to ensure no barite sag or uneven density 11.19 Install MPD Element Q 17 • Ensure rig crew is familiar with MPD connection operations • Ensure max pressure relief settings are set correction to ensure no wellbore damage is created 11.20 Drill 9-7/8" hole section to section TD per Geologist and Drilling Engineer in Upper Kalubik (To mitigate trapped injection pressure potential), 7,560' MD RPM: 120+ Flow Rate: 600 GPM (200 ft/min Annular Velocity) WOB as needed Target ECD: 11.3 ppg EMW (Range +/- 5%) Utilize MPD to maintain CBHP (constant bottom hole pressure) at the HRZ on connections, following Annular pressure ramp schedule • This will reduce the pumps on/ pumps off pressure cycles on shales • Slow ramp pumps on/off on each connection • Smooth connections are more important that connection time • Monitor losses on connetions, reduce annular pressure if needed. • Pump tandem high visc high weight / low visc low weight sweeps to aid in hole cleaning, monitor ECD effect of sweeps • Take MWD surveys every stand • Monitor hole cleaning indicators: PUW, pump pressure and ECD. Backream connections if necessary • Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. 11.21 At TD; CBU at full rate and RPM least 4-5 times at maximum circulation and rotation. Alternate reciprocation depths while CBU to reduce risk of troughing and dropping inclination. 11.22 Perform wiper trip t/ above the HRZ, offsetting swab with MPD maintaining 11.3 CBHP. Page 16 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Ilileorp Alaska, LLC 11.23 RIH to bottom • Slow string speed to limit surge on shales 11.24 Weight up at TD for shale stability, ±10.5 ppg, maintaining CHBP of 11.3 pPR EMW • Perform weight up with pre -sheared spike fluid, weighting up with .3 ppg increments 11.25 Observe well for flow 11.26 Spot Casing Running Pill t/ above HRZ • 12ppb black product, graphite, 4% lube 11.27 TOOH with the drilling assembly t/ 10-3/4" Shoe, Offsetting Swab with MPD • Follow tripping schedule, matching string speed and annular pressure • Rack back DP while TOOH, Do not lay down drill pipe. This is to minimize open hole time before casing is on bottom. 11.28 If backreaming is necessary: • Circulate at max rate while maintaining drilling ECD's (flow will be less due to 10.5 ppg MW) • Perform CBHP connections • Rotate at maximum rpm that can be sustained. • Limit pulling speed to 5 — 10 min/std (slip to slip time, not including connections). • If backreaming operations are commenced, continue backreaming to the shoe and circ at least a b/u once at the shoe. 11.29 CBU x2 at 10-3/4" Shoe 11.30 Continue TOOH to HWDP/ BHA, offsetting swab with MPD 11.31 Pull RCD Bearing element 11.32 LD BHA Page 17 0 llileorp Alaska, r.LG Milne Point Unit K -44A Kuparuk Producer Drilling Procedure 12.0 Run & Cement 7" Intermediate Casing 12.1 Change pipe rams to 7" solid body, and test same 12.2 R/U 7" casing running equipment. • Ensure 7" TXP (BTC Compatible) x NC50 crossover is on rig floor and M/U to FOSV. • Ensure all casing has been drifted prior to running. • Be sure to count the total # of joints before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. • R/U CRT w/ cement swivel. 12.3 M/U & threadlock shoe track assy consisting of: • (1) Float shoe joint w/ float shoe bucked on. Install (2) solid body centralizers over a stop ring at 10' from each end. • (1) Baker locked joint. Install (1) solid body centralizer mid joint over a stop ring • (1) Float collar joint w/ float collar bucked on pin end. Install (1) solid body centralizer mid tube over a stop ring. • Ensure proper operation of float shoe and float collar. 12.4 Run 7" 26# L-80 TXP casing. • Fill casing while running using CRT or fill up line. • Use "BOL 2000" thread compound. Dope pin end only w/ paint brush. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Install centralizers on every ioint to 500' above shoe death. • Install 3 centralizers across 10-3/4" casing shoe. 12.5 RIH following casing running schedule, keeping surge below max drilling ECD EMW • Circulate BU at 10-3/4" shoe & — 500' above HRZ (6,980' MD) to ensure mud is conditioned prior to RIH • Model circulation rates, do not exceed 11.3 un;z EMW ECD, for both losses at the colville and shale stability • Do not circulate in the middle of the HRZ, can increase possibility of packoffs • Past 7" casing runs through HRZ have had success with very slow running speeds, do not stack weight or push casing down. Let the hole dictate running speeds. 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. Slow in and out of slips. 12.7 Lower string to depth. MU hanger and landing joint. Casing will be set on depth with hanger. 7" longstring trine; will utilize prior K -44A hanger, ensure any needed crossovers are available Page 18 llileorp Alaska, LLC 12.8 12.9 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Circulation and condition mud for cement job through CRT. Reduce YP to < 20 to help ensure success of cement job. Slowly stage up pump rates, if possible, in 15 min increments .25-.5 bpm at a time. After circulating, set string at setting depth. 7" Casing Torque Values Connection MUT (Min) MUT (Opt) MUT (Max) Max Operating ft -lb ft -lb ft -lb Torque, ft -lb TXP 13,280 14,750 16,230 20,000 Page 19 H flileorl) Alaska, LLC Milne Point Unit K -44A Kuparuk Producer Drilling Procedure TXP& BTC -- 051.0912018 Outside Diameter 7.000 in- Min. Wall 87.5% 0.362 in- Plam End Weight 25.69 bslf-, Thickness AN Grade L80 sow PERFORMANCE Type 1 Wall Thickness 0.362 in- Connection OD REGULAR BcxkyY'jeld Stren.1h 604 x1 000 lbs InternalMeld Option shtys COUPLING PIPE BODY 5410 psi Body: Red 1st Band: Red Grade LEO Type V Drift API Standard 1st Rand: Brown 2nd Band: [—CONNECTION DATA 2nd Band:- Brown Type Casing 3rd Band: - 3rd Band:- and--4th Connection 01) 4thBand: - PIPE BODY DATA, GEOMETRY Nominal OD 7M0 in. Nmina]l Vk4ght 26 lbs+'ft Nh 6-151 in, Nofrdnal ID 6176 in. Wall Thickness 0.362 in- Plam End Weight 25.69 bslf-, OD Tolerance AN PERFORMANCE BcxkyY'jeld Stren.1h 604 x1 000 lbs InternalMeld 7240 psi shtys 80000 psi Collapse 5410 psi [—CONNECTION DATA I GEOMETRY Connection 01) 7.656 in. C-0ing Lerch 10.200 in, Connection ID 6-264 iri. Make-up Loss 4.579 in. Threads per in 5 Connection OD Option REGULAR PERFORMANCE Tension Efficieriqv 100.0% Joint Yield Strength 604 -NO x1000 Internal Pressure Caparity V] 7240.000 psi b5 Compression Eff-,.4&my 100 r:v Compression Sarength 604-000x1ODO Max Mowable Berdng 52';100 ft lbs External Pressure Capacity 5410.000 psi MAKE-UP TORQUES Minnum 13280 Nbs Op-brnLrn 14750 1�tlbs Va;cmum 16230 ftlbF OPERATION LIMIT TORQUES Operalinq Torque 20000 ft-,Ibs Yield Tome 23400'1-lbs Notes 11-iiis connection is fully interchangeable with: TXFI,'RD BTC - 7 in. - 23129/32 135 138 lb,—,'ft Page 20 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Ililcorp Alaska, r.1.0 12.10 Hold a pre -j ob safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. • How to handle cement returns at surface, regardless of how unlikely it • Which pump will be utilized for displacement, and how fluid will be fed to displacement PUMP. • Positions and expectations of personnel involved with the cement operation. • Extra hands in the pits to strap during the cement job to identify any losses • Document efficiency of all possible displacement pumps prior to cement job. 12.11 7" cement job will be a single stage, single slurry job. 12.12 RU Cement lines to cement swivel on CRT. Plugs will be dropped manually. 12.13 Pump 5 bbls fresh water. Pressure test surface cement lines to 4000 psi. 12.14 Pump remaining 40 bbls 10.5 ppg tuned spacer. 12.15 Drop bottom plug, Mix and pump slurry per below calculations, 50% OH excess volume: Section: Calculation: of Vol (ft3) 9.875" OH x 7" Casing: (7,552'— 7,052') x 0.0471 bpf x 1.5 = 35.25 198 7" Shoe Track: 80' x.038 bpf = 3 16.8 Total Volume: 1 38.25 214.7 Slurry Information 12.16 After pumping cement, drop top plug and displace cement with drilling mud. Use rig pumps for displacement. Ensure to have a good baseline measurement for pump displacement ahead of time. Displacement calcs: Once cement turns the corner, slow displacement rates to 2 bpm. This is to ensure we do not exceed ECD limits and have circumferential cement Page 21 Cement Slurry System ExpandaCem Density 15.8 Ib/gal Yield 1.16 ft3/sk Mixed Water 4.972 gal/sk 12.16 After pumping cement, drop top plug and displace cement with drilling mud. Use rig pumps for displacement. Ensure to have a good baseline measurement for pump displacement ahead of time. Displacement calcs: Once cement turns the corner, slow displacement rates to 2 bpm. This is to ensure we do not exceed ECD limits and have circumferential cement Page 21 Ililcorp Alaska, LIA: • 7,472' x .038 bpf = 283.9 bbls 'y Milne Point Unit K -44A Kuparuk Producer Drilling Procedure 12.17 Reciprocate casing during cement job. If at anytime pipe movement gets sticky, land casing hanger. 12.18 Monitor returns closely while displacing cement. Ensure pits are strapped every 10 bbls of displacement and communicated with Co Rep. If losses are seen, let DSM know and possibly reduce pump rate. 12.19 Do not over displace by more than 1/2 shoe track volume. Total volume in shoe track is 3.5 bbls 12.20 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. If this is the case, monitor the pressure on the casing and do not let it exceed 500 psi over the final pump pressure. Ensure to report the following on wellez: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration • Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface & volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Send final "As -Run " casing tally & casing and cement report to iengel(acr�hilcorp. com and cdinger ,hilcoW. com. This will be included with the EOW documentation that goes to the AOGCC. 12.21 R/D cementing equipment. Flush out wellhead with FW. 12.22 Test void to 250/4000 psi for 10 min. 12.23 Freeze protect 10-3/4" x 7" Annulus 12.24 Lay down 5" DP Page 22 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Ilileorp Alaska, LLC 13.0 Production Hole Section Summary Depths of Interest (MD/TVD) Directional BHA Drilling Notes Casing & Cement 7" Shoe wp04 Bit MW 7,552/ 6,676 6-1/8" NOV SK613 10-10.5ppg Baradrill N Casing 4-1/2" 12.6# L-80TXP Slotted Lower Kalubik / KLGM RSS 7,695/ 6,765 GeoPilot Centralizers Increase MW t/ 1/jt Kuparuk D Inc: 10.5-11 at TD , Build to 89° by 8,840' 7,849/ 6,850 Hold to TD MWD/LWD Gamma / Res / PWD KuparukC Azi: Azimuthal Resistivy 8,457/ 7,059 Maintain 760 (Geo Steering) MPD Instal I RCD at Shoe after Drill out Cement TD Drillpipe CBHP Target: None 9,677/ 7,118 4" HT38 11.5- 12 PPG EMW @ Lower Kalubik TOOH: Offset swab to 11.5 -12 ppg EMW Page 23 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Ililcorp Alaska, TAX 14.0 Drill 6-1/8" Production Lateral 14.1 Change lower pipe rams to 2-7/8" x 5" VBR. Test to 250/3500. Chart Test • Test joints: 3-1/2", 4", 4-1/2" 14.2 P/U 6-1/8" RSS Directional BHA • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. • Workstring will be 4" 14# S-135 HT -38 / XT 39 • Run x2 Solid Plunger Floats for MPD 14.3 6-1/8" hole mud program summary: • Density: Although Kalubik / Kuparuk D pressures are predicted to be normal, past wells in this fault block have seen higher pressure. 10.0 ppg with MPD will be used as a precaution. Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. • Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. • Rheology: Ensure 6 rpm is >6.125 (hole diameter) for sufficient hole cleaning, YP as low as possible. Keep viscosifier additions to an absolute minimum (N -VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps • Inhibition: Watch MBT levels, dilute as necessary to maintain. Add KCl % if needed • Run the centrifuge continuously while drilling the production hole, this will help with solids removal and minimize sand content and LGS to maintain fluid properties and quality of the mud system. • Dump and dilute as necessary to keep drilled solids to a minimum • PVT will be used throughout the drilling phase. Remote monitoring stations will be available at the driller's console, Co Man office, & Toolpusher office. System Type: 10.0 — 11.5 ppg Baradrill N Pro Section Page 24 Viscositv I Plastic Viscosity I Yield Point I Total Solids I MBT Ililcorp Alaska, LLC Milne Point Unit K -44A Kuparuk Producer Drilling Procedure 6-1/8" 1 10.0 -11.5 1 75-175 1 15-25 1 15-25 1 < 10% 1 < 7 1 8.5 14.4 TIH w/ 6-1/8" directional assembly on 4" DP to above TOC. Shallow test MWD and LWD on trip in. 14.5 Note depth of TOC on morning report. Circulate bottoms up. 14.6 R/U and test casing to 3500 psi / 30 min. Ensure to record volume / pressure and plot on FIT J graph. AOGCC regulation is 50% of burst, test pressure is 3500 psi. i` Ly 4 14.7 Ensure even 10.0 ppg MW in and out before drilling shoe track 14.8 Drill out shoe track and 20' of new formation. 14.9 CBU and condition mud for FIT. ,f 14.10 Conduct FIT to 13.0 ppg EMW. 14.11 Install MPD Element • Ensure rig crew is familiar with MPD connection operations • Ensure max pressure relief settings are set correction to ensure no wellbore damage is created 14.12 Drill 6-1/8" hole section to section TD per Geologist and Drilling Engineer. • Flow Rate: 150-250 gpm (Target 200 ft/min AV) • RPM: 120 — for hole cleaning • WOB as needed • Target ECD and CBHP: 12.0 ppg EMW (This is for Kalubik shale stability) • Utilize MPD to maintain CBHP (constant bottom hole pressure) on connections, following Annular pressure ramp schedule • This will reduce the pumps on/ pumps off pressure cycles on shales • Slow ramp pumps on/off on each connection • Smooth connections are more important that connection time • Monitor connections for losses, adjust as necessary • Take MWD surveys every stand drilled. • 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. • Watch for fluid losses while drilling through Kuparuk. If losses are seen contact Drilling engineer and adjust MW and CBHP to highest without losses. 14.13 At TD;-CBU at least 3 times at maximum circulation and rotation • Circulate at full drill rate (150-250 gpm). Page 25 Ililcorp Alaska, TAX • Rotate at maximum rpm that can be sustained, target 120 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure 14.14 Observe well for flow. Displace well to brine 10.0ppg NaCl/Nabr Brine w/ 2% lube. 14.15 TOOH with the drilling assembly t/ 7" Shoe, Offsetting Swab with MPD • Follow tripping schedule, matching string speed and annular pressure • Rack back DP while TOOH, Do not lay down drill pipe. This is to minimize open hole time before liner is on bottom. 14.16 If backreaming is necessary: • Circulate at max rate while maintaining drilling ECD's • Perform CBHP connections • Rotate at maximum rpm that can be sustained. • Limit pulling speed to 5 — 10 min/std (slip to slip time, not including connections). • If backreaming operations are commenced, continue backreaming to the shoe and circ at least a b/u once at the shoe. 14.17 CBU at 7" Shoe. Increase brine weight once inside shoe to 11.0 ppg (this will be determined by connection monitoring while drilling this hole section) 14.18 Continue TOOH to HWDP/ BHA, offsetting swab with MPD • Once inside casing, drop rabbit on remaining drillpipe on TOOH that will be used to run the 4.5" liner. Confirm diameter drift with Baker for setting liner hanger 14.19 Pull RCD Bearing element at HWDP 14.20 L/D 6-1/8" BHA 14.21 No additional logs are planned for the 6-1/8" hole section. Page 26 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Hilcorp Ala,ka, LI.1: 15.0 Run 4-1/2" Slotted Liner Completion 15.1 Ensure rams have been tested on 4" & 4-1/2" test joint prior to running liner. 15.2 Ensure wear bushing is installed in wellhead. 15.3 R/U 4-1/2" casing running equipment. • Ensure 4-1/2" TXP crossover is on rig floor and M/U to FOSV with 1 joint of 4" DP. • Ensure all casing has been drifted prior to running. • Be sure to count the total # of joints before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 15.4 Run 4-1/2" slotted liner per completion tally. • Dope pin end only w/ paint brush. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Run 1 centralizer per joint for the entire liner 4-1/2" Tenaris TXP Make Up Torques Casing OD Minimum O timum Maximum 4.5" 5,550 ft -lbs 1 6,170 ft -lbs 6,790 ft -lbs 4-1/2" Tenaris TXP Operatiniz Limit Torques Casing OD Operating Yield 4.5" 6,790 ft -lbs 8,890 ft -lbs Page 27 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Ilileorp Alaska. LLC TXPd BTC r �.as 08l0312018 CONNECTION' DATA GEOMETRY Connection OD 5.000 in. Outside Diameter 4.500 in. Min. Wall 87.5?% Threads per in 5 Crnnedon 00 Option REGULAR PERFORMANCE Thickness (•j Grade LBO .loin; Y*ld Strength 2B OO@ x 1X0 Inteeanal Pressure Capaury I8430.Q00 psi lbs Type 1 Compression Effzki rzqy 100% Compression, Strength 288_000 x1000 Wall Thickness 0.271 in- Connection OD REGULAR Option COUPLING PIPE BODY Body: Red 1st Band: Red Grade LBO Type 1' Drift API Standard tst Baaxd: Brown 2nd Band: 2nd Band: - Brown Type Casing 3rd Band:- 3rd Band: - 4th Band: - Y!%E EODY DATA t I GEOMETRY I Nominal OO 4.590 in. Nominal Weight 12.6lbs,'It Gr ft 3.833 n- Nonsnal lit 3.958 in. Wall Tricknes=_ 0.271 in. Plain E; d'%Weight 12.25 bs'F OD Tcderarre API PERFORMANCE Brd^y Yield Strength 288 x1000 lbs Interna 'afield B430 phi SMYS 80000 psi Callayse 7500 psi CONNECTION' DATA GEOMETRY Connection OD 5.000 in. Coupling Length 9.075 in. Cznneotion ID 3.946 ae Make-up Los=- 4.016 in- Threads per in 5 Crnnedon 00 Option REGULAR PERFORMANCE Tension Elficie;tcy 100.0% .loin; Y*ld Strength 2B OO@ x 1X0 Inteeanal Pressure Capaury I8430.Q00 psi lbs Compression Effzki rzqy 100% Compression, Strength 288_000 x1000 ?Aax. .sable Bering 81 ";'too 0 lbs External Pressure Capacity 7500.000 psi ....... L MAKE UP TORQUES Minimum 55508-ks Optimum 6170ft4bs R&axrnurn 67901t -lbs OPERATION LJMIT TORQUES Operating Tcrque 6790 F -±s Yield Torgte 8800 ft -lbs Nates This connection is fully interchangeable with: TXP.3 BTC - 4.5 in_ -10.5111.6 113.5 i 15.1 Ibsift Page 28 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Ililcorp Alaska, LLC 15.5 Ensure to run enough liner to provide for approx 150' overlap inside 7" casing. Ensure hanger/pkr will not be set in a 7" connection and the packer should be above the 7" float collar. 15.6 Before picking up Baker ZXP liner hanger / packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 15.7 M/U Baker ZXP liner top packer. Fill liner tieback sleeve with packer fluid, ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set UP. 15.8 Note: SCMT tool may be ran on running tool for 7" TOC evaluation 15.9 Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 15.10 RIH w/ liner on DP no faster than 1-2 min / stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 15.11 Fill DP with Top drive every 10 stands or as appropriate. Slotted liner should fill while RIH. 15.12 Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + S/O depth every 5 stands. Record torque value if it becomes necessary to rotate the string to bottom. 15.13 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 15.14 RIH to TD as per running schedule. Monitor run for losses. 15.15 Once liner is on bottom, drop ball and pump down, slowing pump rate before ball is on seat 15.16 Once ball is on seat, increase drill pipe pressure to set liner hanger, — 2700psi. Slack off to ensure liner hanger is set. 15.17 Increase pressure to release running tool from liner hanger. Pressure up in 500 psi increments holding for 5 min each up to 4000 psi until indication that running tool has released. 15.18 Pickup to expose rotating dog sub, set down on liner and set ZXP liner top packer. Page 29 0 Ilileorp Alnsku, LLC Milne Point Unit K -44A Kuparuk Producer Drilling Procedure 15.19 With packoff on running tool still engaged, bleed DP pressure to zero, close BOP and test 7" x 4" annulus to 3000 psi for 30 min and chart record same. Rotate and set down, if necessary to ensure liner packer is set. Bleed off pressure and open BOPE. 15.20 Pressure up t/ 500 psi, pickup 2-3' to verify that the HRD setting tool has released. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. 15.21 Pick up above liner top. CBU x2. Displace 9.6 ppg clean brine. 15.22 If SCMT tool is ran on liner running tool, use SCMT to log TOC of 7" 15.23 POOH, L/D 4" DP and inspect running tools. 15.24 L/D remaining 4" DP out of derrick. V' 15.25 RU E -Line and run 7" CBL Cs 1 a 15.26 Ensure cement has reached 2000psi compressive strength before preforming CBL, this will allow cement to be detected by logging tools 15.27 Run CBL from 4-1/2" liner top to 500' above planned 7" TOC 15.28 RD E -line. Ensure to report the following on wellez: • Pre flush type, volume (bbls) & weight (ppg) • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration • Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure Send final "As -Run " casing tally & casing report to iengeikhilcoW. com, itoomeyghilcorp. com, and cdingerga,hilcorp. com. This will be included with the EOW documentation that goes to the AOGCC. Page 30 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Ilileorp Alaska, LLC 16.0 Run 3-1/2" ESP Completion 16.1 RU spooler with ESP power cable. 16.2 Verify the ESP components as per Centrilift. Verify that the length of the motor lead flat cable will place the splice between the discharge head and the 10' handling pup collar. A Centrilift rep shall be on the rig floor at all times during the running of the ESP. 16.3 Makeup new ESP assembly with new motor lead extension, seal section and motor. 16.4 Run the 3-1/2" ESP Completion as per tally 16.5 M/U ESP assembly and RIH to setting depth. • Ensure appropriate well control crossovers on rig floor and ready. • Monitor displacement from wellbore while RIH. • Check the conductivity of electric cable every 2,000' and every new splice while running in hole. QUAI Tubing Specification �heei TOOL 3-112, 9.30#9 L80, EUE 8RD, R2 Connection I Tool Joint (Upset) Nominal OD: 9.500 in Connection: 3-112" EUE 8RD ID: 2.992 to Coupling OD: 4.500 in ^ Weight: T9.30 Awn Tool Joint ID: 2.992 In Grade: LBO Drift: 2.897 in Tube Wall: 0.254 in Connection I Tool Joint Performance Tubing Length: _ R2 Thread Compound Friction Factor. 1.0 Inspection Class: Premium Class r Maximum MUT: 4,000 ft -lbs — RBW: 0,203 in Optimal MUT: 3,200 ft -lbs Tube Tensile: 163,178 lbs Minimum MUT: 2,400 11q:s Tube Coltapse: 7,399 psi Tube Internal Burst 9,289 psi Displacement Estimate; 0.00339 bbls/ft LW2!ns Tod J-'Asl Capacity Estimate: 0-00870 bbWft pneh+dee TOW JOinesl 16.6 Fill tubing while splicing cable, mid -cable splices and tubing hanger splices. After tubing is full, break circulation by pumping 10 bbls down the tubing to clear any debris. 16.7 Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. Page 31 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Ilileorp Alaska, LLC 16.8 MU tubing hanger and landing joint. Splice ESP power cable and terminate control lines. Test cable. Install a brass -shipping cap on the ESP penetrator. 16.9 Land tubing with extreme care to minimize damaging the ESP penetrator. pigtail and alignment pin. 16.10 RILDS and test hanger. LD landing joint. 16.11 Install BPV and N/D BOP. 16.12 N/U tree / adapter and tree. Test tubing hanger void to 500 psi low / 5000 psi high. Terminate the cap strings. 16.13 Circulate diesel freeze protection down 3-1/2" x 7" annulus (Volume should equal capacity of tubing to 2500' + tubing annulus to 2500'). Connect IA to tree and allow diesel freeze protect to "U-tube" into position. 16.14 Pull BPV. Set TWC. Test tree to 250 psi low / 5000 psi high. Pull TWC. Set BPV. 16.15 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 17.0 "MO 17.1 RDMO Innovation Rig Page 32 Ililcorp Ala.ka, LLC. 18.0 Innovation Rig BOP Schematic 13-5/8' 5M C Annular BOF 13-518' 5M C Technology t 3-1/8" Kill 13-5t8" 5M C Technology Page 33 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure 2-7/8" x 5-1/2" VBR Blind Rams 3-1/8" Choke line 2-7/8" x 5-1/2" VBR 3"x 5M x 5M 0 llilcorp Alaska, LLC 19.0 Days vs Depth 0 1000 2000 3000 $ 4000 a v 0 5000 v 6000 7000 8000 9000 10000 Page 34 MPU K -44A Kuparuk Producer Days vs Depth 0 S 10 15 Days Milne Point Unit K -44A Kuparuk Producer Drilling Procedure 20 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Ililcorp Alaska, LLC 20.0 Formation Tops & Information MPU K -44A Formations (wp04) MD (ft) TVDss (ft) ND (ft) Formation Pressure (psi) EMW (ppg) Colville 5732 5013 5069 2256 8.56 HRZ 7480 6572 6627 2957 8.58 KLB 7606 6655 6710 2994 8.58 K LG M 7695 6710 6765 3019 8.58 Kuparuk D 7849 6795 6850 3057 8.58 Kuparuk C 8487 7004 7059 3151 8.58 4400- N s.inds 4700' �,kfl.CX EF) OSwds 4600- 6 Efl 4$00' Top of Seabee Seabee 6,000 6330' •1-100' 6550' N-100' e75a +1-100' 6950' *1-100' POSSIBLE SHALLOW GAS +/- 4500 (CASCADE #1) Schrader Bluff Sands: continued layered coarsening upward sands as above except more condensed. Possible hydrocarbon bearing. Seabee (Colville) Interval: Predominantly interbedded sttstone and clay with beds of sand. shale and occasional seams of coal. The Seabee Is generally uneventful until reaching the HRZ. Expect good penetration rates f+f-100 V11). HRZ V HRZ: Highly Radioactive Zone. Very dark, thistle type shale, organic, good source rock. Tuft (bentonitic) zone le H possible at top of HRZ. Kalubik Shale: Marker f tK19 good lag marker. lubik Gradually diminishing ROP. D- Kuparuk Interval: Shale The "D" Stlaleisthe top Kuparuk sediment and Is known asthe "Cap Rook". 70430' — - - N-100' B (LZ) SANDS 7200' A AND 73oa' +l-100' Page 35 C SANDS: Sandstone, shales upward. Oil bearing target LCU: Lower Cretaceous Unconformtty B Sands: Also known as the laminated Zone begins below LCU. Fine to medium grain sands becoming more shaley with depth. Hydrocarbon bearing. Pinches out to the north and thickens to the southeast- Top sand, 6-7, is targeL Use controlled drilling rate in Kuparuk for LWO. A- Fine grain sandstone. Potential hydrocarbon bearing. Secondary Kuparuk target at K -Pad Miluveach shales: oredominantty silty shale. I _ -j - L 9.7 p I10.1l10.2 PP9 i 99 ppg EMW' ORIGINAL RESERVOIR =PRESSURE l ial Kuparuk reservoir uro of 3600 psi ss (9.9 ppg). Average trature +167 deg F at the Current 2004 reservoir uros are 7.6 to 4.0 ppg I 11.0 'Enter Kuparuk cautiously. ALTHOUGH NO WLSTULS ON K•PAD HAVE CK PIPE IN THIS INTERVAL, THIS IS A STUCK PIPE INTERVAL ON 8. E. f and L Pads. Casing seat for normal Kuparuk completion. Milne Point Unit K -44A Kuparuk Producer Drilling Procedure llileorp Alaska, LAG 21.0 Anticipated Drilling Hazards Intermediate & Production Hole Sections: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low -vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate with AV of 200 ft/min. Lost Circulation: Lost circulation has been seen in the Colville formation at EMW exceeding — 12.0 ppg. Monitor ECDs during production section to ensure ECDs stay below 12.0. Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Abnormal Pressures and Temperatures: Although Kuparuk reservoir pressure is predicted to be normal (.45 psi/ft TVD), a past well in this fault block encountered trapped injection pressure in the Kuparuk D. This is the reason for the 7" top set depth and high production hole mud weight. Wellbore Stability: This well will drill through historically trouble shales, HRZ & Kalubik. Maintain sufficient MW for stability and utilize MPD to maintain constant bottom hole pressure to mitigate on/off pressure cycles. Use MPD to offset swab effect while TOOH. Follow tripping in hole schedule to manage surge pressures on shales. Anti -Collision: This well has no close approaches on the planned wellpath. Monitor MWD survey for magnetic interference while drilling ahead. Faulting: There are no known faults in either hole section. H2S: Treat every hole section as though it has the potential for 1-12S. No 1-12S events have been documented on drill wells on "K" pad. • The AOGCC will be notified within 24 hours if 1-12S is encountered in excess of 20 ppm during drilling operations. • 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 36 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Ililrorp Alaska, LLC 22.0 Innovation Rig Layout Page 37 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Ifileorp Alaska, LIX 23.0 FIT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: 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. Page 3 8 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Ildvorp Alaska, HA: 24.0 Innovation Choke Manifold Schematic Page 39 25.0 Casing Design Information Calculation & Casing Design Factors n Hilcorp E �� Hole Size 9.875 Hole Size 6-1/8" Drilling Mode MAS P(9.875"): 2737 Milne Point Unit DATE: 8.30.19 WELL: MPU K -44A DESIGN BY: Joe Engel Design Criteria: Mud Density: Mud Density: attached MASP determination & calculation) Production Mode MASP: 2918 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation ' 1, 2, 3 Max MW gradient external stress and the casing evacuated for the internal stress Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Casina Section Calculation/Specification 1 2 3 Casing OD P. 4-1/2" Slotted Top (MD) 0 7,400 Top (TVD) 0 6,600 Bottom (MD) 7,552 9,677 Bottom (TVD) 6,676 7,118 Length 7,552 2,277 Weight (ppf) 26 12.6 Grade L-80 L-80 Connection TV TXP Weight w/o Bouyancy Factor (lbs) 196,352 28,690 Tension at Top of Section (Ibs) 196,352 28,690 Min strength Tension (1000 lbs) 604 288 Worst Case Safety Factor (Tension) 3.08-" 10.04 ✓ Collapse Pressure at bottom (Psi) 3,338 3,630 Collapse Resistance w/o tension (Psi) 5,410 7,500 Worst Case Safety Factor (Collapse) 1.62 2.07 MASP (psi) 2,737 2,918 Minimum Yield (psi) 7,240 8,430 Worst case safety factor (Burst) 2.65 2.89 Page 40 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure 11ilcorp Alaska, LLC 26.0 9-7/8" & 6-1/8" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 14 9-7/8" Intermediate Hole Section HilMrp MPU K -44A Milne Point MD TVD Planned Top: 5600 4952 Planned TD: 7552 6676 4nticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Kalubik 61710 2994 1 - 1 8.6 0.446 Offset Well Mud Densities Well MW range Top [TVD) Bottom (TVD) Date L-43 9.3-9.8 439 6,745 2004 L-41 9.5-10.8 4,850 6,889 2018 L-55 9.5-10.5 4,563 6,890 2018 *MWforShale Stability Assumptions: 1. Fracture gradient at shoe is estimated at 0.7 psi /ft based on field test data. 2. Maximum planned mud density for the 9.875" hole section is 11.0 ppg. 3. Calculations assume Kuparuk reservior contains 100% gas (worst case). 4. Calculations assume worst case event is complete evacuation of wellbore to gas. Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface: 10-3/4" Shoe 5597MD / 4952' TVD 4952 (ft) x 0.7(psi/ft)= 3466 3466 (psi) - [0.1(psi/ft)*4952(ft)]= 2972 psi Drilling Mode MASP MASP from pore pressure (wellbore completely evacuated togas) 6676(ft) x 0.51(psi/ft)= 3405 psi 3405 (psi) - [0.1(psi/ft)*6676(ft)]= 2737 psi Summary: 1. MASP while drilling 8-1/2" Intermediate hole is governed by the wellbore completely evacuated to gas from the Kuparuk Reservior Page 41 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Ililcorp Alaska, LLC Maximum Anticipated Surface Pressure Calculation Hilcor� p 6.125" Production Hole Section MPU K -44A Milne Point MD TVD Planned Top: 7552 6676 Planned TD: 9677 7118 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Top Kuparuk C Sand 7,059 3151 Oil 8.6 0.446 Offset Well Mud Densities Well MW mnwe Tnn ITVDI Rnttnm (TVnl nates L-41 10-10.5 6,889 7,725 2018 L-55 10.5-11.5 6,890 7,713 2018 Assumptions: 1. Fracture gradient at shoe is estimated at 0.7 psi /ft based on field test data. 2. Maximum planned mud density for the 6-1/8" hole section is 10.0 ppg. 3. Calculations assume the Kuparuk reservior contains 100'% gas (worst case). 4. Calculations assume worst case event is complete evacuation of wellbore to gas. Fracture Pressure at 7" shoe considering a full column of gas from shoe to surface: 6676 (ft) x 0.7(psi/ft)= 4673 4673 (psi) - [0. 1(psi/ft) *6676(ft) ] = 4005 psi Drilling Mode MASP MASP from pore pressure (wellbore completely evacuated to gas) 7118(ft) x 0.51(psi/ft)= 3630 psi 3630(psi)-[0.1(psi/ft)*7118(ft)]= 2918psi Summary: 1. MASP while drilling 6-1/8" Intermediate hole is governed by wellbore completely evacuated togas from the Kuparuk. Page 42 Ilileorp :Alaska, LLA: 27.0 Spider Plot (NAD 27) (Governmental Sections) ADL028232 Milne Point Unit K -44A Kuparuk Producer Drilling Procedure Legend i MPU K-44A_SHL X MPU K- 4A_YPH T RAPU K -44A BHL • Othet Surface Hales (SHL) Olhet Bottorn Holes (BHL) - - - Othet Well Paths OR and Gas Unit Boundary � , I Pad Footprint o�oo° .\IPU K- A_BHL - NIPIJ K -44A TPH .1 +•N-194 Sec. 2 I I \ r / N. ADL375133 1 U012N011E. E , A 3 r Kra ADL375132 ' • ". i S.C. 9 Sec. 10 Milne Point Unit MPK-44A Well rvio cwc: 9 :zs �s WpO4 Page 43 Sec. 11 4 1,200 2,400 Feet Sec. 1 0 Ililcorp Alaska, LLT: 28.0 Surface Plat (As Built) (NAD 27) Milne Point Unit K -44A Kuparuk Producer Drilling Procedure jt4`.� 19 p E 30 -2 2a 32. ,13 7M ��2r 5• • 8 y 4 s • + K-44 MF K j • • 14 7 7 ■ • 19 j 10 2, • 22 x i� e 9 C t ■ 30 VICINITY MAP 33 ■ ■ 34 j 37 ■ ■ as j gA�m)i�,44]).i 43. �7 K -PAD j �a,• ]ri 9 RENAMED CONDUCTOR REVISION NOTE » IkELL �� K-44 AS -BUILT CONDUCTOR Tuna ly . Bamhlft 1o2Q0 T,+S AS-Eiuv pRAw4C IS A REISSUE OF ■ EXISTING CONDUCTOR FREMOVS AS -BUILT DRAVANG FOR CONDUCTOR MP K -IC. RENAMED CONDUCTOR IS AS FOLLOWS. jprlay1,.C� OLD COND. NAME NE'W GOND. NAM MP K-10 MP K-44 SURVEYQR'S CERTIFICATE I HEREBY CERTFY THAT I AM PROPERLY REGSTERED AND UC£.NSED NOTES TO PRACTICE LAND SURY£nNC IN THE STATE OF ALASKA AND THAT 1. DATE OF SURVEY: MARC" 21-25, 1996, TYS AS-BUIL7 REPRESEN'•.'S A SUR%CY MADE BY ME OR UNDER YY DIRECT 2, REFV;IENCE FIELD BOCOL MPSO-04 (13-21). SUPERMSION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, ALASKA, NAD 27, CORRECT AS OF MARCH 24, 1996. 4. MP'J K -PAD SCALE FACTOR IS: 0.99990V2, 5, HCRIZONTAL CONTROL BASED ON U`.,GS MONUMENT 'FOX' ANO Y'U MONUMENT C -i. GRAPHIC SCALE S. ELEVATIONS ARE BP MPU DATUM (M,5k ). 0 75 150 309 7. VVITM CONTROL IS BASED ON BRAIDEN CAP AT WELL C-1, EL£VAMN - 16,06'. MTA9Lmg1G BY WW40FF & ASSOCIATES. ( IN Ful 1 I wd, + 1.0 +t . i n u , nTOArrCn -!1 It T 1'S Ai P 11 P' 1IAAIAT LAGi?IFIIAIN A4 ACM'A WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO, COORDINATES COORDINATES POSITION(CIMS)?OSITION D.DD BOX ELEV. OFFSETS Y=6.005,880.17 N 9,939.93 70'25'33.570" 70.4259917' 2g'3 3,744' KSL K-44 X= 584,535.02 E 5,109.88 149'16'40.034" 149.3111206' 2,020' FEL rn°81WA _ Hilcor Alaska ...r P MiLNE POINT K -PAD RENAMED CONDUCTOR m + av ts•tm roe riaratlou -- --.. _� w s. I'�—._-. WELL K-44 e,a an iawsw u. a Page 44 Hilcorp Alaska, LLC Milne Point M Pt K Pad Plan: MPK-44 MPU K -44A Plan: MPU K -44A wp04 Standard Proposal Report 27 August, 2019 HALLIBURTON Sperry Drilling Services HALLIBURTON Spurry Drilling - Hilcorp Alaska, LLC Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Closest Approach 3D Error Surface: Pedal Curve Warning Method: Error Ratio ate (N/E) Reference: Well Plan: MPK-44, True North Vertical (TVD) Reference: MPU K -44A Planned RKB @ 55.80usft .asured Depth Reference: MPU K -44A Planned RKB @ 55.80usft Calculation Method: Minimum Curvature iec MD Inc Azi TVD +N/ -S +E/ -W Dleg TFace VSect Target Annotation 1 5600.00 32.92 75.32 4954.17 655.14 2189.98 0.00 0.00 2283.93 0.00 0.00 6005880.17 584535.02 70" 25' 33.570 N KOP : Start Dir 5.05'/100': 5600' MD, 4954.17'TVD : 173.19° RT TF 2 6064.30 9.99 91.10 5383.69 686.78 2354.58 5.05 173.19 2451.24 Date: 2019-08-02T00:00:00 Validated: Yes Version: End Dir : 6064.3' MD, 5383.69' TVD 3 6242.98 9.99 91.10 5559.66 686.18 2385.57 0.00 0.00 2481.12 127.50 498.46 MPK-44 Interp (MPK44) Start Dir 3.031/100' : 6242.98' MD, 5559.66'TVD 4 7475.27 47.00 77.72 6624.64 783.44 2952.95 3.03 -16.20 3054.95 MPU K-44RD wp03 CPI Start Dir 3°/100' : 7475.27' MD, 6624.64'TVD 5 7660.07 52.54 77.72 6743.94 813.44 3090.75 3.00 0.00 3195.90 MPU K-44RD wp03 CP2 Start Dir 3.50/100' : 7660.07' MD, 6743.94'TVD 6 8407.43 78.67 76.37 7049.92 965.49 3748.15 3.50 -2.99 3870.49 FORMATION TOP DETAILS End Dir : 8407.43' MD, 7049.92' TVD 7 8492.85 78.67 76.37 7066.70 985.22 3829.55 0.00 0.00 3954.24 Formation Start Dir 3°/100' : 8492.85' MD, 7066.7'TVD 8 8571.89 81.00 76.84 7080.64 1003.24 3905.22 3.00 11.17 4032.02 MPU K-44RD wp03 tgt1 9 8840.96 89.03 76.05 7103.99 1066.03 4165.59 3.00 -5.65 4299.83 KLGM End Dir : 8840.96' MD, 7103.99' TVD 10 9677.27 89.03 76.05 7118.10 1267.65 4977.12 0.00 0.00 5136.01 MPU K-44RD wp03 tgt2 Total Depth : 9677.27' MD, 7118.1' TVD 2000 2250 ry5R0 c X000 c) 3000 �yp0 Lp000 tj 3750 R�00 KOP : Start Dir 5.05°/100' : 5600' MD, 4954.17'TVD : 173.19° RT TF ] End Dir : 6064.3' MD, 5383.69' TVD Start Dir 3.03°/100' : 6242.98' MD, 5559.66'TVD j 4500 - _ (D SB BASE g5�� ' Start Dir 31/100' : 7475.27' MD, 6624.64'TVD WELL DETAILS: Plan: MPK-44 52500 Ground Level: 29.30 y0Z Start Dir 3.51/100' : 7660.07' MD, 6743.94 -TVD +N/ -S +E/ -W Northing Easting Latitlude Longitude End Dir : 8407.43' MD, 7049.92' TVD 6000 HRZ 0.00 0.00 6005880.17 584535.02 70" 25' 33.570 N 149" 18'40.034 W Milne Point 7 x 9 7/8""'10 SURVEY PROGRAM Site: Site: M Pt K Pad -' _ I D 7 o o co - Tota Depth . 9677.27 M 118.1 TVD Date: 2019-08-02T00:00:00 Validated: Yes Version: - =KUP D= We//: Plan: MPK-44 Depth From Depth To Survey/Plan Tool Wellbore: MPU K -44A MPU K-44RD wp03 CP2 127.50 498.46 MPK-44 Interp (MPK44) 2 MWD Interp Azi+Sag 8370 593.84 5550.20 MWD+IFR2+MS+sag (1) (MPK44) 2 MWD+IFR2+MS+Sag Design: MPU K -44A wp04 5626.31 5600.00 MWttt1DK+IFR2+MpS+sag (�2)) (MPK-44) 2_MWD+IFR2+MS+Sag 5600.00 5892.54 tMPU wpOg4(y1pPU 2_MWD _Interp Azi+Sag K� K -g44 5892.54 7552.54 M �'P 1M) 2_MWD+IFR2+MS+Sag 7552.54 9677.27 MPU K44Awp04 (MPU K44A) 2_MWD+IFR2+MS+Sag FORMATION TOP DETAILS 0 CASING DETAILS TVDPath TVDssPath MDPath Formation TVD TVDSS MD Size Name 5069.23 5013.43 5732.41 SB BASE 500 6676.18 6620.38 7552.54 7 7" x 9 7/8"" 6627.90 6572.10 7480.06 HRZ 7118.10 7062.30 9677.27 4-1/2 4 1/2" x 6 1/8" 6710.64 6654.84 7606.29 KLB 750 6765.04 6709.24 7695.26 KLGM 6850.35 6794.55 7849.78 KUP D 1000 7059.68 7003.88 8457.13 KUP C 1500 15p0 2000 2250 ry5R0 c X000 c) 3000 �yp0 Lp000 tj 3750 R�00 KOP : Start Dir 5.05°/100' : 5600' MD, 4954.17'TVD : 173.19° RT TF ] End Dir : 6064.3' MD, 5383.69' TVD Start Dir 3.03°/100' : 6242.98' MD, 5559.66'TVD j 4500 - _ (D SB BASE g5�� ' Start Dir 31/100' : 7475.27' MD, 6624.64'TVD MPU K-44RD wp03 tgtl -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 Vertical Section at 75.71° (1500 usft/in) 52500 y0Z Start Dir 3.51/100' : 7660.07' MD, 6743.94 -TVD 6 End Dir : 8407.43' MD, 7049.92' TVD 6000 HRZ 000 Start Dir 3'1100': 8492.85' MD, 7066.7'TVD KLB 7 x 9 7/8""'10 End Dir : 8840.96' MD, 7103.99' TVD KLGM _ MPU K-44RD wp03 GPI--, �5�0 o� -' _ I D 7 o o co - Tota Depth . 9677.27 M 118.1 TVD 6750 - =KUP D= -- - - _ _- _-_ -T - o 0_ ,-� 0 � KUP_C MPU K-44RD wp03 CP2 ----- - - - 4 1/2" x 6 1/8" 8370 7500 MPU K -44A wp04 MPK-44 ; MPU K-44RD wp03 tgt2 MPU K-44RD wp03 tgtl -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 Vertical Section at 75.71° (1500 usft/in) HALLIBURTON Pro Milne Point Site: M Pt K Pad Well: Plan: MPK-44 f WELL DETAILS: Plan: MPK-0 G..W le�e1: 29.30 +x/ -s +E/ -w Nnnhing E ti.g [afiln,de Longimdc 584538.02 g�,T, o„ftl„w Wellbore: MPU K -44A 0.00 0.00 6005880.17 0°25'37.570N 49°18'40.034W Plan: MPU K -44A wp04 REFERENCE INFORMATION Co-oN— (NIE) Reference: Well Plan: MPK4 , True Noah Veni.l (D/D) Ref—: MPU K-0 A Planned R103 @ 55.80u0 (I—fi.n) 2200 Measured Depth Refen:nm: MPU K -44A Pb -ed RK @ 55.80osft (1— —) Calwlatien Method: Minimum C,m— CASING DETAILS MDSiName 75525 77" z 9 7/8"' r7-711'..1'.. 1833 7062.30 9677.27 4-1 f2 4 MY 6118" MPU K- 4A %1,04 1467 MPU K-14RD up03 tgt2 MPU K-44RD up03 CP2 MPU K44RD up03 tIVI MPU K-44RD up03 CPI 1100 MPK-44 2 Total lkplL :96]].2]' MD, 7118.1' i'4D rk End Du :8830.96' HOJ, 7103.99' TVD 733 4 o Start Dir Y/100': 84'9 2,85- MD, 7068.71 VD rJ + t c $ � End Di, :8407.41'HID,7W9.92TVD rb Srurt D"u35"/100':76611.07'H[D, 6743.94TVD _ Stan Dir 3°/100':7475.27' MD, 6614.647VD ,a 367 � C 0 c Stan Dir 3.03'/100' : 6242.98' MD, 5559.66'TVD c sc 0 �� i Ed Du : 6064.3' MD, 5383.69' TVD a KOP: Stan Dir 5.05°/100': 5600' MD, 4954.] TTVD: 173.19° RTTF 1 0 367 733 1100 1467 1837 2200 2567 2933 7300 3667 4033 4400 4767 5133 West(-)/Eas1(+) (550 usft/in) HALLIBURTON Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt K Pad Well: Plan: MPK-44 Wellbore: MPU K -44A Design: MPU K-44Awp04 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPK-44 TVD Reference: MPU K -44A Planned RKB @ 55.80usft (Innovati, MD Reference: MPU K -44A Planned RKB @ 55.80usft (Innovati� 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 Audit Notes: Tie On Depth: 5,600.00 +N/ -S Site M Pt K Pad, TR -12-11 Direction Phase: Vertical Section: Site Position: Northing: 5,994,744.31 usft Latitude: 70° 23'44.152 N From: Map Easting: 583,595.36usft Longitude: 149° 19' 11.252 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.64 ° Well Plan: MPK-44 +N/ -S +E/ -W Well Position +N/ -S 0.00 usft Northing: 6,005,880.17 usfl Latitude: 70° 25'33.570 N Depth Inclination +E/ -W 0.00 usft Easting: 584,535.02 usfl Longitude: 149° 18'40.034 W Position Uncertainty 0.00 usfl Wellhead Elevation: 0.00 usfl Ground Level: 29.30 usft Wellbore MPU K -44A 75.32 4,954.17 4,898.37 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 6,242.98 9.99 91.10 (1 (°) (nT) 7,475.27 BGGM2018 10/2/2019 16.52 80.94 57,414.64576475 Design MPU K-44Awp04 77.72 6,743.94 6,688.14 Audit Notes: Tie On Depth: 5,600.00 +N/ -S Version: Direction Phase: Vertical Section: (usft) Depth From (TVD) 0.00 0.00 (usft) 75.71 26.50 Dogleg Plan Sections Turn +N/ -S +E/ -W Measured Rate Rate Vertical TVD Depth Inclination Azimuth Depth System (usft) (°) (°) (usfl) usfl 5,600.00 32.92 75.32 4,954.17 4,898.37 6,064.30 9.99 91.10 5,383.69 5,327.89 6,242.98 9.99 91.10 5,559.66 5,503.86 7,475.27 47.00 77.72 6,624.64 6,568.84 7,660.07 52.54 77.72 6,743.94 6,688.14 8,407.43 78.67 76.37 7,049.92 6,994.12 8,492.85 78.67 76.37 7,066.70 7,010.90 8,571.89 81.00 76.84 7,080.64 7,024.84 8,840.96 89.03 76.05 7,103.99 7,048.19 9,677.27 89.03 76.05 7,118.10 7,062.30 PLAN Tie On Depth: 5,600.00 +N/ -S +E/ -W Direction (usft) (usft) (°) 0.00 0.00 75.71 Dogleg Build Turn +N/ -S +E/ -W Rate Rate Rate Tool Face (usft) (usft) (°/100usft) (°1100usft) (°/100usft) (°) 655.14 2,189.98 0.00 0.00 0.00 0.00 686.78 2,354.58 5.05 -4.94 3.40 173.19 686.18 2,385.57 0.00 0.00 0.00 0.00 783.44 2,952.95 3.03 3.00 -1.09 -16.20 813.44 3,090.75 3.00 3.00 0.00 0.00 965.49 3,748.15 3.50 3.50 -0.18 -2.99 985.22 3,829.55 0.00 0.00 0.00 0.00 1,003.24 3,905.22 3.00 2.94 0.59 11.17 1,066.03 4,165.59 3.00 2.99 -0.29 -5.65 1,267.65 4,977.12 0.00 0.00 0.00 0.00 8/27/2019 2:05.09PM Page 2 COMPASS 5000.15 Build 91 Planned Survey Measured Halliburton HALLIBURTON Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPK-44 Company: Hilcorp Alaska, LLC TVD Reference: MPU K -44A Planned RKB @ 55.80usft (Innovatif Project: Milne Point MD Reference: MPU K -44A Planned RKB @ 55.80usft (Innovatii Site: M Pt K Pad North Reference: True Well: Plan: MPK-44 Survey Calculation Method: Minimum Curvature Wellbore: MPU K -44A (°) (°) Design: MPU K-44Awp04 usft (usft) 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) -29,30 26.50 0.00 0.00 26.50 -29.30 0.00 0.00 6,005,880.17 584,535.02 0.00 0.00 127.50 0.33 35.07 127.50 71.70 0.24 0.17 6,005,880.41 584,535.18 0.33 0.22 217.75 0.14 35.07 217.75 161.95 0.54 0.38 6,005,880.72 584,535.39 0.21 0.50 314.49 0.14 35.07 314.49 258.69 0.73 0.52 6,005,880.91 584,535.53 0.00 0.68 402.90 0.09 35.07 402.90 347.10 0.88 0.62 6,005,881.06 584,535.63 0.06 0.82 498.46 0.40 35.07 498.46 442.66 1.21 0.85 6,005,881.39 584,535.86 0.32 1.13 593.84 0.41 35.07 593.83 538.03 1.77 1.24 6,005,881.95 584,536.24 0.01 1.64 687.81 0.33 59.69 687.80 632.00 2.18 1.67 6,005,882.37 584,536.66 0.19 2.15 781.91 3.51 62.00 781.84 726.04 3.67 4.44 6,005,883.89 584,539.42 3.38 5.21 873.49 3.72 59.90 873.24 817.44 6.47 9.49 6,005,886.75 584,544.44 0.27 10.79 970.74 6.44 60.18 970.09 914.29 10.77 16.95 6,005,891.13 584,551.85 2.80 19.09 1,064.85 7.19 59.23 1,063.54 1,007.74 16.41 26.59 6,005,896.87 584,561.42 0.81 29.82 1,159.10 9.92 54.29 1,156.73 1,100.93 24.16 38.25 6,005,904.76 584,572.99 3.00 43.03 1,253.51 13.85 51.79 1,249.10 1,193.30 35.90 53.74 6,005,916.68 584,588.35 4.20 60.94 1,346.39 14.07 47.45 1,339.24 1,283.44 50.42 70.80 6,005,931.38 584,605.23 1.15 81.05 1,441.24 17.25 57.75 1,430.58 1,374.78 65.72 91.19 6,005,946.92 584,625.45 4.44 104.59 1,536.45 19.82 56.51 1,520.84 1,465.04 82.17 116.60 6,005,963.64 584,650.67 2.73 133.27 1,630.57 21.66 54.34 1,608.86 1,553.06 101.10 144.02 6,005,982.88 584,677.87 2.12 164.52 1,724.48 23.28 53.85 1,695.64 1,639.84 122.15 173.09 6,006,004.26 584,706.70 1.74 197.88 1,818.53 23.16 54.11 1,782.07 1,726.27 143.96 203.08 6,006,026.40 584,736.44 0.17 232.33 1,913.55 27.58 60.21 1,867.92 1,812.12 165.85 237.33 6,006,048.69 584,770.43 5.40 270.92 2,006.78 28.52 67.63 1,950.22 1,894.42 185.05 276.65 6,006,068.33 584,809.54 3.87 313.77 2,101.08 30.13 74.89 2,032.46 1,976.66 199.80 320.34 6,006,083.56 584,853.05 4.14 359.74 2,195.53 32.67 75.78 2,113.07 2,057.27 212.24 367.94 6,006,096.54 584,900.50 2.73 408.94 2,290.18 34.98 74.94 2,191.70 2,135.90 225.57 418.91 6,006,110.45 584,951.31 2.49 461.63 2,384.37 35.13 75.78 2,268.80 2,213.00 239.24 471.26 6,006,124.71 585,003.49 0.54 515.72 2,478.97 35.02 75.73 2,346.22 2,290.42 252.62 523.95 6,006,138.68 585,056.02 0.12 570.09 2,573.36 33.40 75.95 2,424.28 2,368.48 265.60 575.40 6,006,152.25 585,107.32 1.72 623.15 2,667.57 33.35 76.18 2,502.95 2,447.15 278.08 625.70 6,006,165.29 585,157.47 0.14 674.98 2,762.05 33.30 76.40 2,581.90 2,526.10 290.38 676.13 6,006,178.17 585,207.75 0.14 726.88 2,856.79 33.14 76.15 2,661.15 2,605.35 302.70 726.55 6,006,191.05 585,258.03 0.22 778.78 2,952.48 33.13 76.31 2,741.28 2,685.48 315.15 777.35 6,006,204.07 585,308.68 0.09 831.09 3,044.77 32.98 76.91 2,818.64 2,762.84 326.80 826.32 6,006,216.28 585,357.51 0.39 881.42 3,139.78 32.89 76.51 2,898.38 2,842.58 338.68 876.59 6,006,228.73 585,407.64 0.25 933.07 3,234.28 32.30 76.66 2,977.99 2,922.19 350.49 926.11 6,006,241.10 585,457.02 0.63 983.97 3,328.87 31.84 76.87 3,058.15 3,002.35 361.99 975.00 6,006,253.15 585,505.77 0.50 1,034.18 3,423.11 32.11 75.94 3,138.09 3,082.29 373.72 1,023.50 6,006,265.43 585,554.13 0.60 1,084.08 3,517.28 34.16 75.56 3,216.94 3,161.14 386.40 1,073.39 6,006,278.66 585,603.87 2.19 1,135.55 3,612.24 34.31 76.28 3,295.45 3,239.65 399.39 1,125.21 6,006,292.24 585,655.53 0.45 1,188.97 3,706.07 34.14 76.62 3,373.03 3,317.23 411.76 1,176.51 6,006,305.19 585,706.69 0.27 1,241.74 3,797.09 33.88 77.33 3,448.48 3,392.68 423.23 1,226.11 6,006,317.22 585,756.15 0.52 1,292.64 3,894.62 33.84 77.42 3,529.47 3,473.67 435.11 1,279.14 6,006,329.70 585,809.03 0.07 1,346.96 3,988.44 34.21 76.67 3,607.23 3,551.43 446.88 1,330.30 6,006,342.05 585,860.05 0.60 1,399.44 4,082.72 34.36 77.19 3,685.13 3,629.33 458.89 1,382.03 6,006,354.64 585,911.64 0.35 1,452.54 4,177.40 32.99 75.74 3,763.92 3,708.12 471.16 1,433.07 6,006,367.49 585,962.53 1.68 1,505.03 8/172019 2:05:09PM Page 3 COMPASS 5000.15 Build 91 Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt K Pad Well: Plan: MPK-44 Wellbore: MPU K -44A Design: MPU K-44Awp04 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss (usft) (1) (1) (usft) usft Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPK-44 TVD Reference: MPU K -44A Planned RKB @ 55.80usft (Innovati MD Reference: MPU K -44A Planned RKB @ 55.80usft (Innovatii ' North Reference: True Survey Calculation Method: Minimum Curvature +N/ -S (usft) 4,266.58 32.62 75.98 3,838.88 3,783.08 482.97 4,367.46 31.79 76.90 3,924.24 3,868.44 495.58 4,461.04 32.57 76.47 4,003.44 3,947.64 507.06 4,555.85 33.60 75.78 4,082.88 4,027.08 519.47 4,650.41 33.10 76.12 4,161.86 4,106.06 532.09 4,744.94 33.54 76.51 4,240.86 4,185.06 544.38 4,838.93 34.23 76.88 4,318.88 4,263.08 556.43 4,933.43 34.35 77.85 4,396.96 4,341.16 568.08 5,027.55 33.76 76.44 4,474.94 4,419.14 579.80 5,121.19 34.34 76.97 4,552.52 4,496.72 591.85 5,212.33 32.72 76.12 4,628.49 4,572.69 603.56 5,310.08 32.24 76.10 4,710.95 4,655.15 616.16 5,404.93 33.16 75.79 4,790.77 4,734.97 628.61 5,499.61 33.09 75.51 4,870.06 4,814.26 641.43 5,550.20 33.18 75.62 4,912.43 4,856.63 648.32 5,589.54 32.97 75.38 4,945.39 4,889.59 653.70 10 3/4" 586,717.24 0.62 2,283.93 2,239.06 6,006,572.88 5,600.00 32.92 75.32 4,954.17 4,898.37 655.14 KOP : Start Dir 5.05°/100' : 5600' MD, 4954.17'TVD : 173.19° RT TF 5,700.00 27.91 76.60 5,040.38 4,984.58 667.46 5,732.41 26.29 77.11 5,069.23 5,013.43 670.82 SB BASE 2,438.71 2,354.58 6,006,593.51 586,881.45 5.05 5,800.00 22.92 78.38 5,130.68 5,074.88 676.81 5,900.00 17.96 81.09 5,224.36 5,168.56 683.12 6,000.00 13.06 85.76 5,320.69 5,264.89 686.35 6,064.30 9.99 91.10 5,383.69 5,327.89 686.78 End Dir : 6064.3' MD, 5383.69' TVD 6,006,597.66 586,973.41 6,100.00 9.99 91.10 5,418.85 5,363.05 686.66 6,200.00 9.99 91.10 5,517.33 5,461.53 686.33 6,242.98 9.99 91.10 5,559.66 5,503.86 686.18 Start Dir 3.03°/100' : 6242.98' MD, 5559.66'TVD 587,131.20 6,300.00 11.66 88.71 5,615.67 5,559.87 686.22 6,400.00 14.62 85.84 5,713.04 5,657.24 687.36 6,500.00 17.60 83.92 5,809.10 5,753.30 689.88 6,600.00 20.60 82.54 5,903.59 5,847.79 693.77 6,700.00 23.60 81.50 5,996.23 5,940.43 699.01 6,800.00 26.61 80.68 6,086.77 6,030.97 705.60 6,900.00 29.62 80.02 6,174.96 6,119.16 713.51 7,000.00 32.64 79.47 6,260.55 6,204.75 722.73 7,100.00 35.66 79.00 6,343.30 6,287.50 733.22 7,200.00 38.68 78.60 6,422.97 6,367.17 744.96 7,300.00 41.70 78.25 6,499.35 6,443.55 757.92 7,400.00 44.72 77.93 6,572.22 6,516.42 772.05 7,475.27 47.00 77.72 6,624.64 6,568.84 783.44 Start Dir 31/100' : 7475.27' MD, 6624.64'TVD 8/27/2019 2.05.09PM Page 4 COMPASS 5000.15 Build 91 Map Map +E/ -W Northing Easting DLS Vert Section (usft) (usft) (usft) 3,783.08 1,479.92 6,006,379.82 586,009.24 0.44 1,553.34 1,532.19 6,006,393.02 586,061.35 0.96 1,607.10 1,580.68 6,006,405.05 586,109.71 0.87 1,656.93 1,630.93 6,006,418.03 586,159.81 1.16 1,708.68 1,681.36 6,006,431.22 586,210.09 0.56 1,760.67 1,731.81 6,006,444.08 586,260.39 0.52 1,812.59 1,782.80 6,006,456.71 586,311.24 0.77 1,864.98 1,834.75 6,006,468.94 586,363.05 0.59 1,918.20 1,886.13 6,006,481.24 586,414.29 1.05 1,970.89 1,937.16 6,006,493.87 586,465.17 0.70 2,023.31 1,986.12 6,006,506.13 586,513.99 1.85 2,073.64 2,037.08 6,006,519.31 586,564.80 0.49 2,126.13 2,086.78 6,006,532.32 586,614.36 0.99 2,177.37 2,136.91 6,006,545.71 586,664.33 0.18 2,229.11 2,163.69 6,006,552.90 586,691.03 0.21 2,256.77 2,184.48 6,006,558.51 586,711.75 0.62 2,278.24 2,189.98 6,006,560.01 586,717.24 0.62 2,283.93 2,239.06 6,006,572.88 586,766.17 5.05 2,334.53 2,253.44 6,006,576.41 586,780.51 5.05 2,349.29 2,280.93 6,006,582.71 586,807.93 5.05 2,377.41 2,315.25 6,006,589.41 586,842.17 5.05 2,412.23 2,341.76 6,006,592.94 586,868.64 5.05 2,438.71 2,354.58 6,006,593.51 586,881.45 5.05 2,451.24 2,360.77 6,006,593.46 586,887.65 0.00 2,457.21 2,378.11 6,006,593.33 586,904.99 0.00 2,473.94 2,385.57 6,006,593.27 586,912.44 0.00 2,481.12 2,396.27 6,006,593.42 586,923.14 3.03 2,491.50 2,418.96 6,006,594.82 586,945.82 3.03 2,513.77 2,446.58 6,006,597.66 586,973.41 3.03 2,541.16 2,479.06 6,006,601.91 587,005.84 3.03 2,573.60 2,516.31 6,006,607.58 587,043.02 3.03 2,610.99 2,558.22 6,006,614.64 587,084.85 3.03 2,653.23 2,604.67 6,006,623.08 587,131.20 3.03 2,700.20 2,655.54 6,006,632.87 587,181.96 3.03 2,751.77 2,710.68 6,006,643.98 587,236.97 3.03 2,807.79 2,769.94 6,006,656.39 587,296.09 3.03 2,868.11 2,833.15 6,006,670.06 587,359.15 3.03 2,932.57 2,900.14 6,006,684.95 587,425.96 3.03 3,000.97 2,952.94 6,006,696.94 587,478.63 3.03 3,054.95 8/27/2019 2.05.09PM Page 4 COMPASS 5000.15 Build 91 Halliburton Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPK-44 Company: Hilcorp Alaska, LLC TVD Reference: MPU K -44A Planned RKB @ 55.80usft (Innovati Project: Milne Point MD Reference: MPU K -44A Planned RKB @ 55.80usft (Innovatii Site: M Pt K Pad North Reference: True Well: Plan: MPK-44 Survey Calculation Method: Minimum Curvature Wellbore: MPU K -44A Design: MPU K-44Awp04 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) 6,572.10 7,480.06 47.14 77.72 6,627.90 6,572.10 784.19 2,956.37 6,006,697.72 587,482.05 3.00 3,058.46 HRZ 7,500.00 47.74 77.72 6,641.39 6,585.59 787.31 2,970.72 6,006,701.01 587,496.36 3.00 3,073.14 755254 .--49.32 77.72 6,676.18 6,620.38 795.69 3,009.19 6,006,709.82 587,534.73 3.00 3,112.48 7" x 9 7/8"" 50.74 77.72 6,706.67 6,650.87 803.42 3,044.73 6,006,717.95 587,570.17 3.00 3,148.83 7,606.29 50.93 77.72 6,710.64 6,654.84 804.46 3,049.50 6,006,719.05 587,574.93 3.00 3,153.70 KLB 7,660.07 52.54 77.72 6,743.94 6,688.14 813.44 3,090.75 6,006,728.49 587,616.08 3.00 3,195.90 Start Dir 3.51/100' : 7660.07' MD, 6743.94'TVD 7,695.26 53.77 77.64 6,765.04 6,709.24 819.45 3,118.26 6,006,734.81 587,643.52 3.50 3,224.05 KLGM 7,700.00 53.94 77.63 6,767.84 6,712.04 820.27 3,122.00 6,006,735.67 587,647.25 3.50 3,227.87 7,800.00 57.44 77.42 6,824.20 6,768.40 838.11 3,202.64 6,006,754.43 587,727.66 3.50 3,310.42 7,849.78 59.18 77.32 6,850.35 6,794.55 847.38 3,243.96 6,006,764.16 587,768.88 3.50 3,352.75 KUP_D 7,900.00 60.93 77.22 6,875.42 6,819.62 856.97 3,286.41 6,006,774.23 587,811.21 3.50 3,396.25 8,000.00 64.43 77.04 6,921.31 6,865.51 876.76 3,373.01 6,006,795.00 587,897.57 3.50 3,485.05 8,100.00 67.92 76.86 6,961.70 6,905.90 897.41 3,462.11 6,006,816.66 587,986.43 3.50 3,576.50 8,200.00 71.42 76.70 6,996.43 6,940.63 918.86 3,553.38 6,006,839.13 588,077.44 3.50 3,670.24 8,300.00 74.92 76.54 7,025.38 6,969.58 941.00 3,646.49 6,006,862.33 588,170.28 3.50 3,765.93 8,407.43 78.67 76.37 7,049.92 6,994.12 965.49 3,748.15 6,006,887.97 588,271.65 3.50 3,870.49 End Dir : 8407.43' MD, 7049.92' TVD 8,457.13 78.67 76.37 7,059.68 7,003.88 976.97 3,795.51 6,006,899.98 588,318.87 0.00 3,919.22 KUP_C 8,492.85 78.67 76.37 7,066.69 7,010.89 985.22 3,829.55 6,006,908.62 588,352.81 0.00 3,954.24 Start Dir 3°/100' : 8492.85' MD, 7066.7'TVD 8,500.00 78.88 76.42 7,068.09 7,012.29 986.87 3,836.36 6,006,910.35 588,359.61 3.00 3,961.25 8,571.89 81.00 76.84 7,080.64 7,024.84 1,003.24 3,905.22 6,006,927.49 588,428.27 3.00 4,032.02 8,600.00 81.84 76.76 7,084.83 7,029.03 1,009.59 3,932.29 6,006,934.14 588,455.26 3.00 4,059.81 8,700.00 84.82 76.46 7,096.44 7,040.64 1,032.59 4,028.90 6,006,958.24 588,551.59 3.00 4,159.11 8,800.00 87.81 76.17 7,102.87 7,047.07 1,056.20 4,125.85 6,006,982.94 588,648.26 3.00 4,258.89 8,840.96 89.03 76.05 7,103.99 7,048.19 1,066.03 4,165.59 6,006,993.22 588,687.89 3.00 4,299.83 End Dir : 8840.96' MD, 7103.99' TVD 8,900.00 89.03 76.05 7,104.99 7,049.19 1,080.27 4,222.88 6,007,008.10 588,745.01 0.00 4,358.86 9,000.00 89.03 76.05 7,106.68 7,050.88 1,104.37 4,319.92 6,007,033.30 588,841.76 0.00 4,458.85 9,100.00 89.03 76.05 7,108.36 7,052.56 1,128.48 4,416.96 6,007,058.51 588,938.50 0.00 4,558.83 9,200.00 89.03 76.05 7,110.05 7,054.25 1,152.59 4,513.99 6,007,083.71 589,035.25 0.00 4,658.82 9,300.00 89.03 76.05 7,111.74 7,055.94 1,176.70 4,611.03 6,007,108.91 589,132.00 0.00 4,758.80 9,400.00 89.03 76.05 7,113.42 7,057.62 1,200.81 4,708.06 6,007,134.12 589,228.75 0.00 4,858.79 9,500.00 89.03 76.05 7,115.11 7,059.31 1,224.91 4,805.10 6,007,159.32 589,325.49 0.00 4,958.77 9,600.00 89.03 76.05 7,116.80 7,061.00 1,249.02 4,902.14 6,007,184.53 589,422.24 0.00 5,058.75 9,677.27 89.03 76.05 7,118.10 7,062.30 1,267.65 4,977.11 6,007,204.00 589,497.00 0.00 5,136.01 Total Depth : 9677.27' MD, 7118.1' TVD - 4 1/2" x 61/8" 8/27/2099 2 05 09PM Page 5 COMPASS 5000.15 Build 91 HALLIBURTON Halliburton Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPK-44 Company: Hilcorp Alaska, LLC TVD Reference: MPU K -44A Planned RKB @ 55.80usft (Innovati Project: Milne Point MD Reference: MPU K -44A Planned RKB @ 55.80usft (Innovati Site: M Pt K Pad North Reference: True Well: Plan: MPK-44 Survey Calculation Method: Minimum Curvature Wellbore: MPU K -44A Design: MPU K-44Awp04 Vertical Dip Depth Depth SS Targets Dip Direction (usft) Name Lithology Target Name SB -BASE 6,627.90 hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Shape {°) (°) (usft) (usft) (usft) MPU K-44RD wp03 CP2 0.00 0.00 6,743.94 813.45 3,090.75 plan misses tarqet center by 0.01 usft at 7660.07usft MD (6743.94 TVD, 813.44 N, 3090.75 E) Point +N/ -S +E/ -W (usft) (usft) MPU K-44RD wp03 CP1 0.00 0.00 6,624.64 783.44 2,952.95 plan hits tarqet center 686.78 2,354.58 End Dir : 6064.3' MD, 5383.69' TVD 5,559.66 686.18 Point Start Dir 3.03°/100' : 6242.98' MD, 5559.66'TVD 6,624.64 783.44 2,952.94 Start Dir 31/100' : 7475.27' MD, 6624.64'TVD MPU K-44RD wp03 tqtl 0.00 0.00 7,080.64 1,003.24 3,905.22 plan hits tarqet center End Dir : 8407.43' MD, 7049.92' TVD 7,066.69 985.22 3,829.55 Start Dir 31/100' : 8492.85' MD, 7066.7'TVD Point 1,003.24 3,905.23 End Dir : 8840.96' MD, 7103.99' TVD 7,118.10 1,066.03 MPU K-44RD wp03 tgt2 0.00 0.00 7,118.10 1,267.65 4,977.12 plan hits tarqet center Point Casing Points Measured Depth (usft) 9,677.27 7,552.54 Formations Measured Depth (usft) 5,732.41 7,480.06 8,457.13 7,695.26 7,606.29 7,849.78 Plan Annotations Measured Depth (usft) 5,600.00 6,064.30 6,242.98 7,475.27 7,660.07 8,407.43 8,492.85 8,840.96 9,677.27 Vertical Depth (usft) Name 7,118.10 4 1/2" x 6 1/8" 6,676.18 7" x 9 7/8"" Northing Easting (usft) (usft) 6,006,728.50 587,616.07 6,006,696.94 587,478.63 6,006,927.49 588,428.27 6,007,204.00 589,497.00 Casing Hole Diameter Diameter 4-1/2 6-1/8 7 9-7/8 Vertical Vertical Dip Depth Depth SS Dip Direction (usft) Name Lithology 5,069.23 SB -BASE 6,627.90 HRZ 7,059.68 KUP_C 6,765.04 KLGM 6,710.64 KLB 6,850.35 KUP_D Vertical Local Coordinates Depth +N/ -S +E/ -W (usft) (usft) (usft) Comment 4,954.17 655.14 2,189.98 KOP : Start Dir 5.05°/100' : 5600' MD, 4954.17'TVD : 173.19° RT TF 5,383.69 686.78 2,354.58 End Dir : 6064.3' MD, 5383.69' TVD 5,559.66 686.18 2,385.57 Start Dir 3.03°/100' : 6242.98' MD, 5559.66'TVD 6,624.64 783.44 2,952.94 Start Dir 31/100' : 7475.27' MD, 6624.64'TVD 6,743.94 813.44 3,090.75 Start Dir 3.51/100' : 7660.07' MD, 6743.94'TVD 7,049.92 965.49 3,748.15 End Dir : 8407.43' MD, 7049.92' TVD 7,066.69 985.22 3,829.55 Start Dir 31/100' : 8492.85' MD, 7066.7'TVD 7,103.99 1,003.24 3,905.23 End Dir : 8840.96' MD, 7103.99' TVD 7,118.10 1,066.03 4,165.59 Total Depth :9677.27' MD, 7118.1' TVD 8/27/2019 2:05 09PM Page 6 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt K Pad Plan: MPK-44 MPU K -44A MPU K -44A wp04 Sperry Drilling Services Clearance Summary Anticollision Report 27 August, 2019 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt K Pad -Plan: MPK-44 -MPU K -44A - MPU K -44A wp04 Well Coordinates: 6,005,880.17 N, 584,535.02E (70° 25' 33.57" N, 149° 18' 40.03" W) Datum Height: MPU K -44A Planned RKB @ 55.80usft (Innovation) Scan Range: 5,600.00 to 9,678.18 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: 91 Scan Type: Scan Type: 25.00 HALLIBURTON Sperry Drilling Services Hilcorp Alaska, LLC HALLIBURTON Milne Point Anticollision Report for Plan: MPK-44 - MPU K -44A wp04 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt K Pad - Plan: MPK-44 - MPU K -44A - MPU K -44A wp04 Scan Range: 5,600.00 to 9,678.18 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft Survey tool program From (usft) 127.50 593.84 5,626.31 5,600.00 5,892.54 7,552.54 To Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft M Pt Cascade CASCADE 1 - CASCADE 1 - CASCADE 1 5,600.00 1,368.05 5,600.00 1,330.21 4,478.73 36.151 Clearance Factor CASCADE 1 -CASCADE 1-A- CASCADE 1-A 5,600.00 1,462.57 5,600.00 1,432.82 4,261.12 49.159 Clearance Factor CASCADE 1 - CASCADE 1-A- CASCADE 1-A 5,600.00 1,462.57 5,600.00 1,432.82 4,261.12 49.159 Ellipse Separation M Pt K Pad MPK-13 - MPK-13 - MPK-13 6,461.70 1,025.87 6,461.70 938.24 6,416.67 11.706 Centre Distance MPK-13 - MPK-13 - MPK-13 6,500.00 1,026.29 6,500.00 937.88 6,450.90 11.608 Ellipse Separation MPK-13 - MPK-13 - MPK-13 6,875.00 1,067.63 6,875.00 972.19 6,833.45 11.185 Clearance Factor MPK-18 - MPK-18 - MPK-18 5,600.00 1,029.89 5,600.00 883.32 5,401.62 7.027 Clearance Factor MPK-I8-MPK-I8A-MPK-18A 5,600.00 1,029.89 5,600.00 883.32 5,401.62 7.027 Clearance Factor Plan: MPK-44 - MPK-44 - MPK-44 7,973.83 37.30 7,973.83 21.63 7,899.71 2.380 Clearance Factor Survey tool program From (usft) 127.50 593.84 5,626.31 5,600.00 5,892.54 7,552.54 To (usft) 498.46 5,550.20 5,600.00 5,892.54 MPUK-44Awp04 7,552.54 MPU K-44Awp04 9,677.27 MPU K-44Awp04 Survey/Plan Survey Tool 2_MWD_Interp Azi+Sag 2 MWD+IFR2+MS+Sag 2_MWD+IFR2+MS+Sag 2 MWD_InterpAzi+Sag 2 MWD+IFR2+MS+Sag 2_MWD+IFR2+MS+Sag Separation Warning Pass - Pass - Pass - Pass - Pass - Pass - Pass - Pass - Pass - 27 August. 2019 - 14:05 Page 2 of 5 COMPASS HALLIBURTON Anticollision Report for Plan: MPK-44 - MPU K -44A wp04 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance 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 27 August, 2019 - 14:05 4 Page 3 of 5 COMPASS t HALLISUFITON Project: Milne Point REFERENCE INFORMATION WELL DETAIISPIan: MPK44 NAD1927(NADCONCONUS) Alaska Zane 04 Site: M Pt K Pad Co ordinae (WEI Reference: WBII Plan: MPK44 True @ 5 Gmund level: 29.30 V.N Re/er K -44A Planned RKB ® 55.60us0 (Innova4onl ffVDs, wr�r D�nOne -MPU d +N/ -S +E/ -W N.nw. latittude Longitudc Well: Plan: MPK44 Measured Depth Refemnce: MPU K44A Plannetl RKB (d SS BOusn (Innova0on) 8 Eyring Wellbore: MPU K -44A CaI,UI ion Method: Minimum Curvature 0.00 0.00 6005880.17 584535.01_ 70` 25' 33.570 N 149° 18' 40.034 Plan: MPU K -44A Wp04 SURVEY PROGRAM NO GLOBAL FILTER: Using user defined selection 8 filtering criteria 5600.00 To 9678.18 EM Date: 2019-08-02700:00:00 Validated: Yes Version: Depth From Depth To Suivey/Plan Toal CASING DETAILS Ladder/S.F. Plots 127.50 498.46 MPK441nterp (MPK44) 2 MWD_Interp Azi+Sag 593.84 5550.20 MWD+IFR2+MS+sag (1) (MPK44) 2_MWD+IFR2+MS+Sag TVD TVDSS MD Size Name 5626 31 5600.00 MWD+IFR2+MS+sag (2) (MPK-44) 2_MW D+IFR2+MS+Sag 6676.18 6620.38 7552.54 7 7" z 9 7/8 5600.00 5892.54 MPU K44A wp04 (MPU K44A) 2 MWD Interp Azi+Sag 7118.10 7062.30 9677.27 4-1/2 4 12" x 6 US" 5892.54 7552.54 MPU K44A p04 (MPU K4M 4A) 2 WD+IFR2+MS+Sag 7552.54 9677.27 MPU K44A wp04 (MPU K44A) 2 MWD+IFR2+MS+Sag .._...... . .. _.-...._. -I _...--� �- =150.00 N I I jC3 0120.00 -�I I APK-44 c I I m 90.00- 0.00 60.00 60.00 d)°� f1I o I I I 30.00 __-._1 _.__.__.. ... __.... .�....____ i I c � i I U I I I , 0.00- 5625 5850 6075 6300 6525 6750 6975 7200 7425 7650 7875 8100 8325 8550 8775 9000 9225 9450 9675 9900 Measured Depth (450 usft/in) 4.00 - ---- I is o 3.00 lL m 2.00 CIL Collision Risk Procedures Req. Collision Avoidance Req. N -Go Zone - Stop Drilling :. NOERRORS I o.00 5625 5850 6075 6300 6525 6750 6975 7200 7425 7650 7875 8100 8325 8550 8775 9000 9225 9450 9675 9900 Measured Depth (450 usft/in) TRANSMITTAL LETTER CHECKLIST WELL NAME: j K'" PTD:< 19 -- lie ZDevelopment _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: M i I hf_" Pa 1 V -POOL: �u u(- C Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. 'API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, V/ 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, KUPARUK RIVER OIL - 525100 Well Name: MILNEPT UNIT K -44A Program DEV Well bore seg ❑ PTD#:2191160 Company _Kilcorp Alaska LLC _Initial Class/Type DEV 1 -OIL GeoArea 890- Unit 11328_ On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool - Yes 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate- bond in force Yes 11 Permit -can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes Can permit be approved before 15 -day wait Yes DLB 9/3/2019 113 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 -mile area of review identified (For service well only) - - NA 16 Pre -produced injector: duration of pre -production less than 3 months -(For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 18 Conductor string provided NA S/T from 10 3/4" casing shoe... set at 5597ft md. Engineering 19 Surface casing protects all known USDWs NA 20 CMT vol adequate to circulate on conductor & surf csg NA 21 CMT vol adequate to tie-in _long string to surf csg No 22 CMT will coverall known _productive horizons Yes Kup C zone will have a horizontal lateral with slotted liner '23 Casing designs adequate for C,_T, B &-p_ermafrost Yes BTC ca_Ic_s supplied. Meet industry standards. 24 Adequate tankage or reserve pit Yes Innovation has steel pits. 25 If a re -drill, has a 1-0-403 for abandonment been approved Yes 319-355 sundry approved. 26 Adequate wellbore separation proposed Yes No issues with close crossings, 27 If diverter required, does it _meet regulations NA - Wellhead in place.. Using BOPE Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure = 3151 psi (8.6 ppg EMW will use MPD to establish 11.3 ECD . GLS 9/5/2019 129 BOPEs, do they meet regulation Yes Innovation has 5000 psi WP BOPE I30 BOPE press rating appropriate; test to -(put psig in comments) Yes MASP = 2918 psi- Will test BOPE to 3500 psi 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown- Yes 33 Is presence of H2S gas probable Yes I34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogensulfidemeasures - - No 1-12S measures required. Potential exists to encounter H2S in this mature reservoir. Geology 36 Data presented on potential overpressure zones Yes Appr Date 37 Seismic analysis of shallow gas zones NA_ DLB 9/3/2019 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Verify BHP after drilling C lateral to determine if ESP packer is required. Per CO 390A Commissioner: Date: Commissioner: Date Commissioner Date
