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219-185
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-21826-61-00Well Name/No. KUPARUK RIV UNIT 3O-04L1-01Completion Status1-OILCompletion Date4/12/2020Permit to Drill2191850Operator ConocoPhillips Alaska, Inc.MD12079TVD6683Current Status1-OIL6/16/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR/ResNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC4/30/2020 Electronic File: 3O-04L1-01 EOW NAD27.pdf32983EDDigital DataC4/30/2020 Electronic File: 3O-04L1-01 EOW NAD27.txt32983EDDigital DataC4/30/2020 Electronic File: 3O-04L1-01 EOW NAD83.pdf32983EDDigital DataC4/30/2020 Electronic File: 3O-04L1-01 EOW NAD83.TXT32983EDDigital Data0 0 2191850 KUPARUK RIV UNIT 3O-04L1-01 LOG HEADERS2191850 KUPARUK RIV UNIT 3O-04L1-01 LOG HEADERS32983LogLog Header ScansC5/8/20208313 12079 Electronic Data Set, Filename: 3O-04L1-01 GAMMA RES.las33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01 2MD Final.cgm33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01 5MD Final.cgm33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01 5TVDSS Final.cgm33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01 2MD Final.pdf33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01 5MD Final.pdf33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01 5TVDSS Final.pdf33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01 EOW NAD27.pdf33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01 EOW NAD27.txt33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01 EOW NAD83.pdf33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01 EOW NAD83.TXT33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01 Final Surveys TD at 12079 ft MD.csv33011EDDigital DataTuesday, June 16, 2020AOGCCPage 1 of 33O-04L1-01GAMMA RES.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-21826-61-00Well Name/No. KUPARUK RIV UNIT 3O-04L1-01Completion Status1-OILCompletion Date4/12/2020Permit to Drill2191850Operator ConocoPhillips Alaska, Inc.MD12079TVD6683Current Status1-OIL6/16/2020UICNoWell 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:4/12/2020Release Date:12/13/2019C5/8/2020 Electronic File: 3O-04L1-01 Final Surveys TD at 12079 ft MD.xlsx33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01 Survey Listing.txt33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01 Surveys.txt33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01_25_tapescan_BHI_CTK.txt33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01_5_tapescan_BHI_CTK.txt33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01_output.tap33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01 2MD Final.tif33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01 5MD Final.tif33011EDDigital DataC5/8/2020 Electronic File: 3O-04L1-01 5TVDSS Final.tif33011EDDigital DataTuesday, June 16, 2020AOGCCPage 2 of 3 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-21826-61-00Well Name/No. KUPARUK RIV UNIT 3O-04L1-01Completion Status1-OILCompletion Date4/12/2020Permit to Drill2191850Operator ConocoPhillips Alaska, Inc.MD12079TVD6683Current Status1-OIL6/16/2020UICNoComments:Compliance Reviewed By:Date:Tuesday, June 16, 2020AOGCCPage 3 of 3M. Guhl6/16/2020 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:9. Ref Elevations: KB:59 17. Field / Pool(s): GL: 19 BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 1734/1659 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 N/A (ft MSL) 22. Logs Obtained: GR/Res 23. BOTTOM 16 H-40 115 9 5/8 J-55 4029 7J-55 6769 2 3/8 L-80 6676 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Gas WAG ConocoPhillips Alaska, Inc. 4/12/2020 219-185 P.O. Box 100360 Anchorage, AK 99510-0360 4/5/2020 50-029-21826-61-00 789' FNL, 1879 ' FWL, Sec 22, T13N, R9E, UM 4/6/2020 KRU 3O-04L1-01 3417' FNL, 3357' FEL, Sec 16, T13N, R9E, UM Kuparuk River Field/Kuparuk Oil Pool 1461' FNL, 2132' FEL, Sec 16, T13N, R9E, UM 8660/6545 ADL 25513 525516 6026625 12079/6683 LONS 85-100 WT. PER FT.GRADE SETTING DEPTH MD SETTING DEPTH TVD 520266 6024665 521480 6026625 N/A AMOUNT PULLEDTOP BOTTOM TOP 8620/6519 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, 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 CASING, LINER AND CEMENTING RECORD CASING 115 35 24 199sx AS III HOLE SIZE CEMENTING RECORD 36 35 5099 35 12 1/4 1200sx AS III, 375sx class G 62.5 35 Slotted Liner 26 33 8961 33 8 1/2 300sx Class G, 175sx AS I 4.6 7930 12035 6028 3 TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3 1/2 8549 8477 SLOTTED LINER@ 7937 - 12035 MD and 6035-6676 TVD…...04/11/2020 ACID, FRACTURE, CEMENT SQUEEZE, ETC. Per 20 AAC 25.283 (i)(2) attach electronic information PRODUCTION TEST N/A - not online WAITING FOR HOOKUP Date of Test: Oil-Bbl: Water-Bbl: Choke Size: Gas-Oil Ratio: Sr Pet Eng Sr Pet Geo Sr Res Eng Flow Tubing Oil-Bbl:Water-Bbl: WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No (attached) No No REVISED Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Huey Winston at 2:37 pm, May 27, 2020 Completion Date 4/12/2020 HEW RBDMS HEW 5/13/2020 G DLB 05/28/2020 DLB DSR-5/27/2020 6022030 VTL 6/11/20 SFD 6/10/2020 1a. Well Status:Oil SPLUG Other AbandonedSuspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2.Operator Name: 6.Date Comp., Susp., or 14.Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section):8.Date TD Reached: 16.Well Name and Number: Surface: Top of Productive Interval:9.Ref Elevations: KB:59 17.Field / Pool(s): GL: 19 BF: Total Depth: 10.Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19.DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 1734/1659 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 N/A (ft MSL) 22.Logs Obtained: GR/Res 23. BOTTOM 16 H-40 115 9 5/8 J-55 4029 7J-55 6769 2 3/8 L-80 6676 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Gas WAG ConocoPhillips Alaska, Inc. 4/12/2020 219-185 P.O. Box 100360 Anchorage, AK 99510-0360 4/5/2020 50-029-21825-61-00 789' FNL, 1879 ' FWL, Sec 22, T13N, R9E, UM 4/6/2020 KRU 3O-04L1-01 3417' FNL, 3357' FEL, Sec 16, T13N, R9E, UM Kuparuk River Field/Kuparuk Oil Pool 1446' FNL, 2465' FEL, Sec 16, T13N, R9E, UM 8660/6545 ADL 25513 525516 6026625 12079/6683 LONS 85-100 WT. PER FT.GRADE SETTING DEPTH MD SETTING DEPTH TVD 520266 6024665 521480 6026625 N/A AMOUNT PULLEDTOP BOTTOM TOP 8620/6519 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, 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 CASING, LINER AND CEMENTING RECORD CASING 115 35 24 199sx AS III HOLE SIZE CEMENTING RECORD 36 35 5099 35 12 1/4 1200sx AS III, 375sx class G 62.5 35 Slotted Liner 26 33 8961 33 8 1/2 300sx Class G, 175sx AS I 4.6 7930 12035 6028 3 TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3 1/2 8549 8477 SLOTTED LINER@ 7937 - 12035 MD and 6035-6676 TVD…...04/11/2020 ACID, FRACTURE, CEMENT SQUEEZE, ETC. Per 20 AAC 25.283 (i)(2) attach electronic information PRODUCTION TEST N/A - not online WAITING FOR HOOKUP Date of Test: Oil-Bbl: Water-Bbl: Choke Size: Gas-Oil Ratio: Sr Pet Eng Sr Pet Geo Sr Res Eng Flow Tubing Oil-Bbl:Water-Bbl: WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No (attached) No No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Huey Winston at 10:33 am, May 13, 2020 6 1461 2132 SUPERCEDED Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 1734 1659 Top of Productive Interval 9445 6617 TD 12079 6682 Kuparuk A1 31. List of Attachments:Daily Operations Summary, Definitive Survey, Schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. James Ohlinger Contact Name:Jeff Connelly Staff CTD Engineer Contact Email:jeff.s.connelly@cop.com Authorized Contact Phone:(907) 328-8854 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: If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: Formation @TPI-Kuparuk A1 This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). INSTRUCTIONS Authorized Name: Authorized Title: Signature w/Date: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. No No Sidewall Cores:Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by James Ohlinger DN: CN=James Ohlinger, O=ConocoPhillips, OU=CTD, E=James.J.Ohlinger@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2020-05-12 14:27:25 Foxit PhantomPDF Version: 9.7.0 James Ohlinger 3O-04 Final CTD SchematicUpdated: JSC (4/13/2020)TOWS @ 8620' MD16" 62# H-40 shoe @ 115' MD3O-04L1-01TD @ 12,079' MDSlotted liner: 12,035' to 7930.5' (NS seal-bore recepticle)3O-04L1TD @ 11,784'' MDSlotted liner: 11,784' to 9447' MD (liner-top billet)TOWS @ 8660' MDSeal-bore deployment sleeveFor liner-top packer post rigTop at 7930'Packer not yet set: 4/12/20203O-04L1_PB1Slotted Liner: 8718' to 8656' (to preserve perf's)Wash-down depth = 8751' (No new hole drilled)Note: FCO of lateral L1-01 will require pulling liner from 8621'to 7930' Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: ELMD, TIED INTO K1 MARKER AT 8344' MD 8,684.0 12/29/2019 3O-04 condijw Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set LTP 4/16/2020 3O-04 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 35.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 5,099.2 Set Depth (TVD) … 4,029.0 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 8,961.3 Set Depth (TVD) … 6,768.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,951.4 Set Depth (ftKB) 8,850.0 Set Depth (TVD) … 6,686.8 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,951.4 6,037.9 45.08 PACKER 2RH ZXP w/HD LINER TOP PACKER 4.310 7,970.0 6,051.0 45.08 HANGER DG FLEX-LOCK LINER HANGER 4.400 7,979.8 6,058.0 45.08 SBE BAKER SEAL BORE EXTENSION 4.000 Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.1 Set Depth (ft… 7,987.9 Set Depth (TVD) (… 6,063.7 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd AB Mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.1 31.1 0.08 HANGER CIW GEN IV TUBING HANGER w/ Type 'H' Profile 2.992 508.1 508.1 0.38 NIPPLE CAMCO DS NIPPLE 3.5" x 2.875" 2.875 7,901.7 6,002.8 45.10 NIPPLE CAMCO 3.5" x 2.812" DS NIPPLE SN: T070815 2.812 7,950.4 6,037.2 45.08 LOCATOR BAKER GBH LOCATOR sub w/ 7-ft Space out 2.992 7,959.1 6,043.3 45.08 SEAL ASSY Baker 80-40 Seals 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,920.0 6,015.7 45.09 Liner Top Packer Northern Solutions PTSA Liner Top Packer w/ 1.781" R Nipple. 9.79' OAL Length. (2.31" G F/N to Pull assembly) Stung into liner top @ 7930' RKB 4/16/2020 1.781 7,930.0 6,022.8 45.09 CTD Liner CTD Liner top from 3O-04L1-01 4/10/2020 1.920 8,663.0 6,549.7 42.97 WHIPSTOCK 2.63" OD BAKER GEN 2, 3-1/2" X 4-1/2" WHIPSTOCK, -1.5° LOHS, RA TAG AT 8670.4' 12/29/2019 1.000 8,694.0 6,572.4 42.89 Fish SLIP STOP CATCHER SUB FISH. 1/2 OF A SLIP, 2 FULL SLIPS, SLIP RETAINER RING & 2.70" X 30" CATCHER. 10/24/2018 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,622.0 8,640.0 6,519.7 6,532.9 C-4, C-1, UNIT B, 3O-04 5/7/1989 12.0 CMT SQZ 2 1/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO 8,653.0 8,669.0 6,542.4 6,554.1 A-3, 3O-04 5/7/1989 12.0 CMT SQZ 2 1/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO 8,675.0 8,695.0 6,558.5 6,573.1 A-1, 3O-04 1/5/2015 6.0 APERF 2.5" 6SPF, 60 DEGREE PHASING, DEEP penetrating chgs 8,675.0 8,695.0 6,558.5 6,573.1 A-1, 3O-04 8/8/2016 6.0 APERF 2.5'" POWERJET OMEGA CHARGES 6 SPF, 60 DEG PHASING 8,675.0 8,698.0 6,558.5 6,575.3 A-2, 3O-04 5/7/1989 12.0 CMT SQZ 2 1/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO 8,675.0 8,695.0 6,558.5 6,573.1 A-2, 3O-04 7/18/2013 6.0 APERF 3-3/8" OD 6 SPF MILLENNIUM 60 DEG PHASING 25gr HMX 8,710.0 8,730.0 6,584.1 6,598.8 A-1, 3O-04 9/25/1988 8.0 CMT SQZ 4 1/2" HSD Csg Gun, 45 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 RWO Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 7,950.0 8,850.0 6,036.9 6,686.8 LINER CMT 7/15/2013 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,098.4 2,599.8 WTF KBMG 1 GAS LIFT GLV BK 0.156 1,329.0 12/11/2019 2 4,760.7 3,787.1 WTF KBMG 1 GAS LIFT GLV BK 0.188 1,354.0 12/11/2019 3 6,117.1 4,747.2 WTF KBMG 1 GAS LIFT OV BK 0.250 0.0 12/10/2019 4 7,166.4 5,485.2 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/14/2019 5 7,843.2 5,961.6 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/18/2014 3O-04, 5/12/2020 11:57:33 AM Vertical schematic (actual) CTD Liner; 7,930.0 PRODUCTION; 33.0-8,961.3 LINER; 7,951.4-8,850.0 CMT SQZ; 8,710.0-8,730.0 Fish; 8,694.0 CMT SQZ; 8,675.0-8,698.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 WHIPSTOCK; 8,663.0 CMT SQZ; 8,653.0-8,669.0 CMT SQZ; 8,622.0-8,640.0 Liner Cement; 7,950.0 ftKB SEAL ASSY; 7,959.1 LOCATOR; 7,950.4 Liner Top Packer; 7,920.0 NIPPLE; 7,901.6 GAS LIFT; 7,843.2 GAS LIFT; 7,166.4 GAS LIFT; 6,117.1 SURFACE; 35.0-5,099.2 GAS LIFT; 4,760.7 GAS LIFT; 3,098.4 NIPPLE; 508.1 CONDUCTOR; 35.0-115.0 HANGER; 31.1 KUP PROD KB-Grd (ft) 40.00 Rig Release Date 7/9/1988 3O-04 ... TD Act Btm (ftKB) 8,984.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292182600 Wellbore Status PROD Max Angle & MD Incl (°) 51.60 MD (ftKB) 2,600.00 WELLNAME WELLBORE3O-04 Annotation Last WO: End Date 7/21/2013 H2S (ppm) 140 Date 9/25/2013 Comment SSSV:NIPPLE Notes: General & Safety End Date Annotation 10/31/2018 Note: Unable to locate mandrels @ 7166 & 7832' RKB 1/27/2016 NOTE: MILLED RESIN TO 8,730 CTMD = COMPLETE 10/2/2015 NOTE: Pumped SANDLOCK-V resin frac with 8-PPA Jordan Unimin sand, 8.9-BPM, 5000-psi. 3O-04, 5/12/2020 11:57:33 AM Vertical schematic (actual) CTD Liner; 7,930.0 PRODUCTION; 33.0-8,961.3 LINER; 7,951.4-8,850.0 CMT SQZ; 8,710.0-8,730.0 Fish; 8,694.0 CMT SQZ; 8,675.0-8,698.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 APERF; 8,675.0-8,695.0 WHIPSTOCK; 8,663.0 CMT SQZ; 8,653.0-8,669.0 CMT SQZ; 8,622.0-8,640.0 Liner Cement; 7,950.0 ftKB SEAL ASSY; 7,959.1 LOCATOR; 7,950.4 Liner Top Packer; 7,920.0 NIPPLE; 7,901.6 GAS LIFT; 7,843.2 GAS LIFT; 7,166.4 GAS LIFT; 6,117.1 SURFACE; 35.0-5,099.2 GAS LIFT; 4,760.7 GAS LIFT; 3,098.4 NIPPLE; 508.1 CONDUCTOR; 35.0-115.0 HANGER; 31.1 KUP PROD 3O-04 ... WELLNAME WELLBORE3O-04 Casing Strings Casing Description Liner L1 Lateral OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 9,451.5 Set Depth (ftKB) 11,874.0 Set Depth (TVD) … 6,587.5 Wt/Len (l… 4.60 Grade L-80 Top Thread STL Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,451.5 6,617.7 84.23 Aluminum Billet Aluminum Liner Top Billet 1.920 10,228.6 6,644.6 92.29 Deployment Sleeve Shorty Deployment Sleeve 1.000 3O-04L1, 5/12/2020 11:58:50 AM Vertical schematic (actual) Liner L1 Lateral; 9,451.5- 11,874.0 PRODUCTION; 33.0-8,961.3 LINER; 7,951.4-8,850.0 Liner L1-01; 7,930.5-12,035.2 Liner Cement; 7,950.0 ftKB CTD Liner; 7,930.0 SEAL ASSY; 7,959.1 LOCATOR; 7,950.4 Liner Top Packer; 7,920.0 NIPPLE; 7,901.6 GAS LIFT; 7,843.2 GAS LIFT; 7,166.4 GAS LIFT; 6,117.1 Annular Fluid - Seawater; 2,500.0-7,931.0 SURFACE; 35.0-5,099.2 GAS LIFT; 4,760.7 GAS LIFT; 3,098.4 Annular Fluid - Diesel; 0.0- 2,500.0 NIPPLE; 508.1 CONDUCTOR; 35.0-115.0 HANGER; 31.1 KUP PROD KB-Grd (ft) 40.00 Rig Release Date 7/9/1988 3O-04L1 ... TD Act Btm (ftKB) 11,874.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292182660 Wellbore Status PROD Max Angle & MD Incl (°) 99.53 MD (ftKB) 11,714.70 WELLNAME WELLBORE3O-04 Annotation End DateH2S (ppm) 140 Date 9/25/2013 Comment Casing Strings Casing Description Liner L1-01 OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 7,930.5 Set Depth (ftKB) 12,035.2 Set Depth (TVD) … 6,676.1 Wt/Len (l… 4.70 Grade L-80 Top Thread ST-L Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,930.5 6,023.5 45.08 SBR NSAK, 225 Seal Bore Receptical, (2.25") 2.250 8,621.0 6,519.4 43.36 Deployment Sleeve NSAK 350-238, QCLL Receptical- L80 1.920 10,371.4 6,580.1 91.61 Deployment Sleeve NSAK 350-238, QCLL Receptical- L80 1.920 3O-04L1-01, 5/12/2020 12:04:24 PM Vertical schematic (actual) Liner L1-01; 7,930.5-12,035.2 PRODUCTION; 33.0-8,961.3 CTD Liner; 7,930.0 Liner Top Packer; 7,920.0 NIPPLE; 7,901.6 GAS LIFT; 7,843.2 GAS LIFT; 7,166.4 GAS LIFT; 6,117.1 Annular Fluid - Seawater; 2,500.0-7,931.0 SURFACE; 35.0-5,099.2 GAS LIFT; 4,760.7 GAS LIFT; 3,098.4 Annular Fluid - Diesel; 0.0- 2,500.0 NIPPLE; 508.1 CONDUCTOR; 35.0-115.0 HANGER; 31.1 KUP PROD KB-Grd (ft) 40.00 Rig Release Date 7/9/1988 3O-04L1-01 ... TD Act Btm (ftKB) 12,035.2 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292182661 Wellbore Status PROD Max Angle & MD Incl (°) 95.22 MD (ftKB) 10,016.96 WELLNAME WELLBORE3O-04 Annotation End DateH2S (ppm) 140 Date 9/25/2013 Comment Page 1/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/25/2020 00:00 3/25/2020 02:00 2.00 MIRU MOVE MOB P Phase1 on spine rd. Phase 2 on access roads and pads Rig and ancillary equipment on location. Stage light plants and heater while dropping off jeeps. Loader dressed far end of pad for Shop & 1/2 way house. 0.0 0.0 3/25/2020 02:00 3/25/2020 03:30 1.50 MIRU MOVE MOB P Prep well head, remove snow, lay pit liner, stage mats and lay plywood around cellar. 0.0 0.0 3/25/2020 03:30 3/25/2020 05:00 1.50 MIRU MOVE MOB P Set 1/2 way house and mats and plywood, spot shop 0.0 0.0 3/25/2020 05:00 3/25/2020 06:48 1.80 MIRU MOVE MOB P Pull pits forward and stage out of way, Spot Sub over well, crew change, continue to spot sub, come off jack. 0.0 0.0 3/25/2020 06:48 3/25/2020 07:12 0.40 MIRU MOVE MOB P Spot inner mats, 0.0 0.0 3/25/2020 07:12 3/25/2020 08:18 1.10 MIRU MOVE MOB P Move pits, spot up, set outer mats, come off jack 0.0 0.0 3/25/2020 08:18 3/25/2020 10:24 2.10 MIRU WHDBOP RURD P Work rig up checklist 0.0 0.0 3/25/2020 10:24 3/25/2020 11:24 1.00 MIRU WHDBOP NUND P Nipple up stack and gather RKB's. 0.0 0.0 3/25/2020 11:24 3/25/2020 12:24 1.00 MIRU WHDBOP RURD P Continue to work RU check list, start to inventory pits, grease rig valves / stack. Valve crew called out to grease tree valves, stand by until swab test as contingency. 0.0 0.0 3/25/2020 12:24 3/25/2020 15:00 2.60 MIRU WHDBOP RURD P Fluid pack and shell test to 4000 psi - good 0.0 0.0 3/25/2020 15:00 3/25/2020 15:18 0.30 MIRU WHDBOP BOPE P Start BOT test 250/4000 psi 2500 psi annular test winessed Brian Bixby, 0.0 0.0 3/25/2020 15:18 3/25/2020 15:36 0.30 MIRU WHDBOP BOPE T test 1. Swab 2 - fail 0.0 0.0 3/25/2020 15:36 3/25/2020 22:00 6.40 MIRU WHDBOP BOPE P Test 2. Blind/Shear, BOP TV2, Charlie 4, 5, 8, &12 Test 3. BOP TV 1, Charlie 3, 7, & 11 Test 4. Manual choke D & Super choke C Test 5. Romeo 3, Bleeder 3, Tango 2, Charlie 2, & 10 Test 6. Charlie 1, 9, Bravo 5, and Tango 1 – install TIW test joint Test 7. Lower 2” pipe slip rams, TIW #1, Romeo 1, Bleeder 1 Test 8. Annular BOP Test 9. Upper 2” pipe slip rams, Bravo 6, & 8 Test 10. Bravo 7 – swap out 2” test joint for 2-3/8” Test 11. 2-3/8” pipe slip rams, TIW#2 – check N2 levels, swap to 2” test joint Test 12. Draw down accumulator Test 13. Stab injector and line up to reverse circulate coil, test inner reel valve and stripper. Tested all gas detectors, pits, cellar, Verified flow alarms - PVT 0.0 0.0 3/25/2020 22:00 3/25/2020 22:30 0.50 MIRU WHDBOP PRTS P Install nozzle, blow down choke, inspect pack offs 0.0 0.0 3/25/2020 22:30 3/25/2020 23:00 0.50 MIRU WHDBOP PRTS P Re-test swab #2 (fail), call out grease crew for re-grease 0.0 0.0 Rig: NABORS CDR3-AC Page 2/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/25/2020 23:00 3/26/2020 00:00 1.00 MIRU WHDBOP PRTS P Call out KDTH, replace failed tiger tank manifold block valve, test tiger tank line, ODS PDL (good) 0.0 0.0 3/26/2020 00:00 3/26/2020 01:30 1.50 MIRU WHDBOP PRTS P Re-test Swab #2 (pass), test DS PDL (good) 0.0 0.0 3/26/2020 01:30 3/26/2020 02:00 0.50 MIRU WHDBOP PRTS P Brake off PDL, blow down test pump, and RD all testing equipment. 0.0 0.0 3/26/2020 02:00 3/26/2020 03:30 1.50 PROD1 WHPST PULD P PJSM, PU/MU/PD milling assembly 0.0 76.9 3/26/2020 03:30 3/26/2020 03:57 0.45 PROD1 WHPST PULD P Surface test CoilTrak tools (good), tag up, reset counters 76.9 76.9 3/26/2020 03:57 3/26/2020 05:45 1.80 PROD1 WHPST TRIP P RIH, w/milling assembly BHA #1 Weatherford 1.0° ako motor, pumping seawater min rate, WHP 1,187, IA=561, OA=538 76.9 8,355.0 3/26/2020 05:45 3/26/2020 05:57 0.20 PROD1 WHPST DLOG P Log formation for depth correction of - 16' 8,348.0 8,396.0 3/26/2020 05:57 3/26/2020 07:39 1.70 PROD1 WHPST DISP P Flush well with seawater, bottoms up, Roll hole to Duo / Pro, bottoms up Park - close EDC - observe pressure at 6359 sensor depth. Bleed into BHP of 3877 psi for 11.7 ppg EMW 8,396.0 8,448.0 3/26/2020 07:39 3/26/2020 07:57 0.30 PROD1 WHPST TRIP P RIH, try tag pinch point@ 8662.2', PU Wt 44 k lbs Set rate, RBIH Choke acting up, decent amount of solids shoing up on the shaker. 8,448.0 8,662.0 3/26/2020 07:57 3/26/2020 10:45 2.80 PROD1 WHPST MILL P CT 4241 psi @ 1.86 bpm in/out, 3957 psi BHP T RIH Wt 18.7 k lbs Stick slip issues, 8662.9' WOB to 1 k, and again @ 8663.1' WOB to 1.8 k lbs. Mix new mud with additional 1% 776, pump 10 bbl sweep, see coil WT increase from 17.4 to 18.4 k lbs, best effect with sweep high on the back side 4000 - 1000' from surface. Bleed IA and OA from ~ 1000 psi to 417 and 160 psi respectively 8,662.0 8,664.9 3/26/2020 10:45 3/26/2020 12:39 1.90 PROD1 WHPST MILL P WOB rapidly climbed from 2 k to 2.3 k lbs, Parked stick as 10 bbl sweep was on the back side and 1 k of CT weight stacked up. Reengaged stick at 1 ft/hr Mill ahead 8,664.9 8,667.1 3/26/2020 12:39 3/26/2020 13:51 1.20 PROD1 WHPST MILL P WOB rapidly climbed from 2 k to 2.4 k lbs while milling at 1 ft/hr. WOB rapidly fell off - BOW 8667.1' Adding pinch - 7.2' window 8,667.1 8,668.6 3/26/2020 13:51 3/26/2020 14:39 0.80 PROD1 WHPST MILL P Drill ahead in formation. 8675' PU Wt Dril to TD PU 44 k lbs 8,668.6 8,685.0 3/26/2020 14:39 3/26/2020 16:45 2.10 PROD1 WHPST REAM P Perform reaming pases, as milled, 30 L 30R, and 180 from as milled - highside. 8,685.0 8,553.0 3/26/2020 16:45 3/26/2020 18:15 1.50 PROD1 WHPST TRIP P POOH 8,553.0 76.9 3/26/2020 18:15 3/26/2020 19:15 1.00 PROD1 WHPST PULD P PUD & LD milling assembly, inspect, obtain pictures of mils, gauge 2.79" no -go 76.9 0.0 3/26/2020 19:15 3/26/2020 19:33 0.30 PROD1 WHPST CTOP P Install nozzle, stab INJH, jet stack, unstab INJH, brake off nozzle 0.0 0.0 3/26/2020 19:33 3/26/2020 20:51 1.30 PROD1 DRILL PULD P PD, kickoff/drilling assembly BHA #2, surface test tools (good) 0.0 72.2 Rig: NABORS CDR3-AC Page 3/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/26/2020 20:51 3/26/2020 22:33 1.70 PROD1 DRILL TRIP P Tag up, reset counters, RIH 72.2 8,355.0 3/26/2020 22:33 3/26/2020 22:45 0.20 PROD1 DRILL DLOG P Log formation (K1) -13.0' 8,355.0 8,400.0 3/26/2020 22:45 3/26/2020 22:57 0.20 PROD1 DRILL TRIP P Continue IH 8,400.0 8,636.0 3/26/2020 22:57 3/26/2020 23:15 0.30 PROD1 DRILL TRIP P Perform perssure survey above window, 22:55 - AP= 4,135. EMW= 12.39 ppg 23:00 - AP= 4,091, EMW= 12.22 ppg 23:05 - AP= 3,973, EMW= 11.80 ppg 23:10 - AP= 3,984, EMW= 11.84 ppg Bleed 100 WHP 23:15 - AP= 3,948, EMW= 11.693 ppg Bleed 100 WHP 23:20 - AP= 3,931, EMW= 11.643 ppg 8,636.0 8,636.0 3/26/2020 23:15 3/26/2020 23:27 0.20 PROD1 DRILL TRIP P Pass through the window clean, bring pump up to rate, 1.83 bpm @ 4,006 psi, DIff=440, BHP=4,125, IA=413, OA=188 8,636.0 8,695.0 3/26/2020 23:27 3/26/2020 23:39 0.21 PROD1 DRILL TRIP T No WOB noticed, PUH clean 43k, RBIH down to 8,698', PUH phone town team. 8,695.0 8,698.0 3/26/2020 23:39 3/26/2020 23:51 0.20 PROD1 DRILL DLOG P Log RA marker 8,671', continue IH logging RES and near bit. 8,698.0 8,702.0 3/26/2020 23:51 3/27/2020 00:00 0.15 PROD1 DRILL TRIP P PUH above WS, wait on decision forward 8,702.0 8,702.0 3/27/2020 00:00 3/27/2020 01:18 1.30 PROD1 DRILL CIRC T Above Window, recip pipe, circulating 1.2 bpm WOO 8,702.0 8,619.0 3/27/2020 01:18 3/27/2020 01:54 0.60 PROD1 DRILL CIRC T Circulate 5x5 sweep, pump BU, sample (frac-sand) 8,619.0 8,619.0 3/27/2020 01:54 3/27/2020 02:06 0.20 PROD1 DRILL DRLG T RIH, 1.82 bpm @ 4,030 psi, Diff=420, attempt to find bottom down to 8,707', 8,619.0 8,707.0 3/27/2020 02:06 3/27/2020 02:42 0.60 PROD1 DRILL WPRT T pull wiper up hole w/sweep, PUW 43 K 8,707.0 8,586.0 3/27/2020 02:42 3/27/2020 03:12 0.50 PROD1 DRILL CIRC T Circulate BU, sample (frac-sand), build addtional sweeps in pits. continue circulating BU 8,586.0 8,580.0 3/27/2020 03:12 3/27/2020 03:24 0.20 PROD1 DRILL TRIP T RBIH, 1.87 bpm at 4,056 psi, Diff=460, set down @ 8,614' 6k DHWOB 8,580.0 8,614.0 3/27/2020 03:24 3/27/2020 03:42 0.30 PROD1 DRILL WPRT T Pull wiper up hole to TT, pumping 1.8 bpm at 3,900 psi, pull heavy 8,523', RBIH to 8,550', PBUH, clean continue wiper up hole to TT. 8,614.0 8,100.0 3/27/2020 03:42 3/27/2020 04:12 0.50 PROD1 DRILL TRIP T RBIH, 1.87 bpm at 4,056 psi, Diff=460, set down @ 8,715' 1.5k DHWOB 8,100.0 8,715.0 3/27/2020 04:12 3/27/2020 04:30 0.30 PROD1 DRILL WPRT T Pull wiper above widnow wtih sweep, pull heavy -12 k, temporily detained pull 50k @ 8,585', work pipe, open choke bleed WHP in tention, popped free, 8,715.0 8,585.0 3/27/2020 04:30 3/27/2020 05:24 0.90 PROD1 DRILL WPRT T Continue Wiper up hole, PUW 37 k Pull heavy 8558-8577' Stack out, work pipe free - 8,585.0 7,837.0 3/27/2020 05:24 3/27/2020 06:48 1.40 PROD1 DRILL TRIP T POOH for cklean out run- bottoms up, Open EDC - 7,837.0 52.0 3/27/2020 06:48 3/27/2020 07:42 0.90 PROD1 DRILL PULD T Bump up, PUD BHA #2 Bit graded out 1-3-BT chipped reamers 52.0 0.0 3/27/2020 07:42 3/27/2020 08:36 0.90 PROD1 DRILL PULD T PD BHA #3 - clean out assembly 1° fixed motor w D331 ridge set Tag up, set depth 0.0 55.0 Rig: NABORS CDR3-AC Page 4/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/27/2020 08:36 3/27/2020 10:00 1.40 PROD1 DRILL PULD T RIH 55.0 8,355.0 3/27/2020 10:00 3/27/2020 10:12 0.20 PROD1 DRILL DLOG T Tie into the K1 for a -15' correction 8,355.0 8,380.0 3/27/2020 10:12 3/27/2020 12:18 2.10 PROD1 DRILL WASH T Close EDC, set rate 1.89 bpm, free spin diff 580 RIH to 8675, WOB to 2.5 - PU Wt 40 k Pull up though the window -clean RBIH to 8716.6 WOB to 190 lbs PU 41 k lbs, tried to pack off, RBIH pull up slowly and clean through window. RBIH to 8716.6', WOB 4.1k lbs PUH clean RBIH to 8715' WOB2.8 k PU 41 k clean- PUH through window clean Chase sweeps out of hole - seeing reduced solids to surface over time. RBIH and dry tag 8718' 8 k WOB - PU Wt 40 clean 8,355.0 8,711.0 3/27/2020 12:18 3/27/2020 12:42 0.40 PROD1 DRILL TRIP T PUH to log 8,711.0 8,354.0 3/27/2020 12:42 3/27/2020 12:54 0.20 PROD1 DRILL TRIP T Tie into K1 for +1' 8,354.0 8,378.0 3/27/2020 12:54 3/27/2020 13:18 0.40 PROD1 DRILL DRLG T RBIH Slight WOB spike @ 8661' CT 4216 psi @ 1.88 bpm, 576 free spin, motor work at 8715.4' Mill/Drill ahead 1 foot, 733 psi diff and WOB to 1.9 k lbs park Mill/Drill ahead 1 more foot with 802 psi diff and WOB 2.6 k lbs 8,378.0 8,717.4 3/27/2020 13:18 3/27/2020 14:48 1.50 PROD1 DRILL TRIP T PU Wt 44 k lbs POOH, More sand showing up at 3000' cut pulling speed and send 5x5 sweep POOH, Bump up, space out 8,717.4 46.0 3/27/2020 14:48 3/27/2020 16:18 1.50 PROD1 DRILL TRIP T PUD BHA #3, clean out assembly, 46.0 0.0 3/27/2020 16:18 3/27/2020 17:06 0.80 PROD1 DRILL TRIP T PD BHA #4 - Build drillig assembly #2, 2.55 ° AKO over a RR P104 0.0 72.2 3/27/2020 17:06 3/27/2020 18:36 1.50 PROD1 DRILL TRIP T RIH 72.2 8,355.0 3/27/2020 18:36 3/27/2020 18:48 0.20 PROD1 DRILL DLOG T Log formation for depth - 13.0' 8,355.0 8,375.0 3/27/2020 18:48 3/27/2020 19:06 0.30 PROD1 DRILL TRIP T Continue IH 8,375.0 8,685.0 3/27/2020 19:06 3/27/2020 19:18 0.20 PROD1 DRILL DLOG T Tie in RA for offical window depths @ 8,669.5', continue IH to bottom 8,685.0 8,718.0 3/27/2020 19:18 3/27/2020 19:30 0.20 PROD1 DRILL TRIP T PUH to confrim window area (clean) 8,718.0 8,646.0 3/27/2020 19:30 3/27/2020 20:00 0.50 PROD1 DRILL DRLG T RBIH to bottom, bring pump online 1.82 bpm at 4,111 psi, Diff=504, WHP=574, BHP=4,156, IA=816, OA=218, drill ahead from 8,718', stall motor muliple times 8,718'-8,725' 8,646.0 8,725.0 3/27/2020 20:00 3/27/2020 20:24 0.40 PROD1 DRILL DRLG T BOB attempting to get 1.82 bpm at 4,012 psi, Diff=575, WHP=574, BHP=4,156, IA=816, OA=218, 8,725.0 8,000.0 3/27/2020 20:24 3/27/2020 20:48 0.40 PROD1 DRILL TRIP T PUH, confir with TE, circulate sweeps, pull to the above window, addtional sweep exiting the bit, continue pulling to the TT, RBIH, to above window open EDC 8,000.0 8,646.0 3/27/2020 20:48 3/27/2020 21:24 0.60 PROD1 DRILL TRIP T POOH, pumping max rate, change of plans 8,646.0 6,826.0 Rig: NABORS CDR3-AC Page 5/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/27/2020 21:24 3/27/2020 22:00 0.60 PROD1 DRILL TRIP T RBIH to above window for displacing well to KWF 6,826.0 8,655.0 3/27/2020 22:00 3/27/2020 22:39 0.65 PROD1 DRILL CTOP T Perfrom static pressure survey @ 8,655.7' Perform perssure survey above window, 22:00 - AP= 4,254. EMW= 12.68 ppg 22:05 - AP= 4,218, EMW= 12.59 ppg 22:10- AP= 4,195, EMW= 12.51 ppg 22:15 - AP= 4,173, EMW= 12.44 ppg 22:20 - AP= 4,152, EMW= 12.39 ppg 22:25 - AP= 4,136, EMW= 12.18 ppg Bleed 250 WHP 22::30 - AP= 3,962, EMW= 11.82 ppg Bleed 250 WHP 22:38 - AP=3939, EMW= 11.641 ppg 8,655.0 8,655.0 3/27/2020 22:39 3/28/2020 00:00 1.35 PROD1 DRILL CIRC T Recip pipe, while waiting on Vac Truck support 8,655.0 8,539.0 3/28/2020 00:00 3/28/2020 02:00 2.00 PROD1 DRILL CIRC T Continue recip pipe, transferring fluid for displacement, RBIH to bottom 8,655' 8,539.0 8,413.0 3/28/2020 02:00 3/28/2020 02:30 0.50 PROD1 DRILL CIRC T Circulate 12.0 ppg completion fluid down coil, 8,413.0 8,655.0 3/28/2020 02:30 3/28/2020 04:18 1.80 PROD1 DRILL TRIP T POOH, displacing well to completion fluid 8,655.0 54.0 3/28/2020 04:18 3/28/2020 05:12 0.90 PROD1 DRILL PULD T At surface, flow check - good, LD BHA #4 over a dead well. 54.0 0.0 3/28/2020 05:12 3/28/2020 05:30 0.30 PROD1 DRILL PUTB T PU L1-PB1, 3 joints of 2-3/8" ST-L slotted liner wish a solid bull nose under a shorty deployment sleve. 0.0 90.0 3/28/2020 05:30 3/28/2020 06:30 1.00 PROD1 DRILL PULD T PU BHA #5, L1-PB1 running assembly. Crew change, Stab on, bump up and set counters. 90.0 137.0 3/28/2020 06:30 3/28/2020 08:00 1.50 PROD1 DRILL RUNL T RIH with L1-PB1 completion 137.0 8,427.0 3/28/2020 08:00 3/28/2020 08:12 0.20 PROD1 DRILL DLOG T tie into the K1 for a -16' correction 8,427.0 8,448.6 3/28/2020 08:12 3/28/2020 08:30 0.30 PROD1 DRILL RUNL T Close EDC, PU Wt 42 k lbs RIH Window clean, stack out at 8721' SEt between 6.5 and 8.4 k WOB 3 times. PU Wts 42 k lsbs clean. STack 9.6 k WOB, pump down coil while stacked, no change, PU and attempr to RBIH again, same bottom 8,448.6 8,721.0 3/28/2020 08:30 3/28/2020 08:54 0.40 PROD1 DRILL RUNL T PU and consult with TE. RBIH, Work pipe to 10 k WOB with choke close, edc to 14 ppg EMW No sucess breaking down suspect bridge 8,721.0 8,721.0 3/28/2020 08:54 3/28/2020 10:30 1.60 PROD1 DRILL PULL T PUH, open EDC, POOH 8,721.0 153.0 3/28/2020 10:30 3/28/2020 10:54 0.40 PROD1 DRILL PULD T LD BHA #5 153.0 90.0 3/28/2020 10:54 3/28/2020 11:12 0.30 PROD1 DRILL PULL T remove one joint from completion, new L1-PB1 - 2 joints of 2-3/8" STL with a non ported bullnose under a shorty. LOA 62.05' 90.0 60.0 3/28/2020 11:12 3/28/2020 11:36 0.40 PROD1 DRILL PULD T PU BHA #6, L1 60.0 106.0 3/28/2020 11:36 3/28/2020 13:06 1.50 PROD1 DRILL RUNL T RIH W BHA #6 - L1-PB1 completion 106.0 8,400.0 3/28/2020 13:06 3/28/2020 13:18 0.20 PROD1 DRILL DLOG T Tie into the K1 for a -16' correction 8,400.0 8,432.0 Rig: NABORS CDR3-AC Page 6/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/28/2020 13:18 3/28/2020 13:30 0.20 PROD1 DRILL RUNL T Close EDC, PU Wt 41 k lbs, RIH to set depth Find bottom at 8718' PU Wt 41 k WOB to -3.7 k lbs RBIH, set liner on bottom, pump 1.5 bpm diff pressure 1200 psi PU wt 41 k lsb WOB -3.0 k lbs, park and reset depth, open EDC 8,432.0 8,623.0 3/28/2020 13:30 3/28/2020 14:48 1.30 PROD1 DRILL TRIP T POOH 8,623.0 67.0 3/28/2020 14:48 3/28/2020 15:24 0.60 PROD1 DRILL PULD T Flow check, LDBHA #7 over a dead well. 67.0 0.0 3/28/2020 15:24 3/28/2020 16:06 0.70 PROD1 WHPST PULD T PU BHA #7 BOT 3.5" x 4.5" WS setting assembly. 0.0 75.0 3/28/2020 16:06 3/28/2020 17:42 1.60 PROD1 DRILL TRIP T RIH, 0.0 8,363.0 3/28/2020 17:42 3/28/2020 17:54 0.20 PROD1 DRILL DLOG T Log formation for depth -13.0' 8,363.0 8,386.0 3/28/2020 17:54 3/28/2020 18:24 0.50 PROD1 DRILL TRIP T Continue IH to setting depth 8,632.12', close EDC, bring pump up to shear 856 diff, 1,900 psi, 1.6 k DHWOB, creep in hole stack out 3.7 k, PUH PUW 39 k 8,386.0 8,620.0 3/28/2020 18:24 3/28/2020 19:54 1.50 PROD1 DRILL TRIP T POOH 8,620.0 74.9 3/28/2020 19:54 3/28/2020 20:18 0.40 PROD1 DRILL OWFF T At surface, check well for flow, PJSM 74.9 74.9 3/28/2020 20:18 3/28/2020 21:00 0.70 PROD1 DRILL PULD T LD settting tools ove a dead well 74.9 0.0 3/28/2020 21:00 3/28/2020 21:54 0.90 PROD1 WHPST PULD T PU window milling assembly, BHA #8 0.0 76.9 3/28/2020 21:54 3/28/2020 22:48 0.90 PROD1 WHPST TRIP T RIH 76.9 8,370.0 3/28/2020 22:48 3/28/2020 23:00 0.20 PROD1 WHPST DLOG T Log formation for depth control -14.0' 8,370.0 8,423.0 3/28/2020 23:00 3/28/2020 23:48 0.80 PROD1 WHPST DISP T Continue IH, 8,600' displace well to milling fluid 8,423.0 8,600.0 3/28/2020 23:48 3/29/2020 00:00 0.20 PROD1 WHPST TRIP T RIH, dry tag Pinch Point @ 8622.8', PUH obtain pump parameters. 8,600.0 8,622.8 3/29/2020 00:00 3/29/2020 02:00 2.00 PROD1 WHPST WPST T Begin milling ahead, 1.83 bpm at 4,060 psi, Diff=530, WHP=537, BHP=4,120, IA=25, OA=194 8,622.8 8,624.3 3/29/2020 02:00 3/29/2020 03:00 1.00 PROD1 WHPST WPST T 1.85 bpm at 4,140 psi, Diff=673, WHP=545, BHP=4,120, IA=25, OA=194 8,624.3 8,625.0 3/29/2020 03:00 3/29/2020 04:30 1.50 PROD1 WHPST WPST T 1.85 bpm at 4,140 psi, Diff=673, WHP=545, BHP=4,120, IA=25, OA=194, notice WOB started increasing steady from 8,626' 8,625.0 8,627.0 3/29/2020 04:30 3/29/2020 06:48 2.30 PROD1 WHPST WPST T 1.83 bpm at 4,202 psi, Diff=732, WHP=550, BHP=4,130, IA=226, OA=235 8,627.0 8,628.8 3/29/2020 06:48 3/29/2020 08:36 1.80 PROD1 WHPST WPST T 1.83 bpm at 4,202 psi, Diff=732, WHP=536, BHP=4111 ** Looks like BOW 8628.8' 8,628.8 8,629.0 3/29/2020 08:36 3/29/2020 09:30 0.90 PROD1 WHPST WPST T 1.83 bpm at 4,509 psi, Diff=992, WHP=550, BHP=4,130, IA=226, OA=235 8,629.0 8,630.8 3/29/2020 09:30 3/29/2020 10:06 0.60 PROD1 WHPST WPST T 1.83 bpm at 4,539 psi, Diff=943, WHP=490, BHP=4125, IA=422, OA=274 ** Mill ahead 8,630.8 8,635.7 Rig: NABORS CDR3-AC Page 7/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/29/2020 10:06 3/29/2020 11:36 1.50 PROD1 WHPST REAM T TD rat hole @ 8635' PU Wt 44 k lbs. Perform reaming passes @ as milled, 30L & 30 R and 180 from as milled (HS) from 8622' to 8631', Pump TD sweep 8,635.7 8,619.0 3/29/2020 11:36 3/29/2020 13:36 2.00 PROD1 WHPST TRIP P Dry drift, - clean. Pump sweep out of hole while PUH slowly, launch second sweep, Open EDC, POOH pumping 2.2 bpm. Decent unload of metal At ~3000'. Micro Motion at 100% drive gain. 8,619.0 57.0 3/29/2020 13:36 3/29/2020 14:42 1.10 PROD1 WHPST PULD P PUD BHA # 8, Window milling assembly. Mill and string reamer guaged out @ 2.80 no go for both. 57.0 0.0 3/29/2020 14:42 3/29/2020 15:00 0.30 PROD1 DRILL CIRC P Stab injector and jet stack 0.0 0.0 3/29/2020 15:00 3/29/2020 15:48 0.80 PROD1 DRILL PULD P PD BHA # 9, Build #1 drilling assembly - 2.4° AKO with RR dynamus RIH, Struggling with Choke B, Swap to A., flush and inspect replace cone and seat. 0.0 72.0 3/29/2020 15:48 3/29/2020 16:36 0.80 PROD1 DRILL TRIP P RIH 72.0 8,360.0 3/29/2020 16:36 3/29/2020 17:36 1.00 PROD1 DRILL DLOG P Log formaiton - 15.5' 8,360.0 8,388.0 3/29/2020 17:36 3/29/2020 17:48 0.20 PROD1 DRILL TRIP P Continue IH, pass through window clean 8,388.0 8,636.0 3/29/2020 17:48 3/29/2020 18:00 0.20 PROD1 DRILL DRLG P OBD, 1.8 bpm at Diff=515 psi, WHP=502, BHP=4,081, IA=191, OA=239 8,636.0 8,641.0 3/29/2020 18:00 3/29/2020 18:30 0.50 PROD1 DRILL WPRT T Computers locked up, PUH off bottom 47 k, continue up hole throught the window pumping 0.5 bpm clean, re- boot computers (all good) 8,641.0 8,548.0 3/29/2020 18:30 3/29/2020 18:42 0.20 PROD1 DRILL WPRT P RBIH, HS TF stackout @ 8,624.5' 5k DHWOB 8,548.0 8,624.5 3/29/2020 18:42 3/29/2020 19:00 0.30 PROD1 DRILL WPRT T PUH clean, atttemp to pass through window x 7, 10 LOHS, 10 ROHS, 30 LOHS, 30 ROHS, no success, PU's clean 8,624.5 8,624.5 3/29/2020 19:00 3/29/2020 19:12 0.20 PROD1 DRILL WPRT T Circulate 5x5 sweep, pull up hole slowly pumping 1.8 bpm 8,624.5 8,500.0 3/29/2020 19:12 3/29/2020 19:24 0.20 PROD1 DRILL WPRT T RBIH, stackout @ 8,543', PUH, pulling negitive 3.6k DHWOB, 1,500 k over CTPUW, work pipe, 8,500.0 8,543.0 3/29/2020 19:24 3/29/2020 19:48 0.40 PROD1 DRILL WPRT T Continue POOH slowly, AP=4,500 psi, bridge broke free @ 8,513', continue up hole, atttempting to pack off x 5, continue wiper to the TT, launch addtional 5x5 sweeps. 8,543.0 7,987.0 3/29/2020 19:48 3/29/2020 20:00 0.20 PROD1 DRILL WPRT T Encounter packoff event, turn back around and RBIH 7,987.0 8,280.0 3/29/2020 20:00 3/29/2020 20:15 0.25 PROD1 DRILL WPRT T Wiper back up hole enounter addtional packoff events x 3, 8,280.0 8,246.0 3/29/2020 20:15 3/29/2020 20:27 0.20 PROD1 DRILL WPRT T Sweep at surface, choke plugged off, line up to choke A, still packing off at surface choke, work choke open and close. *** Note: Large pieces of debris at shaker and in MM, 1/4-1 inch resin/sand, Pictures on s:drive. 8,246.0 8,172.0 Rig: NABORS CDR3-AC Page 8/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/29/2020 20:27 3/29/2020 21:33 1.10 PROD1 DRILL WPRT T RBIH, clean 4.5" with sweeps 8,172.0 8,600.0 3/29/2020 21:33 3/29/2020 22:57 1.40 PROD1 DRILL TRIP T Pull OH above TT, RBIH, open EDC, POOH, right before tagup packed off choke B, bi-pass choke 8,600.0 72.0 3/29/2020 22:57 3/30/2020 00:00 1.05 PROD1 DRILL PULD T At surface, PUD build assembly 72.0 0.0 3/30/2020 00:00 3/30/2020 01:12 1.20 PROD1 DRILL PULD T PD, cleanout assembly, tag up, reset counters 0.0 62.4 3/30/2020 01:12 3/30/2020 02:48 1.60 PROD1 DRILL TRIP T RIH, with cleanout assembly BHA #10 62.4 8,360.0 3/30/2020 02:48 3/30/2020 03:00 0.20 PROD1 DRILL DLOG T Log formation for depth control -14.5' 8,360.0 8,373.0 3/30/2020 03:00 3/30/2020 04:30 1.50 PROD1 DRILL TRIP T Continue IH, pumping 1.80 bpm at 3,992 psi, Diff=430 psi, WHP=541, BHP=4,125, IA=149, OA=231 8,627.3' - 1.0 k DHWOB with no set down, continue IH to bottom 8,641.5' 5 k, pull wiper up to the BOW 8,629' w/ 5x5 sweep, RBIH to bottom, launch second 5x5 sweep, continue pulling to the TT 8,373.0 8,641.5 3/30/2020 04:30 3/30/2020 05:12 0.70 PROD1 DRILL MILL T RBIH, thought window clean, drill ahead from 8,640.5' to 8,643' @ 7 fph 1.80 bpm at 4,360 psi, Diff=304, WHP=480, BHP=4,124, IA=305, OA=256 8,641.5 8,643.0 3/30/2020 05:12 3/30/2020 05:48 0.60 PROD1 DRILL MILL T Clean up open hole, and cased hole into 3.5" multiple sweeps, returns cleaning up. Mostly sand, some clumps. 8,643.0 7,945.0 3/30/2020 05:48 3/30/2020 06:42 0.90 PROD1 DRILL CIRC T RBIH, drift through window - clean, dry tag bottom 8643' 4.7 K WOB. PUH on the pump, clean through window, back on pump, clean trip - park and open EDC 7,945.0 8,597.0 3/30/2020 06:42 3/30/2020 08:24 1.70 PROD1 DRILL TRIP T POOH pumping 2.5 bpm - fan choke - bit depth 4737 - 4598' sweeps at surface. some large chunks, reduced amount from previous. 8,597.0 42.0 3/30/2020 08:24 3/30/2020 09:30 1.10 PROD1 DRILL PULD T PUD BHA # 10,. Flush blow dow and snake out MM. Mill gauged out 2.78" No go. 42.0 0.0 3/30/2020 09:30 3/30/2020 10:24 0.90 PROD1 DRILL PULD T PD BHA # 11, Build assembly - 2.4 ° AKO w RR Dynamus from previous attempt. Bump up, space out. 0.0 72.0 3/30/2020 10:24 3/30/2020 11:54 1.50 PROD1 DRILL TRIP T RIH 72.0 8,355.0 3/30/2020 11:54 3/30/2020 12:06 0.20 PROD1 DRILL TRIP T Tie for -14.5' 8,355.0 8,373.0 3/30/2020 12:06 3/30/2020 12:18 0.20 PROD1 DRILL TRIP T PU Wt 41 k lbs, Close EDC - RIH, launch preemptive 5x5 sweep. 8,373.0 8,642.0 3/30/2020 12:18 3/30/2020 14:24 2.10 PROD1 DRILL DRLG P CT 4023 psi @ 1.83 bpm in, BHP 4051 psi, free spin 453 psi, WH 560 psi, IA 293 psi, OA 252 psi. CT RIH Wt 16-18 k lbs. OBD, See WOB early at 8,641', motor work at 8643'. Drill ahead, Partial loss of returns @ 8650', PU 44 k lbs WOB -3 k lbs, torquing up, Clean up, RBIH. Drill ahead choke cleaned up, ROP increased to ~ 40 ft/hr. *** TD build section #1 @ 8,697' 8,642.0 8,697.0 Rig: NABORS CDR3-AC Page 9/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/30/2020 14:24 3/30/2020 14:54 0.50 PROD1 DRILL WPRT P PU Wt 42 k lbs PUH on TD wiper 8,697.0 8,359.0 3/30/2020 14:54 3/30/2020 15:06 0.20 PROD1 DRILL DLOG P Tie into the K1for a +1 8,359.0 8,377.0 3/30/2020 15:06 3/30/2020 15:24 0.30 PROD1 DRILL DLOG P RBIH, window clean - WOB spike to 2.6 k lbs @ 8603 Log RA tag @ 8627.5 8,377.0 8,659.0 3/30/2020 15:24 3/30/2020 17:12 1.80 PROD1 DRILL TRIP P PUH, open EDC, POOH pumping 2.5 bpm, chasing sweeps 8,659.0 74.0 3/30/2020 17:12 3/30/2020 18:12 1.00 PROD1 DRILL PULD P At surface, tag up, spaceout, PUD build assembly #1 74.0 0.0 3/30/2020 18:12 3/30/2020 19:30 1.30 PROD1 DRILL PULD P PU/PD, build assembly #2 0.0 72.2 3/30/2020 19:30 3/30/2020 21:42 2.20 PROD1 DRILL TRIP P RIH, @ 7,330', spike in WHP 1,100 psi, choke B plugged off switch to choke A. bleed pressure down to 1,000 psi, free up and continue RIH 72.2 8,360.0 3/30/2020 21:42 3/30/2020 21:54 0.20 PROD1 DRILL DLOG P Log formation for depth, correction - 16.5' 8,360.0 8,388.0 3/30/2020 21:54 3/30/2020 22:06 0.20 PROD1 DRILL TRIP P Continue IH clean through window 8,388.0 8,697.0 3/30/2020 22:06 3/31/2020 00:00 1.90 PROD1 DRILL DRLG OBD, 1.84 bpm at 4,247 psi, Diff=522, WHP=491, BHP=4,157, IA=270, OA=242 8,697.0 8,875.0 3/31/2020 00:00 3/31/2020 02:12 2.20 PROD1 DRILL DRLG P OBD, 1.82 bpm at 4,424 psi, Diff=816, WHP=467, BHP=4,193, IA=512, OA=290 8,875.0 9,010.0 3/31/2020 02:12 3/31/2020 02:30 0.30 PROD1 DRILL WPRT P TD Build section @ 9,010', wiper up hole w/5x5 sweep, pull through the window, over pull down hole -5.2k @ 8,621' 9,010.0 8,620.0 3/31/2020 02:30 3/31/2020 02:48 0.30 PROD1 DRILL WPRT T Continue pulling up hole allowing sweep to get above 8,620.0 8,450.0 3/31/2020 02:48 3/31/2020 03:18 0.50 PROD1 DRILL WPRT T RBIH through window notice 2.3k bobble at TOW 8,622', continue IH to 8,700', pull back up hole, over pull 1- 2k 8,646', turn around RBIH to bottom, launch 5x5 sweep 8,450.0 9,000.0 3/31/2020 03:18 3/31/2020 04:00 0.70 PROD1 DRILL WPRT T PUH, PUW 40 k, continue wiper up hole with 5x5 sweep, 8,622 - 3.5 k DHWOB 9,000.0 8,600.0 3/31/2020 04:00 3/31/2020 06:30 2.50 PROD1 DRILL TRIP P POOH, pumping 1.8 bpm at 4,233 psi, Diff=463, WHP=490, IA=587, OA=308 Jog near surface, circ bottoms up from jog, park shallow, open EDC 8,600.0 51.0 3/31/2020 06:30 3/31/2020 07:18 0.80 PROD1 DRILL PULD P PUD, BHA # 12, 2nd stage build assembly. 51.0 0.0 3/31/2020 07:18 3/31/2020 07:42 0.40 PROD1 DRILL BOPE P Vac stack and perform weekly BOP function test - good 0.0 0.0 3/31/2020 07:42 3/31/2020 08:36 0.90 PROD1 DRILL PULD P PD BHA #13, NOV agitator over hybrid motor with RB dyna pilot. 0.0 51.0 3/31/2020 08:36 3/31/2020 10:12 1.60 PROD1 DRILL TRIP P RIH Park shallow, close EDC, test 1.0 bpm 421 psi diff - vibrations - 1/0 1.48 bpm 714 psi dff - vibrations - 2/0 1.81 bpm 1000 psi diff - vibrations - 2/0 51.0 8,366.0 3/31/2020 10:12 3/31/2020 10:24 0.20 PROD1 DRILL DLOG P Tie into the K1 for a -16' correction. 8,366.0 8,383.0 Rig: NABORS CDR3-AC Page 10/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/31/2020 10:24 3/31/2020 10:48 0.40 PROD1 DRILL TRIP P Continue to RIH, S/D in window 8624' 5.5 k lbs, PU clean Spin bit, RBIH, 2.5 k lbs WOB spike slid through, WOB spike 4.7 - 5.8 k @ 8658-8662' 8,366.0 9,010.0 3/31/2020 10:48 3/31/2020 13:48 3.00 PROD1 DRILL DRLG P CT 4669 psi @ 1.84 bpm WH 510 psi, BHP 4195 psi, targeting 12.2 ppg EMW at the window, 12.3 ppg @ the bit. OBD, WOB 0.5 k lbs, ROP up to 240 ft/hr. Drill into possible fault and then ankerite off and on. Swap to new mud 9,010.0 9,193.0 3/31/2020 13:48 3/31/2020 16:00 2.20 PROD1 DRILL DRLG P New mud at the bit 9193' CT 4714 psi, @ 1.86 bpm, free spin 866 psi, BHP 4218 pis. 9,193.0 9,237.0 3/31/2020 16:00 3/31/2020 21:00 5.00 PROD1 DRILL DRLG P Struggling to drop angle, time drill and trough. Two atempts, break through ankerite drill ahead CT 5087 psi @ 1.86 bpm, free spin 950 psi, BHP 4320 psi, WH 484 psi, IA 724 psi, OA 313 psi. 9,237.0 9,392.0 3/31/2020 21:00 3/31/2020 23:00 2.00 PROD1 DRILL DRLG P OBD, CT5457 psi, 1.86 bpm, BHP 4253 psi, 9,392.0 9,590.0 3/31/2020 23:00 3/31/2020 23:12 0.20 PROD1 DRILL WPRT P PUH PUW 42 k, short wiper up hole to get addtional turn x 2. 9,590.0 9,590.0 3/31/2020 23:12 4/1/2020 00:00 0.80 PROD1 DRILL DRLG P BOBD, 1.82 bpm at 5,070 psi, Diff=1,008 psi, WHP=452, BHP=4,251, IA=778, OA=326 9,590.0 9,675.0 4/1/2020 00:00 4/1/2020 00:24 0.40 PROD1 DRILL DRLG P OBD, 1.82 bpm at 5,506 psi, Diff=1,475 psi, WHP=522, BHP=4,197, IA=806, OA=330 9,675.0 9,730.0 4/1/2020 00:24 4/1/2020 00:54 0.50 PROD1 DRILL WPRT T Geo wiper up hole, unable to obtain DLGS needed to stay within polygon, PUW 42 k 9,730.0 8,647.0 4/1/2020 00:54 4/1/2020 01:30 0.60 PROD1 DRILL WPRT T Wiper back in hole, RIW 15 k, up against hard line polygon, 8,647.0 9,655.0 4/1/2020 01:30 4/1/2020 02:12 0.70 PROD1 DRILL WPRT T Wiper up hole, launch 5x5 sweep, perform 250' jog EOB (9,000'-9,250') 9,655.0 8,600.0 4/1/2020 02:12 4/1/2020 04:12 2.00 PROD1 DRILL TRIP T POOH, chasing sweep to the TT 8,600.0 78.3 4/1/2020 04:12 4/1/2020 05:42 1.50 PROD1 DRILL PULD T PUD, lateral BHA #13, Bit Grade 1-1, plugged nozzle x 2 78.3 0.0 4/1/2020 05:42 4/1/2020 07:12 1.50 PROD1 DRILL PULD T PD, lateral BHA #14 w/re-run bi-center bit Dyna-Pilot. 0.0 78.3 4/1/2020 07:12 4/1/2020 08:30 1.30 PROD1 DRILL TRIP T Tag up, reset counters, RIH 78.3 8,365.0 4/1/2020 08:30 4/1/2020 08:42 0.20 PROD1 DRILL DLOG T Log formation for depth control, - 15.5', PUW 42 k 8,365.0 8,381.0 4/1/2020 08:42 4/1/2020 09:00 0.30 PROD1 DRILL TRIP T Continue IH through the window clean, *** Note: Observed tight spot @ 8,660' 8k bobble 8,381.0 9,730.0 4/1/2020 09:00 4/1/2020 11:00 2.00 PROD1 DRILL DRLG P OBD, 1.85 bpm at 5,020 psi, Diff=911 9,730.0 9,927.0 4/1/2020 11:00 4/1/2020 13:00 2.00 PROD1 DRILL DRLG P OBD, 1.85 bpm at 5,616 psi, Diff=1,581, WHP=297, BHP=4,298, IA=651, OA=296 9,927.0 10,068.0 4/1/2020 13:00 4/1/2020 14:18 1.30 PROD1 DRILL DRLG P OBD, 1.85 bpm at 5,235 psi, Diff=1,100, WHP=194, BHP=4,321, IA=766, OA=306 10,068.0 10,140.0 Rig: NABORS CDR3-AC Page 11/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/1/2020 14:18 4/1/2020 14:36 0.30 PROD1 DRILL WPRT P Wiper up hole with 5x5 sweep, PUW 43 k 10,140.0 9,340.0 4/1/2020 14:36 4/1/2020 14:54 0.30 PROD1 DRILL WPRT P Wiper back in hole, RIW 15 k 9,340.0 10,140.0 4/1/2020 14:54 4/1/2020 15:54 1.00 PROD1 DRILL DRLG P BOBD, 1.84 bpm at 5,016 psi, Diff=988, WHP=363, BHP=4,288, IA=783, OA=309 10,140.0 10,397.0 4/1/2020 15:54 4/1/2020 17:42 1.80 PROD1 DRILL WPRT P BHA Wiper, PUW=43K 10,397.0 10,397.0 4/1/2020 17:42 4/1/2020 18:42 1.00 PROD1 DRILL DRLG P 10397', Drill, 1.85 BPM @ 5150 PSI FS, BHP=4330 10,397.0 10,399.0 4/1/2020 18:42 4/1/2020 18:54 0.20 PROD1 DRILL WPRT P Pull 100' wiper. Tough spot, PUW=49K 10,399.0 10,399.0 4/1/2020 18:54 4/1/2020 20:06 1.20 PROD1 DRILL DRLG P Continue to work tough spot. Break out @ 10,406'. 1.84 BPM @ 5005 PSI FS, BHP=4300 10,399.0 10,550.0 4/1/2020 20:06 4/1/2020 20:48 0.70 PROD1 DRILL WPRT P Pull 1000' wiper trip #2. with sweeps. PUW= 42K 10,550.0 10,550.0 4/1/2020 20:48 4/1/2020 21:42 0.90 PROD1 DRILL DRLG P 10,550', Drill, 1.84 BPM @ 5000 PSI FS, BHP=4315 10,550.0 10,720.0 4/1/2020 21:42 4/1/2020 21:48 0.10 PROD1 DRILL WPRT P Stacking, Pull 100' wiper, PUW=42K 10,720.0 10,720.0 4/1/2020 21:48 4/1/2020 23:36 1.80 PROD1 DRILL DRLG P 10,720', Drill, 1.84 BPM @ 4875 PSI FS, BHP=4290 10,720.0 10,849.0 4/1/2020 23:36 4/1/2020 23:42 0.10 PROD1 DRILL WPRT P 10849, Stacking, BHA wiper, PUW=45K 10,849.0 10,849.0 4/1/2020 23:42 4/2/2020 00:00 0.30 PROD1 DRILL DRLG P 10849', Drill, 1.84 BPM @ 4890 PSi FS, BHP=4300 10,849.0 10,856.0 4/2/2020 00:00 4/2/2020 00:24 0.40 PROD1 DRILL WPRT P Pull 500' wiper for poor weight transfer 10,856.0 10,856.0 4/2/2020 00:24 4/2/2020 02:42 2.30 PROD1 DRILL DRLG P 10856', Drill, 1.84 BPM @ 5170 PSI FS, BHP=4315 10,856.0 10,944.0 4/2/2020 02:42 4/2/2020 03:42 1.00 PROD1 DRILL WPRT P Wiper trip #3 to window with tie in. Jog below window, 200' Clean trip up 10,944.0 8,640.0 4/2/2020 03:42 4/2/2020 03:48 0.10 PROD1 DRILL DLOG P Log RA marker for +8' correction 8,640.0 8,661.0 4/2/2020 03:48 4/2/2020 04:36 0.80 PROD1 DRILL WPRT P Continue wiper trip back to bottom. 8,661.0 10,944.0 4/2/2020 04:36 4/2/2020 06:36 2.00 PROD1 DRILL DRLG P BOBD, 1.82 bpm at 5,000 psi, Diff=904, WHP=521, BHP=4,367, IA=458, OA=285 10,944.0 11,168.0 4/2/2020 06:36 4/2/2020 11:48 5.20 PROD1 DRILL DRLG P OBD, 1.82 bpm at 4,485 psi, Diff=940, WHP=573, BHP=4,328, IA=455, OA=286 11,168.0 11,400.0 4/2/2020 11:48 4/2/2020 12:18 0.50 PROD1 DRILL WPRT P Wiper up hole, PUW 42 k (#1) 11,400.0 10,400.0 4/2/2020 12:18 4/2/2020 12:48 0.50 PROD1 DRILL WPRT P Wiper back in hole, RIW 10,400.0 11,400.0 4/2/2020 12:48 4/2/2020 14:30 1.70 PROD1 DRILL DRLG P BOBD, 1.83 bpm at 4,775 psi, Diff=925, WHP=410, BHP=4,300, IA=453, OA=287 11,400.0 11,586.0 4/2/2020 14:30 4/2/2020 14:42 0.20 PROD1 DRILL WPRT P Wiper up hole 200', PUW 52 k 11,586.0 11,386.0 4/2/2020 14:42 4/2/2020 14:54 0.20 PROD1 DRILL WPRT P Wiper back in hole, RIW 6 k 11,386.0 11,586.0 4/2/2020 14:54 4/2/2020 16:12 1.30 PROD1 DRILL DRLG P BOBD, 1.83 bpm at 4,775 psi, Diff=925, WHP=410, BHP=4,300, IA=453, OA=287 11,586.0 11,679.0 4/2/2020 16:12 4/2/2020 16:54 0.70 PROD1 DRILL WPRT P 11679', Pull 800' wipe trip, PUW= 42K 11,679.0 11,679.0 Rig: NABORS CDR3-AC Page 12/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/2/2020 16:54 4/2/2020 18:12 1.30 PROD1 DRILL DRLG P 11679', Drill, 1.83 BPM @ 5037 PSI FS, BHP=4373 11,679.0 11,727.0 4/2/2020 18:12 4/2/2020 18:54 0.70 PROD1 DRILL WPRT P 11727', Pull 700' wiper, PUW=42K 11,727.0 11,727.0 4/2/2020 18:54 4/2/2020 21:24 2.50 PROD1 DRILL DRLG P 11,727', Drill, 1.81 BPM @ 4800 PSI FS, BHP=4390. Low ROP Ankorite like. 11,727.0 11,748.0 4/2/2020 21:24 4/3/2020 00:00 2.60 PROD1 DRILL WPRT P 11748', Drill, 1.81 BPM @ 4800 PSI FS, BHP=4400. Pump sweeps, Lube pills to help with weight transfer. Frequent BHA wipers 11,748.0 11,803.0 4/3/2020 00:00 4/3/2020 00:06 0.10 PROD1 DRILL DRLG P 11803', Drill, 1.86 BPM @ 4800 PSI FS, BHP=4395 11,803.0 11,821.0 4/3/2020 00:06 4/3/2020 00:24 0.30 PROD1 DRILL WPRT P 11821', Pull 200' Wiper. PUW=42K 11,821.0 11,821.0 4/3/2020 00:24 4/3/2020 02:18 1.90 PROD1 DRILL DRLG P 11821', Drill, 1.89 BPM @ 4800 PSI FS, 11,821.0 11,870.0 4/3/2020 02:18 4/3/2020 07:54 5.60 PROD1 DRILL WPRT P Start wiper trip to swab valve. Pump additional sweeps at window with jog below window, PUW=45K, Pull 500' above window. Pump 3rd set of sweeps. MM plugging off with resin type debrie, 11,870.0 79.0 4/3/2020 07:54 4/3/2020 09:24 1.50 PROD1 DRILL TRIP P Tag up at surface, reset counters, RBIH 79.3 8,365.0 4/3/2020 09:24 4/3/2020 09:36 0.20 PROD1 DRILL DLOG P Log formation for depth - 15.5' 8,365.0 8,395.0 4/3/2020 09:36 4/3/2020 09:48 0.20 PROD1 DRILL TRIP P Continue IH to above window, obtain pressure surney @ 8,600' 8,395.0 8,602.0 4/3/2020 09:48 4/3/2020 10:18 0.50 PROD1 DRILL CTOP P 8,600' park to obtain static pressure survey, 11.736 ppg/3,945 psi AP/8553.65 CTMD/6,411.28' TVD 8,602.0 8,602.0 4/3/2020 10:18 4/3/2020 12:00 1.70 PROD1 DRILL TRIP P Continue IH,weight bobble .75 k-2.5 k, confirm TD @ 11,874' 8,602.0 11,874.0 4/3/2020 12:00 4/3/2020 12:15 0.25 PROD1 DRILL TRIP P Hesitate for :beaded liner runnig pill 11,874.0 11,874.0 4/3/2020 12:15 4/3/2020 13:15 1.00 PROD1 DRILL TRIP P Pull up to the window laying in 12.0 ppg, beaded LRP 11,874.0 8,370.0 4/3/2020 13:15 4/3/2020 13:30 0.25 PROD1 DRILL TRIP P Continue POOH, painting EOP flags. 8,370.0 8,365.0 4/3/2020 13:30 4/3/2020 13:42 0.20 PROD1 DRILL DLOG P Log formation for depth control + 4.5' 8,365.0 8,388.0 4/3/2020 13:42 4/3/2020 15:30 1.80 PROD1 DRILL TRIP P Continue POOH to surface 8,388.0 79.3 4/3/2020 15:30 4/3/2020 15:48 0.30 PROD1 DRILL TRIP P Found leaking seal on INJH hydraulic oil cooler 79.3 79.3 4/3/2020 15:48 4/3/2020 16:18 0.50 PROD1 DRILL OWFF P At surface, tag up, check well for flow (no-flow) 79.3 79.3 4/3/2020 16:18 4/3/2020 16:48 0.50 PROD1 DRILL PULD P LD drilling aassebly over a dead well 79.3 0.0 4/3/2020 16:48 4/3/2020 17:18 0.50 COMPZ1 CASING PUTB P Prep RF for liner ops, PJSM 0.0 0.0 4/3/2020 17:18 4/3/2020 20:00 2.70 COMPZ1 CASING PUTB P PU L1 slotted liner assemly wtih 58 joints, shorty deployment sleeve, non- ported bullnose. 0.0 1,645.4 4/3/2020 20:00 4/3/2020 21:12 1.20 COMPZ1 CASING PULD P M/U coiltrack to liner. C/O checks in UQC, M/U injector and surface test. Check pack offs 1,645.4 1,689.7 4/3/2020 21:12 4/3/2020 22:30 1.30 COMPZ1 CASING RUNL P RIH BHA #15 1,689.7 8,508.0 Rig: NABORS CDR3-AC Page 13/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/3/2020 22:30 4/3/2020 22:36 0.10 COMPZ1 CASING DLOG P Correct to flag for -18.5' correction, PUW=40K 8,508.0 8,489.0 4/3/2020 22:36 4/3/2020 23:48 1.20 COMPZ1 CASING RUNL P Clean pass through window and down to bottom @ 11870'. PUW=49K. Set back down. Bring pumps on 1.5 BPM. PUW=41K 8,489.0 11,870.0 4/3/2020 23:48 4/3/2020 23:54 0.10 COMPZ1 CASING TRIP P PUH, remove liner length left in hole. 11,870.0 10,209.0 4/3/2020 23:54 4/4/2020 00:00 0.10 COMPZ1 CASING TRIP P Trip out BHA #15 10,209.0 9,975.0 4/4/2020 00:00 4/4/2020 00:42 0.70 COMPZ1 CASING TRIP P Continue out of well, Paint EOP flag @ 9400' 9,975.0 8,335.0 4/4/2020 00:42 4/4/2020 00:48 0.10 COMPZ1 CASING DLOG P Tie into K1 for +4 foot correction. BOL @ 11874', TOL10228.4 8,335.0 8,355.0 4/4/2020 00:48 4/4/2020 02:12 1.40 COMPZ1 CASING TRIP P Continue out of well, Paint EOP flag @ 7700 8,388.0 44.0 4/4/2020 02:12 4/4/2020 02:36 0.40 COMPZ1 CASING PULD P Tag up, Flow check well, PJSM, Lay down BHA #15 on dead well 44.0 0.0 4/4/2020 02:36 4/4/2020 03:06 0.50 COMPZ1 CASING PUTB P Prep floor to run liner 0.0 0.0 4/4/2020 03:06 4/4/2020 04:24 1.30 COMPZ1 CASING PUTB P M/U L1 upper liner segment with ported bullnose, 6.07" solid pup, 25 Jts slotted liner, and liner top billet 0.0 767.7 4/4/2020 04:24 4/4/2020 04:36 0.20 COMPZ1 CASING PULD P Rig down floor from liner ops 767.7 767.7 4/4/2020 04:36 4/4/2020 05:06 0.50 COMPZ1 CASING PULD P PJSM, Make up coiltrak to liner top billet. Make up to coil and surface test. 767.7 821.3 4/4/2020 05:06 4/4/2020 06:36 1.50 COMPZ1 CASING RUNL P Trip in hole BHA #16 821.3 8,537.0 4/4/2020 06:36 4/4/2020 06:48 0.20 COMPZ1 CASING RUNL P Correct to the EOP flag, -15.8' 8,537.0 8,537.0 4/4/2020 06:48 4/4/2020 07:06 0.30 COMPZ1 CASING RUNL P Continued IH, seen bobble @ 9,427' 3.5 k 8,537.0 10,224.0 4/4/2020 07:06 4/4/2020 07:24 0.30 COMPZ1 CASING RUNL P CT PUW 47 k, - 2.08 k DOWOB, set back down, bring pump online 1.5 bpm/847 psi diff, PUH CT PUW 41 k/0 k DHWOB, stop and remove liner length from coutners 10,224.0 9,451.6 4/4/2020 07:24 4/4/2020 07:36 0.20 COMPZ1 CASING TRIP P POOH 9,451.6 8,620.0 4/4/2020 07:36 4/4/2020 07:45 0.15 COMPZ1 CASING DLOG P Log the RA +3.0', confirm TOL @ 9,451.6', continue POOH 8,620.0 44.2 4/4/2020 07:45 4/4/2020 09:15 1.50 COMPZ1 CASING TRIP P At surface, check well for flow, PJSM 44.2 44.2 4/4/2020 09:15 4/4/2020 09:57 0.70 COMPZ1 CASING PULD P Inspect CT, found flat spot x 2, continue to LD setting tools over a dead well 44.2 0.0 4/4/2020 09:57 4/4/2020 10:09 0.20 PROD2 STK CTOP P Cut BHI Upper and Lower Quick off, trim 20' of coiled tubing **** Note: CT Length 15,480' 0.0 0.0 4/4/2020 10:09 4/4/2020 11:15 1.10 PROD2 STK CTOP P Install CTC, pull test 35 k, (good) 0.0 0.0 4/4/2020 11:15 4/4/2020 12:33 1.30 PROD2 STK CTOP P Install BHI tested Upper Quic, test eline, P/T 4,500 psi (good) 0.0 0.0 4/4/2020 12:33 4/4/2020 13:18 0.75 PROD2 STK PULD P PU/MU, L1-01 kickoff/drilling assembly BHA #17, surface test tools (good) 0.0 78.3 4/4/2020 13:18 4/4/2020 14:54 1.60 PROD2 STK TRIP P RIH 78.3 8,370.0 4/4/2020 14:54 4/4/2020 15:06 0.20 PROD2 STK DLOG P Log formation for depth control - 15.0' 8,370.0 8,388.0 Rig: NABORS CDR3-AC Page 14/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/4/2020 15:06 4/4/2020 15:18 0.20 PROD2 STK TRIP P Continue IH 8,388.0 8,600.0 4/4/2020 15:18 4/4/2020 16:06 0.80 PROD2 STK DISP P Park coil hesitate for Drilling Fluid to get to the bit (10 mins), displace well 8,600.0 8,600.0 4/4/2020 16:06 4/4/2020 16:54 0.80 PROD2 STK TRIP T Close EDC, RIH towards bottom, set down @ 8662', x 5 at DTF. try 30° RODTF, and 30° LODTF, no success. phone TE, try 90° ROHS, 90° LOHS, 310° ROHS, 60° ROHS, no success. 8,600.0 8,662.0 4/4/2020 16:54 4/4/2020 18:24 1.50 PROD2 STK TRIP T POOH 8,662.0 78.3 4/4/2020 18:24 4/4/2020 20:00 1.60 PROD2 STK PULD T PUD, drilling assembly # 17 78.3 0.0 4/4/2020 20:00 4/4/2020 21:06 1.10 PROD2 STK PULD T PD BHA #18 FCO with 2° AKO motor and 2.78 D-331 ridge set. From pre loaded PDL. Make up to injecot and surface test. 0.0 62.3 4/4/2020 21:06 4/4/2020 22:42 1.60 PROD2 STK TRIP T Trip in hole, Shallow test BHA @ 500', continue in 62.3 8,360.0 4/4/2020 22:42 4/4/2020 22:48 0.10 PROD2 STK DLOG T Log K1 for -14' correction 8,360.0 8,371.0 4/4/2020 22:48 4/4/2020 23:06 0.30 PROD2 STK TRIP T Continue in well, set down in window 8424 20 FPM, PUH. RBIH 30 FPM pop through window 8,371.0 8,660.0 4/4/2020 23:06 4/4/2020 23:54 0.80 PROD2 STK MILL T Stack out @ 8660. Try milling @ 1.48 BPM @ 3710 PSI FS, BHP=4140. Stalled twice making no footage. Try to work past at various speeds and TF's. No good 8,660.0 8,660.0 4/4/2020 23:54 4/5/2020 00:00 0.10 PROD2 STK MILL T Mill obstruction, 1.8 BPM @ 4140 PSI FS, BHP=4137 8,660.0 8,660.0 4/5/2020 00:00 4/5/2020 00:18 0.30 PROD2 STK MILL T Mill / work pipe down. Stall at 8660 and 8662. Stack out at 8666 with no motor work. Break through down to 8697. 8,660.0 8,696.0 4/5/2020 00:18 4/5/2020 01:06 0.80 PROD2 STK REAM T Pump sweeps. Back ream up to 8650 @ HS, LS, and HS again 8,696.0 8,650.0 4/5/2020 01:06 4/5/2020 01:12 0.10 PROD2 STK OTHR T Dry drift area, Stack out @ 8662. Push through to 8690 8,650.0 8,690.0 4/5/2020 01:12 4/5/2020 01:30 0.30 PROD2 STK REAM T Make reaming passes @ HS, 40L, and 40R 8,690.0 8,640.0 4/5/2020 01:30 4/5/2020 01:36 0.10 PROD2 STK OTHR T Dry drift 8640 down. Stack weight @ 8662 8,640.0 8,690.0 4/5/2020 01:36 4/5/2020 01:54 0.30 PROD2 STK REAM T 8690, Make additional reaming passes @ 150L, 150R, HS 8,690.0 8,650.0 4/5/2020 01:54 4/5/2020 02:00 0.10 PROD2 STK OTHR T Dry drift down to 8690. Took very little weight @ 8660. Looks good. Pump sweeps. Pull up through window pumping 8,650.0 8,690.0 4/5/2020 02:00 4/5/2020 03:42 1.70 PROD2 STK TRIP T Trip out of hole, Jog 150 back down to 350', 8,690.0 40.4 4/5/2020 03:42 4/5/2020 04:42 1.00 PROD2 STK PULD T At surface, PJSM, Tag up and space out. PUD BHA #17 40.4 0.0 4/5/2020 04:42 4/5/2020 05:30 0.80 PROD2 STK PULD T PU/PD L1-01 kickoff/drilling assembly BHA #19, 0.0 78.3 4/5/2020 05:30 4/5/2020 07:00 1.50 PROD2 STK TRIP T RIH 78.3 8,370.0 4/5/2020 07:00 4/5/2020 07:12 0.20 PROD2 STK DLOG T Log formation for depth control - 15.5' 8,370.0 8,394.0 4/5/2020 07:12 4/5/2020 07:24 0.20 PROD2 STK TRIP P Continue RIH through window and 8,660' clean to bottom, dry tag TOB @ 9,447' 8,394.0 9,447.0 Rig: NABORS CDR3-AC Page 15/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/5/2020 07:24 4/5/2020 07:36 0.20 PROD2 STK TRIP P PUH, PUW 39 k, obtain pump paramerters 9,447.0 9,445.0 4/5/2020 07:36 4/5/2020 07:45 0.15 PROD2 STK WPST P RIH to mill 1.86 bpm at 4,724 psi, Diff=898 psi, WHP=412, BHP=4,225, IA=0, OA=213, stall motor @ 9,445', PU and try again. 9,445.0 9,445.0 4/5/2020 07:45 4/5/2020 09:45 2.00 PROD2 STK WPST P RIH, 1.86 bpm at 4,724 psi, Diff=898 psi, WHP=412, BHP=4,225, IA=0, OA=213 9,445.0 9,448.0 4/5/2020 09:45 4/5/2020 10:33 0.80 PROD2 DRILL DRLG P Drill ahead, 1.85 bpm at 4,853 psi, DIff=980 psi, WHP=460, BHP=4,251, IA=121, OA=280 9,448.0 9,550.0 4/5/2020 10:33 4/5/2020 10:45 0.20 PROD2 DRILL WPRT P PUH to drift KOP, PUW 43 k 9,550.0 9,430.0 4/5/2020 10:45 4/5/2020 10:57 0.20 PROD2 DRILL WPRT P RBIH, clean past billet,(KOP 9,445') 9,430.0 9,550.0 4/5/2020 10:57 4/5/2020 13:27 2.50 PROD2 DRILL DRLG P BOBD, 1.83 bpm at 5,362 psi, Diff=887, WHP=372, BHP=4,255, IA=234, OA=288 9,550.0 9,850.0 4/5/2020 13:27 4/5/2020 13:39 0.20 PROD2 DRILL WPRT P Wiper up hole to 9,460' PUW 42 k 9,850.0 9,460.0 4/5/2020 13:39 4/5/2020 13:51 0.20 PROD2 DRILL WPRT P Wiper back in hole, RIW 16 k 9,460.0 9,850.0 4/5/2020 13:51 4/5/2020 16:57 3.10 PROD2 DRILL DRLG P BOBD, 1.84 bpm at 4,772 psi, DIff=920, WHP=381, BHP=4,271, IA=330, OA=309 9,850.0 10,041.0 4/5/2020 16:57 4/5/2020 18:27 1.50 PROD2 DRILL DRLG P OBD, 1.84 bpm at 5,120 psi, DIff=1,217, WHP=353, BHP=4,271, IA=469, OA=353 10,041.0 10,260.0 4/5/2020 18:27 4/5/2020 19:00 0.55 PROD2 DRILL WPRT P 10260', Wiper trip #2, PUW=43K 10,260.0 10,260.0 4/5/2020 19:00 4/5/2020 21:36 2.60 PROD2 DRILL DRLG P 10,260', Drill, 1.86 BPM @ 4850 PSI FS, BHP=4310 10,260.0 10,680.0 4/5/2020 21:36 4/5/2020 22:24 0.80 PROD2 DRILL WPRT P 10680', Wiper trip #3 to window with tie in, PUW=42K 10,680.0 8,650.0 4/5/2020 22:24 4/5/2020 22:30 0.10 PROD2 DRILL DLOG P Log RA for +5.5' correction 8,650.0 8,662.0 4/5/2020 22:30 4/5/2020 23:36 1.10 PROD2 DRILL DLOG P Make MAD pass for resistivity comparison 8,662.0 9,500.0 4/5/2020 23:36 4/6/2020 00:00 0.40 PROD2 DRILL WPRT P Continue wiper trip back to bottom 9,500.0 10,585.0 4/6/2020 00:00 4/6/2020 00:06 0.10 PROD2 DRILL WPRT P Complete wiper to bottom 10,585.0 10,683.0 4/6/2020 00:06 4/6/2020 01:36 1.50 PROD2 DRILL DRLG P 10683', Drill, 185 BPM @ 4820 PSI FS, BHP=4300 10,683.0 10,935.0 4/6/2020 01:36 4/6/2020 01:48 0.20 PROD2 DRILL WPRT P 10935', BHA wiper, PUW=41K, Swap mud pumps 10,935.0 10,935.0 4/6/2020 01:48 4/6/2020 03:24 1.60 PROD2 DRILL DRLG P 10935', Drill, 1.8 BPM @ 4820 PSi FS, BHP=4345 10,935.0 11,090.0 4/6/2020 03:24 4/6/2020 04:06 0.70 PROD2 DRILL WPRT P 11,090', Wiper trip #1, 1000', PUW=40K, Clean trip up and down 11,090.0 11,090.0 4/6/2020 04:06 4/6/2020 04:48 0.70 PROD2 DRILL DRLG P 11,090', Drill, 1.88 BPM @ 4880 PSI FS, BHP=4371 11,090.0 11,209.0 4/6/2020 04:48 4/6/2020 04:54 0.10 PROD2 DRILL WPRT P BHA wiper, Swap back to pump 2, PUW=40K 11,209.0 11,209.0 4/6/2020 04:54 4/6/2020 06:36 1.70 PROD2 DRILL DRLG P 11,209', Drill, 1.88 BPM @ 4890 PSI FS, BHP=4524 11,209.0 11,383.0 4/6/2020 06:36 4/6/2020 06:54 0.30 PROD2 DRILL WPRT P Wiper up hole PUW 42 k 11,383.0 10,583.0 4/6/2020 06:54 4/6/2020 07:12 0.30 PROD2 DRILL WPRT P Wiper back in hole, RIW 14 k 10,583.0 11,383.0 Rig: NABORS CDR3-AC Page 16/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/6/2020 07:12 4/6/2020 08:30 1.30 PROD2 DRILL DRLG P BOBD, 1.88 bpm at 5,080 psi, Diff=956, WHP=563, BHP=4,375, IA=336, OA=298 11,383.0 11,482.0 4/6/2020 08:30 4/6/2020 08:39 0.15 PROD2 DRILL WPRT P BHA Wiper up hole, PUW 43 k 11,482.0 11,482.0 4/6/2020 08:39 4/6/2020 10:51 2.20 PROD2 DRILL DRLG P BOBD, 1.88 bpm at 5,080 psi, Diff=956, WHP=563, BHP=4,375, IA=336, OA=298 11,482.0 11,703.0 4/6/2020 10:51 4/6/2020 11:03 0.20 PROD2 DRILL WPRT P BHA Wiper up hole, PUW 46 k 11,703.0 11,703.0 4/6/2020 11:03 4/6/2020 11:48 0.75 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 4,651 psi, DIff=882, WHP=574, BHP=4,399, IA=340, OA=298 11,703.0 11,801.0 4/6/2020 11:48 4/6/2020 12:48 1.00 PROD2 DRILL WPRT P Wiper up hole, PUW 43 k 11,801.0 8,640.0 4/6/2020 12:48 4/6/2020 13:00 0.20 PROD2 DRILL DLOG P Log RA marker correction + 6.0' 8,640.0 8,668.0 4/6/2020 13:00 4/6/2020 14:00 1.00 PROD2 DRILL WPRT P Wiper back in hole, RIW 16 k 8,668.0 11,801.0 4/6/2020 14:00 4/6/2020 16:12 2.20 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 4,548 psi, DIff=815, WHP=491, BHP=4,413, IA=366, OA=301 11,801.0 11,921.0 4/6/2020 16:12 4/6/2020 16:18 0.10 PROD2 DRILL WPRT P 11921', BHA Wiper, PUW=42K 11,921.0 11,921.0 4/6/2020 16:18 4/6/2020 18:12 1.90 PROD2 DRILL DRLG P 11,921', Drill, 1.86 BPM @ 4689 PSI FS, BHP=460 11,921.0 11,931.0 4/6/2020 18:12 4/6/2020 18:18 0.10 PROD2 DRILL WPRT P BHA wiper, PUW=42K, Low ROP 11,931.0 11,931.0 4/6/2020 18:18 4/6/2020 21:12 2.90 PROD2 DRILL DRLG P 11,931', Drill, 1.87 BPM @ 4710 PSI FS, BHP=4460 11,931.0 12,055.0 4/6/2020 21:12 4/6/2020 21:18 0.10 PROD2 DRILL WPRT P BHA wiper, PUW=50K 12,055.0 12,055.0 4/6/2020 21:18 4/6/2020 21:48 0.50 PROD2 DRILL DRLG P 12055', Drill, 1.87 BPM @ 4675 PSI FS, BHP=4410 12,055.0 12,080.0 4/6/2020 21:48 4/6/2020 22:12 0.40 PROD2 DRILL WPRT P 12,080', Geo called TD, PUH circulating sweeps down coil 12,080.0 12,080.0 4/6/2020 22:12 4/7/2020 00:00 1.80 PROD2 DRILL WPRT P Start swab wiper, PUW=46K. Jog 8850-8890 12,080.0 8,564.0 4/7/2020 00:00 4/7/2020 02:06 2.10 PROD2 DRILL WPRT P Continue swab wiper trip 8,564.0 54.2 4/7/2020 02:06 4/7/2020 03:36 1.50 PROD2 DRILL WPRT P Tag up at surface, RBIH 54.2 8,387.0 4/7/2020 03:36 4/7/2020 03:42 0.10 PROD2 DRILL DLOG P Log K1 for -15' correction 8,387.0 8,378.0 4/7/2020 03:42 4/7/2020 03:48 0.10 PROD2 DRILL TRIP P Continue in well 8,378.0 8,600.0 4/7/2020 03:48 4/7/2020 04:06 0.30 PROD2 DRILL PRTS P 8600', Stop for static BHP, Sensor depth 6468.72 TVD, BHP=3951, EMW=11.75 8,600.0 8,600.0 4/7/2020 04:06 4/7/2020 05:24 1.30 PROD2 DRILL TRIP P Continue in well. Clean pass through window, Slight bump @ 8660' 500LBS 8,600.0 12,079.0 4/7/2020 05:24 4/7/2020 05:36 0.20 PROD2 DRILL TRIP P Tag bottom 12,079. PUH circulating LRP down CT 12,079.0 12,079.0 4/7/2020 05:36 4/7/2020 07:00 1.40 PROD2 DRILL TRIP P POOH, laying in beaded 12.0 ppg beaded LRP 12,079.0 8,600.0 4/7/2020 07:00 4/7/2020 08:30 1.50 PROD2 DRILL TRIP P Continue POOH displacing well to completion fluid 8,600.0 78.3 4/7/2020 08:30 4/7/2020 09:00 0.50 PROD2 DRILL TRIP P At surface, check well for flow, PJSM (no-flow) 78.3 78.3 4/7/2020 09:00 4/7/2020 09:30 0.50 PROD2 DRILL TRIP P LD drilling assembly BHA #19 over a dead well 78.3 0.0 Rig: NABORS CDR3-AC Page 17/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/7/2020 09:30 4/7/2020 10:00 0.50 COMPZ2 CASING PUTB P Prep-RF for liner ops, PJSM 0.0 0.0 4/7/2020 10:00 4/7/2020 10:18 0.30 COMPZ2 CASING PUTB P PU liner segment #1 w/54 jts of slotted liner, solid bullnose, and QCLL 0.0 246.3 4/7/2020 10:18 4/7/2020 12:18 2.00 COMPZ2 CASING CTOP T Notice was recieved Kuparuk Field in phase 3 conditions, PU safety joint secure well 246.3 246.3 4/7/2020 12:18 4/7/2020 12:30 0.20 COMPZ2 CASING SFTY P Phase 3 lifted to Rig, PJSM 246.3 246.3 4/7/2020 12:30 4/7/2020 14:06 1.60 COMPZ2 CASING PUTB P Continue PU liner segment #1 remaining 47 joints 246.3 1,663.8 4/7/2020 14:06 4/7/2020 14:48 0.70 COMPZ2 CASING PULD P PU CoilTrack tools, MU QCLL, stab on and surface test tools (good) 1,663.8 1,707.6 4/7/2020 14:48 4/7/2020 16:06 1.30 COMPZ2 CASING RUNL P Tag up, reset counters, RIH 1,707.6 8,031.3 4/7/2020 16:06 4/7/2020 16:18 0.20 COMPZ2 CASING RUNL P Correct -23.8' at window flag, PUW 8,031.3 8,031.0 4/7/2020 16:18 4/7/2020 17:30 1.20 COMPZ2 CASING RUNL P Continue IH towards bottom 8,031.0 11,079.0 4/7/2020 17:30 4/7/2020 17:42 0.20 COMPZ2 CASING RUNL P Set on bottom, PUW 50 k/ -6 k, set out on bottom, bring pump on line @ 1.5 bpm/1,264 diff, PUW 38 k/0.3 k, PUH, remove liner length from counters 11,079.0 10,415.0 4/7/2020 17:42 4/7/2020 18:24 0.70 PROD2 CASING TRIP P POOH 10,415.0 8,335.0 4/7/2020 18:24 4/7/2020 18:36 0.20 COMPZ2 CASING DLOG P Log formation for TOL confirmation + 8.5' 8,335.0 8,335.0 4/7/2020 18:36 4/7/2020 19:54 1.30 COMPZ2 CASING TRIP P Continue OOH 8,335.0 44.2 4/7/2020 19:54 4/7/2020 20:06 0.20 COMPZ2 CASING OWFF P At surface, check well for flow, PJSM 44.2 44.2 4/7/2020 20:06 4/7/2020 20:18 0.20 COMPZ2 CASING PULD P LD setting tools over a dead well 44.2 0.0 4/7/2020 20:18 4/7/2020 20:48 0.50 COMPZ2 CASING PUTB P Prep RF for liner OPS, PJSM 0.0 0.0 4/7/2020 20:48 4/7/2020 23:12 2.40 COMPZ2 CASING PUTB P PU Liner segment #2 w/57 jts slotted liner 0.0 1,750.4 4/7/2020 23:12 4/7/2020 23:24 0.20 COMPZ2 CASING RURD P R/D liner running equipment. 1,750.4 1,704.4 4/7/2020 23:24 4/7/2020 23:54 0.50 COMPZ2 CASING PULD P PJSM, M/U Coiltrack to liner. Stab injector and surface test tools. Check packoffs 1,704.4 1,794.2 4/7/2020 23:54 4/8/2020 00:00 0.10 COMPZ2 CASING TRIP P RIH BHA #21 EDC closed 1,794.2 2,273.0 4/8/2020 00:00 4/8/2020 01:06 1.10 COMPZ2 CASING TRIP P Continue in with BHA #21 L1-01 intermediate section 2,273.0 8,514.0 4/8/2020 01:06 4/8/2020 01:12 0.10 COMPZ2 CASING DLOG P Correct to flag for -21'' correction 8,514.0 8,494.0 4/8/2020 01:12 4/8/2020 01:42 0.50 COMPZ2 CASING TRIP P Continue in well 8,494.0 10,090.0 4/8/2020 01:42 4/8/2020 01:48 0.10 COMPZ2 CASING DLOG P Log K1 for +3' correction. 10,090.0 10,104.0 4/8/2020 01:48 4/8/2020 01:54 0.10 COMPZ2 CASING TRIP P Continue in well, Clean pass through window 10,104.0 10,412.0 4/8/2020 01:54 4/8/2020 02:36 0.70 COMPZ2 CASING CTOP P Tag TOL 10,412. Pick up to 60K. Have latch into lower liner segment. Set back down. Bring on pumps 1.4 BPM Pick up. still latched in. Bring pumps to 1.7 work pipe. Still latched. Goto 2 BPM work pipe still latched. Consult town 10,412.0 10,412.0 Rig: NABORS CDR3-AC Page 18/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/8/2020 02:36 4/8/2020 03:06 0.50 COMPZ2 CASING CTOP T Pull both sections of liner up to 10360. PUW=74K Bring pumps online. Liner has released. Attempt to work liner back to bottom pumping. Run at liner. Unable to get it to move 10,412.0 10,412.0 4/8/2020 03:06 4/8/2020 03:12 0.10 COMPZ2 CASING TRIP T Start out of hole, remove liner length left in hole from counters 10,412.0 8,335.0 4/8/2020 03:12 4/8/2020 03:18 0.10 COMPZ2 CASING DLOG T Log K1 for +3' correction 8,335.0 8,352.0 4/8/2020 03:18 4/8/2020 03:24 0.10 COMPZ2 CASING TRIP T RBIH. Tag TOL pumping 1.5 BPM @8621' 8,352.0 8,621.0 4/8/2020 03:24 4/8/2020 05:06 1.70 COMPZ2 CASING TRIP T Trip out of well pumping across the top, Paint 7700' EOP flag 8,621.0 46.0 4/8/2020 05:06 4/8/2020 05:48 0.70 COMPZ2 CASING PULD T At surface, Flow check well, PJSM. Lay down BHA #21 on dead well 46.0 0.0 4/8/2020 05:48 4/8/2020 09:48 4.00 COMPZ2 CASING WAIT T Wait on Tempress vibrating tool. BOT stuck behind D-26 scissor lift module move 0.0 0.0 4/8/2020 09:48 4/8/2020 10:30 0.70 COMPZ2 CASING PULD T PJSM, M/U BHA # 22 with tempress vibrating tool. Make up to injector and surface test tool 0.0 46.2 4/8/2020 10:30 4/8/2020 12:00 1.50 COMPZ2 CASING TRIP T RIH, BHA #22, EDC open 46.2 8,372.0 4/8/2020 12:00 4/8/2020 12:06 0.10 COMPZ2 CASING DLOG T Log K1 for -15.5' 8,372.0 8,356.0 4/8/2020 12:06 4/8/2020 12:12 0.10 COMPZ2 CASING TRIP T Continue in well, wt check @ 8570' 41K close EDC. 8,356.0 8,622.0 4/8/2020 12:12 4/8/2020 12:18 0.10 COMPZ2 CASING CTOP T 8622', ag TOL. Bring pump online 1.47 BPM @ 4830 PSI, BHP=4160. Returns never come above .9 BPM 8,622.0 8,622.0 4/8/2020 12:18 4/8/2020 13:54 1.60 COMPZ2 CASING CIRC T PUH to 8607'. Open EDC, displace well to 8.8 PPG drilling mud 8,622.0 8,607.0 4/8/2020 13:54 4/8/2020 14:00 0.10 COMPZ2 CASING CTOP T Mud all around, Shut EDC RBIH. Tag up @ 8621. Pump 1.59 BPM @ 3800 PSI, BHP=4350. 8,607.0 8,621.0 4/8/2020 14:00 4/8/2020 14:36 0.60 COMPZ2 CASING CTOP T 8621', P/U and restart, PUW=40K 8,621.0 8,625.0 4/8/2020 14:36 4/8/2020 15:36 1.00 COMPZ2 CASING CTOP T P/U Observing packing off on back side, PUH. More packing with over pulls Pull heavy at 8486 packing off. Can not RIH. Pop free coming up. Head for 3 1/2. Get sample of returns to geo. Sand and resin, Slight overpull when CTC enters 3 1/2 8,625.0 7,724.0 4/8/2020 15:36 4/8/2020 16:00 0.40 COMPZ2 CASING CTOP T Clear up in 3 1/2 RBIH to clean 4 1/2. Clean running in 7,724.0 8,620.0 4/8/2020 16:00 4/8/2020 16:30 0.50 COMPZ2 CASING CTOP T 8620', Lightly tag top of billet. Recip up to 3 1/2". Circulate and clean up from 8,620' to 7,700'. 8,620.0 8,620.0 4/8/2020 16:30 4/8/2020 18:30 2.00 COMPZ2 CASING CTOP T Circulate 12.0 ppg KWF in the CT and lay in KWF. 8,620.0 44.0 4/8/2020 18:30 4/8/2020 19:30 1.00 COMPZ2 CASING CTOP T Monitor well, static. LD BHA and remove upper checks. MU nozzle to jet stack. 44.0 0.0 4/8/2020 19:30 4/8/2020 20:00 0.50 COMPZ2 CASING CTOP P Jet stack at 2.0 bpm. Test Inner reel valve and stripper250/4,000 psi 0.0 0.0 Rig: NABORS CDR3-AC Page 19/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/8/2020 20:00 4/8/2020 21:30 1.50 COMPZ2 CASING CTOP P Unstab cart, MU night cap. Grease tree, stack, and romeo valves. Flush surface lines with fresh water and fluid pack. Shell test. Swab 2 leaking. Regrease swab 2 - good test. 0.0 0.0 4/8/2020 21:30 4/8/2020 22:00 0.50 COMPZ2 CASING CTOP P PJSM and prep to test BOPE. 0.0 0.0 4/8/2020 22:00 4/9/2020 00:00 2.00 COMPZ2 CASING BOPE P Test BOPE to 250 psi / 4,000 psi. Annular to 2,500 psi. 0.0 0.0 4/9/2020 00:00 4/9/2020 03:18 3.30 COMPZ2 CASING BOPE P Test 1. Swab 2 Test 2. Blind/Shear, BOP TV2, Charlie 4, 5, 8, &12 Test 3. BOP TV 1, Charlie 3, 7, & 11 Test 4. Manual choke D & Super choke C Test 5. Romeo 3, Bleeder 3, Tango 2, Charlie 2, & 10 Test 6. Charlie 1, 9, Bravo 5, and Tango 1 – install TIW test joint Test 7. Lower 2” pipe slip rams, TIW #1, Romeo 1, Bleeder 1 Test 8. Annular BOP Test 9. Upper 2” pipe slip rams, Bravo 6, & 8 Test 10. Bravo 7 – swap out 2” test joint for 2-3/8” Test 11. 2-3/8” pipe slip rams, TIW#2 – check N2 levels, swap to 2” test joint Test 12. Draw down accumulator Test 13. Stab injector and line up to reverse circulate coil, test inner reel valve and stripper. Tested all gas detectors, pits, cellar, Verified flow alarms - PVT Bravo 8 fail / pass. LD test joint. 0.0 0.0 4/9/2020 03:18 4/9/2020 04:48 1.50 COMPZ2 CASING PUTB P PJSM for running liner. PU upper section of liner: dissolvable bull nose 24 joints 2 3/8" slotted liner deployment sleeve 0.0 741.9 4/9/2020 04:48 4/9/2020 05:12 0.40 COMPZ2 CASING PULD P Install checks in UQC. Stab on injector. Check packoff. Check comms to BHI tools - good. 741.9 785.7 4/9/2020 05:12 4/9/2020 06:18 1.10 COMPZ2 CASING TRIP P Trip in well, BHA #23 785.7 6,408.0 4/9/2020 06:18 4/9/2020 07:36 1.30 COMPZ2 CASING TRIP P POOH BHA #23 6,408.0 45.0 4/9/2020 07:36 4/9/2020 08:12 0.60 COMPZ2 CASING PULD P PJSM, Flow check well. Unstab injector and rack back. 45.0 0.0 4/9/2020 08:12 4/9/2020 08:24 0.20 COMPZ2 CASING PUTB P Reconfig BHA. Lay down 2 jts slotted. P/U 10' pup, BHA #24 with QCLL, 22 Jts slotted, 2 pups, and seal bore receptical 0.0 688.0 4/9/2020 08:24 4/9/2020 08:36 0.20 COMPZ2 CASING PULD P Make up coil trak to liner. Make up injector and service test 688.0 734.2 4/9/2020 08:36 4/9/2020 10:12 1.60 COMPZ2 CASING TRIP P RIH BHA #24, Make a -15' correction 734.2 8,613.0 4/9/2020 10:12 4/9/2020 10:24 0.20 COMPZ2 CASING CTOP P Set down multiple times multiple speeds. Unable to latch 8,613.0 8,613.0 4/9/2020 10:24 4/9/2020 10:30 0.10 COMPZ2 CASING TRIP P PUH to 8564 8,613.0 8,564.0 Rig: NABORS CDR3-AC Page 20/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/9/2020 10:30 4/9/2020 10:36 0.10 COMPZ2 CASING DLOG P Log formation for a +9' correction 8,564.0 8,573.0 4/9/2020 10:36 4/9/2020 11:00 0.40 COMPZ2 CASING TRIP P RBIH to bottom. Set down on top of liner. No latch. Shut choke. Attemp to pump down backside. Well pressured right up. Attemp latching multiple times. 8,573.0 8,622.0 4/9/2020 11:00 4/9/2020 12:24 1.40 COMPZ2 CASING TRIP P POOH for cleanout BHA. 8,622.0 690.4 4/9/2020 12:24 4/9/2020 14:30 2.10 COMPZ2 CASING PULD P At surface, Flow check well. PJSM Lay down BHA # 24 690.4 0.0 4/9/2020 14:30 4/9/2020 15:00 0.50 COMPZ2 CASING PULD P P/U BHA #25, FCO BHA With 2" nozzle. Make up injector and surface test. 0.0 42.8 4/9/2020 15:00 4/9/2020 16:30 1.50 COMPZ2 CASING TRIP P Trip in BHA #25, EDC open, Start mud down CT 42.8 8,340.0 4/9/2020 16:30 4/9/2020 16:36 0.10 COMPZ2 CASING DLOG P Log gamma tie in for -15.5 8,340.0 8,355.0 4/9/2020 16:36 4/9/2020 18:00 1.40 COMPZ2 CASING TRIP P Continue in for fill clean out. Displace well to mud 8,355.0 8,617.0 4/9/2020 18:00 4/9/2020 20:12 2.20 COMPZ2 CASING WASH P Cleanout QCLL at 8,621' and above to 7,940'. stab into QCLL and pump. 1.86 / 1.84 bpm in/out 3,889 psi Pull up hole and Packing off when pulling into the 3 1/2" tubing. RIH to 8,100' and clear packoff. Pump 5 bbl low, 5 bbls high visc. sweep Pull back up. 7,872' and no packoffs. Maintain 12.2 ppg EMW at the window. MicroMotion packing off. Flush MM and captured 1/2" diameter pieces of resin. 8,618.0 8,615.0 Rig: NABORS CDR3-AC Page 21/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/9/2020 20:12 4/9/2020 21:30 1.30 COMPZ2 CASING WASH P 8,615' 1.87 bpm in, 1.87 out 3,783 psi annular 4,119, bore 4,228, diff: 109. 18 - 20K 8,618' set down 1k WOB. PU: 39K nozzle out of QCLL work nozzle back into QCLL, saw pressure increase to 4,400 - 4,900 psi 3.7K WOB PU 20'. RIH to 8,617' no pressure increase seen. wash down slowly at .4 fpm to 8,618.8 and saw pressure increase indication of nozzle going into QCLL. PU 43K to 8,610' and wash back down flushing QCLL to 8,619.3' and set down 2K WOB and saw 80 psi increase. PU and repeat. Sweep exiting the nozzle. Wash down 8,617.82' set down 1K WOB, minor pressure increase. PU wash down 8,619.21', no pressure increase. PU. Wash down 8,619.26 w/ 1.71 K WOB. No pressure increase. PU 44K. Wash down 8,619.38 w/ 2.23K WOB. 20 psi pressure increase. appears to be repeatable depth with no pressure increase. PU. Pump 5 x 5 sweep. Pull up into the 3 1/2" tubing. 7,983', pressure increase to 4,300 psi w/ CTC inside the the 3 1/2" and viscous sweep out of the nozzle. Run back in hole and pressure remaining elevated at 4,268 psi. circulating sweep out of the hole. RIH and pressure returnned to normal at 8,260' +/-. 8,615.0 7,993.0 4/9/2020 21:30 4/9/2020 22:12 0.70 COMPZ2 CASING WASH P RIH, Tie in at 8,331' to 8,353'. +3' correction. Pump sweep. RIH to confirm tag depth. 8,610'. 1.84 bpm in, 1.91 out. 3,800 psi sweep exiting the nozzle at 8,613'. 3,940 psi. wash down to 8,621.26 with .5K WOB. Wash out and back into QCLL same depth and WOB. PU to 8,613'. Wash back down to QCLL 8,621.54' and set down 1.85K WOB. Good confirmation of tag depth and clean repeatable without packoff. 7,993.0 8,621.0 4/9/2020 22:12 4/9/2020 23:42 1.50 COMPZ2 CASING WASH P Pull up hole to clean up 4.5" x 3.5" transition. Pull clean into 3.5" tubing with no packoffs. Pump 10 bbls high visc sweep and 5 x 5 sweep. RIH 8,400' some packing off, RIH to 8,591'. Open EDC. 8,621.0 8,591.0 4/9/2020 23:42 4/10/2020 00:00 0.30 COMPZ2 CASING WASH P POOH and increase pump rate to 2.69 in / 2.41 out, 5,361 psi Annular velocity in 4.5" liner 240 fps. Getting 1/2" - 3/4" resin chunks out at +/- 8,060' nozzle depth. POOH, jog in hole at 3,500' and at surface. MP choke packing off. Switch chokes. 8,591.0 8,060.0 Rig: NABORS CDR3-AC Page 22/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/10/2020 00:00 4/10/2020 02:12 2.20 COMPZ2 CASING WASH P POOH with EDC open and cleanout tubing to surface. 2.69 in, 5,361 psi. MM out bypassed due to packing off. POOH, jog in hole at 3,500' and at surface. MP choke packing off. Switch chokes. 8,060.0 20.0 4/10/2020 02:12 4/10/2020 04:00 1.80 COMPZ2 CASING TRIP P RIH. Close and test EDC at 500'. Tie in 8,331' to 8,353'. -15' correction 20.0 8,353.0 4/10/2020 04:00 4/10/2020 04:54 0.90 COMPZ2 CASING WASH P 1.84 in / 1.91 out 3,650 psi Tag 8,619.96 w/ 0.95K WOB. WOB falling off slowly Wash down 8,620.2. PU 42K. to 8,608' 8,620.8' at 2.3K WOB. WOB falling off slowly to 1.6K. PU to 8,611'. Wash down. Tag at 8,621.12 w/ 1.33 K WOB. Set down to 2.4K WOB. Pressure increased to 4,000 psi. PU to 8,614'. Repeat tag. 8,621.48 with 1.99K WOB. PU 42K. Pull up to confirm clean entry into 3.5" tubing. Pull up to 7,974', packing off. Run back in hole. Pull back up into 3.5" tubing clean. 8,353.0 7,883.0 4/10/2020 04:54 4/10/2020 05:36 0.70 COMPZ2 CASING CIRC P Pump 20 bbls 12.0 ppg high visc. pill at 149K LSRV, followed by 12.0 ppg KWF. Some packing off. Still getting resin rocks back at bottoms up. MM packing off. Tag 8,620.6 at 1.5K WOB. 7,883.0 7,942.0 4/10/2020 05:36 4/10/2020 07:00 1.40 COMPZ2 CASING TRIP P Paint white flag, POOH 7,942.0 45.0 4/10/2020 07:00 4/10/2020 08:36 1.60 COMPZ2 CASING PULD P Tag up, Flow check well, PJSM Lay down BHA #25 45.0 0.0 4/10/2020 08:36 4/10/2020 10:00 1.40 COMPZ2 CASING PUTB P P/U BHA #26 with QCLL disolvable bull nose, 22 Jts BLANK liner, 10' pups and NS GS spear with sealing prong. Make up coiltrak. M/U to insector and surface test 0.0 733.5 4/10/2020 10:00 4/10/2020 11:18 1.30 COMPZ2 CASING RUNL P Trip in well 733.5 8,545.0 4/10/2020 11:18 4/10/2020 11:30 0.20 COMPZ2 CASING DLOG P Tie into gamma, minus 14.5' 8,545.0 8,570.0 4/10/2020 11:30 4/10/2020 12:18 0.80 COMPZ2 CASING RUNL P Continue in well, Tag up @ 8621 @ min rate, Shut down pump. P/U not latched. Trip in washing down. Pick up. No latch. Wash back down. Jet @ 1 BPM. Packed off. Shut down pump. Holding 1500PSI Circ pressure. Pick up. Looks like liner not on. Make multiple attempts to latch. Trip out of well 8,570.0 8,621.0 4/10/2020 12:18 4/10/2020 13:36 1.30 COMPZ2 CASING TRIP P POOH, pumping across top 8,621.0 45.0 4/10/2020 13:36 4/10/2020 14:00 0.40 COMPZ2 CASING PULD P At surface, Flow check well. PJSM, Unstab injector. Pull Coiltrak from well. BHA #26 No liner, 45.0 0.0 4/10/2020 14:00 4/10/2020 14:30 0.50 COMPZ2 CASING PULD P Reconfigure BHA. P/U non sealing NS GS spear. Put in well, M/U coil to tool and surface test - Good 0.0 43.8 Rig: NABORS CDR3-AC Page 23/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/10/2020 14:30 4/10/2020 15:54 1.40 COMPZ2 CASING TRIP P RIH BHA #27 43.8 7,855.0 4/10/2020 15:54 4/10/2020 16:00 0.10 COMPZ2 CASING DLOG P Log Gamma tie in for -14.5' 7,855.0 7,876.0 4/10/2020 16:00 4/10/2020 16:06 0.10 COMPZ2 CASING TRIP P Continue in well, PUW=38K @ 7876, zero DHWOB 7,876.0 7,933.0 4/10/2020 16:06 4/10/2020 17:30 1.40 COMPZ2 CASING TRIP P Set down on liner, PUH, PUW=41K, DHWOB=-2.7K, Unable to latch into section 2 of liner. Trip out of well 7,933.0 733.5 4/10/2020 17:30 4/10/2020 21:00 3.50 COMPZ2 CASING PULD P Lay down BHI tools and solid liner (wet). 733.5 0.0 4/10/2020 21:00 4/10/2020 21:30 0.50 COMPZ2 CASING OTHR P Load slotted liner into the pipe shed and restrap. 0.0 0.0 4/10/2020 21:30 4/10/2020 23:24 1.90 COMPZ2 CASING PULD P PJSM for picking up liner. PU steel bullnose, 22 joints slotted liner, 2 pup joints (10' total), and deployment sleeve. MU CoilTrak tools. Stab injector. Test CoilTrak tools - good. 0.0 734.2 4/10/2020 23:24 4/11/2020 00:00 0.60 COMPZ2 CASING TRIP P RIH with liner. 734.2 3,100.0 4/11/2020 00:00 4/11/2020 01:18 1.30 COMPZ2 CASING TRIP P RIH with liner. Tie in, 8,535' - 8,580'. - 14.5' correction. PU wt.: 41K RIH and tag TOL section 2 at 8,621', set down 3.5K WOB. Bring pump online to 1.5 bpm to release GS from liner. PU= 39K BHP=3768PSI, TVD=6461.58 3,100.0 8,621.0 4/11/2020 01:18 4/11/2020 04:54 3.60 DEMOB MOVE DMOB P Liner released. Set end of CT depth. Displace CT with seawater. POOH. PJSM with LRS for FP. FP well from 2,500' to surface with 30 bbls of diesel. Tag up at surface. 7,918.6 28.3 4/11/2020 04:54 4/11/2020 07:06 2.20 DEMOB MOVE PULD P PJSM, PUD BHA # 28 Liner running tools, Lay down tools Final SITP=1170 28.3 0.0 4/11/2020 07:06 4/11/2020 10:00 2.90 DEMOB MOVE RURD P Remove checks from UQC. Mix corrosion inhibitor 20 BBl pill. Pump 20 BBls fresh water, 20 BBl inhibitor, 50 BBls fresh water down CT out to TT 0.0 0.0 4/11/2020 10:00 4/11/2020 11:00 1.00 DEMOB MOVE CTOP P PJSM w HES N2 pumpers. MIRU N2 pumper, Begin cool down 0.0 0.0 4/11/2020 11:00 4/11/2020 12:30 1.50 DEMOB MOVE CTOP P PT N2 to 4K. Bring online 1500 SCF for 15 minutes. S/D N2 bleed off to TT 0.0 0.0 4/11/2020 12:30 4/11/2020 14:00 1.50 DEMOB MOVE CTOP P Pull upper QC. Position injector / reel for inner reel iron removal. Remove inner reel iron - wash pipe - Pressure bulkhead. Load pits with fresh water flush 0.0 0.0 4/11/2020 14:00 4/11/2020 18:00 4.00 DEMOB MOVE CTOP P PSSM, Position injector for CT removal from injector and secure. Remove CT counters. Unstab and secure CT to reel, install shipping chains. RU slings and shackles, remove stripper/brass, continue to flush pits. 0.0 0.0 Rig: NABORS CDR3-AC Page 24/24 3O-04 Report Printed: 5/12/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/11/2020 18:00 4/11/2020 21:00 3.00 DEMOB MOVE CTOP P Remove reel containment and saddle clamps Housekeeping in pipe shed. Send out riser sections under pipe rack. Remove excess cut coil. Modify shipping boxes. Flush and corrosion inhibit all pits. 0.0 0.0 4/11/2020 21:00 4/12/2020 00:00 3.00 DEMOB MOVE CTOP P Clean stripper and prep for storage. Remove all inner reel iron from pipe shed. Send out Baker tools from pipe shed. Remove QTS and pump in sub riser. 0.0 0.0 4/12/2020 00:00 4/12/2020 00:00 0.00 DEMOB Rig up reel for removal. Prep injector for removal. Break down PDL's for removal 0.0 0.0 Rig: NABORS CDR3-AC &RQRFR3KLOOLSV$ODVND,QFB.XSDUXN ! 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')8+001)::8/0!16! :8(6:8/)717+ /6+8!(+1(! 71(6 68;661)+ ,5$"5&>2/3++80+(16) ;+17; 761): :8:/:1!+ )8/)(1(( ')8+7+1:!:8/071!+ :8(6:8///17; /6+8!6;1;! +(1/: 68;!01)! ,5$"5&>2/3++80!0100 ;+17( :010) :8::(1/; )8/)01)0 ')8+)!17::8:(+1/; :8(6:8/:/1!: /6+8!/:1:: ;1!0 68;/71;7 ,5$"5&>2/3++807(1+7 ;(1/7 :71+0 :8::/16! )8/:(1!0 ')8++:1(+:8:(:16! :8(6:8/7:1!/ /6+8!;)1!7 017/ 68;771:( ,5$"5&>2/3+68(((1/) ;(1)7 :)16) :8:7(16) )8/7617( ')8(;;17+:8:++16) :8(6:8/;;17: /6+8)++1:! 01/0 68;0;1/6 ,5$"5&>2/3+68(6010; ;(1+0 :+10) :8:7/1+; )8/;/1;) ')8(:61;!:8:+:1+; :8(6:8:(+10; /6+8)!71): 717: 680+017+ ,5$"5&>2/3+68()/16! ;+166 :+1/7 :8:771:) )8/0610: ')8()01/7:8:+;1:) :8(6:8:(01+/ /6+8)/(1:0 71+7 680!(10) ,5$"5&>2/3+68(701(( ;+166 :+1/7 :8:;61;( )8:(;1;/ ')8(6(166:8:6!1;( :8(6:8:6/1+! /6+8)7010; (1(( 680//10( "D$$ Transmittal #1273 Detail Date: 5/8/2020 To (External Party):From (CPAI Contact): Email*: abby.bell@alaska.gov Email*: richard.e.elgarico@conocophillips.com First Name*:Abby First Name*: Ricky Last Name*: Bell Last Name*: Elgarico Phone Number:(907) 79 Phone Number: (907) 265-6580 Company: AOGCC Company: ConocoPhillips Address: 333 West 7th Ave.Address: 700 G Street City: Anchorage City: Anchorage State: AK State: AK Zip Code: 99501 Zip Code: 99501 Transmittal Info Sent Via: FTP Tracking #: Justification: Data Detail Quantity*:Description*:Type*: 1 CD4-215l1 LWD Data - CGM, LAS, PDF, TAPESCAN, TIF Digital 1 CD5-23L1 LWD Data - CGM, LAS, PDF, TAPESCAN, TIF Digital 1 CD5-23L1-01 LWD Data - CGM, LAS, PDF, TAPESCAN, TIF Digital 1 3R-105 LWD Data - CGM, LAS, PDF, TAPESCAN, TIF Digital 1 3R-105L1 LWD Data - CGM, LAS, PDF, TAPESCAN, TIF Digital 1 3R-107 LWD Data - CGM, LAS, PDF, TAPESCAN, TIF Digital 1 3R-107L1 LWD Data - CGM, LAS, PDF, TAPESCAN, TIF Digital 1 CD4-214L1 LWD Data - CGM, LAS, PDF, TAPESCAN, TIF Digital 1 3O-04L1 LWD Data - CGM, LAS, PDF, TAPESCAN, TIF Digital 1 3O-04L1-01 LWD Data - CGM, LAS, PDF, TAPESCAN, TIF Digital Received by the AOGCC on 05/08/2020 PTD: 2191850 E-Set: 33011 1 3O-04L1PB1 LWD Data - CGM, LAS, PDF, TAPESCAN, TIF Digital Attachments: Received By: ___________________________ Signature: ___________________________ Date: _________________ Approver: ___________________________ Signature: ___________________________ Date: _________________ Abby Bell Abby Bell 05/08/2020 21 91 85 32983 Letter of Transmittal Baker Hughes 'Date` April 30, 2020 To: _._ .From: Abby Bell Harvey Finch AOGCC Baker Hughes 333 West 7`h Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 i Please find enclosed the directional survey data for the following well(s): 30-04UP61 30-041-1 30.041-1-01 i RECEIVED APR 3 0 2020 AOGCC (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Harvey Finch Baker Hughes Wellplanner Harvey.FinchCcbbakerhughes com I THE STATE 'ALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk Oil Pool, KRU 30-04L1-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-185 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Surface Location: 789' FNL, 1879' FWL, Sec. 22, T13N, R9E, UM Bottomhole Location: 1410' FNL, 2210' FEL, Sec. 16, T13N, R9E, UM Dear Mr. Ohlinger: Enclosed is the approved application for the permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 188-062, API No. 50-029- 21826-00-00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. VSincer , r ice C a DATED thisN? day of December, 2019. STATE OF ALASKA AL, N OIL AND GAS CONSERVATION COMMI, )N PERMIT TO DRILL 20 AAC 25.005 DEC - 6 2019 1 a. Type of Work: Drill ElLateral ❑✓ Redrill ❑ Reentry ❑ 1b. Proposed Well Class: Exploratory - Gas ❑ Stratigraphic Test ElDevelopment - Oil ❑� Exploratory - Oil ❑ Development - Gas ❑ Service - WAG ❑ Service - Disp ❑p Service - Winj ElSingle Zone ❑ Service - Supply ❑ Multiple Zone ❑ eel s roposed for: C albedas LJ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket ❑✓ Single Well ❑ Bond No. 5952180 11. Well Name and Number: KRU 30-041-1-01 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12,000' TVD: 55',6523' 12. Field/Pool(s): Kuparuk River Pool / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 789' FNL, 1879' FWL, Sec. 22, T13N, R9E, UM Top of Productive Horizon: 1657' FSL, 1987' FWL, Sec. 16, T13N, R9E, UM Total Depth: 1410' FNL, 2210' FEL, Sec. 16, T13N, R9E, UM 7. Property Designation: ADL 25513 8. DNR Approval Number: LONS 85-100 13. Approximate Spud Date: 12/17/2019 9. Acres in Property: 2560 14. Distance to Nearest Property: 7450' 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 12406" y- 5.956662- --Zone- 4 10. KB Elevation above MSL (ft): 59' GL / BF Elevation above MSL (ft): 19' 15. Distance to Nearest Well Open to Same Pool: 42' (3R-26) 16. Deviat d we : ` iso epth: 02-50 feet Maximum Hole Angle: 98 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 4244 Surface: 3588 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) 3" 2-3/8" 4.7# L-80 ST -L 3225' 8775' 6550' 12000' 6502' 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): 8,984 6785 8694 Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 8,850 6687 N/A Casing Length Size Cement Volume MD TVD Conductor 80' 16" 199 Sx ASI II 115' 115' Surface 5064' 9-5/8" 1200 Sx ASI II, 375 Sx Class G 5099' 4029' Production 8928' 7' 300 Sx Class G, 175 Sx ASI 8961' 6799' Liner 899' 4-1/2" 28 bbls Class G 8850' 6687' Perforation Depth MD (ft): 8675'- 8695' Perforation Depth TVD (ft): 6559'-6573 Hydraulic Fracture planned? ❑ ❑✓ 20. Attachments: Property Plat ❑ BOP Sketch Drilling Program Diverter Sketch Seabed Report Time v. Depth Plot H Drilling Fluid Program Shallow Hazard Analysis 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: Shane Germann Authorized Name: James Ohlinger Contact Email: Shane.Germann COP.Conn Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4597 Authorized Signature: Date: -040" Commission Use Only Permit to Drill Number: 9 —1195 API Number: 5Z — 1'3 Permit Approval Date: See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Nov' Mud log req'd: Yes❑ No[' Other.,r,pfCS f b� rssL� t f0 406G 0 p5) _� Samples req'd: Yes�/NoE] r _e, ffj f- 12/_tSS L'r<- HzS measures: Yes Directional svy req'd: Yes N?*No❑ Spacing exception req'd: Yes ❑ No / Inclination -only svy req'd: Yes E] No� Post initial injection MIT req'd: Yes El No[`l' Y�rl'g hc� �o�,9AC Z5. o 5-r!,6) /5 Gjr-aYJf'ed to x110 w -the kl' ke,Ff-pbe Qny pc, aIv,-iq {i1G �f7�iv-t-, APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: J I C)rrR4 [� his p ���is ��Submit Form and This permit is val d for 24 months fr� the date of approval per 20 AAC 2 0050 Attachments in Duplicate (z 1(2,( (�>, ;�Z�`y/ ConocoPhilli s p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 5, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill three laterals out of the KRU 30-04 (PTD# 188-062) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in mid December 2019. The objective will be to drill three laterals, KRU 30-041-1, 30-041-1-01 and 30-041-1-02, targeting the Kuparuk A -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to permit to drill applications are the following documents: - Permit to Drill Application Forms (10-401) for 30-041-1, 30-041-1-01 and 30-041-1-02 - Detailed Summary of Operations - Directional Plans for 30-041-1, 30-041-1-01 and 30-041-1-02 - Current Wellbore Schematic - Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4597. Sincerely, a, Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 30-041-1, 30-041-1-01 & 30-041-1-02 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b))................................................................................................................... 2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3))................................................................................................................................................. 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4))................................................................................................................................................. 2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5))................................................................................................................................................. 2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)).................................................................................................................................................. 3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7)).................................................................................................................................................. 3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)).................................................................................................................................................. 3 9. Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9)).................................................................................................................................................. 4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................ 4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................ 4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................6 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25,050(b)). . ..... ... ........... ................................................ .... .............................................................. - 6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 30-041-1, 30-041-1-01 & 30-041-1-02 laterals.........................................................6 Attachment 2: Current Well Schematic for 2M-21...........................................................................................................6 Attachment 3: Proposed Well Schematic for 30-041-1, 30-041-1-01 & 30-041-1-02 laterals...........................................6 Page 1 of 6 December 3, 2019 PTD Application: 30-6"1--1, 30-041-1-01 & 30-041-1-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 30-041-1, 30-041-1-01 & 30-041-1-02. All laterals will be classified as "Development' wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 30-041-1, 30-041-1-01 & 30-041-1-02. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,000 psi. Using the maximum formation pressure in the area of 4244 psi in 30-10 (i.e. 13.1 ppg EMW), the maximum potential surface pressure in 30-04, assuming a gas gradient of 0.1 psi/ft, would be 3588 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. - The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 30-04 was measured at the datum to be 3893 psi (11.82 ppg EMW) on 9/26/2019. The maximum downhole pressure in the 30-04 vicinity is to the south in the 30-10. Pressure was measured to be 4244 psi, at the datum, (13.1 ppg EMW) in June of 2019. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to 30-04 have injected gas, so there is a possibility of encountering free gas while drilling the 30-04 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 2M-21 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 30-04 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 December 3, 2019 PTD Application: 30-0-.L-1, 30-041-1-01 & 30-041-1-02 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner l3tm Liner Top Liner l3tm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 30-041_1 9250' 12,000' 6549' 6503' 2-3/8", 4.7#, L-80, ST -L slotted liner; Surface 115' 1640 670 Surface aluminum billet on to 30-04L1-01 8775' 12,000' 6550' 6523' 2-3/8", 4.7#, L-80, ST -L slotted liner; 4029' 3520 2020 Production 7" aluminum billet on to 30-041_1-02 8670' 10,350' 6496' 6478' 2-3/8", 4.7#, L-80, ST -L slotted liner; 4980 4320 Liner 4-1/2" 12.6 deployment sleeve on top Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded Surface 115' Surface 115' 1640 670 Surface 9-5/8" 36.0 J-55 BTC Surface 5099' Surface 4029' 3520 2020 Production 7" 26.0 J-55 BTC Surface 8961' Surface 6769' 4980 4320 Liner 4-1/2" 12.6 L-80 IBTM 7951' 8850' 6038' 6687' 8430 7500 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Water -Based PowerVis milling fluid (8.6 ppg) — Drilling operations: Water-based PowerVis mud (8.6 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 11.8 ppg NaCl / NaBr completion fluid in order to provide formation over -balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 30-04 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 December 3, 2019 PTD Application: 30-6,,1, 30-041_1-01 & 30-041-1-02 Pressure at the 30-04 Window (8675' MD, 6558' TVD) sing MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations V/ M� KRU well 30-04 is a Kuparuk A -Sand producer equipped with 3-1/2" tubing and 4-1/2" liner. The CTD sidetrack will utilize three laterals to target the A -sands to the north and east of 30-04. The laterals will increase A -sand resource recovery and throughput. Prior to CTD rig up, E -Line will set a mechanical whipstock (TTWS) inside the 442" liner at the planned kick off point of 8675' MD. The 30-041-1 lateral will exit through the 4-1/2" liner and 7" casing at 8675' MD and drill to a planned TD at 12,000' MD, targeting the A sand to the north. The lateral will be completed with 2-3/8" slotted liner from TD up to 9250' MD with an aluminum billet for kicking off. The 30-041-1-01 lateral will kick off at 9250' MD and drill to a planned TD of 12,000' MD targeting the A sand to the north. It will be completed with 2-3/8" slotted liner from TD up to 8775' MD with an aluminum billet for kicking off. The 30-041-1-02 lateral will kick off at 8775' MD and drill to a planned TD of 10,350' MD targeting the A sand to the east. It will be completed with 2-3/8" slotted liner from TD up into the 4-1/2" liner at 8670' MD with a deployment sleeve. Page 4 of 6 December 3, 2019 Pumps On 1.9 bpm) Pumps Off A -sand Formation Pressure 11.8 4023 psi 4023 psi Mud Hydrostatic 8.6 2933 psi 2933 psi Annular friction i.e. ECD, 0.080psi/ft) 694 psi 0 psi Mud + ECD Combined no chokepressure) 3627 psi (underbalanced —396 psi) 2933 psi (underbalanced 1090 psi) Target BHP at Window 11.$ 4024 psi 4024si Choke Pressure Required to Maintain Target BHP 397 psi 1091 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations V/ M� KRU well 30-04 is a Kuparuk A -Sand producer equipped with 3-1/2" tubing and 4-1/2" liner. The CTD sidetrack will utilize three laterals to target the A -sands to the north and east of 30-04. The laterals will increase A -sand resource recovery and throughput. Prior to CTD rig up, E -Line will set a mechanical whipstock (TTWS) inside the 442" liner at the planned kick off point of 8675' MD. The 30-041-1 lateral will exit through the 4-1/2" liner and 7" casing at 8675' MD and drill to a planned TD at 12,000' MD, targeting the A sand to the north. The lateral will be completed with 2-3/8" slotted liner from TD up to 9250' MD with an aluminum billet for kicking off. The 30-041-1-01 lateral will kick off at 9250' MD and drill to a planned TD of 12,000' MD targeting the A sand to the north. It will be completed with 2-3/8" slotted liner from TD up to 8775' MD with an aluminum billet for kicking off. The 30-041-1-02 lateral will kick off at 8775' MD and drill to a planned TD of 10,350' MD targeting the A sand to the east. It will be completed with 2-3/8" slotted liner from TD up into the 4-1/2" liner at 8670' MD with a deployment sleeve. Page 4 of 6 December 3, 2019 PTD Application: 30-0-n-1, 30-041_1-01 & 30-041-1-02 CTD Drill and Complete 30-04 Laterals: Pre -CTD Work 1. RU Slickline: Dummy whipstock drift, C/O GLV's 2. RU E -Line: Caliper, set top of whipstock at 8675' MD 3. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 30-041-1 Lateral (A sand - North) a. Mill 2.80" window at 8675' MD. b. Drill 3" bi-center lateral to TD of 12,000' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 9250' MD. 3. 30-041-1-01 Lateral (A sand - North) a. Kick off of the aluminum billet at 9250' MD. b. Drill 3" bi-center lateral to TD of 12,000' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 8775' MD. 4. 30-041-1-02 Lateral (A sand -East) a. Kick off of the aluminum billet at 8775' MD. b. Drill 3" bi-center lateral to TD of 10,350' MD. c. Run 2-3/8" slotted liner with deployment sleeve from TD up to 8670' MD 5. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post -Rig Work 1. Return to production Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slick -line. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Page 5 of 6 December 3, 2019 PTD Application: 30-6-,.1, 30-041_1-01 & 30-041_1-02 Liner Running - The 30-04 laterals will be displaced to an overbalancing fluid (11.8 ppg NaCl / NaBr) prior to running liner. See "Drilling Fluids" section for more details. - While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 30-041_1 7445' 30-041_1-01 7450' 30-041_1-02 7920' - Distance to Nearest Well within Pool Lateral Name Distance Well 30-041_1 21' 3R-26 30-04L1-01 42' 3R-26 30-04L1-02 1739' 30-02 16.Attachments Attachment 1: Directional Plans for 30-04L1, 30-04L1-01 & 30-04L1-02 laterals Attachment 2: Current Well Schematic for 30-04 Attachment 3: Proposed Well Schematic for 30-04L1, 30-04L1-01 & 30-04L1-02 laterals Page 6 of 6 December 3, 2019 WeilKRU XX -XX Nabors CDR3-AC: 4 -Ram BOP Configuration 2,, Date April 24, 2019 Coiled Tubing and 2-3/8" BHA Quick Test Sub to Ot Top of 7" Otis Distances from top o Excluding quick -test Top of Annular CL Annular Bottom Annular Flan CL Blind/Shears CL 2" Combi's CL 2-3/8" Combi's CL 2" Combi's CL of Top S Top of Swa CL Swab 1 Flow Tee CL SSV CL Master LDS Ground Tree Size 3 1/8 ne ConocoPhilli s p ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 30 Pad 30-04 30-04L1-01 Plan: 30-041-1-01_wp01 Standard Planning Report 04 December, 2019 Baker Hughes i✓' ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit Site: Kuparuk 30 Pad Well: 30-04 Wellbore: 30-041-1-01 Design: 30-041-1-01_wp01 ConocoPhillips Planning Report Baker Hughes Local Co-ordinate Reference: Well 30-04 TVD Reference: Mean Sea Level MD Reference: 30-04: @ 59.00usft (30-04:) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 30 Pad Site Position: Northing: 6,022,094.67 usft Latitude: 700 28' 17.333 N From: Map Easting: 525,478.25 usft Longitude: 1490 47'30.897 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.20 ° Well 30-04 Well Position +N/ -S 0.00 usft Northing: 6,022,030.55 usft Latitude: 70° 28' 16.701 N +E/ -W 0.00 usft Easting: 525,515.58 usft Longitude: 149° 47' 29.806 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 30-041-1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BG G M2018 12/30/2019 16.28 80.92 57,401 Design 30-041-1-01_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,250.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 0.00 0.00 0.00 20.00 1214/2019 3.14.50PM Page 2 COMPASS 5000 14 Build 85H ConocoPhillips ConocoPhillips Planning Report Baker Hughes , Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 30-04 Company: ConocoPhillips Alaska Inc-Kuparuk TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-04: @ 59.00usft (30-04) Site: Kuparuk 30 Pad North Reference: True Well: 30-04 Survey Calculation Method: Minimum Curvature Wellbore: 30-04L1-01 Turn Rate Rate Design: 30-04L1-01_wp01 (°1100usft) (°/100usft) (°/100usft) Plan Sections 0.00 0.00 0.00 0.00 7.00 Measured 4.50 40.00 TVD Below -1.22 6.89 Depth Inclination Azimuth System +N/ -S +El -W (usft) (°) (°) (usft) (usft) (usft) 9,250.00 87.11 338.51 6,549.20 2,446.83 -5,176.51 9,320.00 90.87 341.66 6,550.43 2,512.61 -5,200.34 9,420.00 89.65 348.55 6,549.98 2,609.19 -5,226.02 9,620.00 89.66 2.55 6,551.19 2,808.09 -5,241.49 9,775.00 90.04 13.40 6,551.60 2,961.36 -5,220.01 9,900.00 95.05 6.21 6,546.04 3,084.29 -5,198.75 10,000.00 90.09 1.27 6,541.56 3,183.92 -5,192.25 10,350.00 90.08 25.77 6,541.06 3,521.63 -5,111.06 10,475.00 81.63 23.49 6,550.09 3,634.85 -5,059.14 10,600.00 89.22 19.12 6,560.06 3,750.83 -5,013.93 10,725.00 90.75 10.51 6,560.09 3,871.56 -4,982.00 10,925.00 91.93 24.46 6,555.40 4,061.79 -4,922.08 11,025.00 97.99 27.99 6,546.76 4,151.11 -4,878.10 11,175.00 90.52 35.39 6,535.63 4,278.19 -4,799.58 11,425.00 91.09 52.89 6,532.10 4,456.89 -4,626.18 11,525.00 95.58 58.27 6,526.27 4,513.30 -4,543.89 11,595.00 90.97 59.94 6,522.27 4,549.17 -4,483.93 12,000.00 88.96 88.22 6,522.51 4,659.11 -4,098.42 Dogleg Build Turn Rate Rate Rate TFO (°1100usft) (°/100usft) (°/100usft) (°) 0.00 0.00 0.00 0.00 7.00 5.37 4.50 40.00 7.00 -1.22 6.89 100.00 7.00 0.01 7.00 90.00 7.00 0.25 7.00 88.00 7.00 4.00 -5.75 -55.00 7.00 -4.96 -4.94 -135.00 7.00 0.00 7.00 90.00 7.00 -6.76 -1.82 -165.00 7.00 6.08 -3.49 -30.00 7.00 1.22 -6.89 -80.00 7.00 0.59 6.98 85.00 7.00 6.05 3.53 30.00 7.00 -4.98 4.94 135.00 7.00 0.23 7.00 88.00 7.00 4.49 5.38 50.00 7.00 -6.58 2.39 160.00 7.00 -0.50 6.98 94.00 Target 12/4/2019 3:14:50PM Page 3 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Planning Report Baker Hugheso Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 30-04 Company: ConocoPhillips Alaska Inc-Kuparuk TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-04: @ 59.00usft (30-04) Site: Kuparuk 30 Pad North Reference: True Well: 30-04 Survey Calculation Method: Minimum Curvature Wellbore: 30-04L1-01 Design: 30-04L1-01_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (1) (1) (usft) (usft) (usft) (usft) (*1100usft) (°) (usft) (usft) 9,250.00 87.11 338.51 6,549.20 2,446.83 -5,176.51 528.79 0.00 0.00 6,024,459.38 520,331.23 TIP/KOP 9,300.00 89.79 340.76 6,550.55 2,493.68 -5,193.90 566.87 7.00 40.00 6,024,506.16 520,313.68 9,320.00 90.87 341.66 6,550.43 2,512.61 -5,200.34 582.46 7.00 39.94 6,024,525.07 520,307.17 Start DLS 7.00 TFO 100.00 9,400.00 89.89 347.18 6,549.90 2,589.64 -5,221.82 647.50 7.00 100.00 6,024,602.02 520,285.43 9,420.00 89.65 348.55 6,549.98 2,609.19 -5,226.02 664.43 7.00 100.04 6,024,621.56 520,281.16 Start DLS 7.00 TFO 90.00 9,500.00 89.65 354.15 6,550.47 2,688.25 -5,238.05 734.61 7.00 90.00 6,024,700.56 520,268.87 9,600.00 89.66 1.15 6,551.08 2,788.10 -5,242.13 827.04 7.00 89.97 6,024,800.39 520,264.44 9,620.00 89.66 2.55 6,551.19 2,808.09 -5,241.49 846.05 7.00 89.92 6,024,820.38 520,265.02 Start DLS 7.00 TFO 88.00 9,700.00 89.86 8.15 6,551.53 2,887.71 -5,234.03 923.42 7.00 88.00 6,024,900.02 520,272.21 9,775.00 90.04 13.40 6,551.60 2,961.36 -5,220.01 997.42 7.00 87.98 6,024,973.71 520,285.97 Start DLS 7.00 TFO -55.00 9,800.00 91.05 11.96 6,551.36 2,985.75 -5,214.52 1,022.22 7.00 -55.00 6,024,998.11 520,291.37 9,900.00 95.05 6.21 6,546.04 3,084.29 -5,198.75 1,120.21 7.00 -55.01 6,025,096.70 520,306.80 Start DLS 7.00 TFO -135.00 10,000.00 90.09 1.27 6,541.56 3,183.92 -5,192.25 1,216.05 7.00 -135.00 6,025,196.34 520,312.97 Start DLS 7.00 TFO 90.00 10,100.00 90.08 8.27 6,541.42 3,283.51 -5,183.94 1,312.48 7.00 90.00 6,025,295.95 520,320.93 10,200.00 90.08 15.27 6,541.27 3,381.35 -5,163.56 1,411.39 7.00 90.01 6,025,393.84 520,340.98 10,300.00 90.08 22.27 6,541.13 3,475.97 -5,131.40 1,511.30 7.00 90.02 6,025,488.57 520,372.80 10,350.00 90.08 25.77 6,541.06 3,521.63 -5,111.06 1,561.17 7.00 90.03 6,025,534.30 520,392.99 Start DLS 7.00 TFO -165.00 10,400.00 86.70 24.86 6,542.47 3,566.81 -5,089.69 1,610.93 7.00 -165.00 6,025,579.54 520,414.20 10,475.00 81.63 23.49 6,550.09 3,634.85 -5,059.14 1,685.31 7.00 -164.97 6,025,647.68 520,444.51 Start DLS 7.00 TFO -30.00 10,500.00 83.14 22.61 6,553.40 3,657.65 -5,049.44 1,710.06 7.00 -30.00 6,025,670.51 520,454.13 10,600.00 89.22 19.12 6,560.06 3,750.83 -5,013.93 1,809.76 7.00 -29.88 6,025,763.80 520,489.32 Start DLS 7.00 TFO -80.00 10,700.00 90.44 12.23 6,560.35 3,847.05 -4,986.93 1,909.42 7.00 -80.00 6,025,860.10 520,515.99 10,725.00 90.75 10.51 6,560.09 3,871.56 -4,982.00 1,934.13 7.00 -79.98 6,025,884.63 520,520.83 Start DLS 7.00 TFO 85.00 10,800.00 91.20 15.74 6,558.82 3,944.56 -4,964.98 2,008.55 7.00 85.00 6,025,957.68 520,537.60 10,900.00 91.79 22.72 6,556.21 4,038.89 -4,932.08 2,108.45 7.00 85.09 6,026,052.11 520,570.17 10,925.00 91.93 24.46 6,555.40 4,061.79 -4,922.08 2,133.39 7.00 85.27 6,026,075.04 520,580.09 Start DLS 7.00 TFO 30.00 11,000.00 96.47 27.10 6,549.91 4,129.12 -4,889.57 2,207.78 7.00 30.00 6,026,142.48 520,612.38 11,025.00 97.99 27.99 6,546.76 4,151.11 -4,878.10 2,232.36 7.00 30.19 6,026,164.51 520,623.77 Start DLS 7.00 TFO 135.00 11,100.00 94.26 31.71 6,538.76 4,215.77 -4,840.99 2,305.81 7.00 135.00 6,026,229.28 520,660.65 11,175.00 90.52 35.39 6,535.63 4,278.19 -4,799.58 2,378.63 7.00 135.40 6,026,291.84 520,701.84 Start DLS 7.00 TFO 88.00 11,200.00 90.58 37.14 6,535.40 4,298.35 -4,784.80 2,402.63 7.00 88.00 6,026,312.04 520,716.56 11,300.00 90.81 44.14 6,534.18 4,374.17 -4,719.71 2,496.14 7.00 88.02 6,026,388.09 520,781.37 11,400.00 91.04 51.14 6,532.56 4,441.51 -4,645.88 2,584.67 7.00 88.10 6,026,455.66 520,854.97 11,425.00 91.09 52.89 6,532.10 4,456.89 -4,626.18 2,605.86 7.00 88.21 6,026,471.12 520,874.61 Start DLS 7.00 TFO 50.00 11,500.00 94.46 56.92 6,528.46 4,499.95 -4,564.91 2,667.28 7.00 50.00 6,026,514.38 520,935.73 11,525.00 95.58 58.27 6,526.27 4,513.30 -4,543.89 2,687.01 7.00 50.20 6,026,527.80 520,956.70 Start DLS 7.00 TFO 160.00 1214/2019 3:14:50PM Page 4 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Planning Report Baker Hughes Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit Site: Kuparuk 30 Pad Well: 30-04 Wellbore: 30-04L1-01 Design: 30-04 L 1-01 _wp 01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 30-04 Mean Sea Level 30-04: @ 59.00usft (30-04:) True Minimum Curvature Planned Survey Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 12,000.00 Measured +E/ -W TVD Below (usft) (usft) Vertical Dogleg Toolface Map Map Depth Inclination Azimuth 9,320.00 System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (o) (_) (usft) (usft) (usft) (usft) (°1100usft) (1) (usft) (usft) 11,595.00 90.97 59.94 6,522.27 4,549.17 -4,483.93 2,741.23 7.00 160.00 6,026,563.87 521,016.53 Start DLS 7.00 TFO 94.00 -5,111.06 Start DLS 7.00 TFO -165.00 10,475.00 6,550.09 3,634.85 -5,059.14 Start DLS 7.00 TFO -30.00 10,600.00 6,560.06 11,600.00 90.95 60.29 6,522.19 4,551.66 -4,479.60 2,745.05 7.00 94.00 6,026,566.38 521,020.85 11,700.00 90.46 67.27 6,520.96 4,595.81 -4,389.95 2,817.19 7.00 94.01 6,026,610.83 521,110.34 11,800.00 89.95 74.26 6,520.60 4,628.73 -4,295.59 2,880.40 7.00 94.09 6,026,644.07 521,204.58 11,900.00 89.45 81.24 6,521.12 4,649.94 -4,197.93 2,933.73 7.00 94.12 6,026,665.61 521,302.15 12,000.00 88.96 88.22 6,522.51 4,659.11 -4,098.42 2,976.39 7.00 94.08 6,026,675.13 521,401.62 Planned TD at 12000.00 Plan Annotations Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 12,000.00 6,522.51 2-3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 9,250.00 6,549.20 2,446.83 -5,176.51 TIP/KOP 9,320.00 6,550.43 2,512.61 -5,200.34 Start DLS 7.00 TFO 100.00 9,420.00 6,549.98 2,609.19 -5,226.02 Start DLS 7.00 TFC, 90.00 9,620.00 6,551.19 2,808.09 -5,241.49 Start DLS 7.00 TFO 88.00 9,775.00 6,551.60 2,961.36 -5,220.01 Start DLS 7.00 TFO -55.00 9,900.00 6,546.04 3,084.29 -5,198.75 Start DLS 7.00 TFO -135.00 10,000.00 6,541.56 3,183.92 -5,192.25 Start DLS 7.00 TFO 90.00 10,350.00 6,541.06 3,521.63 -5,111.06 Start DLS 7.00 TFO -165.00 10,475.00 6,550.09 3,634.85 -5,059.14 Start DLS 7.00 TFO -30.00 10,600.00 6,560.06 3,750.83 -5,013.93 Start DLS 7.00 TFO -80.00 10,725.00 6,560.09 3,871.56 -4,982.00 Start DLS 7.00 TFO 85.00 10,925.00 6,555.40 4,061.79 -4,922.08 Start DLS 7.00 TFO 30.00 11,025.00 6,546.76 4,151.11 -4,878.10 Start DLS 7.00 TFO 135.00 11,175.00 6,535.63 4,278.19 -4,799.58 Start DLS 7.00 TFO 88.00 11,425.00 6,532.10 4,456.89 -4,626.18 Start DLS 7.00 TFO 50.00 11,525.00 6,526.27 4,513.30 -4,543.89 Start DLS 7.00 TFO 160.00 11,595.00 6,522.27 4,549.17 -4,483.93 Start DLS 7.00 TFO 94.00 12,000.00 6,522.51 4,659.11 -4,098.42 Planned TD at 12000.00 12/4/2019 3:14:50PM Page 5 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Anticollision Report Baker Hughes Company: ConocoPhil lips Alaska Inc-Kuparuk Project: Kuparuk River Unit -2 Reference Site: Kuparuk 30 Pad Site Error: 0.00 usft Reference Well: 30-04 Well Error: 0.00 usft Reference Wellbore 30-041-1-01 Reference Design: 30-041-1-01_wp01 Reference 30-041-1-01 wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: Depth Range: 9,250.00 to 12,000.00usft Scan Method: Results Limited by: Maximum ellipse separation of 3,000.00 usft Error Surface: Warning Levels Evaluated at: 2.79 Sigma Casing Method: Survey Tool Program Date 12/4/2019 From To (usft) (usft) Survey (Wellbore) 100.00 8,600.00 30-04 (30-04) 8,600.00 9,250.00 30-04L1_wp02 (30-041-1) 9,250.00 12,000.00 30-041-1-01_wp01(30-041-1-01) Well 30-04 30-04: @ 59.O0usft (30-04:) 30-04: @ 59.00usft (30-04) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum ISCWSA Tray. Cylinder North Combined Pedal Curve Added to Error Values Tool Name Description BOSS -GYRO Sperry -Sun BOSS gyro multishot MWD OWSG OWSG MWD - Standard MWD OWSG OWSG MWD - Standard Summary Reference Offset Distance Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 30 Pad 30-01 - 30-01A - 30-01A Out of range 30-01 - 30-01AL2 - 30-01AL2 Out of range 30-02 - 30-02 - 30-02 10,415.73 9,275.00 763.85 665.11 7.736 CC 30-02 - 30-02 - 30-02 10,415.93 9,300.00 764.62 665.04 7.678 ES 30-02 - 30-02 - 30-02 10,416.68 9,400.00 775.47 673.16 7.579 SF 30-02 - 30-02A - 30-02A 10,415.73 9,275.00 763.85 665.00 7.728 CC 30-02 - 30-02A - 30-02A 10,415.93 9,300.00 764.62 664.93 7.670 ES 30-02 - 30-02A - 30-02A 10,416.68 9,400.00 775.47 673.05 7.571 SF 30-02 - 30-02ALl - 30-02AL1 10,415.73 9,275.00 763.85 665.00 7.728 CC 30-02 - 30-02AL1 - 30-02ALl 10,415.93 9,300.00 764.62 664.93 7.670 ES 30-02 - 30-02AL1 - 30-02ALl 10,416.68 9,400.00 775.47 673.05 7.571 SF 30-02 - 30-02ALl PB1 - 30-02ALl PB1 10,415.73 9,275.00 763.85 665.00 7.728 CC 30-02 - 30-02ALl P61 - 30-02ALl PB1 10,415.93 9,300.00 764.62 664.93 7.670 ES 30-02 - 30-02ALl PB1 - 30-02ALl PB1 10,416.68 9,400.00 775.47 673.05 7.571 SF 30-02 - 30-02AL2 - 30-02AL2 10,415.73 9,275.00 763.85 665.00 7.728 CC 30-02 - 30-02AL2 - 30-02AL2 10,415.93 9,300.00 764.62 664.93 7.670 ES 30-02 - 30-02AL2 - 30-02AL2 10,416.68 9,400.00 775.47 673.05 7.571 SF 30-02 - 30-02AL2-01 - 30-02AL2-01 10,415.73 9,275.00 763.85 665.00 7.728 CC 30-02 - 30-02AL2-01 - 30-02AL2-01 10,415.93 9,300.00 764.62 664.93 7.670 ES 30-02 - 30-02AL2-01 - 30-02AL2-01 10,416.68 9,400.00 775.47 673.05 7.571 SF 30-04 - 30-041-1 - 30-04L1_wp02 10,882.09 10,900.00 40.41 10.00 1.329 Take Immediate Action, SF 30-04 - 30-041-1 - 30-04L1_wp02 10,905.25 10,925.00 35.87 9.41 1.355 Take Immediate Action, ES 30-04 - 30-041-1 - 30-04L1_wp02 10,974.61 11,000.00 29.32 21.57 3.784 CC 30-06 - 30-061-1-03 - 30-061-1-03 Out of range 30-06 - 30-061-1-04 - 30-061-1-04 10,456.23 9,490.00 1,316.39 1,224.55 14.333 CC, ES, SF Kuparuk 3R Pad 3R-26 - 3R-26 - 3R-26 11,273.39 8,575.00 46.61 -149.07 0.238 STOP Drilling, ES, SF 3R-26 - 3R-26 - 3R-26 11,286.88 8,550.00 42.37 -117.10 0.266 STOP Drilling, CC CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/4/2019 9:16:07AM Page 2 COMPASS 5000.14 Build 85H v L 7 2 i d Y O 00 a N 3 o2 0 0 o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 L.L L.L LL L.L L.L W l.L l.L w w w w w L.L N V- N HHF---F--F-F--F--� HH H H H� 0 0 0 0 0 00 0 0 0 0 0 0 0 0 O: O O (n Cn (n Cn Cn Cn Cn Cn fn (n Cn Cn (n (n (n Cn ~ CSO J N 0Y'C r'Crrr rr r'C r-tf'CCI c i+ cn mm m m m m m m m g B m B B Big c ¢ in cn co in in in in in in in cn co in CO cn cn a O I-- co I3�OOMCO0a01�.0 LC'J Ott LO i�I( COO COO CD COCMD (MD CMO CO CMO CDCNO -gyp Z 2> 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 :3 D 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 6 0 6 6 a D L t 7 L O O L O 0 6 O� N O O V 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M 0 N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 R LO LO CO RM Oa0 OD 6)MN � LOMO c:! V OI�N O'r0c> 00 LO nOOty: COOCD c> CV r(T MCV CV mm m m w O N V N O O L2'J c=> qD N t• O N V' aD O NNNN.- OO1TOaD 1�CO COa 0 c" co O n n n n +��� n �ggqqqqqq c Ln jj OMNOCO O cR LO r-- cqC? J L WONOi Otb c0 c'M 6i pj L[') NMLO �O LO NLO V LO F LC j N N N N N M M M LU cl OMoO CTO RCO OO)CDmOCDMO t• I`-� J O r'CD O LO 0000 rl-<DN N LO J O f O O C D O O CD L[ J co L O N C D N n j w >sr LL') V LO LO <{ C' V' Ll'1 CD CD L(J V' M M " NCV L Lo LO LL) LO L[') LO Li') L!'i LO LO LO LO L[) LO LO Ln LO LO L{") c Lo O CD O O CO t0 CO (D t0 CD (D CD O CO O CD tD Cp L O " o 0 M S CO LO LO O .- 1� t• S CD O O) o Q O C L O D L O L O V 'It m O N N 1� et r L C') � C T M p N 61 N Z cVO oo �Cp r-: LO M Cn r V Ll)N Lb O�tp NNe- N NMLO LO tO to O M mm CD r 1� LOCO -tO oP to m m m w IACD CO CD CO O O O O CO CV h- M O� LO O LO CT M mmco Zi O jy O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o L O . N c . V . N N M V O r W O M C' C D t 0 0 a-- V L O L O2 O 01 On O mO) O) COCD�N M V u O+ DOOc NM V O D �aO ` Z O j KUP PROD WELLNAME 30-04 -LBORE 30-04 C0110C0P11llIp5 Alaska, Inc. wall ArMDUtes max Angie a mu I lu Field Name Wellbore APIIUWI Wellbore Status I cl (°) MD (ftKB) Act Btm (ftKB/ K PAR KRIVER NIT 2921 2 PR D 1.60 2,600.00 8,984.0 Comment 11 (ppm) Date Annotation Entl Dale KB Gfd (ft) Rig Release Date SSSV:NIPPLE 140 9/25/2013 Last WO: 7/21/2013 40.00 7/9/1988 30-04, 9/26/2019 6:31:57 PM Last Tag Vertical schematic (actual) Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 8,696.0 9/26/2019 30-04 zembaej HANGER; 31.1 Last RBV Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth 9/26/2019 30-04 zembaej Casing Strings Casing Description OD (In) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (ND)... WtlLen (I... Grade Top Thread t s t CONDUCTOR 16 15.06 35.) 115.0 115.0 62.50 H-40 Welded CONDUCTOR', 35.0-115.0 Casing Description OD (In) 10 (In) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I Grade Top Thread SURFACE 95/8 8.92 35.0 5,099.2 4,029.0 36.00 J-55 BTC Casing Description OD (In) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (ND)... Wt/Len (I Grade Top Thread NIPPLE; soar PRODUCTION 7 6.28 33.0 8,961.3 6,768.7 26.00 J-55 BTC Casing Description 00 (in) ID (in) Top(ftKB) Set Depth(ftKB) Set Depth (TVD) Wt/Len(1... Grade Top Thread LINER 4112 3.96 7,951.4 8,850.0 6,686.8 12.60 L-80 IBTM Liner Details GAS LIFT; 3,098.4 Nominal ID Top (ftKB) Top (ND) (ftKB) Top Incl (°) Item Des Co. (in) 7,951.4 6,037.9 45.08 PACKER 2RH ZXP w/HD LINER TOP PACKER 4.310 7,970.0 6,051.0 45.08 HANGER DG FLEX -LOCK LINER HANGER 4.400 GAS LIFT, 4,760.7 7,979.8 6,058.0 45.08 SBE BAKER SEAL BORE EXTENSION 4.000 Tubing Strings Tubing Description String Ma... ID (In) TOp (hKB) Set Depth (ft.. Set Depm (ND) (... Wt (Ib/ft) Grade Top Connection TUBING WO 31/2 2.99 31.1 7,987.9 6,063.7 9.30 L-80 EIE 8rd AB Mod Completion Details Top (TVD) Top Incl Nominal SURFACE, 35.05,099 .2 Top (ftKB) (ftKB) (°) Item Des Com ID (in) 31.1 31.1 0.08 HANGER CIW GEN IV TUBING HANGER w/ Type'H' Profile 2.992 GAS LIFT; 6,1171 508.1 508.1 0.38 NIPPLE CAMCO DS NIPPLE 3.5" x 2.875" 2.875 7,901.7 6,002.8 45.10 NIPPLE CAMCO 3.5" x 2.812" DS NIPPLE SN: T070815 2.812 7,950.4 6,037.2 45.08 LOCATOR BAKER GBH LOCATOR sub w/ 7-h Space out 2.992 7,959.1 6,043.3 45.08 SEAL ASSY Baker 80-40 Seals 2.990 GAS LIFT; 7,166.4 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ND) Top Incl Top (ftKB) (ftKB) (°) Des Com Run Date ID (in) 8,694.0 6,572.4 42.89 Fish SLIP STOP CATCHER SUB FISH. 1/2 OF A SLIP, 2 10/24/201 0.000 GAS uFT, 7,843z FULL SLIPS, SLIP RETAINER RING & 2.70" X 30" 8 CATCHER. Perforations & Slots Shot NIPPLE, 7,901.6 Dens Top (TVD) at. (TVD) (shotslft Top(ftKB) Btm(ftKB) (RKB) (ftKB) Linked Zone Date I Tyle Co. 8,622.0 8,640.0 6,519.7 6,532.9 C-4, C-1, UNIT 5/7/1989 12.0 CMT SOZ 2 1/8" EnerJet, 60 deg. B, 30-04 phasing -- Squeezed behind 4-1/2" liner during 2013 RWO LOCATOR; 7,950.4 8,653.0 8,669.0 6,542.4 6,554.1 A-3,30-04 5/7/1989 12.0 CMT SOZ 2 1/8" EnerJet, 60 deg. phasing - Squeezed behind SEAL ASSY: 7,959.1 4-1/2" liner during 2013 RWO 8,675.0 8,695.0 6,558.5 6,573.1 A-1, 30-04 1/5/2015 6.0 APERF 2.5" 6SPF, 60 DEGREE PHASING, DEEP penetrating chgs 8,675.0 8,695.0 6,558.5 6,573.1 A-1, 30-04 8/8/2016 6.0 APERF 2.5'" POWERJET OMEGA Liner Cement; 7,950.0 axe CHARGES 6 SPF, 60 DEG PHASING 8,675.0 8,698.0 6,558.5 6,575.3 A-2,30-04 5/7/1989 12.0 CMT SOZ 21/8" EnerJet, 60 deg. phasing -- Squeezed behind 4-1/2" liner during 2013 CMT SOZ, 8,6220-8,640.0- RWO 8,675.0 8,695.0 6,558.5 6,573.1 A-2,30-04 7/18/2013 6.0 APERF 3-3/8" OD 6 SPF MILLENNIUM 60 DEG PHASING 25gr HMX 8,710.0 8,730.0 6,584.1 6,598.8 A-1, 30-04 9/25/1988 8.0 CMT SOZ 4 1/2" HSD Csg Gun, 45 deg. phasing - Squeezed CMT SOZ; 8,653.0-8,669.0 behind 4-1/2" liner during 2013 RWO APERF; 8,675.0-8,6950 APERF; 8,6750-8,50 Cement Squeezes (TVD) Btm (ND) APERF; 8,675.0-Q695.0Top CMT SOZ; 8,675.0-8,698.0 Top(ftKB) Bt. (ftKB) (MB) (RKB) Des Start Date Com 7,950.0 8,850.0 6,036.9 6,686.8 LINER CMT 7/15/2013 Mandrel Inserts Fish; 8,694.0 St ad on Top (ND) Valve Latch Port Size TRO Run N Top (RKB) (ftKB) Make Model OD (In) Sery Type Type (In) (psi) Run Date Com 3,098.4 2,599.8 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/30/2018 CMT saZ; 8.710.o-8,730.0- 2 4,760.7 3,787.1 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/30/2018 3 6,117.1 4,747.2 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/1/2018 4 7,166.4 5,485.2 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/14/2019 5 7,843.2 5,961.6 WTF KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/18/2014 Notes: General & Safety End Date Annotation 7/10/1994 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 9/8/2003 NOTE: 31" Surf CSG Patch covering hole located 32" below OA valve. PT @ 1,500 psi - good 2013 RWO 5/18/2009 NOTE: View Schematic w/ Alaska Schematic9.0 10/2/2015 NOTE: Placed total of 8.1 -bbl SANDLOCK-V and 1509# sand behind pipe 10/2/2015 NOTE: Pumped SANDLOCK-V resin frac with 8 -PPA Jordan Unimin sand, 8.9 -BPM, 5000 -psi. LINER; 7,951 4-8,1150.0 1/27/2016 NOTE: MILLED RESIN TO 8,730 CTMD = COMPLETE 10/31/2018 Note: Unable to locate mandrels @ 7166 & 7832' RKB PRODUCTION; 33 0,13,961.3 u § \ � 2 v � 0 k 6 n lip-4 s / � f M �,CL o a § §5 / { LO 70 2 E a)§§g %k k[ \ / TM 20 \ / L f© L§ .a ) 2k ca CL- �... \ C42 D & §0) \ ƒ CF)E G _k a S / § / ) I /§ o U) . a Q o §CO { §j� s k m A m / 0 0 0 (■q § \ § B h bU- § \ 3 37 5 mom i lip-4 s � o k§ S \ f M �,CL o a § §5 2 LO 70 2 �� a)§§g %k k[ -% / TM 20 §® L E§m� .a �a 2k �... §I 1.00�G 1.5 V m z CD U N U N Ln O a O a` O O M U O 0) C a w m w O a0 M of cV M O cD r r O co r- 7 OD O t`') V c m E N m O E co U cV ch co M r- ❑ LO 0) aP- 0 t V � N cm neo °gym C Y J1 UlJ a_w N N U N LL U) LY)❑m U LO Q C N C N U N U) O co N N V 0 00 O N to r— (0 cor O c o oU� O � V O O -a00 V ❑ ❑ ❑ N o 1 a ��� L y N NN N 0 .�O1 [OO (O W Cl) N �❑ U? 0000 omrooro '❑ co Cl)o) Q Oc7 no Nm O Oif)r N O O CO LO d Q co co co n w r N Loepp, Victoria T (CED) From: Germann, Shane <Shane.Germann@conocophillips.com> Sent: Monday, December 9, 2019 9:13 AM To: Loepp, Victoria T (CED) Cc: Ohlinger, James J Subject: KRU 30-04 PTD & Sundry Applications Attachments: 30-04 Proposed Schematic V1.1.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, I'm following up after our conversation on Friday concerning the naming of the proposed 30-04 CTD laterals (1-1, 1-1-01, & 1-1-02). After some research, the 4-1/2" scab liner that was cemented in place on 7/15/2013 was perforated through to the A2 sand for production. It was perforated on 3 occasions (7/18/2013, 1/5/2015, & 8/8/2016) from 8675'— 8695' MD. The original CTD schematic sent with the PTD applications made it unclear if the cemented scab liner had been perforated, so I've updated and attached the schematic to show these perforations. I believe this would make the L1, L1-01, and L1-02 naming convention correct. Please let me know if you have any questions or would like to discuss further. Shane Germann Coiled Tubing Drilling Engineer co Phi II ps .Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 Boyer, David L (CED) From: Germann, Shane <Shane.Germann@conocophillips.com> Sent: Thursday, December 12, 2019 9:14 AM To: Boyer, David L (CED) Cc: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]X, Y Surface Location for Three KRU 30-04 Laterals from 3)-04 Motherbore Dave, Thanks for catching this and letting me know. It does appear the x,y surface location on the BakerHughes documents are accurate. I must have made a mistake while converting the coordinates. Doing the coordinate conversions again, the surface location from box 4a (legal description) matches the x,y surface location from BakerHughes and what you have listed below. I'm sorry for the confusion this caused. Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 From: Boyer, David L (CED) <david.boyer2@alaska.gov> Sent: Thursday, December 12, 2019 8:55 AM To: Germann, Shane <Shane.Germann@conocophillips.com> Cc: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]X, Y Surface Location for Three KRU 30-04 Laterals from 3)-04 Motherbore Hi Shane, In reviewing the PTD applications for the three 30-04 laterals, I encountered a large difference in the x, y surface location reported on the PTD vs. the x, y calculated by Baker Hughes for the same wellhead. KRU 30-04 motherbore (1988) was already in the AOGCC database including the Albers -150 Northing and Easting coordinates. The legal government section description was consistent since 1988, but only the Baker x, y surface calculation matched previous records in the RBDMS and GeoGraphix databases. We are using the Baker surface x, y for all three laterals. For example, on the x axis alone, the discrepancy was 4500'. made the corrections on the PTD but wanted to advise you of this anomaly. Perhaps it was a cut and paste error from another well? We are using: x=525515.58 & Y=6022030.55 from the survey file. Best, Dave Boyer AOGCC Tfdll., olnts Source coordinate system State Plane 1927 • :Alaska Zone 4 Datum: NAD 1927 - North America Datum of 1927 (glean) 5993905.62 r— 476227..35 1 "022030.55 525515.58 2 Target coordinate system Albers Equal Area ", 150) Datum: NAD 1927 - North America Datum of 1927 Mean) Easting Northing 1 7931.4 2278521.7 2 - oLf- �eU heed . V Type values into the spreadsheet or copy and paste columns of data from a spreadsheet using the keyboard shortcuts Ctr1+C to copy and Ctrl+fir to paste. Then click on the appropriate arrow button to transform the points to the desired coordinate system. < Back Finish Cancel Help TRANSMITTAL LETTER CHECKLIST WELL NAME: R (.L O -- O Lf - PTD: PTD: — -----� I cf.. —1 85 V Development _ Service _ Exploratory _ Stratigraphic Test — Non -conventional FIELD: _ cq DGl {� u KR 7ye` POOL: V l u Gi 1^ u I Ve Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MITI LATERAL The permit is for a new wellbore segment of existing well Permit No. (W — d 6 2-, API No. (If last two digits , 50- OZCI 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 Pilot Hole acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - from records, data and logs acquired for well name on rmit . The permit is approved subject to full compliance with 20 AAC 25.055. Spacing Exception Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where s are first cau t and 10' sam le intervals throu tar et zones. note the following special condition of this permit: Non -Conventional tion or production testing of coal bed methane is not allowed for of welll) until after (COm LA Name) has L Well designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Comnan Name) must contact the AOGCC to obtain advance a roval of such water well testin 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)(3) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100- Well Name: KUPARUK RIV UNIT 30-041-1-01 _ Program DEV - Well bore seg ❑�/ PTD#: 2191850 Company ConocoPhillips Alaska Inc. Initial Class/Type DEV/PEND GeoArea 890 _ _ Unit _11160 On/Off Shore On _ Annular Disposal ❑ Administration 11 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 indrillingunit Yes 8 If deviated, is wellbore plat included Yes Directional plan view _& wellbore profile included. I9 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 administrativ_e_approval Yes 13 Can permit be approved before 15-day_wa_it_ Yes DLB 12/11/2019 14 Well _located within area and strata authorized by Injection Order # (put 10# in comments) (For- NA 15All 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 AS31.05.0300.1.A),0.2.A-D) NA 18 Conductor string provided NA Conductor set for KR_U 30-04 Engineering 19 Surface casing protects all known_ USDWS NA_ Surface casing set for KRU 30-04_ 20 CMT_vol_adequate to circulate on conductor _& surf _csg NA Surface casing set and fully cemented 21 CMT_ vol_ adequate to tie-in long string to surf csg_ NA 22 CMT will coverall known productive horizons No Productive_ interval will be completed with uncemented production liner 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all waste to approved disposal wells 25 If a re -drill, has a 10-403 for abandonment been approved NA- 26 Adequate wellbore separation proposed - Yes - Anti -collision analysis complete; no major risk failures 27 If-diverter required, does it _meet regulations_ NA_ Appr Date 28 Drilling fluid program schematic &_ equip list adequate_ Yes Max formation pressure is 4244 psig(13_.1_ ppg EMW); will drill w/ 8.6 ppg EMW and maintain overbal w/ MPD VTL 12/13/2019 29 BOPEs, do they meet_ regulation Yes 30 BOPE press rating appropriate; test to (put prig in comments) Yes MPSP is 3588 psig; will test BOPs_to 4000 psig 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of 1-12S gas_ probable Yes H2S measures required - 34 Mechanical_ condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No 30 -Pad wells are H2S-bearing. 1-12S_ measures are required. Geology 36 Data presented on potential overpressure zones Yes Managed pressure drilling with CTD unit. Appr Date 37 Seismic analysis of shallow gas zones NA DLB 12/11/2019 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date: Commissioner: Date Com i r Date j �'� , -
