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220-021
By Samantha Carlisle at 6:55 am, Sep 22, 2022 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20539-60-00Well Name/No. COLVILLE RIV NAN-N CD4-215L1Completion Status1-OILCompletion Date3/23/2020Permit to Drill2200210Operator ConocoPhillips Alaska, Inc.MD10853TVD6244Current Status1-OIL5/18/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR/ResNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC4/7/2020 Electronic File: CD4-215L1 EOW - NAD27.pdf32524EDDigital DataC4/7/2020 Electronic File: CD4-215L1 EOW - NAD27.txt32524EDDigital DataC4/7/2020 Electronic File: CD4-215L1 EOW - NAD83.pdf32524EDDigital DataC4/7/2020 Electronic File: CD4-215L1 EOW - NAD83.txt32524EDDigital Data0 0 2200210 COLVILLE RIV NAN-N CD4-215L1 LOG HEADERS32524LogLog Header ScansC5/8/20209600 10853 Electronic Data Set, Filename: CD4-215L1 GAMMA RES.las33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1 2MD Final Log.cgm33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1 5MD Final Log.cgm33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1 5TVDSS Final Log.cgm33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1 2MD Final Log.pdf33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1 5MD Final Log.pdf33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1 5TVDSS Final Log.pdf33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1 EOW - NAD27.pdf33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1 EOW - NAD27.txt33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1 EOW - NAD83.pdf33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1 EOW - NAD83.txt33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1 Final Surveys 10853 TD.csv33002EDDigital DataMonday, May 18, 2020AOGCCPage 1 of 3CD4-215L1 GAMMA RES.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20539-60-00Well Name/No. COLVILLE RIV NAN-N CD4-215L1Completion Status1-OILCompletion Date3/23/2020Permit to Drill2200210Operator ConocoPhillips Alaska, Inc.MD10853TVD6244Current Status1-OIL5/18/2020UICNoWell 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:3/23/2020Release Date:3/6/2020C5/8/2020 Electronic File: CD4-215L1 Final Surveys 10853 TD.xlsx33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1 Survey Listing.txt33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1 Surveys.txt33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1_25_tapescan_BHI_CTK.txt33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1_5_tapescan_BHI_CTK.txt33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1_output.tap33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1 2MD Final Log.tif33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1 5MD Final Log.tif33002EDDigital DataC5/8/2020 Electronic File: CD4-215L1 5TVDSS Final Log.tif33002EDDigital Data0 0 2200210 COLVILLE RIV NAN-N CD4-215L1 LOG HEADERS33002LogLog Header ScansMonday, May 18, 2020AOGCCPage 2 of 3 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20539-60-00Well Name/No. COLVILLE RIV NAN-N CD4-215L1Completion Status1-OILCompletion Date3/23/2020Permit to Drill2200210Operator ConocoPhillips Alaska, Inc.MD10853TVD6244Current Status1-OIL5/18/2020UICNoComments:Compliance Reviewed By:Date:Monday, May 18, 2020AOGCCPage 3 of 3M. Guhl5/18/2020 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 05/08/2020 PTD: 2200210 E-Set: 33002 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 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ______________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:9. Ref Elevations: KB:56.55 17. Field / Pool(s): GL: 13' 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 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: 23. BOTTOM 16 H-40 114 9 5/8 L-80 2392 7 L-80 6214 3 1/2 L-80 6212 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 3/23/2020 220-021 P.O. Box 100360 Anchorage, AK 99510-0360 3/19/2020 50-103-20539-60-00 2952' FNL, 341' FEL, Sec 24, T11N, R4E, UM 3/21/2020 CRU CD4-215L1 1878' FNL, 4124' FEL, Sec 25, T11N, R4E, UM Colville River Field/Nanuq Nanuq Oil Pool 1233' FNL, 4529' FEL, Sec 25, T11N, R4E, UM N/A ADL 380077, ADL 384209, ADL 388902 377902 5957461 10853/6244 LONS 97-007 374052 5953318 373658 5953970 2142/1925 776/774 9602/6222 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 GR/Res CASING, LINER AND CEMENTING RECORD CASING WT. PER FT.GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLEDTOP BOTTOM TOP 65 37 114 37 24 40 37 2854 37 12 1/4 397sx AS Lite, 231sx Class G 35 9514 35 8 3/4 195 sx LiteCRETE 321 sx Class G Pre-Installed 9.3 9361 14,675 6195 6 1/8 Slotted/Solid Liner 26 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 9380 8205/5856 Slotted Liner@: 9570-10853 MD and 6219-6244 TVD…03/22/2020 ACID, FRACTURE, CEMENT SQUEEZE, ETC. Per 20 AAC 25.283 (i)(2) attach electronic information PRODUCTION TEST 4/17/2020 Gas Lift Date of Test: Oil-Bbl: Water-Bbl: Choke Size: Gas-Oil Ratio: 1175 31 N/A 4/17/2020 8.25 38 411 10 N/A Sr Pet Eng Sr Pet Geo Sr Res Eng 12112 Flow Tubing Oil-Bbl:Water-Bbl: 225 720 110 WINJ SPLUG Other Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 11:16 am, Apr 21, 2020 Completion Date 3/23/2020 HEW RBDMS HEW 4/22/2020 G DSR 4/23/2020 10,853 6244 SFD 4/23/2020 SFD 4/23/2020VTL 5/4/20 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 776 774 Top of Productive Interval 9602 6222 TD 10853 6244 Nanuq Reservoir 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. James Ohlinger Contact Name:Ryan McLauglin Staff CTD Engineer Contact Email:Ryan.McLaughlin@cop.com Authorized Contact Phone:444-7886 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: 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. 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. 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). 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 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. 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. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. TPI (Top of Producing Interval). 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). 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. Authorized Name: Authorized Title: Signature w/Date: INSTRUCTIONS 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. Formation at total depth: 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. Permafrost - Top 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. Permafrost - Base Formation @TPI -Nanuq Resv. 28. CORE DATA Yes No If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS NAME Well tested? Yes No No NoSidewall Cores: Yes NoNoSidewallCores: Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment ugllininininnninininnninnnninniniiiniiiinninninniiinniiini 4/21/20 4/21/2020 CD4-215 Final CTD Schematic3-1/2" 9.3# VIT from 9380' RKB to surface3-1/2" 9.3# L-80 liner from 14675' RKB to surfaceCamco TRMAXX-5E SSSV @ 2142' RKB (min ID 2.812")3-1/2" VIT x 3-1/2" IBT XO @ 3997' RKBCamco KBMG GLMs @ 4355' & 8115' RKBBaker Premier Packer @ 8205' RKB (2.875" ID)HES XN Nipple @ 8283' RKB (milled out to 2.80")Locator/WLEG No-Go @ 9351' RKB (2.992" ID)HR Liner Setting Sleeve @ 9361' RKBBaker RS Sealing Nipple @ 9374' RKBBaker Flex Lock DG Liner Hanger @ 9378' RKB9-5/8" 40# L-80 shoe @ 2854' MD7" 26# L-80 shoe @ 9515' MD16" 65# H-40shoe @ 114' 3-1/2" Liner shoe @ 14675' MDKOP @ 9602' MDCD4-215L1 TD @ 10,854' MDSlotted Liner 9570-10,853' MD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: 10,800.0 7/11/2008 CD4-215 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Mill XN 1/24/2020 CD4-215 boehmbh Casing Strings Casing Description CONDUCTOR 46" Insulated OD (in) 16 ID (in) 15.25 Top (ftKB) 37.0 Set Depth (ftKB) 114.0 Set Depth (TVD) … 114.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 36.8 Set Depth (ftKB) 2,854.2 Set Depth (TVD) … 2,392.1 Wt/Len (l… 40.00 Grade L-80 Top Thread Buttress Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 34.6 Set Depth (ftKB) 9,514.5 Set Depth (TVD) … 6,214.1 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description LINER OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 9,361.0 Set Depth (ftKB) 14,675.0 Set Depth (TVD) … 6,212.3 Wt/Len (l… 9.30 Grade L-80 Top Thread SLHT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,361.0 6,194.6 81.41 SLEEVE "HR" LINER SETTING SLEEVE 4.420 9,374.0 6,196.5 81.60 NIPPLE BAKER "RS" SEALING NIPPLE 4.250 9,377.8 6,197.1 81.66 HANGER BAKER FLEX LOCK "DG" LINER HANGER 4.400 Tubing Strings Tubing Description TUBING VITxNORMAL String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.4 Set Depth (ft… 9,379.6 Set Depth (TVD) (… 6,197.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.4 31.4 0.14 HANGER FMC TUBING HANGER 4.500 44.8 44.8 0.20 XO-Reducing 4.5"x3.5" 3.500 2,142.2 1,925.2 48.83 SAFETY VLV CAMCO TRMAXX-5E #HYS-405 2.812 3,996.9 3,164.1 45.37 XO VITxIBT CROSOVER FROM VACUUM INSULATED 3.5" TBG INSIDE 4.5" TUBING TO NORMAL 3.5" TUBING 2.992 8,204.5 5,856.5 63.33 PACKER BAKER PREMIER PACKER 2.875 8,282.5 5,890.6 64.57 NIPPLE HES 'XN' NIPPLE @ 64 DEG. 2.75" Milled to 2.80" 2.800 9,350.6 6,193.0 81.28 WLEG LOCATOR/WLEG FLUTED NO GO 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 9,600.0 6,221.8 84.91 WHIPSTOCK - THRU TBG 3-1/2" Monobre XL Whipstock 1/18/2020 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,501.0 9,712.0 6,212.8 6,233.9 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 9,555.0 9,575.0 6,217.9 6,219.7 4/22/2007 6.0 APERF 2.5" Hyperjet Charges, 60 deg orient 10,550.0 10,733.0 6,231.1 6,219.1 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 10,857.0 11,039.0 6,217.5 6,227.0 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 11,566.0 11,627.0 6,246.6 6,244.2 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 12,184.0 12,730.0 6,219.1 6,214.5 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 12,852.0 13,395.0 6,218.7 6,225.0 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 13,549.0 13,638.0 6,234.2 6,240.3 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 13,793.0 14,280.0 6,248.4 6,246.9 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 14,342.0 14,403.0 6,243.1 6,238.8 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 14,497.0 14,673.0 6,230.9 6,212.5 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots Frac Summary Start Date 4/25/2007 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 4/25/2007 Top Depth (ftKB) 10,550.0 Btm (ftKB) 14,673.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 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 4,354.5 3,420.5 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.188 1,600.0 11/12/2019 2 8,115.1 5,814.6 CAMCO KBMG 1 GAS LIFT OV BK-5 0.250 0.0 11/12/2019 Notes: General & Safety End Date Annotation 12/5/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Horizontal, CD4-215, 4/17/2020 3:08:00 PM Vertical schematic (actual) LINER; 9,361.0-14,675.0 SLOTS; 14,497.0-14,673.0 SLOTS; 14,342.0-14,403.0 SLOTS; 13,793.0-14,280.0 SLOTS; 13,549.0-13,638.0 SLOTS; 12,852.0-13,395.0 FRAC; 10,550.0 SLOTS; 12,184.0-12,730.0 SLOTS; 11,566.0-11,627.0 SLOTS; 10,857.0-11,039.0 SLOTS; 10,550.0-10,733.0 SLOTS; 9,501.0-9,712.0 WHIPSTOCK - THRU TBG; 9,600.0 APERF; 9,555.0-9,575.0 INTERMEDIATE; 34.6-9,514.5 WLEG; 9,350.5 NIPPLE; 8,282.5 PACKER; 8,204.5 GAS LIFT; 8,115.1 GAS LIFT; 4,354.5 SURFACE; 36.8-2,854.2 SAFETY VLV; 2,142.2 CONDUCTOR 46" Insulated; 37.0-114.0 HANGER; 31.4 L1; -1,283.4-0.0 WNS PROD KB-Grd (ft) 43.78 Rig Release Date 12/25/2006 CD4-215 ... TD Act Btm (ftKB) 14,761.0 Well Attributes Field Name NANUQ Wellbore API/UWI 501032053900 Wellbore Status PROD Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBORECD4-215 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP Frac Summary Start Date 4/25/2007 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 4/25/2007 Top Depth (ftKB) 10,550.0 Btm (ftKB) 14,673.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Horizontal, CD4-215L1, 4/19/2020 5:18:01 PM Vertical schematic (actual) LINER; 9,361.0-14,675.0 WHIPSTOCK - THRU TBG; 9,600.0 APERF; 9,555.0-9,575.0 SLOTS; 9,501.0-9,712.0 INTERMEDIATE; 34.6-9,514.5 WLEG; 9,350.5 NIPPLE; 8,282.5 PACKER; 8,204.5 GAS LIFT; 8,115.1 GAS LIFT; 4,354.5 SURFACE; 36.8-2,854.2 SAFETY VLV; 2,142.2 CONDUCTOR 46" Insulated; 37.0-114.0 HANGER; 31.4 L1; -1,283.4-0.0 WNS PROD KB-Grd (ft) 43.78 Rig Release Date 12/25/2006 CD4-215L1 ... TD Act Btm (ftKB) 10,853.0 Well Attributes Field Name NANUQ Wellbore API/UWI 501032053960 Wellbore Status PROD Max Angle & MD Incl (°) 107.48 MD (ftKB) 9,890.65 WELLNAME WELLBORECD4-215 Annotation End DateH2S (ppm) DateComment Page 1/7 CD4-215 Report Printed: 4/15/2020 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) 3/16/2020 12:00 3/16/2020 16:30 4.50 MIRU MOVE RURD P Complete RD on CD4-214. 3/16/2020 16:30 3/16/2020 16:42 0.20 MIRU MOVE MOB P PJSM with Peak crew, 3/16/2020 16:42 3/16/2020 17:30 0.80 MIRU MOVE MOB P Jack service mod, pull mats and crab walk down the pad. 3/16/2020 17:30 3/16/2020 18:00 0.50 MIRU MOVE MOB P Crew change, tire check on sub 3/16/2020 18:00 3/16/2020 18:42 0.70 MIRU MOVE MOB P Jack sub, and pull off well 3/16/2020 18:42 3/16/2020 19:00 0.30 MIRU MOVE MOB P Reposition mats in between modules 3/16/2020 19:00 3/16/2020 20:18 1.30 MIRU MOVE MOB P Spot Sub over well - CD2-415 3/16/2020 20:18 3/16/2020 22:18 2.00 MIRU MOVE MOB P Spot inner service mats, crab walk service mod back to Sub, spot service mod, spot outer mats. off jack. 3/16/2020 22:18 3/16/2020 22:48 0.50 MIRU MOVE MOB P Complete spot up, drop landings and prep entrances / egress. 3/16/2020 22:48 3/17/2020 00:00 1.20 MIRU WHDBOP RURD P Work RU checklist. Extend PUTZ, connect steam to sub, 3/17/2020 00:00 3/17/2020 03:00 3.00 MIRU WHDBOP NUND P Work RU checklist, Extend PUTZ, connect steam to sub, stab stack, rig up PUTZ/interconnect, connect comms, grease valves, Swap out 4' (big tools) riser for 3' and harvest RKB's ***Rig accept @ 01:00, 0.0 0.0 3/17/2020 03:00 3/17/2020 06:00 3.00 MIRU WHDBOP RURD P Continue to grease valves, Start to inventory pits ( Pills 1&2 plus 3 with seawater, Pit 7 125 bbls Power Pro), Grease R7, reconfigure test joint, flood stack 0.0 0.0 3/17/2020 06:00 3/17/2020 09:00 3.00 MIRU WHDBOP BOPE P Prepare equipment for BOP test. 0.0 0.0 3/17/2020 09:00 3/17/2020 14:30 5.50 MIRU WHDBOP BOPE P Test 1. Swab 2 - fail 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 Service Swab 2 and retest: Pass 0.0 0.0 Rig: NABORS CDR3-AC Page 2/7 CD4-215 Report Printed: 4/15/2020 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) 3/17/2020 14:30 3/17/2020 16:54 2.40 MIRU WHDBOP RURD P RU LRS. Fill CT. Spear in with 10 bbls of MeOH followed by seawater at .41 bpm. 0.0 0.0 3/17/2020 16:54 3/17/2020 18:12 1.30 MIRU WHDBOP PRTS P PT inner reel iron, PDLs, and tiger tank line 0.0 0.0 3/17/2020 18:12 3/17/2020 20:30 2.30 PROD1 RPEQPT CTOP P MU CTC and pull test. MU UQC and pressure test. 0.0 0.0 3/17/2020 20:30 3/17/2020 21:06 0.60 PROD1 RPEQPT CTOP P Install nozzle, blow down choke, inspect pack offs 0.0 0.0 3/17/2020 21:06 3/17/2020 23:42 2.60 PROD1 RPEQPT PULD P PU and PD BHA #1, clean out assembly 0.0 53.0 3/17/2020 23:42 3/18/2020 02:18 2.60 PROD1 RPEQPT DISP P Bump up, set counters. Line up down the backside bullhead 40 bbls seawater ~3 bpm, 0.0 53.0 3/18/2020 00:00 3/18/2020 00:24 0.40 PROD1 RPEQPT DISP P Continue to bullheadd down the backside bullhead ~3 bpm, 53.0 53.0 3/18/2020 00:24 3/18/2020 02:12 1.80 PROD1 RPEQPT TRIP P RIH pumping seawater down the coil. Park @ 1498' inspect goose neck alignment - good. Continuin in hole. Shut down pumps, Differential pressure no falling. Try RIH, bullhead more fluid down backside. No change, Note diff was 115 psi @ surface prior to pumping. 53.0 5,038.0 3/18/2020 02:12 3/18/2020 03:12 1.00 PROD1 RPEQPT TRIP T POOH for new upper Coiltrak 5,038.0 53.0 3/18/2020 03:12 3/18/2020 04:12 1.00 PROD1 RPEQPT PULD T PUD BHA #1 53.0 0.0 3/18/2020 04:12 3/18/2020 05:12 1.00 PROD1 RPEQPT PULD T PD BHA #2 0.0 53.0 3/18/2020 05:12 3/18/2020 05:42 0.50 PROD1 RPEQPT TRIP T RIH 53.0 5,038.0 3/18/2020 05:42 3/18/2020 07:42 2.00 PROD1 RPEQPT TRIP P RIH Park, Close EDC, PU Wt 38 k lbs 5,038.0 8,081.0 3/18/2020 07:42 3/18/2020 08:18 0.60 PROD1 RPEQPT DLOG P Attempt to tie into Albian 97. Very nondescript peaks and valleys. Thinking -9' correction but a certain amount of imagination is needed. 8,081.0 8,718.0 3/18/2020 08:18 3/18/2020 08:30 0.20 PROD1 RPEQPT TRIP P RIH 8,718.0 9,430.0 3/18/2020 08:30 3/18/2020 09:03 0.55 PROD1 RPEQPT DLOG P 9,430.0 9,573.0 3/18/2020 09:03 3/18/2020 09:06 0.05 PROD1 RPEQPT DLOG P RIH spinning the bit, hole clean to 9650' 9,573.0 9,335.0 3/18/2020 09:06 3/18/2020 09:12 0.10 PROD1 RPEQPT DLOG P PUH to CCL loging depth 9,335.0 9,700.0 3/18/2020 09:12 3/18/2020 09:36 0.40 PROD1 RPEQPT DLOG P Logg CCL from 9335 - 9650 9,335.0 9,700.0 3/18/2020 09:36 3/18/2020 11:30 1.90 PROD1 RPEQPT TRIP P Park and open EDC, POOH 9,700.0 74.0 3/18/2020 11:30 3/18/2020 12:00 0.50 PROD1 RPEQPT CTOP P Park and inspect saddle clamps and verify torque on reel hubs. 74.0 74.0 3/18/2020 12:00 3/18/2020 13:00 1.00 PROD1 RPEQPT PULD P Tag up, space out, PUD BHA #2 74.0 0.0 3/18/2020 13:00 3/18/2020 13:54 0.90 PROD1 RPEQPT PULD P PD BHA #3, 3-1/2" MonoBore XL Whipstock - 2.625" OD 0.0 72.0 3/18/2020 13:54 3/18/2020 16:12 2.30 PROD1 RPEQPT WPST P RIH 72.0 9,449.0 3/18/2020 16:12 3/18/2020 16:36 0.40 PROD1 RPEQPT DLOG P Tie into the Albain / Nanuk interface for a -10' 9,449.0 9,555.4 Rig: NABORS CDR3-AC Page 3/7 CD4-215 Report Printed: 4/15/2020 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) 3/18/2020 16:36 3/18/2020 17:00 0.40 PROD1 RPEQPT WPST P PU Wt 41 k lbs, continue in hole to set depth PU to neutral weight, close EDC pump 0.4 bpm shear at 3700 psi. S/D 3.84 k lbs WOB, PU Wt 44 k lbs 9,555.4 9,610.8 3/18/2020 17:00 3/18/2020 17:24 0.40 PROD1 RPEQPT WPST P PU Wt 41 k lbs, continue in hole to set depth PU to neutral weight, close EDC pump 0.4 bpm shear at 3700 psi. S/D 3.84 k lbs WOB, PU Wt 44 k lbs 9,555.4 9,610.8 3/18/2020 17:24 3/18/2020 19:12 1.80 PROD1 RPEQPT TRIP P POOH, with open EDC 9,610.8 73.0 3/18/2020 19:12 3/18/2020 20:42 1.50 PROD1 RPEQPT PULD P At surface, PUD setting tools. 73.3 0.0 3/18/2020 20:42 3/18/2020 21:54 1.20 PROD1 WHPST PULD P PD Window milling assembly 0.0 63.2 3/18/2020 21:54 3/18/2020 23:30 1.60 PROD1 WHPST TRIP P RIH 63.2 9,440.0 3/18/2020 23:30 3/18/2020 23:54 0.40 PROD1 WHPST DLOG P Log formation for depth control (Nanuq), minus 9.0', PUW 40 k 9,440.0 9,553.0 3/18/2020 23:54 3/19/2020 00:00 0.10 PROD1 WHPST TRIP P Continue IH, dry tag TOWS @ 9,602.2', 9,553.0 9,601.5 3/19/2020 00:00 3/19/2020 00:18 0.30 PROD1 WHPST TRIP P PUH bring pump online obtain pump parameters 9,601.5 9,601.5 3/19/2020 00:18 3/19/2020 02:18 2.00 PROD1 WHPST MILL P Start milling, 1.87 bpm at 3,600 psi, Diff=446, WHP=581, BHP=3,542, IA=683, OA=393 9,601.5 9,603.9 3/19/2020 02:18 3/19/2020 02:46 0.48 PROD1 WHPST MILL P OB Milling, 1.86 bpm at 3983 psi, Diff=613, WHP=680, BHP=3,629, IA=682, OA=389, @ 9,603.3' spike in motor work, continue milling ahead, notice diff pressure drop @ 9,604', 9,603.9 9,604.4 3/19/2020 02:46 3/19/2020 04:46 2.00 PROD1 WHPST MILL P OB Milling 1.86 bpm at 3,992 psi, Diff=721 psi, WHP=699, BHP=3,650, IA=682, OA=388 9,604.4 9,606.1 3/19/2020 04:46 3/19/2020 05:58 1.20 PROD1 WHPST MILL P OB Milling 1.86 bpm at 4084 psi, Diff=514 psi, WHP=819, BHP=3,751, ROP- 2.0 FT/hr 9,606.1 9,607.5 3/19/2020 05:58 3/19/2020 06:52 0.90 PROD1 WHPST MILL P Increse ROP to 2.5 Ft/hr 9,607.5 9,609.5 3/19/2020 06:52 3/19/2020 08:46 1.90 PROD1 WHPST MILL P Drill ahead @ 10 ft/hr, drilling rat hole 9,609.5 9,622.0 3/19/2020 08:46 3/19/2020 10:04 1.30 PROD1 WHPST REAM P PU Wt 42 k lbs, Pull three reaming up passes as milled - straight motor- Time out 5x5 sweep, dry drift, window clean - tag bottom. 9,622.0 9,580.0 3/19/2020 10:04 3/19/2020 11:40 1.60 PROD1 WHPST TRIP P PU Wt 42 k lbs. POOH 9,580.0 50.0 3/19/2020 11:40 3/19/2020 12:34 0.90 PROD1 WHPST PULD P PUD BH #4, Mill gauged out 2.80" go, 2.79" no, mill shows good indication of successful window. 50.0 0.0 3/19/2020 12:34 3/19/2020 13:34 1.00 PROD1 DRILL PULD P PD BHA #5 2.5° KO motor over a RR BH Dynamus 0.0 72.0 3/19/2020 13:34 3/19/2020 15:22 1.80 PROD1 DRILL TRIP P RIH 72.0 9,440.0 3/19/2020 15:22 3/19/2020 15:46 0.40 PROD1 DRILL DLOG P Tie in to Albian/ Nanook interface for - 10' correction. 9,440.0 9,545.0 3/19/2020 15:46 3/19/2020 15:58 0.20 PROD1 DRILL DLOG P Continue to RIH 9,545.0 9,622.0 3/19/2020 15:58 3/19/2020 16:22 0.40 PROD1 DRILL DRLG P CT 3,767 psi @ 1.84 bpm in / 0 out, diff press 486 psi, BHP 3,663 psi, CT Wt 18k lbs, WOB 3 k lbs. 9,622.0 9,634.0 Rig: NABORS CDR3-AC Page 4/7 CD4-215 Report Printed: 4/15/2020 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) 3/19/2020 16:22 3/19/2020 18:22 2.00 PROD1 DRILL DRLG P Stalling motor, trouble drilling foward, PU's clean, OBD 1.86 bpm at 4,221 psi, Diff=505 psi, WHP=653, BHP=3,723, IA=689, OA=401 9,634.0 9,668.0 3/19/2020 18:22 3/19/2020 20:22 2.00 PROD1 DRILL WPRT P PUH clean, PUW 37 k, 9,630', RBIH 9,668.0 9,668.0 3/19/2020 20:22 3/19/2020 22:22 2.00 PROD1 DRILL DRLG P BOBD, 1.86 bpm at 4,276 psi, Diff=568, WHP=729, BHP=3,720, IA=689, OA=401, pump 5x5 sweep, 9,776' indications of balling up, park just off bottom, attempt to free bit of clay. 9,668.0 9,800.0 3/19/2020 22:22 3/20/2020 00:00 1.63 PROD1 DRILL DRLG P OBD, 1.86 bpm at 4,591 psi, Diff=627, WHP=898, BHP=3,811, IA=688, OA=400 9,800.0 9,881.0 3/20/2020 00:00 3/20/2020 02:00 2.00 PROD1 DRILL DRLG P OBD, 1.87 bpm at 3,967 psi, DIff=556 psi, WHP=871, BHP=3,801, IA=688, OA=399 9,881.0 9,929.0 3/20/2020 02:00 3/20/2020 02:48 0.80 PROD1 DRILL DRLG P OBD, 1.87 bpm at 3,980 psi, Diff=523 psi, WHP=884, BHP=3,802, IA=687, OA=397, PUW's 40 k 9,929.0 9,951.0 3/20/2020 02:48 3/20/2020 03:06 0.30 PROD1 DRILL WPRT P PUH clean, wiper to the window, PUW 41 k 9,951.0 9,450.0 3/20/2020 03:06 3/20/2020 03:18 0.20 PROD1 DRILL DLOG P Log formation for depth control, + 3.0' 9,450.0 9,545.0 3/20/2020 03:18 3/20/2020 03:30 0.20 PROD1 DRILL WPRT P Wiper back in hole, RIW 20 k 9,545.0 9,620.0 3/20/2020 03:30 3/20/2020 03:39 0.15 PROD1 DRILL DLOG P Tie in RA marker @ 9,608', TOWS 9,602', BOW 9,606' 9,620.0 9,640.0 3/20/2020 03:39 3/20/2020 03:51 0.20 PROD1 DRILL WPRT P Continue wiper back in hole, RIW 20 k 9,640.0 9,953.0 3/20/2020 03:51 3/20/2020 06:09 2.30 PROD1 DRILL DRLG P BOBD, CT 3912 psi @ 1.86 bpm, free spin diff 784, BHP 3777 psi. 9,953.0 10,015.0 3/20/2020 06:09 3/20/2020 07:51 1.70 PROD1 DRILL TRIP P PU Wt 41 k lbs PUH above window, park and open EDC Continue out of hole 10,015.0 60.0 3/20/2020 07:51 3/20/2020 08:51 1.00 PROD1 DRILL PULD P PUD BHA # 5, bit balled, 1 plugged nozzle easily cleared, graded 1-1 60.0 0.0 3/20/2020 08:51 3/20/2020 09:51 1.00 PROD1 DRILL PULD P PD BHA # 6, ERD drilling assembly W NOV agitator 0.5° AKO 0.0 78.0 3/20/2020 09:51 3/20/2020 11:33 1.70 PROD1 DRILL TRIP P RIH, close EDC, shallow test agitator, 1.86 bpm diff 1144 psi. 78.0 9,472.0 3/20/2020 11:33 3/20/2020 11:51 0.30 PROD1 DRILL DLOG P Tie into the Albian / Nanook for a -17' correction 9,472.0 9,556.0 3/20/2020 11:51 3/20/2020 12:15 0.40 PROD1 DRILL CIRC P Open EDC, open choke, establish circulation, 1.88 bpm in 1.5 bpm out, 10.6 ppg EMW at the window. - CLose EDC 9,556.0 9,556.0 3/20/2020 12:15 3/20/2020 12:33 0.30 PROD1 DRILL TRIP P RIH, Window clean, drive by the RA tag to confirm depth - on depth - 9608' Continue in hole to bottom, 3 k WOB spike 9653', 9,556.0 10,007.0 3/20/2020 12:33 3/20/2020 15:45 3.20 PROD1 DRILL DRLG P CT 4383 psi 1.88 bpm in and 1.3 bpm out, free spin 1091 psi, BHP 3624 psi, 10.7 ppg EMW, Add power Pro to mud to increase ~35 k LSRV ROP 69 ft/hr 10,007.0 10,228.0 3/20/2020 15:45 3/20/2020 15:57 0.20 PROD1 DRILL WPRT P Pull 200' wiper- PU Wt 42 k lbs - RBIH 10,228.0 10,228.0 Rig: NABORS CDR3-AC Page 5/7 CD4-215 Report Printed: 4/15/2020 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) 3/20/2020 15:57 3/20/2020 16:09 0.20 PROD1 DRILL DRLG P CT 4599 psi 1.88 bpm in and 1.57 bpm out, open choke, 1133 psi free spin diff, BHP 3623 psi, 11.8 ppg ppg EMW at the window. CT Wt 8.8 k lbs, WOB 1.6 k lbs. 10,228.0 10,255.0 3/20/2020 16:09 3/20/2020 18:09 2.00 PROD1 DRILL DRLG P OBD, 1.88 bpm at 4,882 psi, Diff=1,242 psi, WHP=430, BHP=3,723, IA=699, OA=429 10,255.0 10,373.0 3/20/2020 18:09 3/20/2020 18:45 0.60 PROD1 DRILL DRLG P OBD, 1.88 bpm at 4,882 psi, Diff=1,242 psi, WHP=430, BHP=3,723, IA=699, OA=429 10,373.0 10,425.0 3/20/2020 18:45 3/20/2020 18:57 0.20 PROD1 DRILL WPRT P Wiper up hole, PUW 41 k 10,425.0 10,025.0 3/20/2020 18:57 3/20/2020 19:09 0.20 PROD1 DRILL WPRT P Wiper back in hole, RIW 14 k 10,025.0 10,425.0 3/20/2020 19:09 3/20/2020 21:09 2.00 PROD1 DRILL DRLG P BOBD, 1.88 bpm at 4,710 psi, Diff=1,242 psi, WHP=368, BHP=3,445, IA=698, OA=427 10,425.0 10,543.0 3/20/2020 21:09 3/20/2020 21:51 0.70 PROD1 DRILL DRLG P OBD, 1.88 bpm at 4,882 psi, Diff=1,242 psi, WHP=430, BHP=3,723, IA=699, OA=429 10,543.0 10,556.0 3/20/2020 21:51 3/20/2020 22:00 0.15 PROD1 DRILL WPRT P Pull 200' wiper up hole, PUW 46 k 10,556.0 10,356.0 3/20/2020 22:00 3/20/2020 22:09 0.15 PROD1 DRILL WPRT P Wiper back in hole, RIW 10.5 k 10,356.0 10,556.0 3/20/2020 22:09 3/20/2020 22:09 PROD1 DRILL DRLG P BOBD, 1.88 bpm at 4,710 psi, Diff=1,242 psi, WHP=368, BHP=3,445, IA=698, OA=427 10,556.0 3/21/2020 00:00 3/21/2020 01:30 1.50 PROD1 DRILL DRLG P OBD, 1.87 bpm at 5,446 psi, Diff=1,940 psi, WHP=458, BHP=3,522, IA=686, OA=387 10,680.0 10,775.0 3/21/2020 01:30 3/21/2020 01:42 0.20 PROD1 DRILL WPRT P Pull 200' wiper up hole, PUW 50 k, pull 10k over @ 10,218', RBIH, stack out weight, continued pulling wiper to the window. 10,775.0 10,218.0 3/21/2020 01:42 3/21/2020 02:30 0.80 PROD1 DRILL WPRT P Work pipe up hole through tight area's 10,220', 10,171', 10,161', 10,153', 10,138', and 10,033' 10,218.0 10,033.0 3/21/2020 02:30 3/21/2020 02:54 0.40 PROD1 DRILL WPRT P Continue wiper to throught the build section, pull up through window clean. 10,033.0 9,450.0 3/21/2020 02:54 3/21/2020 03:12 0.30 PROD1 DRILL DLOG P Log formation for deprth control + 11.0' 9,450.0 9,462.0 3/21/2020 03:12 3/21/2020 04:42 1.50 PROD1 DRILL WPRT P Wiper back in hole, RIW 40 k, stack out w/pickups 10,028', 10,080', 10,140', 10,362', 10,470', and 10,600' 9,462.0 10,775.0 3/21/2020 04:42 3/21/2020 07:06 2.40 PROD1 DRILL DRLG P BOBD, 1.89 bpm at 4,760 psi, Diff=1,320 psi, WHP=514, BHP=3,616, IA=687, OA=389 10,775.0 10,854.0 3/21/2020 07:06 3/21/2020 07:30 0.40 PROD1 DRILL DRLG P PU Wt 46 k lbs, Pull up hole on wiper to window Start pulling heavy @ 10,290', RBIH Work pipe slowly to 10,175' cant come up, cant go down Working pipe, Snub -10 CT Wt to 65 k Ct Wt 10,854.0 10,186.0 Rig: NABORS CDR3-AC Page 6/7 CD4-215 Report Printed: 4/15/2020 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) 3/21/2020 07:30 3/21/2020 09:00 1.50 PROD1 DRILL DRLG T Pull free to 10,152 - over pulls, starting to see neg WOB when working pipe. Annular pressure falls off steadily from 3,727 psi to 3,487 psi. Packing off below the DPS sensor. Work pipe to 70 k lbs, -12 k WOB, Bleed WH, slowly climbs back. Work pipe, pump two 10 bbl pills of beaded mud - no luck. 10,854.0 10,158.0 3/21/2020 09:00 3/21/2020 10:30 1.50 PROD1 DRILL DRLG T Load 2 totes - 16 bbls LVT into pill pit, pump. 8 bbls out the bit, shut down for 20 min, work pipe, no success. Pump last 8 bbls out bit. S/D pump, open choke - Bleed well head to zero. Work pipe 2x,park in tension - 65 k lbs. Pull free 10,158.0 10,142.0 3/21/2020 10:30 3/21/2020 10:48 0.30 PROD1 DRILL TRIP P Pull to cased hole 10,142.0 9,431.0 3/21/2020 10:48 3/21/2020 11:06 0.30 PROD1 DRILL DLOG P Ti into Albian / Nanook interface for a +5' correction. 9,431.0 9,568.0 3/21/2020 11:06 3/21/2020 12:06 1.00 PROD1 DRILL CIRC P Attempt to open choke, no success. Close choke. 9,568.0 9,543.0 3/21/2020 12:06 3/21/2020 12:18 0.20 PROD1 DRILL DLOG P Park and measure BHP 9526.13MD / 6210.18' TVD Elapsed time BHP(psi) EMW 0 3601 11.15 1352010.90 2350210.84 3348410.79 4347810.70 5347310.75 10 3439 10.65 WH 832 psi, IA 679 psi, OA 200 psi 9,543.0 9,526.0 3/21/2020 12:18 3/21/2020 13:30 1.20 PROD1 DRILL TRIP P RIH on clean out run to bottom. RIH to 10,128, PU, down to 10,200', PU, 10,259', PU 10,455'. Stacking out, PU to 50 k, WOB to -6 k. Annular pressure dropping 80-100 psi when working pipe. Appears to be packing off. Confirm TD of 10,852.8' 9,526.0 10,852.8 3/21/2020 13:30 3/21/2020 14:06 0.60 PROD1 DRILL TRIP P PUH slowly with reduced pump rate. Displace 5 bbls high vis, observe annular pressure, thief zone appears to be mother bore. Pull to cased hole pumping 1 bpm. ****Trouble area is 10,050 to 10,300' Not cleaning up. 10,852.8 9,578.0 3/21/2020 14:06 3/21/2020 14:42 0.60 PROD1 DRILL TRIP P PUH slowly, while pumping 5 bbls high vis, observe annular pressure, thief zone appears to be mother bore. 10,852.8 9,253.0 3/21/2020 14:42 3/21/2020 19:42 5.00 PROD1 DRILL CIRC T Recip coil in cased hole, while building completion fluid 9,253.0 9,253.0 3/21/2020 19:42 3/21/2020 20:42 1.00 PROD1 DRILL TRIP P Completion fluid loaded into pits, RIH to bottom, send 25 bbl 10.7 ppg beaded LRP down coil @ 10,400' 9,253.0 10,850.0 Rig: NABORS CDR3-AC pp p g Confirm TD of 10,852.8' Page 7/7 CD4-215 Report Printed: 4/15/2020 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) 3/21/2020 20:42 3/21/2020 23:00 2.30 PROD1 DRILL TRIP P POOH laying in beaded 10.7 ppg LRP 10,850.0 78.3 3/21/2020 23:00 3/22/2020 00:00 1.00 PROD1 DRILL CIRC P Line up to backside, bring pump online 10.7 ppg completion fluid 84 bbls, Shut down pump and monitor well 78.3 78.3 3/22/2020 00:00 3/22/2020 00:15 0.25 PROD1 DRILL OWFF P Continue monitoring well for flow (no- flow) 78.3 78.3 3/22/2020 00:15 3/22/2020 01:15 1.00 PROD1 DRILL PULD P LD drilling assembly, *** Note: Static Loss rate 12 bph 78.3 0.0 3/22/2020 01:15 3/22/2020 01:45 0.50 COMPZ1 CASING PUTB P Prep RF for liner OPS, PJSM 0.0 0.0 3/22/2020 01:45 3/22/2020 04:21 2.60 COMPZ1 CASING PUTB P PU/MU L1 liner completion 42 jts of slotted liner 0.0 1,283.4 3/22/2020 04:21 3/22/2020 04:51 0.50 COMPZ1 CASING PULD P PU/MU CoilTrak tools, 1,283.4 1,327.6 3/22/2020 04:51 3/22/2020 07:03 2.20 COMPZ1 CASING RUNL P Tag up, reset counters, RIH w/L1 slotted liner completion 42 jts, shorty deployment sleeve and non-ported bullnose 1,327.6 9,538.0 3/22/2020 07:03 3/22/2020 07:15 0.20 COMPZ1 CASING DLOG P Tie into the white window flag for a -11' correction, PU Wt 40 k lbs. 9,538.0 9,528.0 3/22/2020 07:15 3/22/2020 07:57 0.70 COMPZ1 CASING RUNL P Continue in hole with liner, S/D @ 10,079' PU 45 k lbs, clean Work liner slowly to bottom - 20 minutes - PU Wt 62 k, -18 k WOB, Set on bottom, pump 1.5 bpm, diff 895 psi, PU, Ct Wt 3k lbs, WOB -2.95k lbs Set liner on bottom 10,853' TOL 9569' 9,528.0 10,853.0 3/22/2020 07:57 3/22/2020 08:03 0.10 COMPZ1 CASING TRIP P PUH, set depth PUH 10,853.0 9,445.0 3/22/2020 08:03 3/22/2020 08:27 0.40 COMPZ1 CASING DLOG P Tie into formation for +3' correction. 9,445.0 9,549.0 3/22/2020 08:27 3/22/2020 09:51 1.40 COMPZ1 CASING TRIP P POOH 9,549.0 37.0 3/22/2020 09:51 3/22/2020 10:27 0.60 COMPZ1 CASING DLOG P Flow check - LD BHA # 7 over a dead well. 37.0 0.0 3/22/2020 10:27 3/22/2020 12:27 2.00 DEMOB CASING DISP P Displace remaining KW from coil, load with 20 bbls crude FP. Bullhead seawater to well and Diesel FP. WH 743 psi wit ha column of seawater - 8.56 ppg ****Final WH 830 psi 37.0 0.0 3/22/2020 12:27 3/22/2020 13:09 0.70 DEMOB CASING CIRC P Jet stack 0.0 0.0 3/22/2020 13:09 3/22/2020 14:00 0.85 DEMOB CASING CTOP P Rig up air, blow down., unstab, Vac stack, add metOH to tree. 0.0 0.0 3/22/2020 14:00 3/23/2020 00:00 10.00 DEMOB CASING RURD P Work RD checklist, work fluid removal plan, and release 4 Worley vac trucks back to Deadhorse *** Rig release at midnight 0.0 0.0 Rig: NABORS CDR3-AC &RQRFR3KLOOLSV$ODVND,QFB:16 ! 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PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Nanuq Oil Pool, CD4 -215L1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 220-021 Alaska Oil and Gas Conservation Commission Surface Location: 2952' FNL, 341' FEL, Sec. 24, TI IN, R4E, UM Bottomhole Location: 3710' FNL, 389' FEL, Sec. 23, TI IN, R4E, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the permit to drill the above referenced lateral well. The permit is for a new wellbore segment of existing well Permit No. 206-157, API No. 50-103- 20539-00-00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, V, J em ice Chair DATED this -6 day of March, 2020. STATE OF ALASKA AL, A OIL AND GAS CONSERVATION COMMI PERMIT TO DRILL 20 AAC 25.005 )N MAR 4 2020 1 a. Type of Work: Drill ❑ Lateral ❑� Redrill ❑ Reentry ❑ 1b. Proposed Well Class: Exploratory - Gas ❑ Stratigraphic Test ❑ Development - Oil El Exploratory - Oil ❑ Development - Gas ❑ Service - WAG ❑ Service - Disp ❑ Service - Winj ❑ Single Zone 2 Service - Supply ❑ Multiple Zone ❑ 1c. Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket ❑� Single Well ❑ Bond No. 5952180 , 11. Well Name and Number: CD4 -215L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 14,100' TVD: 6209' 12. Field/Pool(s): Colville River Field Nanuq Nanuq Oil Pool 4a. Location of Well (Governmental Section): Surface: 2952' FNL, 341' FEL, Sec. 24, T11 N, R4E, UM Top of Productive Horizon: , 1877' FNL, 4126' FEL, Sec. 25, T11 N, R4E, UM Total Depth: 3710' FNL, 389' FEL, Sec. 23, T11N, R4E, UM 7. Property Designation: ADL 380077, 384209, 388902 8. DNR Approval Number: LONS 97-007 13. Approximate Spud Date: 3/13/2020 9. Acres in Property: 2560 14. Distance to Nearest Property: 2240' 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 377902 y- 5957461 Zone- 4 10. KB Elevation above MSL (ft): 57' GL / BF Elevation above MSL (ft): 13' 15. Distance to Nearest Well Open to Same Pool: 167' (CD4 -23) 16. Deviated wells: Kickoff depth: 9600 feet Maximum Hole Angle: 106 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 3636 Surface: 3014 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 3850' 10,150' 6244' 14,000' 6209' Slotted 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): 14,761' 6205' N/A Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 14,675' 6212' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 77' 16" Pre -Installed 114' 114' Surface 2817' 9-5/8" 397 sx AS Lite, 231 sx Class G 2854' 2392' Intermediate 9478' 7" 195 sx LiteCRETE, 321 sx Class G 9514' 6216' Liner 5314' 3-1/2" N/A 14,675' 6212' Perforation Depth MD (ft): N/A Perforation Depth TVD (ft): N/A Hydraulic Fracture planned? Yes ❑ No 0 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑ Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 1✓ 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: Ryan McLaughlin Authorized Name: James Ohlinger Contact Email: R an.MCLau hlin COP.com Authorized Title: Staff CTD Engineer Contact Phone: 907-265-6218 _�7 Authorized Signature: Date: 3151 J� Z . / Commission Use Only Permit to Drill Number: API Number: 50- (�—ZQ — Permit Approval Dater 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: lv Other: QIP ��S f 3Jc Samples req'd: Yes ❑ No� Mud log req'd: Yes❑ NoL�J ✓HzS measures: Yes ❑ No [— Directional svy req'd: Yes [S4/No El a�ng exception req'd: Yes ElNoL� / Inclination -only svy req'd: Yes ❑ No� Post initial injection MIT req'd: Yes ❑ No APPROVED BY ' Approved by: \ COMMISSIONER THE COMMISSION Date: 3l �lp 2 c� Submit Form and Form 1 - 1 R ised 5/2017 This ermit is valid for 24 rr fflidNoAp�oval per 20 AAC 25.005 g) Attachments in Duplicate ConocoPs philli Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 25, 2020 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 sundry and permits to drill two laterals out of CD4 - 215 (PTD# 206-157) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in April 2020. The objective will be to drill two laterals CRU CD4 -2151_1 and CD4 -215L1-01 targeting the Nanuq 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 the permit to drill applications are the following documents: - Permit to Drill Application Forms (10-401) for CD4 -2151_1 and CD4 -2151_1-01 - Detailed Summary of Operations - Directional Plans for CD4 -2151_1 and CD4 -2151_1-01 - Current wellbore schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-265-6218. Sincerely, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals C134-2151-1 and C134-2151-1-01 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(f) 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...................................................................................................................................................................5 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 CD4 -2151-1 and CD4 -2151-1-01 laterals..................................................................6 Attachment 2: Current Well Schematic for CD4-215.......................................................................................................6 Attachment 3: Proposed Well Schematic for CD4 -2151-1 and CD4 -2151-1-01 laterals....................................................6 Page 1 of 6 February 25 ,2020 PTD Application.. C134-2151-1 & C134-2151-1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are CD4 -2151_1 and CD4 -2151_1-01. The laterals will be classified as "Development -Oil' wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the Nanuq package in the Alpine reservoir. See attached 10-401 form for surface and subsurface coordinates of the CD4 -2151_1 and CD4 -2151_1-01 laterals. 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 3,500 psi. Using the maximum formation pressure in the area of 3636 psi in CD4 -214 (i.e. 11.7 ppg EMW), the maximum potential surface pressure in CD4 -215, assuming a gas gradient of 0.1 psi/ft, would be 3014 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)) eservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in CD4 -215 was measured to be 1971 psi (6.2 ppg EMW) on 11/13/2019. The maximum downhole pressure expected while drilling based on offset wells and pressure management plans is 3636 psi which equates to 11.2 ppg EMW".,/ Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to CD4 -215 have injected gas, so there is a possibility of encountering free gas while drilling the CD4 -215 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 CD4 -215 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 CD4 -215 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 February 25, 2020 PTD Applicatio... CD4 -215L1 & C134-2151-1-01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Existing Casing/Liner Information Category Liner Top Liner Btm Liner Top Liner Btm Top MD Lateral Name MD MD TVDSS TVDSS Liner Details CD4 -2151-1 10,150' 14,000' 6187' 6152' 2-3/8", 4.7#, L-80, ST -L slotted liner; Surface 114' 1640 670 I aluminum billet on to CD4 -2151_1-01 9580' 14,000' 6163' 6153' 2-3/8", 4.7#, L-80, ST -L slotted liner 2392' 3520 2020 Production 7" and sealbore deployment sleeve Existing Casing/Liner Information Category OD Weight f Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 65.0 H-40 Welded Surface 114' Surface 114' 1640 670 Surface 9-5/8" 40.0 L-80 Buttress Surface 2854' Surface 2392' 3520 2020 Production 7" 26.0 L-80 BTCM Surface 9514' Surface 6214' 4980 4320 Tubing 3-1/2" 9.3 L-80 EUE8rdMOD Surface 1 9380' 1 Surface 1 6197' 8430 7500 Liner 3-1/2" 9.3 L-80 SLHT 9361' 1 14,675' 1 7501' 1 6212' 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: Chloride -based PowerVis mud (8.6 ppg) — Drilling operations: Chloride -based PowerVis mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 11.4 ppg NaBr completion fluid in order to provide formation over -balance and shale stability while running completions. If higher pressures are encountered the NaBr will be weighted up, or completion fluid will be switched to potassium formate. JManaged Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation 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 CD4 -215 laterals we will target a constant BHP of 11.4 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 February 25, 2020 PTD Application: CD4 -2151-1 & CD4 -2151-1-01 Pressure at the CD4 -215 Window 9600' MD, 6222' TVD Usin 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 Background CD4 -214 is a Nanuq producer equipped with 3-1/2" tubing and 7" produciton casing. The CTD sidetrack will utilize two laterals to target the Nanuq lobes 3 and 4 to the northwest of CD4 -215. V/ J Nabors CDR3-AC will set a mechanical whipstock inside the 3-1/2" slotted liner at the planned kick off point of 9600' MD. The CD4 -215 lateral will exit through the 3-1/2" liner at 9600' MD and be drilled to a TD of 14,000' MD, targeting the Nanuq lobe 3 to the Northwest. It will be completed with 2-3/8" slotted liner from TD up to 10,150' MD with an aluminum billet for kicking off the CD4 -2151-1-01 lateral. The CD4 -2151-1-01 lateral will drill to a TD of 14,000' MD targeting the Nanuq lobe 4 to the Northwest. It will be completed with 2-3/8" slotted and solid liner from TD up into the 3-1/2" liner at 9580' MD. Page 4 of 6 February 25, 2020 Pumps On 1.8 bpm) Pumps Off Nanug Formation Pressure 6.2 2006 psi 2006 psi Mud Hydrostatic 8.6 2782 psi 2782 psi Annular friction i.e. ECD, 0.08psi/ft) 768 psi 0 psi Mud + ECD Combined no chokepressure) 3550 psi Overbalanced -1544psi) 2782 psi Overbalanced -776psi) Target BHP at Window 11.4 3688 psi 3688 psi Choke Pressure Required to Maintain Target BHP 138 psi 906 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 Background CD4 -214 is a Nanuq producer equipped with 3-1/2" tubing and 7" produciton casing. The CTD sidetrack will utilize two laterals to target the Nanuq lobes 3 and 4 to the northwest of CD4 -215. V/ J Nabors CDR3-AC will set a mechanical whipstock inside the 3-1/2" slotted liner at the planned kick off point of 9600' MD. The CD4 -215 lateral will exit through the 3-1/2" liner at 9600' MD and be drilled to a TD of 14,000' MD, targeting the Nanuq lobe 3 to the Northwest. It will be completed with 2-3/8" slotted liner from TD up to 10,150' MD with an aluminum billet for kicking off the CD4 -2151-1-01 lateral. The CD4 -2151-1-01 lateral will drill to a TD of 14,000' MD targeting the Nanuq lobe 4 to the Northwest. It will be completed with 2-3/8" slotted and solid liner from TD up into the 3-1/2" liner at 9580' MD. Page 4 of 6 February 25, 2020 PTD Application. 4_'#D4 -215L1 & CD4 -2151-1-01 Pre -CTD Work 1. Prep site for Nabors CDR3-AC rig. Ria Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. CD4 -2151_1 Lateral (Nanuq lobe 3 - Northwest) a. Set top of whipstock at 9600' MD. b. Mill 2.80" window at 9600' MD. c. Drill 3" bi-center lateral to TD of 14,000' MD. d. Run 2-3/8" slotted liner with aluminum billet from TD up to 10,150' MD. 3. CD4 -215L1-01 Lateral (Nanuq lobe 4 - Northwest) a. Kickoff of the aluminum billet at 10,150' MD. b. Drill 3" bi-center lateral to TD of 14,100' MD. c. Run 2-3/8" slotted liner and solid liner from TD up to 9580' MD. 4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Ria Work 1. Return well to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the swab valve on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using the swab valve on the Christmas tree, deployment ram on the BOP, check valve and ball valve in the BHA, and a slick -line lubricator. This pressure control equipment listed ensures reservoir pressure is contained during the deployment process. During BHA deployment, the following steps are observed. — Initially the swab valve on the tree is 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 valve. The swab valve is opened and the BHA is lowered in place via slick -line. — When the BHA is spaced out properly, the deployment ram is closed on the BHA to isolate reservoir pressure via the annulus. A closed ball valve and check valve isolate reservoir pressure internal to the BHA. Slips on the deployment ram prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment ram. — The coiled tubing is made up to the BHA with the ball valve in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the ball valve is opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment ram is 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. Liner Running — The CD4 -215 laterals will be displaced to an overbalancing fluid 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. Page 5 of 6 February 25, 2020 PTD Applicatio,i: C134-2151-1 & C134-2151-1-01 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 Alpine Waste Injection Facility for grind and inject disposal. • Incidental fluids generated from drilling operations will also be injected at the Alpine Waste Injection Facility in disposal well (CD1-01A) or trucked to Kuparuk 1 B disposal facilities if the Alpine facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Alpine 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 Lateral Name Distance CD4 -215L1 2240' CD4 -215L1-01 2240' - Distance to Nearest Well within Pool Lateral Name Distance Well CD4 -215L1 167' CD4 -23 CD4 -215L1-01 127' CD4 -23 16. Attachments Attachment 1: Directional Plans for CD4 -215L1 and CD4 -215L1-01 laterals Attachment 2: Current Well Schematic for CD4 -215 Attachment 3: Proposed Well Schematic for CD4 -215L1 and CD4 -215L1-01 laterals Page 6 of 6 February 25, 2020 \ �)00u .Fin «r � :a. ,§ 2 0 ( AmoS)RWlloN/(glns ) / ) \ § ( ( } Con Philli s oco p ConocoPhillips Alaska Inc WNS Western North Slope CD4 Nanuq Pad CD4 -215 CD4 -215L1 Plan: CD4 -2151-1 wp05 (Draft A) Standard Planning Report 13 February, 2020 Baker Hughes ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD4 Nanuq Pad Well: CD4 -215 Wellbore: CD4 -2151-1 Design: CD4 -2151-1 wp05 (Draft A) ConocoPhillips Planning Report Baker Hughes Local Co-ordinate Reference: Well CD4 -215 TVD Reference: Mean Sea Level MD Reference: CD4 -215: @ 56.55usft (CD4 -215:) North Reference: True Survey Calculation Method: Minimum Curvature Project Western North Slope, 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 CD4 Nanuq Pad Site Position: Northing: 5,957,526.10 usft Latitude: 70° 17' 32.966 N From: Map Easting: 378,174.70 usft Longitude: 150° 59' 10.763 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.93 ° Well CD4 -215 Well Position +N/ -S 0.00 usft Northing: 5,957,460.92 usft Latitude: 70° 17' 32.281 N +E/ -W 0.00 usft Easting: 377,902.36 usft Longitude: 150° 59' 18.669 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 19.80 usft Wellbore CD4 -215L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (I (nT) BG G M 2018 12/31/2019 15.87 80.71 57,362 Design CD4 -2151-1 wp05 (Draft A) Audit Notes: Version: Phase: PLAN Tie On Depth: 9,578.27 Vertical Section: Depth From (TVD) +N1 -S +E/ -W Direction (usft) (usft) (usft) (I -19.80 0.00 0.00 330.00 2113/2020 9:02:37PM Page 2 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Planning Report Baker Hughes Database: EDT 14 Alaska Producti Company: ConocoPhillips Alaska I Project: Western North Slope Site: CD4 Nanuq Pad Well: CD4 -215 Wellbore: CD4 -2151.1 Design: CD4 -2151-1 wp05 (Draft Plan Sections Measured Build Turn Depth Inclination Azimuth (usft) (1) (1) 9,578.27 85.29 152.68 9,600.00 84.91 152.74 9,621.00 81.97 152.74 9,651.00 68.47 152.74 9,681.00 59.31 163.81 9,711.00 60.24 179.41 9,858.00 106.09 228.89 10,058.00 90.00 318.89 10,360.00 90.00 340.03 10,750.00 90.00 359.53 11,350.00 90.00 329.53 11,800.00 90.00 352.03 12,300.00 90.00 327.03 12,800.00 90.00 352.03 13,400.00 90.00 322.03 13,600.00 90.00 332.03 14,000.00 99.85 349.52 on nc_WNS A) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: TVD Below Build Turn System +N/ -S +E/ -W (usft) (usft) (usft) 6,163.38 -4,184.64 -3,794.07 6,165.24 -4,203.88 -3,784.14 6,167.64 -4,222.42 -3,774.59 6,175.27 -4,248.15 -3,761.33 6,188.50 -4,273.06 -3,751.30 6,203.67 -4,298.58 -3,747.55 6,221.84 -4,422.95 -3,806.83 6,186.55 -4,407.46 -3,982.72 6,186.55 -4,148.83 -4,135.31 6,186.55 -3,766.87 -4,204.17 6,186.55 -3,195.19 -4,362.40 6,186.55 -2,772.99 -4,509.59 6,186.55 -2,308.27 -4,683.06 6,186.55 -1,843.55 -4,856.54 6,186.55 -1,297.42 -5,088.02 6,186.55 -1,129.84 -5,196.73 6,151.99 -755.63 -5,327.69 Well CD4 -215 Mean Sea Level CD4 -215: @ 56.55usft (CD4 -215:) True Minimum Curvature Dogleg Build Turn Rate Rate Rate ('1100usft) (°1100usft) (°/100usft) 0.00 0.00 0.00 1.77 -1.75 0.28 14.00 -14.00 0.00 45.00 -45.00 0.00 45.00 -30.54 36.89 45.00 3.12 52.00 45.00 31.19 33.66 45.00 -8.05 45.00 7.00 0.00 7.00 5.00 0.00 5.00 5.00 0.00 -5.00 5.00 0.00 5.00 5.00 0.00 -5.00 5.0D 0.00 5.00 5.00 0.00 -5.00 5.00 0.00 5.00 5.00 2.46 4.37 TFO 0.00 171.06 180.00 180.00 135.00 90.00 53.00 90.00 90.00 90.00 -90.00 90.00 -90.00 90.00 -90.00 90.00 60.00 Target 2113/2020 9:02:37PM Page 3 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Planning Report Baker Hughes P Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD4 Nanuq Pad Well: CD4 -215 Wellbore: CD4 -2151-1 Design: CD4 -2151-1 wp05 (Draft A) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well CD4 -215 Mean Sea Level CD4 -215: @ 56.55usft (CD4 -215:) True Minimum Curvature Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 9.578.27 85.29 152.68 6,163.38 -4,184.64 -3,794.07 -1,726.97 0.00 0.00 5,953,338.80 374,041.15 TIP 9,600.00 84.91 152.74 6,165.24 -4,203.88 -3,784.14 -1,748.60 1.77 171.06 5,953,319.40 374,050.76 KOP 9,621.00 81.97 152.74 6,167.64 -4,222.42 -3,774.59 -1,769.43 14.00 -180.00 5,953,300.71 374,060.01 Start DLS 46.00 TFO 180.00 9,651.00 68.47 152.74 6,175.27 -4,248.15 -3,761.33 -1,798.34 45.00 -180.00 5,953,274.77 374,072.85 Start DLS 46.00 TFO 136.00 9,681.00 59.31 163.81 6,188.50 -4,273.06 -3,751.30 -1,824.93 45.00 135.00 5,953,249.71 374,082.47 Start DLS 45.00 TFO 90.00 9,700.00 59.69 173.72 6,198.16 -4,289.08 -3,748.11 -1,840.40 45.00 90.00 5,953,233.63 374,085.39 9,711.00 60.24 179.41 6,203.67 -4,298.58 -3,747.55 -1,848.91 45.00 84.96 5,953,224.12 374,085.81 Start DLS 46.00 TFO 63.00 9,800.00 87.49 210.36 6,228.73 -4,378.87 -3,770.56 -1,906.93 45.00 53.00 5,953,144.23 374,061.49 9,858.00 106.09 228.89 6,221.84 -4,422.95 -3,806.83 -1,926.98 45.00 43.95 5,953,100.74 374,024.52 Start DLS 46.00 TFO 90.00 9,900.00 105.20 248.50 6,210.41 -4,443.84 -3,841.20 -1,927.88 45.00 90.00 5,953,080.42 373,989.82 10,000.00 97.00 293.68 6,190.14 -4,441.46 -3,936.49 -1,878.17 45.00 95.34 5,953,084.35 373,894.58 10,058.00 90.00 318.89 6,186.55 -4,407.46 -3,982.72 -1,825.61 45.00 104.52 5,953,119.09 373,848.92 Start DLS 7.00 TFO 90.00 10,100.00 90.00 321.83 6,186.55 -4,375.12 -4,009.51 -1,784.21 7.00 90.00 5,953,151.86 373,822.66 10,200.00 90.00 328.83 6,186.55 -4,292.93 -4,066.36 -1,684.60 7.00 90.00 5,953,234.96 373,767.15 10,300.00 90.00 335.83 6,186.55 -4,204.42 -4,112.77 -1,584.75 7.00 90.00 5,953,324.20 373,722.19 10,360.00 90.00 340.03 6,186.55 -4,148.83 -4,135.31 -1,525.34 7.00 90.00 5,953,380.14 373,700.56 Start DLS 6.00 TFO 90.00 10,400.00 90.00 342.03 6,186.55 -4,111.00 -4,148.31 -1,486.08 5.00 90.00 5,953,418.17 373,688.17 10,500.00 90.00 347.03 6,186.55 -4,014.66 -4,174.98 -1,389.31 5.00 90.00 5,953,514.93 373,663.08 10,600.00 90.00 352.03 6,186.55 -3,916.35 -4,193.14 -1,295.09 5.00 90.00 5,953,613.51 373,646.51 10,700.00 90.00 357.03 6,186.55 -3,816.84 -4,202.67 -1,204.14 5.00 90.00 5,953,713.16 373,638.60 10,750.00 90.00 359.53 6,186.55 -3,766.87 -4,204.17 -1,160.11 5.00 90.00 5,953,763.14 373,637.91 Start DLS 6.00 TFO -90.00 10,800.00 90.00 357.03 6,186.55 -3,716.89 -4,205.68 -1,116.08 5.00 -90.00 5,953,813.13 373,637.22 10,900.00 90.00 352.03 6,186.55 -3,617.38 -4,215.21 -1,025.14 5.00 -90.00 5,953,912.78 373,629.31 11,000.00 90.00 347.03 6,186.55 -3,519.07 -4,233.37 -930.92 5.00 -90.00 5,954,011.35 373,612.75 11,100.00 90.00 342.03 6,186.55 -3,422.73 -4,260.04 -834.15 5.00 -90.00 5,954,108.11 373,587.65 11,200.00 90.00 337.03 6,186.55 -3,329.07 -4,295.00 -735.56 5.00 -90.00 5,954,202.32 373,554.22 11,300.00 90.00 332.03 6,186.55 -3,238.82 -4,337.99 -635.91 5.00 -90.00 5,954,293.25 373,512.70 11,350.00 90.00 329.53 6,186.55 -3,195.19 -4,362.40 -585.92 5.00 -90.00 5,954,337.27 373,489.01 Start DLS 6.00 TFO 90.00 11,400.00 90.00 332.03 6,186.55 -3,151.55 -4,386.80 -535.92 5.00 90.00 5,954,381.29 373,465.32 11,500.00 90.00 337.03 6,186.55 -3,061.30 -4,429.79 -436.27 5.00 90.00 5,954,472.22 373,423.80 11,600.00 90.00 342.03 6,186.55 -2,967.64 -4,464.75 -337.68 5.00 90.00 5,954,566.42 373,390.37 11,700.00 90.00 347.03 6,186.55 -2,871.30 -4,491.42 -240.91 5.00 90.00 5,954,663.18 373,365.28 11,800.00 90.00 352.03 6,186.55 -2,772.99 -4,509.59 -146.69 5.00 90.00 5,954,761.76 373,348.71 Start DLS 6.00 TFO -90.00 11,900.00 90.00 347.03 6,186.55 -2,674.69 -4,527.75 -52.47 5.00 -90.00 5,954,860.34 373,332.14 12,000.00 90.00 342.03 6,186.55 -2,578.34 -4,554.42 44.30 5.00 -90.00 5,954,957.10 373,307.05 12,100.00 90.00 337.03 6,186.55 -2,484.69 -4,589.3E 142.89 5.00 -90.00 5,955,051.30 373,273.62 12,200.00 90.00 332.03 6,186.55 -2,394.44 -4,632.37 242.54 5.00 -90.00 5,955,142.23 373,232.10 12,300.00 90.00 327.03 6,186.55 -2,308.27 -4,683.06 342.51 5.00 -90.00 5,955,229.20 373,182.82 Start DLS 6.00 TFO 90.00 12,400.00 90.00 332.03 6,186.55 -2,222.11 -4,733.76 442.47 5.00 90.00 5,955,316.16 373,133.53 2/13/2020 9:02:37PM Page 4 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Planning Report Baker Hughes Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well CD4 -215 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Mean Sea Level Project: Western North Slope MD Reference: CD4 -215: @ 56.55usft (CD4 -215:) Site: CD4 Nanuq Pad North Reference: True Well: CD4 -215 Survey Calculation Method: Minimum Curvature Wellbore: CD4 -2151-1 Depth Inclination Design: CD4 -2151-1 wp05 (Draft A) +N1 -S +E/ -W Planned Survey Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 14,000.00 6,151.99 2-3/8" Measured +E/ -W TVD Below (usft) (usft) Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N1 -S +E/ -W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 12,500.00 90.00 337.03 6,186.55 -2,131.86 -4,776.75 542.13 5.00 90.00 5,955,407.10 373,092.02 12,600.00 90.00 342.03 6,186.55 -2,038.20 13,811.71 640.72 5.00 90.00 5,955,501.30 373,058.59 12,700.00 90.00 347.03 6,186.55 -1,941.86 -4,838.37 737.49 5.00 90.00 5,955,598.06 373,033.49 12,800.00 90.00 352.03 6,186.55 -1,843.55 -4,856.54 831.70 5.00 90.00 5,955,696.63 373,016.92 Start DLS 5.00 TFO -90.00 13,400.00 6,186.55 -1,297.42 -5,088.02 Start DLS 5.00 TFO 90.00 13,600.00 6,186.55 -1,129.84 12,900.00 90.00 347.03 6,186.55 -1,745.25 -4,874.71 925.92 5.00 -90.00 5,955,795.21 373,000.36 13,000.00 90.00 342.03 6,186.55 -1,648.90 -4,901.37 1,022.69 5.00 -90.00 5,955,891.97 372,975.26 13,100.00 90.00 337.03 6,186.55 -1,555.25 -4,936.33 1,121.28 5.00 -90.00 5,955,986.17 372,941.83 13,200.00 90.00 332.03 6,186.55 -1,465.00 -4,979.32 1,220.94 5.00 -90.00 5,956,077.11 372,900.32 13,300.00 90.00 327.03 6,186.55 -1,378.84 -5,030.02 1,320.90 5.00 -90.00 5,956,164.07 372,851.03 13,400.00 90.00 322.03 6,186.55 -1,297.42 -5,088.02 1,420.41 5.00 -90.00 5,956,246.41 372,794.36 Start DLS 5.00 TFO 90.00 13,500.00 90.00 327.03 6,186.55 -1,216.00 -5,146.03 1,519.93 5.00 90.00 5,956,328.75 372,737.68 13,600.00 90.00 332.03 6,186.55 -1,129.84 -5,196.73 1,619.89 5.00 90.00 5,956,415.72 372,688.40 Start DLS 5.00 TFO 60.00 13,700.00 92.50 336.36 6,184.37 -1,039.86 -5,240.23 1,719.57 5.00 60.00 5,956,506.39 372,646.36 13,800.00 94.98 340.71 6,177.84 -947.03 -5,276.74 1,818.22 5.00 60.09 5,956,599.79 372,611.38 13,900.00 97.44 345.09 6,167.02 -852.04 -5,305.96 1,915.09 5.00 60.38 5,956,695.23 372,583.70 14,000.00 99.85 349.52 6,151.99 -755.63 -5,327.69 2,009.45 5.00 60.85 5,956,791.98 372,563.55 Planned TD at 14000.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 14,000.00 6,151.99 2-3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 9,578.27 6,163.38 -4,184.64 -3,794.07 TIP 9,600.00 6,165.24 -4,203.88 -3,784.14 KOP 9,621.00 6,167.64 -4,222.42 -3,774.59 Start DLS 45.00 TFO 180.00 9,651.00 6,175.27 -4,248.15 -3,761.33 Start DLS 45.00 TFO 135.00 9,681.00 6,188.50 -4,273.06 -3,751.30 Start DLS 45.00 TFO 90.00 9,711.00 6,203.67 -4,298.58 -3,747.55 Start DLS 45.00 TFO 53.00 9,858.00 6,221.84 -4,422.95 -3,806.83 Start DLS 45.00 TFO 90.00 10,058.00 6,186.55 -4,407.46 -3,982.72 Start DLS 7.00 TFO 90.00 10,360.00 6,186.55 -4,148.83 -4,135.31 Start DLS 5.00 TFO 90.00 10,750.00 6,186.55 -3,766.87 -4,204.17 Start DLS 5.00 TFO -90.00 11,350.00 6,186.55 -3,195.19 13,362.40 Start DLS 5.00 TFO 90.00 11,800.00 6,186.55 -2,772.99 -4,509.59 Start DLS 5.00 TFO -90.00 12,300.00 6,186.55 -2,308.27 13,683.06 Start DLS 5.00 TFO 90.00 12,800.00 6,186.55 -1,843.55 -4,856.54 Start DLS 5.00 TFO -90.00 13,400.00 6,186.55 -1,297.42 -5,088.02 Start DLS 5.00 TFO 90.00 13,600.00 6,186.55 -1,129.84 -5,196.73 Start DLS 5.00 TFO 60.00 14,000.00 6,151.99 -755.63 -5,327.69 Planned TD at 14000.00 2/13/2020 9:02.37PM Page 5 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Anticollision Report Baker Hughes Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Reference Site: CD4 Nanuq Pad Site Error: 0.00 usft Reference Well: CD4 -215 Well Error: 0.00 usft Reference Wellbore CD4 -2151_1 Reference Design: CD4 -2151_1 wp05 (Draft A) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well CD4 -215 CD4 -215: @ 56.55usft (CD4 -215:) CD4 -215: @ 56.55usft (CD4 -215:) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Reference CD4 -2151_1 wp05 (Draft A) Distance 1,289.31 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Between Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 9,578.27 to 14,000.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum ellipse separation of 3,000.00 usft Error Surface: Combined Pedal Curve Warning Levels Evaluated at: 2.79 Sigma Casing Method: Added to Error Values Survey Tool Program Date 2/13/2020 From To (usft) (usft) Survey (Wellbore) Tool Name Description 79.00 898.00 CD4 -215 Srvy 1 - CB -GYRO -SS (CD4 -215 CB -GYRO -SS Camera based gyro single shot 934.61 9,578.27 CD4 -215 Srvy 2 - MWD+IFR-AK-CAZ-SC MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 9,578.27 14,000.00 CD4 -2151_1 wp05 (Draft A) (CD4 -215L1) MWD OWSG OWSG MWD - Standard Summary Site Name Offset Well - Wellbore - Design CD2 Alpine Pad CD2 -60 - CD2 -60A - CD2 -60A CD2 -60 - CD2 -60A - CD2 -60A CD2 -60 - Copy of Plan: CD2 -601_1 - CD2-601_1wp01 CD2 -60 - Copy of Plan: CD2 -601_1 - CD2-601_1wp01 CD4 Nanuq Pad CD4 -05 - CD4 -05 - CD4 -05 CD4 -05 - CD4 -05 - CD4 -05 CD4 -05 - CD4 -05 - CD4 -05 CD4 -07 - CD4 -07 - CD4 -07 CD4 -07 - CD4 -07 - CD4 -07 CD4 -12 - CD4 -12 - CD4 -12 CD4 -12 - CD4 -12 - CD4 -12 CD4 -12 - CD4 -12 - CD4 -12 CD4 -12 - CD4-12PB1 - CD4-12PB1 CD4 -12 - CD4-12PB1 - CD4-12PB1 CD4 -12 - CD4-12PB1 - CD4-12PB1 CD4 -12 - Nanuq 5 - Nanuq 5 CD4 -16 - CD4 -16 - CD4 -16 CD4 -17 - CD4 -17 - CD4 -17 CD4 -208 - CD4 -208 - CD4 -208 CD4 -208 - CD4 -208A - CD4 -208A CD4 -208 - CD4-208AL1 - CD4-208AL1 CD4 -208 - CD4-208APB1 - CD4-208APB1 CD4 -208 - CD4-208PB1 - CD4-208PB1 CD4 -209 - CD4 -209 - CD4 -2D9 CD4 -210 - CD4 -210 - CD4 -210 CD4 -210 - CD4 -210A - CD4 -210A CD4 -210 - CD4-210APB1 - CD4-210APB1 CD4 -210 - CD4 -2108 - CD4 -210B CD4 -211 - CD4 -211 - CD4 -211 CD4 -211 - CD4 -211 L1 - CD4 -211 L1 C D4-211 - C D4-211 L 1 -0 1 - C D4-211 L 1-01 CD4 -213 - CD4 -213 - CD4 -213 CD4 -213 - CD4 -213A - CD4 -213A Reference Offset Distance 1,289.31 Measured Measured Between Between Separation Warning Depth Depth Centres Ellipses Factor (usft) (usft) (usft) (usft) 13,954.48 21,001.00 1,286.79 1,165.19 10.582 CC, ES 14,000.00 20,925.00 1,306.92 1,182.26 10.484 SF 13,924.64 21,054.87 1,282.23 1,187.84 13.584 CC, ES 14,000.00 20,925.00 1,307.08 1,208.65 13.279 SF 13,677.51 8,550.00 1,404.35 1,289.31 12.208 CC 13,705.15 8,725.00 1,414.02 1,281.49 10.670 ES 13,751.18 9,300.00 1,587.57 1,409.00 8.891 SF Out of range Out of range 9,76D.00 9,550.00 1,413.81 1,288.65 11.296 CC 9,760.00 9,575.00 1,413.94 1,288.28 11.252 ES 9,78D.00 9,775.00 1,430.09 1,301.08 11.085 SF 9,760.00 9,550.00 1,413.81 1,288.65 11.296 CC 9,760.00 9,575.00 1,413.94 1,288.28 11.252 ES 9,780.00 9,775.00 1,430.09 1,301.08 11.085 SF Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 211412020 10:44:05AM Page 2 COMPASS 5000.14 Build 85H Summary ConocoPhillips ConocoPhillips Anticollision Report Baker Hughes Company: ConocoPhillips Alaska Inc_WNS Local Co-ordinate Reference: Well CD4 -215 Project: Western North Slope TVD Reference: CD4 -215: @ 56.55usft (CD4 -215:) Reference Site: CD4 Nanuq Pad MD Reference: CD4 -215: @ 56.55usft (CD4 -215:) Site Error: 0.00 usft North Reference: True Reference Well: CD4 -215 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 2.00 sigma Reference Wellbore CD4 -215L1 Database: EDT 14 Alaska Production Reference Design: CD4 -2151-1 wp05 (Draft A) Offset TVD Reference: Offset Datum 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) CD4 Nanuq Pad CD4 -213 -CD4 -2138 -CD4 -213B 12,542.92 8,600.00 806.98 710.44 8.359 CC CD4 -213 - CD4 -213B - CD4 -213B 12,549.50 8,700.00 812.25 705.19 7.587 ES CD4 -213 - CD4 -2138 - CD4 -2138 12,565.87 8,975.00 886.41 756.53 6.825 SF CD4 -213 - CD4-213BPB1 - CD4-213BPB1 12,524.30 8,700.00 653.34 556.47 6.745 CC CD4 -213 - CD4-213BPB1 - CD4-213BPB1 12,533.55 8,775.00 656.98 550.44 6.167 ES CD4 -213 - CD4-213BPB1 - CD4-213BPB1 12,558.01 9,000.00 717.03 587.34 5.529 SF CD4 -213 - CD4-213BPB2 - CD4-213BPB2 12,374.95 8,700.00 621.32 525.66 6.495 CC CD4 -213 - CD4-213BPB2 - CD4-213BPB2 12,400.00 8,775.00 625.61 519.77 5.911 ES CD4 -213 - CD4-213BPB2 - CD4-213BPB2 12,432.19 9,000.00 686.52 558.79 5.375 SF CD4 -214 -CD4 -214 -CD4 -214 9,597.81 8,625.00 1,417.62 1,344.97 19.513 CC, ES CD4 -214 -CD4 -214 -CD4 -214 11,835.17 7,375.00 1,589.13 1,478.87 14.414 SF CD4 -214 -CD4 -2141-1 -CD4-2141-1 wp02 9,651.00 9,550.00 1,082.59 1,003.99 13.774 CC, ES CD4 -214 -CD4 -2141-1 -CD4-2141-1 wp02 13,200.00 12,625.00 1,369.62 1,114.65 5.372 SF CD4 -215 - CD4 -215 - CD4 -215 9,600.00 9,600.00 0.00 -72.09 0.000 STOP Drilling, CC, SF CD4 -215 - CD4 -215 - CD4 -215 9,692.82 9,700.00 23.33 -79.77 0.226 STOP Drilling, ES CD4 -215 -CD4 -215 -CD4 -215 10,879.23 8,950.00 208.91 203.53 38.790 CC CD4 -215 -CD4 -215 -CD4 -215 10,900.00 8,925.00 209.10 203.49 37.218 ES CD4 -215 -CD4 -215 -CD4 -215 12,100.00 7,350.00 1,069.37 1,037.61 21.044 SF CD4 -215 - CD4 -2151-1 - CD4 -2151-1 wp05 (DraftA) 9,975.00 9,975.00 0.00 -69.14 0.000 STOP Drilling, CC CD4 -215 - CD4 -2151-1 - CD4 -2151-1 wp05 (Draft A) 13,400.00 13,400.00 0.00 -262.96 0.000 STOP Drilling, SF CD4 -215 - CD4 -2151-1 - CD4 -2151-1 wp05 (Draft A) 14,000.00 14,000.00 0.00 -296.11 0.000 STOP Drilling, ES CD4 -215 - CD4 -2151-1-01 - CD4 -2151-1-01 wp01 (DraftA 9,950.00 9,950.00 0.00 -127.48 0.000 STOP Drilling, SF CD4 -215 - CD4 -2151-1-01 - CD4 -2151-1-01 wp01 (Draft A 9,975.00 9,975.00 0.00 -69.14 0.000 STOP Drilling, CC CD4 -215 -CD4 -2151-1-01 -CD4-2151-1-01 wp01 (DraftA 13,981.01 13,975.00 5.94 -274.99 0.021 STOP Drilling, ES CD4 -215 - CD4 -2151-1-01 - CD4 -2151-1-01 wp01 (DraftA 13,961.01 13,975.00 5.94 -225.81 0.026 STOP Drilling, CC, ES, SF CD4 -23 - CD4 -23 - CD4 -23 12,404.08 8,575.00 166.98 69.59 Caution Monitor Closely, CC CD4 -23 - CD4 -23 - CD4 -23 12,412.57 8,625.00 177.16 58.76 �496 Take Immediate Action, Ebb CD4 -23 - CD4 -23 - CD4 -23 12,416.27 8,650.00 186.95 61.13 Take Immediate Action, SF/ CD4 -23 -CD4-23P61 -CD4-23PB1 11,533.81 8,525.00 127.97 46.64 Caution Monitor Closely, CC CD4 -23 - CD4-23PB1 - CD4-23PB1 11,537.47 8,500.00 130.12 41.04 1.461 Take Immediate Action, ES CD4 -23 - CD4-23PB1 - CD4-23PB1 11,541.26 8,475.00 136.82 42.21 1.446 Take Immediate Action, SF CD4 -23 - CD4-23PB2 - CD4-23PB2 12,404.08 8,575.00 166.98 69.59 1.714 Caution Monitor Closely, CC CD4-23-CD4-23PB2-CD4-23PB2 12,412.57 8,625.00 177.16 58.76 1.496 Take Immediate Action, ES CD4-23-CD4-23PB2-CD4-23PB2 12,416.27 8,650.00 186.95 61.13 1.486 Take Immediate Action, SF CD4 -24 - CD4 -24 - CD4 -24 Out of range CD4 -24 - CD4-24PB1 - CD4-24PB1 Out of range CD4 -24 - CD4-24PB2 - CD4-24PB2 Out of range CD4 -25 - CD4 -25 - CD4 -25 Out of range CD4 -25 - CD4 -251-1 - CD4 -251-1 Out of range CD4 -25 - CD4-25PB1 - CD4-25PB1 Out of range CD4 -26 - CD4 -26 - CD4 -26 Out of range CD4 -27 - CD4 -27 - CD4 -27 Out of range CD4 -27 - CD4-27PB1 - CD4-27PB1 Out of range CD4 -27 - CD4-27PB2 - CD4-27PB2 Out of range CD4 -27 - CD4-27PB3 - CD4-27PB3 Out of range CD4 -291 - CD4 -291 - CD4 -291 Actual Out of range CD4 -304 - CD4 -304 - CD4 -304 Out of range CD4 -304 - CD4-304PB1 - CD4-304PB1 Out of range CD4 -306 - CD4 -306 - CD4 -306 Out of range CD4 -318 - CD4 -318 - CD4 -318 Out of range CD4 -318 - CD4 -318A- CD4 -318A Out of range CD4 -318 - CD4-318PB1 - CD4-318PB1 Out of range CD4 -319 - CD4 -319 - CD4 -319 11,957.30 14,975.00 898.68 825.15 12.220 CC CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 2/14/2020 10:44.05AM Page 3 COMPASS 5000.14 Build 85H Summary ConocoPhillips ConocoPhillips Anticollision Report Baker Hughes Company: ConocoPhillips Alaska Inc_WNS Local Co-ordinate Reference: Well CD4-215 Project: Western North Slope TVD Reference: CD4-215: @ 56.55usft (CD4-215:) Reference Site: CD4 Nanuq Pad MD Reference: CD4-215: @ 56.55usft (CD4-215:) Site Error: 0.00 usft North Reference: True Reference Well: CD4-215 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 2.00 sigma Reference Wellbore CD4-2151-1 Database: EDT 14 Alaska Production Reference Design: CD4-2151-1 wp05 (Draft A) Offset TVD Reference: Offset Datum Summary CD2 Alpine Pad - CD2 -60 - CD2 -60A- CD2 -60A Reference Offset Distance Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Offset Wellbore Centra CD4 Nanuq Pad Between Minimum Separation Warning Depth Depth Depth CD4 -319 - CD4 -319 - CD4 -319 13,554.86 16,550.00 906.76 821.27 10.607 ES CD4 -319 - CD4 -319 - CD4 -319 13,978.69 17,150.00 950.40 857.93 10.277 SF CD4 -320 - CD4 -320 - CD4 -320 (°) (usft) (usft) (usft) Out of range CD4 -320 - CD4 -320 - CD4 -320 13,954.48 6,215.90 21,001.00 7,453.49 Out of range CD4 -320 - CD4 -320 - CD4-320wp08 -673.17 -5,631.82 1,286.79 1,165.19 Out of range CD4 -320 - CD4-320PB1 - CD4-320PB1 13,955.02 6,215.82 21,000.00 7,453.54 156.06 200.78 Out of range CD4 -320 - CD4-320PB1 - CD4-320PB1 -5,632.30 1,287.04 1,165.40 121.64 Out of range CD4 -321 - CD4 -321 - CD4 -321 20,975.00 7,454.80 156.50 200.44 -179.02 Out of range CD4 -322 - CD4 -322 - CD4 -322 1,293.45 1,170.81 122.65 10.546 Out of range CD4 -322 - CD4 -322 - CD4 -322 7,457.32 157.56 199.76 -176.84 -606.70 Out of range Nanuq 3 - Nanuq 3 - Nanuq 3 1,182.26 124.66 10.484 SF 14,000.00 6,208.54 Out of range Plan: CD4 -97 - Plan: CD4 -97 - CD4-97wp08 157.56 200.10 -177.13 -628.56 -5,656.41 Out of range Prelim: CD4-xxx (QAN 16-09) - Plan: CD4-xxx (QAN 16-09 123.45 10.533 Out of range CD4 Pad Plan: CD4 -23 - Plan: CD4 -23 - CD4-23wp11 11,542.37 8,500.00 106.16 22.49 1.269 Take Immediate Action, CC Plan: CD4 -23 - Plan: CD4 -23 - CD4-23wp11 11,546.45 8,475.00 108.13 14.36 1.153 Take Immediate Action, ES Plan: CD4 -23 - Plan: CD4 -23 - CD4-23wp11 11,550.66 8,450.00 115.47 14.84 1.147 Take Immediate Action, SF CD5 Alpine West Pad CD5-28 - CD5-961-1 - CD5-96L1 wp02 13,639.60 21,750.00 1,349.27 1,251.95 13.865 CC CD5-28-CD5-961-1-CD5-96L1wp02 13,655.45 21,775.00 1,349.40 1,251.87 13.837 ES CD5-28-CD5-961-1-CD5-96L1wp02 14,000.00 22,325.00 1,396.91 1,292.54 13.384 SF CD5-90-CD5-901-1-CD5-96L1wp02 13,639.60 21,750.00 1,349.27 1,251.95 13.865 CC CD5-90-CD5-901-1-CD5-96L1wp02 13,655.45 21,775.00 1,349.40 1,251.87 13.837 ES CD5-90 - CD5-9011 - CD5-96L1 wp02 14,000.00 22,325.00 1,396.91 1,292.54 13.384 SF CD5-96 - CD5-96L1 -CD5-96L1 wp02 13,639.60 21,750.00 1,349.27 1,251.95 13.865 CC CD5-96 - CD5-96L1 -CD5-96L1 wp02 13,655.45 21,775.00 1,349.40 1,251.87 13.837 ES CD5-96 - CD5-96L1 -CD5-961-1 wp02 14,000.00 22,325.00 1,396.91 1,292.54 13.384 SF Nanuk Nanuk 2 - Nanuk 2 - Nanuk 2 Out of range Offset Design CD2 Alpine Pad - CD2 -60 - CD2 -60A- CD2 -60A Offset Site Error: 0.00 usft Survey Program: 84 -CB -GYRO -SS, 744-MWD+IFR2+SAG+MS, 11756-MWD+IFR2+SAG+MS, 14264-MWD+IFR2+SAG+MS Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Distance Measured Vertical Measured Vertical Reference offset Azimuth Offset Wellbore Centra Between Between Minimum Separation Warning Depth Depth Depth Depth from North +N/-8 +E/ -W Centres Ellipses Separation Factor (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (usft) (usft) (usft) 13,954.48 6,215.90 21,001.00 7,453.49 156.04 200.79 179.99 -673.17 -5,631.82 1,286.79 1,165.19 121.60 10.582 CC, ES 13,955.02 6,215.82 21,000.00 7,453.54 156.06 200.78 -179.97 -672.30 -5,632.30 1,287.04 1,165.40 121.64 10.581 13,968.45 6,213.73 20,975.00 7,454.80 156.50 200.44 -179.02 -650.43 -5,644.36 1,293.45 1,170.81 122.65 10.546 14,000.00 6,208.54 20,925.00 7,457.32 157.56 199.76 -176.84 -606.70 -5,668.46 1,306.92 1,182.26 124.66 10.484 SF 14,000.00 6,208.54 20,950.00 7,456.06 157.56 200.10 -177.13 -628.56 -5,656.41 1,300.30 1,176.85 123.45 10.533 CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 2114/2020 10:44:05AM Page 4 COMPASS 5000.14 Build 85H v N d L L71 3 2 L 41 Y O m z�Z$a N !p, 4 NN U �N Ua Q `off wc w do w �0 K c m m � a w w 3r J N d) 3 O) tD @ M Ot Of Of tp ��'Y � Of t0 vi A C Gb Q N tP OO O) tq @ to t0 tf9 h O iL1 t0 N to W N p 7 ' m Op O) OO tO r �! • M ft) ^ 4 N lA o �ot0000000000000000 0 0 0 0 0 0 ,n 0 0 0 0 0 0 0 0 0 0 0 tti°o oouiCZ, ri0000000000 I CO W MO) I O) O) O) C� m O1 O) T O t.O rno r— Cl 0 0 0 0 0 0 0 0 0 Cl 0 0 0 0 Z2 R r-: 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 'DO QOr V ICY a'Cf C A� Mtl) X11) N J M f` V O) M O tD M N ti O 01 tD V N M O V Q O LQ M M UD CC! r— M VLj� O�O r-( O LL, -cr V'-�t titoN lf)�NmM to U + O CO n t 0 t O V 0 .0 M O cc O o 0 t D O 0 W N tit - r- MM NM 1 CO OO—M C? M M tM M CEJ M M -T mr -7 -T to to Q? '-t w04 rD tD oO �tOM N00 ti tD N ctM CR CR V �O U'7 O) V'OO O� ON UO V CO(D e- C-5 00 M 00 N N Ln CO m f✓O) t Z tD O cm:' -0-to N� C M N + N N N N�t� u N �N Yui V Y V'T 'T CMMNN- w J � M - -:r ( V V ti O ti C to ti tD to Lq UD N to Ut) 01 N D N to tD CO l[) LC) UD tD tD U7 4') O to 0) M lL)� tONMrO to to CO co tD ID CD Oo ZE tD tD tD NNO OD O OD oO OD W O W tD W M N CO co O tD 10 CO tO tD C.0 (D to tD co CIOtD tD fD Q C 0) OO -�t V r O) 0) M M M M M M M M N J p Q (O ti� r` OO V W N O tD Ul O O O O O Uc W Z� NNCV NC) W 00000O1 O1 tV I�NNCV O) tO qr N tDN U) Mcr �e �::N N M C') M M M M M M M M N 0 C N O d7 d' M 0 0 0 0 0 0 0 0 (=, cO r D 06 m0 L6 0 0 0 0 0 0 0 0 0 01 00 w 00 CD to cc O 0) m O1 O O W m O O1 00 Q r-0000000 00 0000000 o N o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0o000000ci0000 000 N O Nt f) O D t D L) t D l! 7 t 0 0 0 O O O O tO to cO cO tD f• CO O M r� M C0 M 00 V co 0 mm 1 01 O O) 0 Oa' O O_ N_ N_ _M M_ d- t/l 00 ��NM V to lD N00 OOH NM V tD tO C` d) 3 ConocoPhillips Alaska, Im. •• Well Coy HANGER, 31 CONDUCTOR 46` Insulated, 37-114 SAFETY VLV, 2,142 SURFACE, 37-2,854 GAS LIFT, 4,355 GAS LIFT, 8,115 PACKER, 8,204 NIPPLE, 8,283 WLEG, 9,351 11,566.11,627 SLOTS, SLOTS, 13,79314,280 NNS PROD CD4 -215 Well Attributes Bottom .flax An le & MD ITD Wellbo-A 1UWI Field Name Top Depth Wellbore Status Incl (°) MD (ftKB) Act Btm (ftKB) 501032053900 NANUQ (TVD) (TVD) PROD Bum (ftKB) (ftKB) 14,761.0 Comment Data HIS (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Data SSSV: TRDP 6,212.1 11/23/2006 16.0 Last WO: Alternating solid/slotted pipe 43.78 12/25/2006 Annotation Depth (ftKB) End Date Annotation CARBOLITE WORKING UP FROM 1 ppa TO 12 ppa Last Mod By End Date Last Tag: 10,800.0 7/11/2008 Rev Reason: WELL REVIEW osborl 9/5/2013 4/22/2007 6.0 APERF 2.5' Hyperjet Charges, 60 deg orient 10,550.0 10,733.0 6,231.1 Gasin _Strinvis 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wu... String ... String Top Thrd CONDUCTOR 46" 16 15.250 37.0 114.0 114.0 65.00 H40 WELDED Insulated Casing Description String 0... String ID ... Top (ftKB) Set Depth If Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 36.8 2,854.2 2,392.2 40.00 L-80 Buttress Casing Description String 0... String ID ... Top (ftKB) Set Depth if Set Depth (TVD) ... String Wt... String ... String Top Thrd INTERMEDIATE 7 6.276 34.6 9,514.5 6,215.9 26.00 L-80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth If Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 31/2 2.992 9,361.0 14,675.0 6,212.0 9.30 L-80 SLHT (TVD)Topincl Norm - Teo Ifticel (ftKB) (°) Item Description Comment ID (in) Ing 0 iString ID... ITop (ftKB) Set Depth if Set Depth (TVD) ...I String Wt.. String ... IString Top Thrd 31/2 2.992 31.4 9,379.6 6,194.8 9.30 1 L-80 EUE8rdMOD 6 _ °"s.Incl N3 (In escriotlon Comment �ID (In) I I I I ITUBING TO NORMAL 3.5' TUBING I I 5,,, (TVD) Incl OD Valve Latch Size TRO Run N... Top(ftKB) (ftKB) (°) Make Model (In) Sery Type Type (in) (psi) Run Date Com... 11 4,354.5 3,420.5 43.11 CAMCO KBMG I 1 GAS LIFT IDMY BK -5 10.0001 0.0 7/29/2008 21 8,115.11 5,814.5 60.72 CAMCO KBMG I 1 GAS LIFT IOV BK -5 10.2501 0.017/29/2008 Bottom Shot Min Top Max Btm Top Depth Depth Top (TVD) Bun (TVD) Depth Dens (TVD) (TVD) Top (ftKB) Bum (ftKB) (ftKB) (ftKB) Zone Data (sh••• Type Comment 9,501.0 9,712.0 6,215.4 6,230.3 6,212.1 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe CARBOLITE WORKING UP FROM 1 ppa TO 12 ppa w/0.125" x2 .25' slots 9,555.0 9,575.0 6,218.2 6,219.7 4/22/2007 6.0 APERF 2.5' Hyperjet Charges, 60 deg orient 10,550.0 10,733.0 6,231.1 6,219.1 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125' x2 .25' slots 10,857.0 11,039.0 6,217.6 6,226.4 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 11,566.0 11,627.0 6,246.6 6,244.7 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125' x2.25" slots 12,184.0 12,730.0 6,221.3 6,211.7 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125' x2.25" slots 12,852.0 13,395.0 6,218.6 6,225.1 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2.25' slots 13,549.0 13,638.0 6,234.1 6,240.3 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125' x2.25" slots 13,793.0 14,280.0 6,248.4 6,246.7 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2.25" slots 14,342.0 14,403.0 6,243.1 6,238.7 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2.25" slots 14,497.0 14,673.0 6,231.0 6,212.1 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0. 125" x2.25" slots 5,,, (TVD) Incl OD Valve Latch Size TRO Run N... Top(ftKB) (ftKB) (°) Make Model (In) Sery Type Type (in) (psi) Run Date Com... 11 4,354.5 3,420.5 43.11 CAMCO KBMG I 1 GAS LIFT IDMY BK -5 10.0001 0.0 7/29/2008 21 8,115.11 5,814.5 60.72 CAMCO KBMG I 1 GAS LIFT IOV BK -5 10.2501 0.017/29/2008 Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) T e Date Comment 10,550.0 14,673.0 6,231.1 6,212.1 FRAC 4/25/2007 FRAC NANUQ FORMATION 310,00020/40 CARBOLITE WORKING UP FROM 1 ppa TO 12 ppa ON FORMATION. 5,,, (TVD) Incl OD Valve Latch Size TRO Run N... Top(ftKB) (ftKB) (°) Make Model (In) Sery Type Type (in) (psi) Run Date Com... 11 4,354.5 3,420.5 43.11 CAMCO KBMG I 1 GAS LIFT IDMY BK -5 10.0001 0.0 7/29/2008 21 8,115.11 5,814.5 60.72 CAMCO KBMG I 1 GAS LIFT IOV BK -5 10.2501 0.017/29/2008 lu m m � w w m 111 ; III III III 111 I III III + III III j III III la III 111 III i ' III III III III 111 III III III � 111 III � 111 111 1 III III ' 111 Iil � 111 nl � In Itl ' III nl m ul w III Iil III � 111 III � � Ifi III I � III III � I III lu 1 ; nl lu i � lu III , � IIII/I III ' I Y m III I i � III ul al N_ W m � o w 0 p m m y 0 `t' ti aNi m co ti tmY C� N mmrn SCE@ E CO N N M od N tT M 2' a /���` V 2 N Y M_ b Ow 0 x rn o @) m N > n.S ID E N W u. Yco U` Z o O X N N @) O Z V5 '.0 Food � C7 n C7 0)c CO) > J 2 n i wC— N X rnrn > Cl- c11fLL 0 0 z o N N E CV E Y w (6 J Y Y ca N N W 0d' ca c6 c� c� U 00 U m 2 J S m CO lu m m � w w m 111 ; III III III 111 I III III + III III j III III la III 111 III i ' III III III III 111 III III III � 111 III � 111 111 1 III III ' 111 Iil � 111 nl � In Itl ' III nl m ul w III Iil III � 111 III � � Ifi III I � III III � I III lu 1 ; nl lu i � lu III , � IIII/I III ' I Y m III I i � III ul al TRANSMITTAL LETTER CHECKLIST WELL NAME: C g u, PTD: ago -oma ✓ Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: Coy i I te, R i ver— POOL: %/a h. u q © 1 Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit No. x.06'—hr API No. 50- AQ3-Zp�'3q -Qo-_00 (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Spacing Approval to produce/inject is contingent upon issuance of a Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non- production or production testing of coal bed methane is not allowed for Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool COLVILLE RIVER, NANUQ OIL - 120175 PTD#: 2200210 Company ConocoPhllips Alaska, Inc. Initial Class/Type Well Name: COLVILLE RIV NAWN CD4 -215L1 Program DEV _ Well bore seg ❑�/ DEV/PEND GeoArea 890 Unit 50360 On/Off Shore On Annular Disposal ❑ Administration 1 Permit_fee attached NA - 2 Lease number appropriate--------------- Yes --------------------------------------------------------- 3 Unique Well _ name and number - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 4 Well located in a -defined pool - - - - - - - - - - - - - - - - - - - - - - - -------- _ _ _ _ _ -Yes - - -------------------------------------------------------------------------- 5 Well located proper distance from_ drilling unit -boundary -- - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - - - - - - - - - - - - 6 Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - _ _ _ - _ - - _ _ _ _ - _ _ _ _ - _ - _ - - - - - - - - - - - - - 7 Sufficient acreage available in -drilling unit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ - _ _ - - _ _ - _ _ _ _ _ _ - - - - - - - - - - - _ - - _ 8 -if-deviated, is wellbore plat _inc luded - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - _ _ _ _ Directional_plan view and well bore -profile included. - - - - - - - - - - - - - - - - - - 9 Operator only affected party- - - - - - - - - - - - - - - - - - - - - - - ---------- - - - - -- Yes----------------------------------------------------- 10 Operator has -appropriate _bond inforce --------------------------------- 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-daywait-------------------------------- Yes - - - - - - - - --- - - DLB 3/4/2020 _ _ _ - - _ - --------------------------- 14 Well located within area and strata authorized by Injection Order # (put 10# in_comments)_(For_ NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 All wells -within 1/4 mile area of review identified (For service well only)- - - - - - - - - - - - - - - NA_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ - - - _ 16 Pre -produced injector: duration of pre production less than- 3 months- (For service well only) - _ NA_ 17 Nonconven. gas conforms to AS31.05 030Q.1.A),(j 2.A -D) - - - - - - - - - - - - - - - - - - - - - - NA_ - - 18 Conductor string -provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - - - - - - - Conductor set_for_CD4-215 - - - - - - - - - Engineering 19 Surface casing_p-mtects all known USDWs - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ - - - - _ - Surface casing set for CD4 -215 - - - - - - - - - - - - - - - - - - - - - - 20 CMT_voladequate_to circulate -on conductor & surf_csg NA_ - _ _ _ _ _ _ Surface casing set and fully_cemented - - - - - - - - - - - - - - - - - - - - - - - - - - 21 CMT_voladequate_to tie -in -long string to surf csg--------------- - - - - - - - - - - NA_ - _ - _ _ _ _ _ - _ _ _ _ - - _ - _ _ - - - _ _ - _ - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - 22 CMT -will cover all known -productive horizons - - - - - - - - - - - - - - - - - - - - - - - - - - - - - No_ _ _ _ _ _ _ - Productive interval will be completed with -uncemented slotted_ liner_ 23 Casing designs adequate for C, T, B &_permafr_ost_ - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate tankage or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Rig has steel tanks; all_waste_to approved disposal welss _ _ _ _ _ _ _ _ _ _ _ _ _ 25 Ifa_re-drill, has_a 10-403 for abandonment been approved - _ - - - - - - _ _ NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 26 Adequate wellbore separation proposed - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Anti -collision analysis complete; _major risk failure CD4 -23 in reservoir - - - _ _ - - - _ - _ - - - - - - - - - - - 27 If diverter required, does it meet regulations- - - - - - - - - - - - - - - - - _ - - - - NA_ - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ _ - _ _ _ _ _ _ _ _ _ _ - - - - _ _ _ - - _ _ - - - _ - - - - - - - - - _ - Appr Date 28 Drilling fluid_ program schematic -&- equip list -adequate -_ - _ - - - - - - - Yes - Max reservoir pressure is 3636_psig(11.2_ppg EMW);-will drill w/ 8.6 ppg EMW and maintain_overbal w/ MPD - _ - VTL3/6/2020 29 BOPEs,dotheymeetregulation---------------- --- - - - - ------- - - - - -- Yes--- ----------------------------------------------------------------- 30 BOPE-press rating appropriate; test to -(put psig in comments)- - - - - - - - Yes _ - _ _ _ _ - MPSP is 3014 psig; will test BOPs_to 3500_psig- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 31 Choke -manifold complies w/API_RP-53 (May 84)- - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - No_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ - _ - - _ 33 Is presence -of H2S gas probable- - _ - - - - - - - - - - - - - - No _ -------------------------------------------- 34 Mechanical -condition of wells within AOR verified (For service well only_) _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- - - _ - - - _ - _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ - - - - - 35 Permit can be issued w/o hydrogen_ sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ - - - 1-12$ not encountered in offset wells._ However, rigwill be equipped with operational sensors/alarms. Geology 36 Data_presented on potential overpressure zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ - _ _ - _ - _ _ - - - _ - _ - - - - ------------------------------------------- Appr Date 37 Seismic analysis_ of shallow gas -zones - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - _ _ _ _ - _ _ - _ _ _ _ _ - - - - - - - - - - - _ - - _ DLB 3/4/2020 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 ommis er Dat 3� a©
