The URL can be used to link to this page

Home My WebLink About218-074DATA SUBMITTAL COMPLIANCE REPORT 2/25/2020 Permit to Drill 2180740 Well Name/No. KUPARUK RIV UNIT 1F-071-1-01 Operator ConocoPhillips Alaska, Inc. API No. 50-029-20830-61-00 MD 9846 TVD 6017 Completion Date 11/6/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log No y/ Samples No o/ Directional Survey Yes DATA INFORMATION List of Logs Obtained: GR/Res (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 31487 Digital Data 11/22/2019 Electronic File: 1F-071-1-01 EOW - NAD27.pdf ED C 31487 Digital Data 11/22/2019 Electronic File: 1F-071_1-01 EOW - NAD27.txt ED C 31487 Digital Data 11/22/2019 Electronic File: 1F-071-1-01 EOW NAD83.pdf ED C 31487 Digital Data 11/22/2019 Electronic File: 1F-071_1-01 EOW NAD83.txt Log 31487 Log Header Scans 0 0 2180740 KUPARUK RIV UNIT 1F-071-1-01 LOG HEADERS ED C 31641 Digital Data 7059 9846 12/13/2019 Electronic Data Set, Filename: 1F-071-1-01 GAMMA RES.Ias ED C 31641 Digital Data 12/13/2019 Electronic File: 1F-071-1-01 2MD Final.cgm ED C 31641 Digital Data 12/13/2019 Electronic File: 1F -07L1-01 5MD Final.cgm ED C 31641 Digital Data 12/13/2019 Electronic File: 1 F -07L1-01 5TVDSS Final.cgm ED C 31641 Digital Data 12/13/2019 Electronic File: 1F-071-1-01 21VID Final.pdf ED C 31641 Digital Data 12/13/2019 Electronic File: 1F-071-1-01 51VID Final.pdf ED C 31641 Digital Data 12/13/2019 Electronic File: 1F-071-1-01 5TVDSS Final.pdf ED C 31641 Digital Data 12/13/2019 Electronic File: 1F-071-1-01 EOW - NAD27.pdf ED C 31641 Digital Data 12/13/2019 Electronic File: 1F-071-1-01 EOW - NAD27.txt ED C 31641 Digital Data 12/13/2019 Electronic File: 'IF -071-1-01 Final Surveys TD 9846.csv ED C 31641 Digital Data 12/13/2019 Electronic File: 1F-071-1-01 Final Surveys TD 9846.xlsx ED C 31641 Digital Data 12/13/2019 Electronic File: 1F-071-1-01 Survey Listing.txt ED C 31641 Digital Data 12/13/2019 Electronic File: 1F -07L1-01 Surveys.txt AOGCC Page I of 3 Tuesday, February 25, 2020 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2020 Permit to Drill 2180740 Well Name/No. KUPARUK RIV UNIT 1F-071-1-01 Operator ConocoPhillips Alaska, Inc. API No. 50-029-20830-61-00 MD 9846 TVD 6017 Completion Date 11/6/2019 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED C 31641 Digital Data 12/13/2019 Electronic File: 1F-071-1- 01 _25_tapescan_BH I_CTK.txt ED C 31641 Digital Data 12/13/2019 Electronic File: 1F-071-1- 01 _5_tapescan_B H I_CTK.txt ED C 31641 Digital Data 12/13/2019 Electronic File: 1F-071-1-01_output.tap ED C 31641 Digital Data 12/13/2019 Electronic File: 1F-071-1-01 2MD Final.tif ED C 31641 Digital Data 12/13/2019 Electronic File: 1F-071-1-01 5MD Final.tif ED C 31641 Digital Data 12/13/2019 Electronic File: 1F-071-1-01 5TVDSS Final.tif Log 31641 Log Header Scans 0 0 2180740 KUPARUK RIV UNIT 1F-071-1-01 LOG HEADERS Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report Production Test Informatiore/ NA Geologic Markers/Tops G COMPLIANCE HISTORY Completion Date: 11/6/2019 Release Date: 7/3/2018 Description Comments: Interval Start Stop Directional / Inclination Data 0 Mechanical Integrity Test Information Y / NA Daily Operations Summary / Y l Date Comments Sample Set Sent Received Number Comments Mud Logs, Image Files, Digital Data Y /("?" Composite Logs, Image, Data Files E) Cuttings Samples Y 0 Core Chips YgNA Core Photographs Y Laboratory Analyses Y AOGCC Page 2 of 3 Tuesday, February 25, 2020 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2020 Permit to Drill 2180740 Well Name/No. KUPARUK RIV UNIT 1F-071-1-01 Operator ConocoPhillips Alaska, Inc. API No. 50-029-20830-61-00 MD 9846 TVD 6017 Com let' n Date 11/6/2019 Completion Status 1-0I1- Current Status 1-0I1- UIC No Compliance Reviewed By: _- Date: ZU AOGCC Page 3 of 3 Tuesday, February 25, 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil Q - Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1b. Well Class: Development 0 Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 11/6/2019 14. Permit to Drill Number / Sundry: 218-074 " 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 11/3/2019 15. API Number: 50-029-20830-61-00 4a. Location of Well (Governmental Section): Surface: 1331' FNL, 27'✓FWL, Sec 20, T11N, R10E, UM Top of Productive Interval: 2188' FNL, 1691' FEL, Sec 20, T11 N, RI OE. UM Total Depth: 4190' FNL, 2151' FEL, Sec 20, T11N, R1 OE, UM 8. Date TD Reached: 11/5/2019 16. Well Name and Number: KRU 1F -07L1-01 9. Ref Elevations: K6:115 GL: 74 BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25652 ' 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 540008 ' y- 5958196 " Zone- 4 • TPI: x- 543577 y- 5957360 Zone- 4 Total Depth: x- 543135 y- 5955355 Zone- 4 11. Total Depth MD/TVD: • 9846/6017 ., 19. DNR Approval Number: LONS 80-259 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1322/1322 5. Directional or Inclination Survey: Yes (] (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: • 7665/6014 ` 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs 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 G R/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 1 6 62.5 H-40 35 80 35 80 24 295sx AS II 103/4 45.5 K-55 34 2259 34 2189 131/2 1 000s Fondu & 250sx 7 26 K-55 32 8045 32 6704 181/2 450sx Class G & 250sx 23/8 4.6 L-80 7202 9826 5999 6011 13 ISlotted Liner 24. Open to production or injection? Yes I] No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER @: 7629-9826 MD and 6024-6011 TVD COMPLETION DINE 1L1� -1Per En'IrlI LI 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 7347 6972/5810, 7320/6097 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No j] 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 11/11/2019 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 11/17/2019 Hours Tested: 14 Production for Test Period Oil -Bbl: '22 Z Gas -MCF: �56 Water -Bbl: i I -SZ Choke Size: 176 Gas -Oil Ratio: 2474 Flow Tubing Press. 174psi Casinq Press: 1300psi Calculated 24 -Hour Rate Oil -Bbl: 381 BOPD Gas -MCF: 944 MSCFD Water -Bbl: 3004BWPD Oil Gravity - API (corr): ZS-� Form 10-407 Revised 5/2017L �Z/�6��✓/Z��ONTINUED ON PAGE 2 RBDMS 1� DEC 2O�9Submit OR)IGINIAL/only 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MDlTVD, 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): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1322 1322 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7665 6019 information, including reports, per 20 AAC 25.071. Formation @ TPI - Kuparuk C TD 9846 6017 Formation at total depth: Kluparuk B Shale 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloaical rer)ort, oroduction or well test results, r 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: James Haves Authorized Title: Staff CTD Engineer Contact Email: James.C.Ha es co .com Contact Phone: 263-6927 Authorized//�G/ Signature: Date: f INSTRUCTIONS General: 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. Item 1a: 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. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: 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. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: 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. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: 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. Item 30: 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. Item 31: 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. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 1F-07 Final CTD Schematic 16" 65# H-40 shoe @ 80'M 0-3/4" 45# K-55 shoe D_ 2259' MID JKOP @ 71190' MID :] III I I - 1 IKOP@7210'MD C -sand perfs; 7184'- 7244' MD B -sand 7255'- 7282' MD 2019 Tubing Tai 7,248' MD Original Tubing 7,300 - 7,345' MD 1 A -sand perfs, 7393' - 7458' MD 7" 26# K-55 shoe @ 8045' MD I COMPLETION 3-1/2" 9.3# L-80 ELIE 8rd Tubing to surface 3-1/2" Carrico MMG gas lift mandrels @ 2,619', 4,190', 5,216', 6,022', 6,551', & 6,921' MD. Baker 3-1/2" PBR 6,948' MD (3" ID) Baker FHL Packer @ 6,972' MD (4" ID) 3-1/2" X landing nipple at 7,014' MD (2.813" min ID) REMAINING COMPLETION LEFT IN HOLE OTIS WD Permanend Packer @ 7312' MD (4" ID) OTIS MOE @ 7316' MD (4.35" ID) OTIS XNS nipple @ 7332' MD (2.813" ID) OTIS SOS @ 7338' MD Northern Solutions Wedge * 3-1/2" 9.3# L-80 Base Pipe * 5.905" OD (12.9' long) * -40' Total Length 0.625: Bore thru Upper Tray 1.125" Bore thru Lower Section HES 2.81" X Nipple below 1F-07LI-01 wp03 TD @ 9,826' IVID Top of Liner @ 7202' MD – — ------------ ------------ - -------- 1F-07LI wp07 TD @ 9,608' MD Top of Liner @ 7666' MD Conocomillips Alaska, Inc. 0Fw' ` KUP PROD Well Attribu _ Field Name KlIp Comment SSSV:NONE WELLNAME 1F-07 0/2016 1 Last WO: WELLBORE 1 F-07 40.59 110121/1982 1F-07, 11/25/MI9245:09PM Last Tag Vertical achemat. (achral) Annotation Depth (RKB) I End Date Wellbore Last Mod By ....................... HANGER, 2B.4 ... . ......... I Last Tag: RKB (EST 62' RAT HOLE) 7,520.0 6/13/2019 11 F -U 1condijw Last Rev Reason Annotation I End Date Wellbore 1 Last Mod By Rev Reason: Set Whipstock I 10/22/2019 1F-07 Ifamaj Casing Strings Casing Description OD (in) ID (in) Top (RKB) Set Depth (RKB) Set Depth (TVD)... Wtf h (I... Grade Top Thread '14a'1M'•c"ori0""uciorz:3"s:li=eo:o Annular Fluid - Diesel; 30.4- z,000.o; 7m2019 CONDUCTOR 16 15.25 35.0 80.0 80.0 65.00 H40 WELDED Casing Description SURFACE OD (in) ID (in) 103/4 9.95 Top (RKB) Set Depth (RKB) Set Depth (TVD)... Wt/Len (I Grade Top Thread 34.2 2,258.7 2,189.0 45.50 K-55 BUTT Annular Fluid -0; 7/2;/30.19 z,o0o.0; 727rm1s Casing Description PRODUCTION OD (in) ID (in) 7 6.28 Top (RKB) Set Depth (RKB) Set Depth (TVD)... WVLen (I Grade Top Thread 32.1 8,045.0 16,704.5 26.00 K-55 BTC Tubing Strings SURFACE; 34.2-2,258.7 Tubing Description 3.5' Bill String Ma... 31/2 ID (in) 2.99 Top (RKB) 28.4 set Depth (tt.. 7,248.1 Set Depth (TVD) (... 6,037.3 Wt (lblft) 9.30 Grade L-80 Top Connection EUE GAS LIFT Mandrel; 2,619.4 RWO Completion Details GAS LIFT Mandrel; 4,189.8 Annular Fluid - 990 NaCl 8nne Top (TVD) Top Incl Nominal WM CRW 132 Consign inhibitor; 2,000.08,971.9 Top (ftlCB) (RKB) (°) It.. Des Com ID (in) 7/Cl Bri s Annular Fluid - 9.90 NaCi Bare 28.4 28.4 0.13 HANGER FMC 11" x 3 112" Gen 5 Tubing Hanger W/ 3.5" EUE 8rd Lift thread 2.900 With C132 Gonion nhibmr;2,p0o.7r2SMls9 6,947.1 5,789.5 35.84 LOCATOR Baker gbh -22 locator sub 3.000 GAS LIFT Mandrel; 5,218,7 6,948.1 5,790.3 35.82 SBE Baker 80-40 seal assembly 21.73' OAL +2' off tag 3.980 6,950.1 5,792.0 35.80 SBR Baker 8040 PBR 4.000 GAS LIFT Mandrel; 6,072.0 6,972.0 5,809.8 35.54 PACKER Baker FHL packer 6983' 2.930 7,014.3 5,844.3 35.09 NIPPLE - X HES 3 1/2" x 2.813" X nipple Profile (SN:)2727A-3-3 W/RHC 2.813 installed GAS LIFT Mandrel; 6,550.7 7,187.4 5,987.0 34.03 TANDEM Northern Solutions 3 1/2" x 9 5/8" Tandem Wedge Assembly 2.992 WEDGE 7,201.4 5,998.6 33.97 NIPPLE - X HES 3 1/2" x 2.813" X nipple Profile (SN:) 2.813 GAS LIFT Mandrel; 6,921.8 7,207.2 6,003.4 33.98 TANDEM Northern Solutions 3 1/2" x 9 5/8" Tandem Wedge Assembly 2.992 LOCATOR; 6,947.1 1 WEDGE SBE; 61948.1 7,221.21 6,015.0 33.99 NIPPLE - X 1HES 3 1/2"x 2.813"X nipple Profile (SN:) 2.813 5 SBR; 6,9.1 Tubing Description String Ma... ID (in) Top fftKB) Set Depth (R.. Set Depth (TVD) I[- Wt (Ibrft) Grade Top Connection PACKER; 6,972.0 TUBING - RWO 1984 (after 2018 RWO) 31/2 2.99 7,278.4 7,346.6 6,118.9 9.30 J-55 BTC IPC NIPPLE -X;7,014.3 Completion Details TOP (TVD) Top Incl Nominal Annular Fluid -9.94 8nne; 6,971.9-7,320.0; 72=19 Top (RKB) (RKB) V) Item Des Co. ID (in) 7,318.9 6,096.0 34.00 LOCATOR OTIS STRAIGHT SLOT LOCATOR 3.000 7,320.1 6,097.0 34.00 PACKER OTIS WD PERMANENT PACKER 4.000 7,324.0 6,100.2 33.99 MILL OTIS MILL OUT EXTENSION 4.350 TANDEM WEDGE; 7,187.4 7,340.1 6,113.5 33.94 NIPPLE -XN OTIS 2.81" XNS POLISHED BORE NIPPLE w/ 2.75" NO GO 2.813 7,345.9 6,118.4 33.93 SOS OTIS SHEAR OUT SUB, ELMD TTL @7333' during PPROF on 4.470 NIPPLE - X; 7,2014 3/22/2008 TANDEM WEDGE; 7,207.2 RPERF; 7,184.0-7,244.0 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) FRAC C -SAND; 7,180.0 7,244.0 (PERF; Wedge: Inner Wedge; 7,278.8 Top (RKB) Top (TVD) (RKB) Top Incl (°) Des Com Run Date ID (in) 7,208.8 6,004.7 33.98 Inner Wedge F / 350 Inner Wedge Kick Off Assembly. set top at 10/22/201 0.000 NIPPLE - X; 7,72 XO Threads -Tuning; 7,2222 . 1 1 7204.3' Tied in to K1 Marker (7208.8' tied in to 9 Completion). DAL 12.1' Max OD 2.625" RackS-n; 7,711.0 3.25" SLOTTED LINER WITH ORANGE PEEL WEDGE 7,221.0 6,014.8 33.99 RockScreen 2.75" X -lock w/ 2.625" RockScreen w/ .188 slots (59" 8/25/2019 OAL) 0.000 BOTTOM -Tubing; 7,223.1 7,254.0 6,842.2 34.01 Broken Blast 7/26/2019 0.000 RPERF; 7,255.0.7,25.0 (PERF; 7,255.0.7,260.0 RPERF; 7,268.0.7,282.0 Rings from Original Completion (PERF; gsfro Original Broken Blast Rings horn Original I completion; 7,254.0 • 7,300.0 6,080.3 34.05 CHEMICAL CUT 2.625 Chemical Cut. 7/4/2019 2.992 CHEMICAL CUT; 7,35.0 7,323.0 6,099.4 33.99 CEMENT BAKER H1 CEMENT RETAINER W/ BALL 6/13/2019 1.130 PRODUCTION - Mandrel; 73016 RETAINER - GUTTED REMAOVED, 2.77" OD X 1.16' LENGTH Perforations & Slots LOCATOR; 7,318.9 Shot PACKER; 7,320.1 CEMENT RETAINER- R0 GUTTED; RETAINER MILL; 7,3240 Top (ftKB) Btm (RKB) Top (TVD) Btm(TVD) fftl(B) (RKB) Dens (shotslft Linked Zone Date ) Type Co. 7,184.0 7,244.0 5,984.1 6,033.9 C4, 1F-07 10/21/1982 12.0 IPERF 5" Vann Guns 7,184.0 7,244.0 5,984.1 6,033.9 CA, 1F-07 9/1/1984 12.0 RPFRF 5" DA; 90 deg ph 7,255.0 7,260.0 6,043.0 6,047.2 UNIT B, 1F-07 10/21/1982 12.0 IPERF 5" Vann Guns NIPPLE - XN; 7,340.1 7,255.0 7,260.0 6,043.0 6,047.2 UNIT B, 1F-07 911/1984 12.0 RPERF 5" DA; 90 deg ph 7,268.0 7,282.0 6,053.8 6,065.4 UNIT B, 1F-07 10/21/1982 12.0 IPERF 5" Vann Guns SOS; 7,345.9 7,268.0 7,282.0 6,053.8 6,065.4 UNIT B, 1F-07 9/1/1984 12.0 RPERF 5" DA; 90 deg ph 7,3930 7,405.0 6,157.5 6,167.4 A-4, 1F-07 10/21/1982 12.0 IPERF 5" Vann guns 7,393.0 7,405.0 6,157.5 6,167.4 A-4, 1 F-07 10/102006 6.0 RPERF .5" HSC, HJ RDX, 60 deg. ph RPERF; 7,393.0.7,405.0 7,420.0 7,446.0 6,179.9 6,201.6 A4, 1F-07 10/21/1982 12.0 IPERF 5" Vann guns (PERF; 7,393.0-7,405.0 7,453.01 7,458.0 6,207.5 1 6,211.6 A4, 1F-07 10/21/1982 12.0 IPERF 5" Vann guns FRAC A -SAND; 7,393.0 IPERF; 7,420.0-7,446.0 Frac Summary Start DateProppaIn Designed (lb) Proppant In Formation (lb) IPERF; 7,453.0.7,458.0 9/232000 Stg IF Start Date Top Depth (RKB) Btm (1t!(B) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 1 923/2000 7,184.0 7,244.0 Start Date Proppant Designed (lb) Proppant In Formation (lb) 10/27/2006 I Stg M Start Date Top Depth (RKB) S In (111<13) Link to Fluid System Vol Clean (bbi) Vol Slurry (bbl) Li -01 Lamnl; 7.202.0-9,826.4 1 10/27/2006 7,393.0 7,458.0 PRODUCTION; 32.18,045.0 KUP PROD WELLNAME 1F-07 WELLBORE 1F-07 ConocoPhillips Alaska, Inc. Annotation End Date Last WO: 7/30/2019 1F-0711 r2 201sz45.10PM Mandrel Inserts Vertical senemano (actuaq st ati ........... HANGER: 284...._ .. on Top (ND) Valve Latch Port Size TRO Run M Top (ftKB) (ftKB) Make Model OD (in) S., Type Type (in) (psi) Run Date Co. 1 2,619.4 2,484.6 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,265.0 8/20/2019 2 4,189.8 3,680.2 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,251.0 8/19/2019 3 5,216.7 4,491.1 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,242.0 8/18/2019 4 6,022.01 5,082.1 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,235.0 8/19/2019 °"c"oN"oiicroa; ss:o=eb:o 5 6,550.71 5,476.5 Camco MMG 1 1/2 GAS LIFT GLV RK 1 0.188 1,227.0 8/19/2019 Annolar F1 III 30.4- 2,000.0, 7/27/2019 6 6,921.8 5,769.1 Camco MMG 11/2 GAS LIFT OV RK 0.188 0.0 8/18/2019 7 7,301.6 6,081.6 OTIS OVAL 1 PROD DMY BK 0.000 0.0 9/26/2006 Prod Aular Fluid -Diesel; 30.4- nn 2,000 0, 7/27/2019 uctio n mand rel SURFACE, 34.2-2,258.7— macc essibl GAS LIFT Mandrel; 2,619.4 GAS LIFT Mandrel, 4,189.8 a due Annular Fluid - 9.9# NaCl Brine to With CRW 132 Corrsion orang I nhibitor, 2,000.06,971.9 e 26 2019 peel Annular Fluid - 9.9M NaCl Brine WRh CRW 132 Consion at mnibnon z;000. o$w119 BTM 7/zsrz0ls of GAS LIFT Mandrel; 5,216.7 1 liner Notes: General & Safety End Date Annotation GAS LFT Mandrel; 6,022.0 8/28/2019 1 NOTE: View Schematic w/ Alaska Schematicl O.O GAS LIFT Mandrel; 6,550.7 GAS LIFT Mandrel; 6,921.8 LOCATOR, 6,947.1 SEE; 6,948.1 SBR; 6,950.1 PACKER, 6,9720 NIPPLE - X; 7 014.3 Annular Fluid - 9 W Brine, 6,971.9-7,320.0, 7/22/2(119 TANDEM WEDGE, 7,1874 NIPPLE - X; 7.201 4 TANDEM WEDGE; 7,2072 RPERF; 7,184.0-7,244.0 FRAC C -SAND; 7, 154.0 IPERF; 7,184.0-7,244.0 Inner Wedge; 7,208.8 NIPPLE -X, 7,221.2 XO Threads - Tubing; 7,222.1 RockSureen: 7,221.0 3.25" SLOTTED LINER WITH ORANGE PEEL WEDGE BOTTOM - Tubing; 7,223.1 RPERF', 7,255.0-7,260.0 PERE ; 7,255.0-7,2610 RPERF; 7,268.0-7,282.0 IPERF; 7,268.0-7,2820 I Broken Blast Rings from 6ngi-I Complat-, 7,254.0 • CHEMICAL CUT, 7,300.0 PRODUCTION - Mandrel; 7,301.6 LOCATOR', 7,318.9 PACKER, 7,320.1 CEMENT RETAINER - GUTTED, 7,323.0 MILL', 7,324.0 NIPPLE - XN, 7,340.1 SOS; 7,345 9 RPERF; 7393.0-7,405.0 (PERF; 7393.0-7,405.0 FRAC A -SAND; 7,393.0 IPERF, 7,420.0.7,446.0 ]PERE, 7,453.0-7,458.0 L1-01 Lateral, 7,202.0-9,826.4 PRODUCTION; 32.1-8,045.0 KUP PROD WELLNAME 1F-07 ++-" Well Attribu ConocoPhillips Field Name Wellbore APVUW Wel Alaska, Inc KI IPARI IK RIVER I INIT ro()20DR.1061 PRi WELLBORE 1F -07L1-01 Max Anglr D TD MD 1. Act Sim (ftKB) 03.19 17,73034 9,826.4 End Date KB-Grd (ft) Rig Release Date 40.59 10/21/1982 1F -07L1-01, 11/25/20192: 41:34 PM Casing Strings Vertical schematic (actuap Casing Description L1-01 Lateral OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) Set Dep h (ftKB) Set Depth (TVD)... 7,202.0 9,826.4 6,011.0 WVLen (I... Grade 4.60 L-80 Top Thread STL _.... _............. HANGER: 284 _ Frac Summary Start Date Proppant Designed (lb) Proppant In Formation (lb) 9/23/2000 I Stg # StartDate Top Depth (ftKB) II (ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbp 1 9/23/2000 7,184.0 7,244.0 Start Data Proppant Designed (lb) Proppant In Formation (Ib) ...,..°„,,,,,,,°,°„°,,,,,,,°,° 10/27/2006 CONDUCTOR; 35.080.0 Annular Fluid - Diesel: 30.4- 2,000.0; 7/27/2019 Stg # StartDate 1 10127/2006 Top Depth (ftKB) Btm (ftKB) 7,393.0 1'7,458,0 Link to Fluid System Vol Olean (bbl) Vol Slurry (bbl) Annular Fluid- Diesel: 30.4- 2,000.0. 7/27/2019 SURFACE, 342-22587— 42-22587GAS GASLIFT Mandrel; 2,619,4 GAS LIFT Mandrel; 4,189.8 Annular Fluid 9.9# NBrine R. 32 Cor ZaCl W4h CRW 1 inhlb-, 2,000.08,971.9, 7/26/2019 Annular Fluid - 9.9# NaCl Brine With C 132 C.—,- inhibitor, 2.000.0-6 971.9, 7/26/2019 GAS LIFT Mandrel, 5,216.7 GAS LIFT Mandrel: 6,022.0 GAS LIFT Mandrel, 6,550.7 GAS LIFT Mandrel; 6,921 B LOCATOR', 6,947.1 SHE: 6,948.1 SBR: 6,950.1 PACKER, 6,972.0 NIPPLE - X: 7,014.3 Annular Fluid - 9.9# Brine, 6,971.9-7,320.0, 7x2212019 TANDEM WEDGE: 7,187.4 NIPPLE - X: 7,201.4 TANDEM WEDGE, 7,207.2 RPERF; 7,184.0-7,244.0 FRAC C -SAND; 7,184.0 I PERE, 7,184.0-7,244.0 Inner Wedge; 7,208.8 NIPPLE - X; 7,221.2 XO Threads - Tub,4g 7,222.1 RockScream, 7,221.0 3.25” SLOTTED LINER WITH ORANGE PEEL WEDGE BOTTOM - Tubing, 7,223.1 RPERF; 7,255.0-7,260.0 (PERF; 7,255.0-7,260.0 R P ERF: 7, 268.0-7, 282.0 IPERF; 7,268.0-7,282.0 I Broken Blast Ring. from Original Completion; 7,254.0 • CHEMICAL CUT, 7,300.0 PRODUCTION - Mandrel; 7,301.6 LOCATOR, 7,318.9 PACKER', 7,320.1 CEMENT RETAINER - GUTTED; 7,323.0 MILL', 7,324.0 NIPPLE - XN, 7,340 11 SOS; 7.315 9 RPERF,7,393.0-7,405 0 IPER F, 7,393.0-7,405.0 FRAC A -SAND', 7,393.0 (PERF; 7,420.0-7,446.0 [PERF; 7,453.0.7,458.0 PRODUCTION, 32.1-8.0450— L1-01 Lateral, 7,202.0-9,826.4 m Operations Summary (with Timelog Uepths) 1 F-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/29/2019 10/29/2019 5.00 MIRU MOVE RURD P Continue to work Rig down checklist. 0.0 0.0 00:00 05:00 blow -down steam, water, & all surface lines, disconnect PUTZ, secure BOP stack & freeze protect tree 10/29/2019 10/29/2019 3.70 MIRU MOVE RURD P Complete RD check list, inspect reel, 0.0 0.0 05:00 08:42 saddle clamps, all bolts post 1 R drilling, make changes to HMI scree, install 4 -ram stack valve panel in Ops cab 10/29/2019 10/29/2019 0.60 MIRU MOVE RURD P Peak trucks arrive, load up shop & 1/2 0.0 0.0 08:42 09:18 way house, PJSM 10/29/2019 10/29/2019 1.70 MIRU MOVE MOB P Hook up to sow, pull pits & sub off 0.0 0.0 09:18 11:00 well, jeep up 10/29/2019 10/29/2019 1.00 MIRU MOVE MOB P Clean up pad, jeep up modules, scarf 0.0 0.0 11:00 12:00 pad w/ cat, complete environmental walk around 10/29/2019 10/29/2019 3.30 MIRU MOVE MOB P Move from 1 R -Pad to 1 F -Pad 0.0 0.0 12:00 15:18 10/29/2019 10/29/2019 2.40 MIRU MOVE MOB P De -jeep, spot sub & pits 0.0 0.0 15:18 17:42 10/29/2019 10/29/2019 3.30 MIRU MOVE RURD P Work RU checklist, complete laying 0.0 0.0 17:42 21:00 mats, drop stairs & secure landings, MU PUTZ, MU tiger -tank hard-line 10/29/2019 10/30/2019 3.00 MIRU WHDBOP NUND P Continue RU checklist, spot shop & 0.0 0.0 21:00 00:00 1/2 way house, NU BOP, grease master, swab, & tangos Rig Accepted: 10/29/19 @ 23:00 hrs 10/30/2019 10/30/2019 1.00 MIRU WHDBOP RURD P Continue to rig up working RU check 0.0 0.0 00:00 01:00 list, greese valves, flood up. Passing shell test to 4000 psi. Page 1/11 Report Printed: 11/25/2019 Operations Summary (with Timelog Depths) Sero. , 1 F-07 • • f 1 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/30/2019 10/30/2019 7.00 MIRU WHDBOP BOPE P Test witness waived by Jeff Jones 0.0 0.0 01:00 08:00 AOGCC. Test pressure 250/4000 psi low //high. **Note Annular test pressure not specified on PTD as per norm **tested annular to 250/2500 psi as per normal Test 1. Swab 2 Test 2. Blind/Shear, BOP TV2, Charlie 4, 5, 8, &12 Test 3. BOP TV 1, Charlie 3, 7, & 11 Test 4. Manual choke D & Super choke C Test 5. Romeo 3, Bleeder 3, Tango 2, Charlie 2, & 10 Test 6. Charlie 1, 9, Bravo 5, and Tango 1 — install TIW test joint Test 7. Lower 2" pipe slip rams, TIW #1, Romeo 1, Bleeder 1 Test 8. Annular BOP Test 9. Upper 2" pipe slip rams, Bravo 6, & 8 Test 10. Bravo 7 — swap out 2" test joint for 2-3/8" Test 11. 2-3/8" pipe slip rams, TIW#2 — check N2 levels, swap to 2" test joint Test 12. Draw down accumulator, stabilized starting pressure 2400 psi, time to 200 psi increase 22 sec, full recovery time until pumps shut down 22, N2 bottles — average of 4, 2000 psi Test 13. Stab injector and line up to reverse circulate coil, test inner reel valve and stripper. Tested all gas detectors, pits, cellar, rig floor all functioned properly, Verified flow alarms - PVT 10/30/2019 10/30/2019 0.70 MIRU WHDBOP CTOP P Un Stab injector post inner reel valve / 0.0 0.0 08:00 08:42 stripper test. Run pipe into mouse hole 30' Inspect pipe. One small flat spot 3.5' back from the coil connector - 0.112 " on ODS 10/30/2019 10/30/2019 0.50 PROD1 WHPST PRTS P Stab ODS PDL, PT PDL and tiger tank 0.0 0.0 08:42 09:12 line - good. Unstab. Blow down lines post BOP test. 10/30/2019 10/30/2019 1.10 PROD1 WHPST PULD P Pick up and PD BHA #11, 0.6° AKO 0.0 74.0 09:12 10:18 wear band turned in, NS short shank string reamer (2.79" no go) NS diamond speed mill (2.80" no go) ***Initial pressures T/ 1/0 = 970/24/212 10/30/2019 10/30/2019 1.40 PROD1 WHPST TRIP P Bump up, set counters, RIH 74.0 7,100.0 10:18 11:42 10/30/2019 10/30/2019 0.20 PROD1 WHPST DLOG P Tie into the K1 for a -6.5' 7,100.0 7,134.0 11:42 11:54 10/30/2019 10/30/2019 1.00 PROD1 WHPST DISP P RIH and dry tag WS @ 7205.7' 7,134.0 7,205.7 11:54 12:54 PU Wt 32 k Ibs, Complete seawater flush, turn well over to milling fluid used power pro from 1 R-23, 6% KCI, 3% claystop, 1 % drill zone. Close EDC, PU Wt 32 k lbs set rate, RIH to mill Page 2111 Report Printed: 11/25/2019 Operations Summary (with Timelog Depths) 1 F-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (ftKB) 10/30/2019 10/30/2019 0.60 PROD1 WHPST WPST P Ct 4273 psi @ 1.89 /1.78 bpm in/out 7,134.0 7,204.3 12:54 13:30 respectively. Free spin 580 psi, BHP 3409 psi, targeting 11.8 ppg EMW @ the window. WH 76 psi, IA 548 psi, OA 899 psi. Start seeing WOB @ 7196.7'. WOB climbed to 0.9 k lbs, torqued up into a stall @ 7198' PU 31 k lbs. RBIH dry, set down @ 7205.7'. PU and set rate RIH, same as previous, WOB and motor work starting at 7197.5', stall @ 7198', PU Wt 31 k lbs. RIH to 7204' dry, set rate, contiune in hole to TOWS. Start seeing motor work @ 7204.3" 10/30/2019 10/30/2019 3.50 PROD1 WHPST WPST P CT 4256 psi @ 1.9/1.8 in/out. Free 7,204.3 7,207.3 13:30 17:00 spin 567 psi, BHP 3401 psi CT Wt 17.5 k lbs. OB milling CT Wt 13.43 k bs WOB 3.18 k lbs. 10/30/2019 10/30/2019 1.00 PROD1 WHPST WPST P Continue Milling Window Exit off of 7,207.3 7,207.9 17:00 18:00 HEW with NS rep Chris Lavoie, 1.89 bpm at 4,646 psi, Diff=1,003 psi, WHP=63, BHP=3,373, IA=543, OA=320 10/30/2019 10/30/2019 2.00 PROD1 WHPST WPST P OBM, 1.88 bpm at 4,646 psi, 7,207.9 7,208.5 18:00 20:00 Diff=1,003 psi, WHP=63, BHP=3,373, IA=543, OA=320 10/30/2019 10/30/2019 2.00 PROD1 WHPST WPST P OBM, 1.89 bpm at 4,646 psi, 7,208.5 7,209.1 20:00 22:00 Diff=1,003 psi, WHP=63, BHP=3,373, IA=543, OA=320, DHWOB=3.4 k, CTSW=13.32 k 10/30/2019 10/31/2019 2.00 PROD1 WHPST WPST P OBM, 1.88 bpm at 4,690 psi, 7,209.1 7,209.8 22:00 00:00 Diff=1,003 psi, WHP=63, BHP=3,373, IA=543, OA=320, DHWOB=3.95 k, CTSW=13.3 k *** Note: 5.4' into window exit 10/31/2019 10/31/2019 2.00 PROD1 WHPST WPST P OBM, 1.89 bpm at 4,646 psi, 7,209.8 7,210.6 00:00 02:00 Diff=1,015 psi, WHP=62, BHP=3,373, IA=543, OA=320 *** Note: 6.3' into window exit 10/31/2019 10/31/2019 2.25 PROD1 WHPST WPST P OBM, 1.89 bpm at 4,659 psi, Diff=809 7,210.6 7,211.8 02:00 04:15 psi, WHP=68, BHP=3,380, IA=549, OA=831 10/31/2019 10/31/2019 1.75 PROD1 WHPST WPST P Stall motor, 2.5 k DHWOB, PUH after 7,211.8 7,213.2 04:15 06:00 obtaining correct TF, PUW 28 k, Re- engage mill, 1.89 bpm at 4,248 psi, Diff=569 psi, WHP=130, BHP=3,408, IA=500, OA=390 10/31/2019 10/31/2019 1.50 PROD1 WHPST WPST P Mill ahead,to 7215 estimate 10.7' into 7,213.2 7,215.0 06:00 07:30 window, 2.7' outside window, reamer fully clear of 7" Start increasing BHP from 10.8 ppg EMW to 11.8 ppg @ the window. losses increased slightly. 10/31/2019 10/31/2019 1.70 PROD1 WHPST WPST P Drill ahead, stall twice @ 7218' 7,215.0 7,229.3 07:30 09:12 Restart, drill ahead. CT 4654 psi 1.88/1.81 bpm in/out. BHP 3674 psi, 11.8 ppg EMW. CT 12 k lbs, WOB 2 k lbs, ROP 21.8 ft/hr. Page 3111 Report Printed: 11/25/2019 .., uperations Summary (with Timelog Uepths) 1 F-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WB) 10/31/2019 10/31/2019 1.90 PROD1 WHPST REAM P TD rat hole, perform reaming passes, 7,215.0 7,229.3 09:12 11:06 one as drilled( 11' ROHS) , 30L, 30R and 180 from as milled. Perform dry drift -clean. Tag bottom 10/31/2019 10/31/2019 1.70 PROD1 WHPST TRIP P POOH chasing sweeps spinning the 7,229.3 72.0 11:06 12:48 bit. 100 ft/min 1.91 bpm in and 1.5 bpm out holding 11.8 @ the window. 10/31/2019 10/31/2019 0.90 PROD1 WHPST PULD P PUD BHA#1 72.0 0.0 12:48 13:42 **DSM no go 2.80" ***String reamer no go 2.79" 10/31/2019 10/31/2019 0.50 PROD1 DRILL CIRC P MU nozzle, stab injector, jet stack, un 0.0 0.0 13:42 14:12 stab injector 10/31/2019 10/31/2019 0.90 PROD1 DRILL CIRC P PD BHA#2, build/turn drilling 0.0 72.0 14:12 15:06 assembly. 10/31/2019 10/31/2019 1.30 PROD1 DRILL TRIP P RIH w BHA 72.0 7,098.0 15:06 16:24 10/31/2019 10/31/2019 0.40 PROD1 DRILL DLOG P Attempt to tie into K1, started to stack 7,098.0 7,125.0 16:24 16:48 weight @ 7104, S/D. PUH WT 29 k lbs Looks like we have a greater than 100' correction and just tagged bottom. PUH to 6974'. RIH tie in for + 122' correction. Close EDC, 10/31/2019 10/31/2019 1.00 PROD1 DRILL DRLG P RIH, CT 4413 psi @ 1.89/1.65 bpm 7,125.0 7,229.3 16:48 17:48 in/out. Free spin 528 psi, BHP 3714 psi, 11.9 ppg EMW at the window, RIH wt 14.7 k lbs. 10/31/2019 10/31/2019 0.20 PROD1 DRILL DRLG P OBD, 1.88 bpm at 4,395 psi, FS 7,229.3 7,340.0 17:48 18:00 Diff=528, WHP=250, BHP=3,692, IA=402, OA=407 10/31/2019 10/31/2019 0.20 PROD1 DRILL WPRT P PUH, to log formation 7,340.0 7,100.0 18:00 18:12 10/31/2019 10/31/2019 0.20 PROD1 DRILL DLOG P Log formation (K1) +1.0', tie in the RA 7,100.0 7,127.0 18:12 18:24 marker @ 7,209.5' CTMD *** Note: TOWS 7,205' RA 7,209.5' BOW 7,212' 10/31/2019 10/31/2019 0.20 PROD1 DRILL WPRT P RBIH 7,127.0 7,340.0 18:24 18:36 10/31/2019 10/31/2019 2.20 PROD1 DRILL DRLG P BOBD, 1.86 bpm at 4,395 psi, FS 7,340.0 7,538.0 18:36 20:48 Diff=528, WHP=309, BHP=3,733, IA=399, OA=408 10/31/2019 10/31/2019 0.20 PROD1 DRILL WPRT P PUH, PUW 28 k, preform BHA wiper 7,538.0 7,538.0 20:48 21:00 10/31/2019 10/31/2019 1.30 PROD1 DRILL DRLG P BOBD, 1.86 bpm at 4,395 psi, FS 7,538.0 7,629.0 21:00 22:18 Diff=528, WHP=309, BHP=3,733, IA=399, OA=408 10/31/2019 10/31/2019 0.30 PROD1 DRILL WPRT P Wiper up hole to below window area, 7,629.0 7,230.0 22:18 22:36 PUW 29 k 10/31/2019 10/31/2019 0.25 PROD1 DRILL WPRT P Wiper back in hole, RIW 13.3 k 7,230.0 7,629.0 22:36 22:51 10/31/2019 11/1/2019 1.15 PROD1 DRILL DRLG P BOBD, 1.86 bpm at 4,510 psi, FS 7,629.0 22:51 00:00 Diff=597, WHP=285, BHP=3,736, IA=342, OA=370 11/1/2019 11/1/2019 2.00 PROD1 DRILL DRLG P OBD, 1.86 bpm at 4,767 psi, FS 7,713.0 7,756.0 00:00 02:00 Diff=528, OB Diff=870, WHP=312, BHP=3,724, IA=415, OA=403, 11/1/2019 11/1/2019 2.00 PROD1 DRILL DRLG P OBD, 1.86 bpm at 4,653 psi, OB 7,756.0 7,851.0 02:00 04:00 Diff=807, WHP=306, BHP=3,747, IA=567, OA=500 11/1/2019 11/1/2019 2.10 PROD1 DRILL DRLG 1.88 bpm at 4,806 psi, OB 7,851.0 7,902.9 04:00 06:06 IP TB, 874, WHP=284, BHP=3,738, 07, OA=531 Page 4/11 Report Printed: 11/25/2019 .' operations Summary (with Timelog Uepths) , 1 F-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/1/2019 11/1/2019 0.20 FROM DRILL TRIP P Directionai driller called TD of the 7,902.9 7,211.0 06:06 06:18 build / turn. PU Wt 30 k lbs. POOH chasing sweeps. 11/1/2019 11/1/2019 0.20 PROD1 DRILL DLOG P Log Ra tag on way up, correction 7,902.9 7,211.0 06:18 06:30 lookes high, decide to log +7.5' 11/1/2019 11/1/2019 1.60 PROM DRILL DLOG P Continue out of hole. Tool registering 7,211.0 48.0 06:30 08:06 steady 3's on the lateral vibrations. Park, open EDC, continue out of hole. 11/1/2019 11/1/2019 1.20 PROD! DRILL PULD P Bump up, space out, PUD BHA #2. 48.0 0.0 08:06 09:18 11/1/2019 11/1/2019 0.10 PROM DRILL PULD P Inspect coil, flat spot back - 3-4' Wall 0.0 0.0 09:18 09:24 thickness, 0.2" 11/1/2019 11/1/2019 0.60 PROD1 DRILL PULD P PD BHA#3 partially 0.0 78.0 09:24 10:00 11/1/2019 11/1/2019 0.60 PROM DRILL CTOP P Swap out upper quick connect. Test 78.0 78.0 10:00 10:36 wire, 80.8 ohms conductor, greater than 2000 mega ohms insulation. 11/1/2019 11/1/2019 0.50 PROM DRILL PULD P Complete PD of BHA #4, lateral 78.0 0.0 10:36 11:06 drilling assembly, 11/1/2019 11/1/2019 1.30 PROD1 DRILL TRIP P RIH, shallow test agitator, strong 78.0 7,077.0 11:06 12:24 vibrations felt - 900 psi free spin @ drilling rate. start new mud system #1 down the coil at 3300 bit depth. 11/1/2019 11/1/2019 0.20 PROD1 DRILL DLOG P Tie into the K1 for -3' correction 7,077.0 7,134.0 12:24 12:36 11/1/2019 11/1/2019 0.50 PROD1 DRILL TRIP P Continue to RIH through build. 7,134.0 7,909.0 12:36 13:06 11/1/2019 11/1/2019 4.90 PROD1 DRILL DRLG P CT 4730 psi 1.89 / 1.89 bpm in/out. 7,909.0 8,310.0 13:06 18:00 Free spin 828 psi, BHP 3725 psi, WH 306 psi, IA 147 psi, OA 262 psi. CT Wt. 10 k lbs, Start continuously rotating @ 7940', artificially holding ROP back could drill faster. Pick up to get new parameters with new mud all the way around. CT 4848 psi @ 1.88/1.86 in / out, Free spin 973 psi, BHP 3748 psi, holding 11.8 ppg @ the window, 12.0 ppg at the bit. WH 331 psi, IA 340 psi, OA 328 psi. OBD CT 3.5 k lbs WOB to 2.5 k lbs. Consulted with town. Speed limit increased to 200 ft/hr New mud @ the bit 7910' 11/1/2019 11/1/2019 0.20 PROM DRILL WPRT P Wiper up hole to the EOB, PUW 29 k, 8,310.0 71910.0 18:00 18:12 (wiper #1) 11/1/2019 11/1/2019 0.20 PROD1 DRILL WPRT P Wiper back in hole, RIW 11 k 7,910.0 8,310.0 18:12 18:24 11/1/2019 11/1/2019 2.50 PROM DRILL DRLG P BOBD, 1.88 bpm at 5,049 psi, FS 8,310.0 8,382.0 18:24 20:54 Diff=1,150 psi, WHP=383, BHP=3,763, IA=461, OA=392 11/1/2019 11/1/2019 0.80 PROD1 DRILL DRLG P OB, continue drilling ahead, looks like 8,382.0 8,422.0 20:54 21:42 we drilled out the top of the C4 pay +/- 20', (8,304'-8,322') 11/1/2019 11/1/2019 0.20 PROM DRILL WPRT P Wiper up hole, PUW 33 k above high 8,422.0 8,290.0 21:42 21:54 gamma area (clean) 11/1/2019 11/1/2019 0.20 PROM DRILL WPRT P Wiper back in hole, RIW 5 k 8,290.0 8,422.0 21:54 22:06 11/1/2019 11/2/2019 1.90 FROM DRILL DRLG P BOBD, 1.88 bpm at 4,962 psi, FS 8,422.0 8,633.0 22:06 00:00 Diff=1,048 psi, WHP=346, BHP=3,827, IA=622, OA=494 11/2/2019 11/2/2019 0.75 PROM DRILL DRLG P OBD, 1.88 bpm at 5,000 psi, OB 8,633.0 8,710.0 00:00 00:45 Diff=1,058 psi, WHP=331, BHP=3,788, IA=751, OA=587 Page 5/11 Report Printed: 11/25/2019 Uperations Summary (with Timelog Depths) 1 F-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/2/2019 11/2/2019 0.30 PROM DRILL WPRT P Wiper up hole to the EOB (clean), 8,710.0 7,910.0 00:45 01:03 PUW 33 k 11/2/2019 11/2/2019 0.25 PROM DRILL WPRT P Wiper back in hole, RIW 7 k S/D - 7,910.0 8,710.0 01:03 01:18 8,634' and 8,702' TF related. 11/2/2019 11/2/2019 4.70 PROM DRILL DRLG P BOBD, 1.88 bpm at 4,928 psi, FS 8,710.0 9,018.0 01:18 06:00 Diff=1,146 psi, WHP=337, BHP=3,833, IA=757, OA=633 11/2/2019 11/2/2019 0.80 PROM DRILL DRLG P Crew change pick up, CT Wt 39 k lbs, 9,018.0 9,061.0 06:00 06:48 RBIH, hole is dirty, stacked WOB, a little trouble turning around. Launched 5x5 sweep in anticipation of early wiper. Work way to bottom, drill ahead. CT 5000 psi @ 1.85/1.85 bpm in/out, free spin 990 psi, BHP 3856 psi, CT 3 k lbs, WOB 1.5 k " Bleed both IA and OA from —750 psi to — 220 psi 11/2/2019 11/2/2019 0.60 PROM DRILL WPRT P PUH on long wiper to window PU Wt 9,061.0 7,215.0 06:48 07:24 31 k lbs WOB noisy but slight across the high gamma zone from 8330-8284'. Brief CT over pull to —3k @ 8696 and -1.5 k WOB tug @ 7887'. Overall clean trip - window clean. 11/2/2019 11/2/2019 0.10 PROM DRILL DLOG P Tie into the RA tag for + 10' correction. 7,215.0 7,250.0 07:24 07:30 11/2/2019 11/2/2019 0.90 PROD1 DRILL WPRT P RBIH, 7,250.0 9,061.0 07:30 08:24 Clean hole, CT weight falls off past trouble zone, had to drop RIH speed fro 50 gt/min to 30 then 20 ft/min 11/2/2019 11/2/2019 4.70 PROM DRILL DRLG P CT 4571 psi @ 1.7/1.7 bpm in/out. 9,061.0 9,474.0 08:24 13:06 Free spin 828 psi, BHP 3868 psi. CT to -3 k lbs, WOB to 2.2. Lower pump rte in attempt to target higher WOB, having a little difficulty building angle. 91,25' PU and adjust pumps to 1.9 bpm - drill ahead 9325' PU Wt 39 k lbs 9339' PU Wt 40 k lbs 9357' PU Wt 35 k lbs 9413' PU Wt 45k lbs 9450' PU Wt 49 k lbs 11/2/2019 11/2/2019 0.30 PROM DRILL WPRT P PU on 1st wiper, PU Wt 43 k lbs 9,474.0 8,474.0 13:06 13:24 11/2/2019 11/2/2019 0.90 PROM DRILL WPRT P RBIH 8,474.0 9,474.0 13:24 14:18 11/2/2019 11/2/2019 1.38 PROM DRILL DRLG P Cut rate to help maximize WOB to 9,474.0 9,600.0 14:18 15:40 help build angle. Ct 4113 psi @ 1.55/1.55 bpm in/out, Free spin 673 psi BHP 3876 psi 11.8 ppg EMW at the window, 12.3 ppg @ the bit. CT Wt -3 k lbs, WOB to 1.5 k lbs. Unable to build above 90 °. Getting kicked down. Increase to full drilling rate @ 9571' pump sweeps in anticipation of TD. 11/2/2019 11/2/2019 1.15 PROM DRILL WPRT P POOH, chasing sweeps to the window 9,600.0 7,212.0 15:40 16:49 11/2/2019 11/2/2019 1.50 PROD1 DRILL WPRT P Continue POOH pumping full rate with 7,212.0 78.3 16:49 18:19 EDC closed. Peform job back in hole from 1,000'to 1,500' 11/2/2019 11/2/2019 1.40 PROM DRILL TRIP P At surface, tag up, reset counters, 78.3 7,100.0 18:19 19:43 IRBIH Page 6/11 Report Printed: 71/25/2019 uperations Summary (with Timelog Vepths) 1 F-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftK8) End Depth (ftKB) 11/2/2019 11/2/2019 0.20 PROD1 DRILL DLOG P Log formation for depth control (-4.0') 7,100.0 7,134.0 19:43 19:55 11/2/2019 11/2/2019 0.22 PROD1 DRILL CTOP P RIH above window @ 7,166', obtain 7,134.0 7,166.0 19:55 20:09 static BHP *** Note: 7,166' CTMD / 11.386 ppg / AP 3,507 / CTSensor TVD 5,929.06'/ 13 min 11/2/2019 11/2/2019 1.00 PROD1 DRILL TRIP P Contine IH to confirm TD, RIW at TD 9 7,166.0 9,607.0 20:09 21:09 k, PUW 31 k 11/2/2019 11/2/2019 1.50 PROD1 DRILL CIRC P Vacate fluid from active mud pits and 9,607.0 9,607.0 21:09 22:39 clean, move complition fluid from storage to suction side, check and weight up completion fluid, Hesitate while circulating beaded LRP down coil 11/2/2019 11/3/2019 1.35 PROD1 DRILL TRIP P POOH, laying in 11.7 ppg beaded LRP 9,607.0 7,355.0 22:39 00:00 up to 6,000' Painting EOP TD flag 7,615' 11/3/2019 11/3/2019 0.30 PROD1 DRILL TRIP P Continue POOH laying beaded 11.7 7,355.0 6,000.0 00:00 00:18 ppg LRP up to 6,000', Painted window EOP flag @ 5,099' 11/3/2019 11/3/2019 1.00 PROD1 DRILL TRIP P Continue POOH 6,000.0 78.3 00:18 01:18 11/3/2019 11/3/2019 0.75 COMPZ1 CASING PUTB P Prep RF for liner operations, PJSM for 0.0 0.0 01:00 01:45 PU/MU L1 liner completion 11/3/2019 11/3/2019 0.50 PROD! DRILL PULD P At surface, check well for flow, Minimal 78.3 78.3 01:18 01:48 loss rate (+/- 0.2 bbl) 11/3/2019 11/3/2019 3.30 COMPZ1 CASING PUTB P Start picking up L1 liner completion 0.0 1,941.6 01:45 05:03 w/63 joints of slotted liner, non-ported bullnose, and 3.92' solid liner pup. 11/3/2019 11/3/2019 0.20 PROD1 DRILL PULD P LD drilling assembly, blow down motor 78.3 0.0 01:48 02:00 and BHA in mouse hole 11/3/2019 11/3/2019 -1.00 PROD1 DRILL PULD P (Fall back Day Lights Savings time) 0.0 0.0 02:00 01:00 continue LD drilling assembly 11/3/2019 11/3/2019 0.20 COMPZ1 CASING PUTB P Clear floor after running liner 1,941.6 1,941.6 05:03 05:15 11/3/2019 11/3/2019 1.00 COMPZ1 CASING PULD P PU BHA #4 1,941.6 1,986.0 05:15 06:15 11/3/2019 11/3/2019 0.80 COMPZ1 CASING RUNL P Bump up, set counters, RIH 1,986.0 7,099.9 06:15 07:03 11/3/2019 11/3/2019 0.10 COMPZ1 CASING RUNL P Tie in to white window flag -14.32' 7,099.9 7,085.6 07:03 07:09 11/3/2019 11/3/2019 4.40 COMPZ1 CASING RUNL P PU Wt 29 k lbs, WOB -6.84 k lbs, 7,085.6 9,596.0 07:09 11:33 Continue to RIH with L1 completion. CT RIH Wt 15 k lbs, WOB -5.4 k lbs. RIH W liner. Start to set down at 8451', PU CT 38 k WOB -16 k lbs. Work pipe steadily to 8700' in ever smaller bites. K1 and RA tag +7.5' correction on the drive by, did not stop to reset counters. @ bit depth 9297 CC @ 7312' gained CT WT and RIH with no issues. Set bull nose on bottom, PU 46 k lbs, RBIH, stack weight, pump 1.5 bpm to 951 psi diff, PU Wt 30 k lbs, PUH linere released. Page 7/11 Report Printed: 11/25/2019 Uperations Summary (with Timelog Depths) 1 F-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/3/2019 11/3/2019 1.50 COMPZI CASING TRIP P PUH, reset counters after dropping off 9,596.0 53.0 11:33 13:03 liner. POOH pumping over the top. 11/3/2019 11/3/2019 1.00 COMPZI CASING PULD P Bump up, flow check - good, LD BHA 53.0 0.0 13:03 14:03 #4 over a dead well. 11/3/2019 11/3/2019 0.40 PROD2 STK BOPE P BOP functon test 0.0 0.0 14:03 14:27 11/3/2019 11/3/2019 0.20 PROD2 STK CTOP P Skid cart, run 20' of pipe into the 0.0 0.0 14:27 14:39 mouse hole. Inspect pipe, 0.145" DS, 0.195" DW, 0.195 ODS, 0.175 RS Inspect pack offs - good. 11/3/2019 11/3/2019 0.90 PROD2 STK PULD P PU BHA#5, L1-01 lateral drilling 0.0 83.0 14:39 15:33 assemby, HYC A3 bit W 0.7° AKO motor, same agitator as L1 lateral. Strong surface vibrations felt when drilling L1. 11/3/2019 11/3/2019 1.10 PROD2 STK TRIP P Bump up, set counters, RIH. 83.0 7,105.0 15:33 16:39 11/3/2019 11/3/2019 0.20 PROD2 STK DLOG P Tie into the K1 for a -3.5' correction 7,105.0 7,166.0 16:39 16:51 11/3/2019 11/3/2019 1.00 PROD2 STK DISP P Displace well to drilling fluid while 7,166.0 7,166.0 16:51 17:51 recipping in tubing. 11/3/2019 11/3/2019 0.50 PROD2 STK TRIP P Continue IH 7,166.0 7,663.0 17:51 18:21 11/3/2019 11/3/2019 0.20 PROD2 STK TRIP P Dry tag TOB @ 7,663', PUH 28 k, 7,663.0 7,663.0 18:21 18:33 PUH, establish pump parameters, 1.88 bpm at 5,463 psi, FS Diff=1,286 psi, WHP=156, BHP=3,706, IA=O, OA=242 11/3/2019 11/3/2019 0.30 PROD2 STK WPST P Kickoff billet as per RP, 1.88 bpm at 7,663.0 7,663.0 18:33 18:51 5,463 psi, FS Diff=1,286 psi, WHP=156, BHP=3,706, IA=O, OA=242 11/3/2019 11/3/2019 0.50 PROD2 STK WPRT T Trouble with weight transfer, perform 7,663.0 7,212.0 18:51 19:21 wiper to the window 11/3/2019 11/3/2019 0.40 PROD2 STK WPRT T RBIH, dry tag TOB @ 7,666' 7,212.0 7,665.0 19:21 19:45 11/3/2019 11/3/2019 2.15 PROD2 STK WPST P 1.88 bpm at 5,463 psi, FS Diff=1,286 7,665.0 7,674.0 19:45 21:54 psi, WHP=156, BHP=3,706, IA=O, OA=242, 1 fph, 2 fph, and then 3 fph 11/3/2019 11/3/2019 1.00 PROD2 DRILL DRLG P Drill ahead, 1.87 bpm at 4,685 psi, OB 7,674.0 7,735.0 21:54 22:54 Diff=1,014 psi, WHP=377, BHP=3,758, IA=O, OA=365 11/3/2019 11/3/2019 0.10 PROD2 DRILL WPST P Wlper up hole, PUW 29 k, dry drift 7,735.0 7,636.0 22:54 23:00 kickoff point (clean) 11/3/2019 11/3/2019 0.10 PROD2 DRILL WPST P Wiper back in hole, RIW 10 k 7,636.0 7,735.0 23:00 23:06 11/3/2019 11/4/2019 0.90 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 4,685 psi, OB 7,735.0 7,840.0 23:06 00:00 Diff=980 psi, WHP=377, BHP=3,758, IA=O, OA=365 11/4/2019 11/4/2019 2.30 PROD2 DRILL DRLG P OBD, 1.87 bpm at 4,685 psi, OB 7,840.0 8,064.0 00:00 02:18 Diff=980 psi, WHP=377, BHP=3,758, IA=O, OA=365 11/4/2019 11/4/2019 0.20 PROD2 DRILL WPRT P Wiper up hole, PUW 29 k 8,064.0 7,690.0 02:18 02:30 11/4/2019 11/4/2019 0.20 PROM DRILL WPRT P Wiper back in hole, RIW 10.5 k 7,690.0 8,064.0 02:30 02:42 11/4/2019 11/4/2019 1.00 PROD2 DRILL DRLG P BOBD, 1.86 bpm at 4,805 psi, OB 8,064.0 8,158.0 02:42 03:42 Diff=1,057 psi, WHP=373, BHP=3,759, IA=O, OA=412 11/4/2019 11/4/2019 4.40 PROM DRILL DRLG P OBD, 1.86 bpm at 4,805 psi, OB 8,158.0 8,600.0 03:42 08:06 Diff=1,057 psi, WHP=373, BHP=3,759, IA=O, OA=412 Page 8/11 Report Printed: 11/25/2019 operations Summary (with Timelog Vepths) 1 F-07 Rig: NABORS CDR3-AC 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) 11/4/2019 11/4/2019 0.40 PROD2 DRILL WPRT P Wiper up hole, PUW 30 k 8,600.0 7,702.0 08:06 08:30 11/4/2019 11/4/2019 0.30 PROD2 DRILL WPRT P Wiper back in hole, RIW 7 k 7,702.0 8,600.0 08:30 08:48 11/4/2019 11/4/2019 8.30 PROD2 DRILL DRLG P CT 5027 psi @ 1.85/1.85 in/out, free 8,600.0 9,036.0 08:48 17:06 spin 1058 psi, BHP 3806 psi - 11.9 ppg EMW at the window, 12.3 ppg at the bit. OBD CT Wt 5.7 k lbs WOB 0.8 k lbs. 8786' PU Wt 30 k lbs 8800' PU Wt 35 k lbs 8914' PU Wt 34 k lbs 11/4/2019 11/4/2019 0.80 PROD2 DRILL WPRT P PU Wt 30 k lbs. 3rd long wiper to the 9,036.0 7,215.0 17:06 17:54 window for tie in 11/4/2019 11/4/2019 0.20 PROD2 DRILL DLOG P Log the RA marker correction of +6.5' 7,215.0 7,220.0 17:54 18:06 11/4/2019 11/4/2019 0.50 PROD2 DRILL WPRT P Wiper back in hole, RIW 7 k 7,220.0 9,036.0 18:06 18:36 11/4/2019 11/5/2019 5.40 PROD2 DRILL DRLG P BOBD, 1.89 bpm at 4,193 psi, FS 9,036.0 9,370.0 18:36 00:00 Diff=1,050 psi, WHP=303, BHP=3,850, IA=273, OA=590 11/5/2019 11/5/2019 2.20 PROD2 DRILL DRLG P OBD, 1.89 bpm at 5,604 psi, OB 9,370.0 9,432.0 00:00 02:12 Diff=1,250 psi, WHP=276, BHP=276, IA=519, OA=724 11/5/2019 11/5/2019 0.50 PROD2 DRILL WPRT P Wiper up hole 8,632', PUW 29 k 9,432.0 8,632.0 02:12 02:42 11/5/2019 11/5/2019 0.40 PROD2 DRILL WPRT P Wiper back in hole, RIW 0 8,632.0 9,432.0 02:42 03:06 11/5/2019 11/5/2019 1.50 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 5,415 psi, FS 9,432.0 9,482.0 03:06 04:36 Diff=1,036 psi, WHP=240, BHP=3,859, IA=499, OA=738 11/5/2019 11/5/2019 0.20 PROD2 DRILL WPRT P BHA wiper, PUW 29 k 9,482.0 9,482.0 04:36 04:48 11/5/2019 11/5/2019 7.20 PROD2 DRILL DRLG P BOBD, 1.87 bpm at 5,559 psi, FS 9,482.0 9,771.0 04:48 12:00 Diff=1,124 psi, WHP=222, BHP=3,878, IA=567, OA=760 TD extended from 9910 to 9950' Turned down @ 9685' droped angle to 72 and drilled ahead 11/5/2019 11/5/2019 0.20 PROD2 DRILL WPRT P PU Wt 29 k lbs, PUH on wiper#2 9,771.0 8,964.0 12:00 12:12 11/5/2019 11/5/2019 1.00 PROD2 DRILL WPRT P RBIH, fight weight transfer cutting rate 8,964.0 9,771.0 12:12 13:12 and RIH speed to make headway. Pump beaded pill PUH at 1.9 bpm, RIH on beads 11/5/2019 11/5/2019 1.90 PROD2 DRILL DRLG P CT 5585 psi @ 1.85/1.85 in/out, Free 9,771.0 9,844.0 13:12 15:06 spin 1021 psi, BHP 4017 psi. CT Wt -3 to -5 k lbs, WOB - 1 k lbs. TD called by Geo / asset 11/5/2019 11/5/2019 1.10 PROD2 DRILL WPRT P PUH on swab wiper 9,844.0 7,150.0 15:06 16:12 hole, billet, & window clean 11/5/2019 11/5/2019 1.10 PROD2 DRILL WPRT P Continue out of hole on swab wiper. 7,150.0 78.3 16:12 17:18 Jog tubing, bump up set counters 0.25 bbl of cuttings returned on the trip 11/5/2019 11/5/2019 1.50 PROD2 DRILL TRIP P RBIH 78.3 7,100.0 17:18 18:48 WOB spikes in the tubing while RIH, 3166' WOB 2.3 k lbs 4132' WOB 2.2 k lbs 4710' WOB 1.9 k lbs 4815' WOB 1.7 k lbs Page 9/11 Report Printed: 11/25/2019 uperations Summary (with Timelog Uepths) 1 F-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) 11/5/2019 11/5/2019 0.20 PROD2 DRILL DLOG P Tie into the K1 for a -3.5' correction 7,100.0 7,126.7 18:48 19:00 11/5/2019 11/5/2019 0.20 PROD2 DRILL DLOG P RIH to 7171.93' and and 5933.93 7,126.7 7,126.7 19:00 19:12 Park and trap 3675 psi, monitor pressure for 5 min bleed -200 psi monitor well 5 more minutes. BHP slowly fell from 3675 psi ( 11.9ppg) to 3560 psi in 5 min - 11.54 ppg- After bleedin the well the pressure stabilized at 3415 psi 11.07 ppg. 11/5/2019 11/5/2019 0.90 PROD2 DRILL TRIP P Continue in hole 7,126.7 9,846.0 19:12 20:06 1.6 k WOB spike at the window 7521' WOB spike to 2 k lbs ride to bottom on a 20 bbl beaded mud pill. Cary 9 k CT Wt to bottom. Tagged bottom @ 9846' 11/5/2019 11/5/2019 0.70 PROD2 DRILL TRIP P Circ LRP to the bit 9,846.0 9,841.0 20:06 20:48 11/5/2019 11/5/2019 1.00 PROD2 DRILL DISP P PUH laying in weighted liner running 9,841.0 7,223.0 20:48 21:48 pill 11/5/2019 11/5/2019 0.20 PROD2 DRILL DISP P tie into the RA tag for a +5.5' 7,223.0 7,248.0 21:48 22:00 correction Paint yellow flag at 7248.83' 11/5/2019 11/5/2019 1.40 PROD2 DRILL DISP P Continue out of hole 7,223.0 78.3 22:00 23:24 top of LRP 6300'. Paint white window flag @ 4478.23 11/5/2019 11/5/2019 0.50 PROD2 DRILL OWFF P At surface, check well for flow (no- 78.3 78.3 23:24 23:54 flow), loss rate <1.0 bph 11/5/2019 11/6/2019 0.10 PROD2 DRILL PULD P LD, drilling assembly on a dead well. 78.3 0.0 23:54 00:00 11/6/2019 11/6/2019 0.50 PROD2 DRILL PULD P Continue LD and flushing drilling 0.0 0.0 00:00 00:30 assembly 11/6/2019 11/6/2019 0.30 COMPZ1 CASING PUTB P Prep RF for Liner Ops, PJSM 0.0 0.0 00:30 00:48 11/6/2019 11/6/2019 3.00 PROD2 CASING PUTB P Start PU L1-01 2-3/8" slotted liner with 0.0 2,197.6 00:48 03:48 non -ported bullnose. 11/6/2019 11/6/2019 1.25 PROD2 CASING PUTB P PU solid liner section 2,197.6 2,624.4 03:48 05:03 11/6/2019 11/6/2019 0.80 PROD2 CASING PULD P MU CoilTrak tools 2,624.4 2,668.5 05:03 05:51 11/6/2019 11/6/2019 1.10 PROD2 CASING RUNL P RIH 2,668.5 4,415.0 05:51 06:57 11/6/2019 11/6/2019 0.15 PROD2 CASING RUNL P Correct to the EOP flag -7.56' 4,415.0 4,415.0 06:57 07:06 11/6/2019 11/6/2019 0.30 PROD2 CASING RUNL P Continue RIH 4,415.0 8,437.0 07:06 07:24 11/6/2019 11/6/2019 2.00 PROD2 CASING RUNL P Work liner down hole, PUW's 50 k 8,437.0 9,147.0 07:24 09:24 11/6/2019 11/6/2019 2.00 PROD2 CASING RUNL P Continue working pipe down hole, 9,147.0 9,535.0 09:24 11:24 PUW's 50 k, -22.5 k 11/6/2019 11/6/2019 1.90 PROD CASING RUNL P Continue working pipe down hole, 9,535.0 9,826.4 11:24 13:18 PUW's 50 k, -22.5 k, log the K1 (+2.5') 11/6/2019 11/6/2019 0.25 PROD2 CASING RUNL P Bring pump online 1.5 bpm at .92 bpm9,826.4 9,826.4 13:18 13:33 out, 967 psi, PUW 25 k, Page 10/11 Report Printed: 11/25/2019 Uperations Summary (with Timelog Uepths) t 3, 1 F-07 ... . Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/6/2019 11/6/2019 1.00 DEMOB WELLPR DISP P PUH, remove liner length from 9,826.4 7,202.0 13:33 14:33 counters, send SW down coil, shut down pump obtain SBHP. Note: Static BHP 11.7 ppg KWF in well, 7,174', 11.702 ppg (5964.56' TVD) 11/6/2019 11/6/2019 0.85 DEMOB WELLPR DISP P POOH while displacing well to SW, 7,202.0 2,527.0 14:33 15:24 LRS on location, hold PJSM with Rig crew, rig up and PIT customer line. 4 k psi (good) stanby 11/6/2019 11/6/2019 0.60 DEMOB WELLPR DISP P Load 38 bbl of diesel into the reel. 2,527.0 2,527.0 15:24 16:00 11/6/2019 11/6/2019 0.70 DEMOB WELLPR FRZP P POOH freeze protecting well from 2,527.0 37.0 16:00 16:42 2500' with diesel 11/6/2019 11/6/2019 1.50 DEMOB WELLPR PULD P At surface, PJSM, PUD BHA#6 liner 37.0 0.0 16:42 18:12 running tools and lay down tools. 11/6/2019 11/6/2019 1.30 DEMOB WHDBOP CIRC P M/U Nozzle to coil. Stab on well. Flush 0.0 0.0 18:12 19:30 tree, BOPE stack, and rig surface lines. Shut down and unstab injector. 11/6/2019 11/6/2019 0.40 DEMOB RIGMNT CTOP P Remove UQC and cut CTC. trim 14' 0.0 0.0 19:30 19:54 coil to remove flat spot. 11/6/2019 11/6/2019 2.30 DEMOB RIGMNT CTOP P Prep CT. Install CTC. Pull test to 35K 0.0 0.0 19:54 22:12 11/6/2019 11/6/2019 0.80 DEMOB RIGMNT CTOP P Install UQC and rehead E -line. Test 0.0 0.0 22:12 23:00 wire - Good 11/6/2019 11/7/2019 1.00 DEMOB NUND P Vac out stack. Put methanol in tree. 0.0 0.0 23:00 00:00 �WHDBOP Start nipple down. Rig Release @ 24:00 Hrs Page 11/11 Report Printed: 11/25/2019 ConocoPhillips ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 1F Pad 1 F -07L1-01 50-029-20830-61 Baker Hughes INTEQ Definitive Survey Report 20 November, 2019 Baker Hughes S ConoeoPhiiiips ConocoPhillips Definitive Anker Hughes g Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1 F-07 Project: Kuparuk River Unit TVD Reference: 1 F-07 @ 115.00usft (1 F-07) Site: Kuparuk 1 F Pad MD Reference: 1 F-07 @ 115.00usft (1 F-07) Well: 1F-07 North Reference: True Wellbore: 1F-07LI-01 Survey Calculation Method: Minimum Curvature Design: 1F-071-1-01 Database: EDT 14 Alaska Production Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1F-07 Well Position -NIS 0.00 usft Northing: 5,958,196.36usft Latitude: 70° 17'48.221 N +E/-W 0.00 usft Easting: 540,008.25usft Longitude: 149° 40'33.704 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 Usti Wellbore 1F-07L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 111 jrl BGGM2018 12/1/2019 16.30 80.82 57,393 ... ........ Design1F-071-1-01_,,.�.m...............m,» �_._...-,........,,. ,,. w a,.....,..,.....,n.,,�»�».,,.�.»...,.....,... ... .. a.-�.�.,. .,w,.,. ,�-.,._.. -.,�.. ......,....,...,.,..�..,,,,.,,,.,.......,, .,,-,«...m___.� .,_-. Audit Notes: I Version: 1.0 Phase: ACTUAL Tie On Depth: 7,649.91 Vertical Section: Depth From (TVD) +N/-S +El-W Direction (usft) (usft) (usft) (°) 115.00 0.00 0.00 180.00 Survey Program Date From To Survey Survey , i (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 7,200.00 1 F-07 (1 F-07) BOSS-GYRO Sperry-Sun BOSS gyro multishot 8/25/2000 7,205.00 7,320.65 1F-071_1 MWD-INC (1 F-071-1) MWD-INC_ONLY(INC>10°) MWD-INC_ONLY_FILLER(INC>10°) 10/30/2019 10/30/2019 7,350.28 7,649.91 1F-071_1 MWD (I F-071-1) MWD OWSG OWSG MWD- Standard 10/30/2019 11/2/2019 7,665.00 9,809.62 iF-011-1-01 MWD(iF-071-1-01) MWDOWSG OWSG MWD- Standard 11/4/2019 11/6/2019 11/10/2019 1:33IOPM Page 2 COMPASS 5000.14 Build 85H Conoco ll1ps ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well i F-07 Project: Kuparuk River Unit TVD Reference: 1F-07 @ 115.00usft (IF-07) Site: Kuparuk 1F Pad MD Reference: 1 F-07 @ 115.00usft (11F-07) Well: 1F-07 North Reference: True Wellbore: 1F -07L1-01 Survey Calculation Method: Minimum Curvature Design: 1F -07L1-01 Database: EDT 14 Alaska Production Survey 11202019 1:33.1OPM Page 3 COMPASS 5000.14 Build 65H Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E( -W Northing Fasting DLS Section Survey Tool Name Annotation With) (1). (1) (usft) (usft) (usft) (N�) (ft) lftl (`1100') Iftl 7,649.91 97.67 233.75 6,020.94 5,905.94 -847.25 3,576.65 5,957,366.24 543,589.01 45.27 847.25 MWD OWSG (3) TIP 7,665.00 96.93 241.00 6,019.02 5,904.02 -855.31 3,564.05 5,957,360.11 543,576.45 47.91 855.31 MWD OWSG (4) KOP 7,701.00 100.17 234.39 6,013.66 5,898.66 -874.32 3,533.98 5,957,340.95 543,546.49 20.26 874.32 MWD OWSG (4) 7,730.75 103.19 233.01 6,007.64 5,892.64 -891.56 3,510.50 5,957,323.59 543,523.10 11.12 891.56 MWD OWSG (4) 7,759.84 100.61 232.40 6,001.64 5,886.64 -908.81 3,487.86 5,957,306.22 543,500.55 9.10 908.81 MWD OWSG (4) 7,791.18 97.14 230.93 5,996.81 5,881.81 -928.01 3,463.58 5,957,286.89 543,476.38 12.00 928.01 MWD OWSG (4) 7,819.96 93.64 228.92 5,994.10 5,879.10 -946.45 3,441.66 5,957,268.33 543,454.56 14.01 946.45 MWD OWSG(4) 7,850.33 93.25 225.37 5,992.28 5,877.28 -967.07 3,419.44 5,957,247.60 543,432.45 11.74 967.07 MWD OWSG (4) 7,880.96 93.63 221.83 5,990.44 5,875.44 -989.21 3,398.35 5,957,225.35 543,411.49 11.60 989.21 MWD OWSG (4) 7,901.18 93.13 218.16 5,989.25 5,874.25 -1,004.67 3,385.38 5,957,209.82 543,398.60 18.29 1,004.67 MWD OWSG (4) 7,931.11 92.55 210.63 5,987.76 5,872.76 -1,029.32 3,368.51 5,957,185.09 543,381.86 25.20 1,029.32 MWD OWSG (4) 7,960.96 93.13 206.06 5,986.28 5,871.28 -1,055.55 3,354.36 5,957,158.78 543,367.85 15.41 1,055.55 MWD OWSG (4) 7,990.33 92.24 200.41 5,984.90 5,869.90 -1,082.50 3,342.79 5,957,131.78 543,356.43 19.45 1,082.50 MWD OWSG (4) 8,019.84 92.18 194.75 5,983.76 5,868.77 -1,110.60 3,333.89 5,957,103.63 543,347.68 19.17 1,110.60 MWD OWSG (4) 8,050.86 94.12 192.15 5,982.06 5,867.06 -1,140.72 3,326.68 5,957,073.48 543,340.63 10.45 1,140.72 MWD OWSG (4) 8,081.31 95.23 189.08 5,979.58 5,864.58 -1,170.54 3,321.09 5,957,043.63 543,335.20 10.69 1,170.54 MWD OWSG (4) 8,116.09 93.94 187.39 5,976.80 5,861.80 -1,204.85 3,316.13 5,957,009.30 543,330.42 6.10 1,204.85 MWD OWSG (4) 8,145.42 90.95 185.69 5,975.55 5,860.55 -1,233.96 3,312.79 5,956,980.17 543,327.24 11.72 1,233.96 MWD OWSG (4) 8,176.22 88.86 187.44 5,975.60 5,860.60 -1,264.55 3,309.27 5,956,949.56 543,323.88 8.85 1,264.55 MWD OWSG (4) 8,206.38 91.14 189.28 5,975.60 5,860.60 -1,294.39 3,304.89 5,956,919.71 543,319.66 9.71 1,294.39 MWD OWSG (4) 8,231.40 90.98 190.95 5,975.13 5,860.13 -1,319.02 3,300.49 5,956,895.06 543,315.39 6.70 1,319.02 MWD OWSG (4) 8,263.06 90.55 190.89 5,974.71 5,859.71 -1,350.10 3,294.50 5,956,863.95 543,309.56 1.37 1,350.10 MWD OWSG (4) 8,292.68 92.12 194.52 5,974.02 5,859.02 -1,378.98 3,287.98 5,956,835.03 543,303.21 13.35 1,378.98 MWD OWSG (4) 8,317.24 88.25 194.23 5,973.94 5,858.94 -1,402.77 3,281.89 5,956,811.22 543,297.24 15.80 1,402.77 MWD OWSG (4) 8,351.59 86.10 196.00 5,975.64 5,860.64 -1,435.89 3,272.94 5,956,778.06 543,288.47 8.10 1,435.89 MWD OWSG (4) 8,382.95 83.60 195.33 5,978.45 5,863.45 -1,465.96 3,264.51 5,956,747.94 543,280.20 8.25 1,465.96 MWD OWSG (4) 8,412.95 87.39 197.00 5,980.81 5,865.81 -1,494.67 3,256.19 5,956,719.19 543,272.03 13.80 1,494.67 MWD OWSG (4) 8,442.55 89.05 196.32 5,981.73 5,866.73 -1,523.02 3,247.70 5,956,690.80 543,263.70 6.06 1,523.02 MWD OWSG (4) 8,473.43 87.54 191.43 5,982.64 5,867,64 -1,552.97 3,240.30 5,956,660.81 543,256.46 16.57 1,552.97 MWD OWSG (4) 8,50548 87.05 189.89 5,984.16 5,869.16 -1,584.43 3,234.38 5,956,629.32 543,250.70 5.04 1,584.43 MWD OWSG (4) 11202019 1:33.1OPM Page 3 COMPASS 5000.14 Build 65H ConocoPhillips am�Huom ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit Site: Kuparuk 1F Pad Well: 1F-07 Wellbore: 1 F -07L1-01 Design: 1 F -07L1-01 Survey Local Co-ordinate Reference: Well 1 F-07 ND Reference: t F-07 @ 115 00usft (1 F-07) MD Reference: 1 F-07 @ 115.00usft (1 F-07) Map North Reference: True 333 Survey Calculation Method: Minimum Curvature ND Database: EDT 14 Alaska Production •�-W Northing Easting DLS 111202019 1:33:10PM Page 4 COMPASS 5000.14 Build 85H Map Map Vertical MD Inc Aid ND NDSS +WS •�-W Northing Easting DLS Section fusttl 1°I f% (usR) lash► (-ft) (us►t) (°(1000 Survey Tool Name Annotation IM (ft) (ft) 8,534.03 a5.48 186.86 5,986.02 5,871.02 -1,612.61 3,230.23 5,956,601.12 543,246.70 11.93 1,612.61 MWD OWSG (4) 8,565.72 85.21 184.77 5,988.59 5,873.59 -1,644.04 3,227.03 5,956,569.69 543,243.67 6.63 1,644.04 MWD OWSG (4) 8,593.13 82.77 179.50 5,991.46 5,876.46 -1,671.26 3,226.01 5,956,542.45 543,242.80 21.09 1,671.26 MWD OWSG (4) 8,622.80 85.14 177.98 5,994.59 5,879.59 -1,700.76 3,226.66 5,956,512.97 543,243.60 9.47 1,700.76 MWD OWSG (4) 8,653.26 87.39 173.32 5,996.57 5,881.57 -1,731.06 3,228.97 5,956,482.68 543,246.07 16.96 1,731.06 MWD OWSG (4) 8,682.82 93.04 171.87 5,996.46 5,881.46 -1,760.36 3,232.78 5,956,453.41 543,250.04 19.73 1,760.36 MWD OWSG (4) 8,711.63 89.66 169.71 5,995.78 5,880.78 -1,788.78 3,237.39 5,956,425.01 543,254.80 13.92 1,788.78 MWD OWSG (4) 8,741.86 92.18 171.90 5,995.30 5,880.30 -1,818.62 3,242.22 5,956,395.21 543,259.78 11.04 1,818.62 MWD OWSG (4) 8,773.10 90.18 172.51 5,994.65 5,879.65 -1,849.56 3,246.45 5,956,364.29 543,264.18 6.69 1,849.56 MWD OWSG (4) 8,802.92 94.67 174.26 5,993.39 5,878.39 -1,879.14 3,249.88 5,956,334.72 543,267.77 16.16 1,879.14 MWD OWSG (4) 8,831.38 89.42 170.61 5,992.38 5,877.38 -1,907.32 3,253.63 5,956,306.57 543,271.67 22.46 1,907.32 MWD OWSG (4) 8,863.18 88.86 167.62 5,992.85 5,877.85 -1,938.54 3,259.63 5,956,275.38 543,277.84 9.56 1,938.54 MWD OWSG (4) 8,892.21 90.52 164.54 5,993.01 5,878.01 -1,966.72 3,266.61 5,956,247.25 543,284.97 12.05 1,966.72 MWD OWSG (4) 8,922.96 93.16 163.14 5,992.02 5,877.02 -1,996.23 3,275.17 5,956,217.78 543,293.68 9.72 1,996.23 MWD OWSG (4) 8,952.80 97.30 160.67 5,989.30 5,874.30 -2,024.47 3,284.39 5,956,189.60 543,303.05 16.14 2,024.47 MWD OWSG (4) 8,982.10 95.20 158.13 5,986.11 5,871.11 -2,051.73 3,294.64 5,956,162.40 543,313.44 11.21 2,051.73 MWD OWSG (4) 9,019.68 96.94 162.53 5,982.14 5,867.14 -2,086.91 3,307.22 5,956,127.29 543,326.20 12.53 2,086.91 MWD OWSG (4) 9,052.03 93.01 163.11 5,979.33 5,864.33 -2,117.69 3,316.73 5,956,096.56 543,335.88 12.28 2,117.69 MWD OWSG (4) 9,082.58 91.47 166.45 5,978.14 5,863.14 -2,147.14 3,324.75 5,956,067.15 543,344.05 12.03 2,147.14 MWD OWSG (4) 9,112.90 92.67 170.35 5,977.04 5,862.04 -2,176.82 3,330.84 5,956,037.51 543,350.30 13.45 2,176.82 MWD OWSG (4) 9,142.46 91.35 174.85 5,976.01 5,861.01 -2,206.11 3,334.64 5,956,008.25 543,354.26 15.86 2,206.11 MWD OWSG (4) 9,172.82 87.57 178.03 5,976.29 5,861.29 -2,236.40 3,336.53 5,955,977.97 543,356.31 16.27 2,236.40 MWD OWSG (4) 9,201.81 89.94 180.88 5,976.92 5,861.92 -2,265.37 3,336.80 5,955,949.00 543,356.74 12.78 2,265.37 MWD OWSG (4) 9,235.39 93.04 184.11 5,976.05 5,861.05 -2,298.90 3,335.34 5,955,915.47 543,355.45 13.33 2,298.90 MWD OWSG (4) 9,266.71 93.28 188.92 5,974.32 5,859.32 -2,329.96 3,331.79 5,955,884.39 543,352.07 15.35 2,329.96 MWD OWSG (4) 9,296.84 91.63 192.18 5,973.03 5,858.03 -2,359.55 3,326.28 5,955,854.78 543,346.72 12.12 2,359.55 MWD OWSG (4) 9,327.04 90.77 194.40 5,972.40 5,857.40 -2,388.94 3,319.34 5,955,825.36 543,339.94 7.88 2,388.94 MWD OWSG (4) 9,358.56 91.72 197.96 5,971.71 5,856.71 -2,419.19 3,310.56 5,955,795.06 543,331.32 11.69 2,419.19 MWD OWSG (4) 9,388.03 89.66 200.54 5,971.36 5,856.36 -2,447.01 3,300.85 5,955,767.19 543,321.75 11.20 2,447.01 MWD OWSG (4) 9,422.15 91.26 204.78 5,971.08 5,856.08 -2,478.49 3,287.71 5,955,735.65 543,308.78 13.28 2,478.49 MWD OWSG (4) 9,452.02 87.72 206.75 5,971.35 5,856.35 -2,505.38 3,274.73 5,955,708.69 543,295.95 13.56 2,505.38 MWD OWSG (4) 111202019 1:33:10PM Page 4 COMPASS 5000.14 Build 85H 101, ConocoPhillips Bk, Rghee it Comxo�1lips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit stile: Kupamk 1F Pad Well: 1 F-07 Wellbore: IF -0 Ll -01 Design: IF -07L1 01 Inc Azl Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well IF -07 1F-07 @ 115.00usft (IF -07) iF-07 @ 115.00usft (1F-07) True Minimum Curvature EDT 14 Alaska Production t Map Map Map Vertical i MD Inc Azl TVD TWSS +NlS +E/ -W Northing EaaNng Section Survey Tool Name S (uaft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (^1100') In) 9,481.72 86.62 204.98 5,972.82 5,857.82 -2,532.07 3,261.79 5,955,681.93 543,283.15 7.01 2,532.07 MWD OWSG (4) 9,511.70 88.49 205.92 5,974.09 5,859.09 -2,559.12 3,248.92 5,955,654.82 543,270.42 6.98 2,559.12 MWD OWSG(4) 9,542.13 89.08 205.19 5,974.74 5,859.74 -2,586.56 3,235.79 5,955,627.31 543,257.45 3.08 2,586.56 MWD OWSG (4) 9,573.02 88.83 204.02 5,975.30 5,860.30 -2,614.64 3,222.93 5,955,599.17 543,244.74 3.87 2,614.64 MWD OWSG (4) 9,602.58 87.64 203.94 5,976.21 5,861.21 -2,641.64 3,210.93 5,955,572.11 543,232.88 4.03 2,641 64 MWD OWSG (4) 9,63360 87.08 203.67 5,977.64 5,862.64 -2,669.99 3,198.42 5,955,543.69 543,220.52 2.00 2,669.99 MWD OWSG (4) 9,664.83 86.47 204.13 5,979.40 5,864.40 -2,698.50 3,185.79 5,955,515.12 543,208.04 2.44 2,698.50 MWD OWSG(4) 9,691.71 85.45 201.64 5,981.29 5,866.29 -2,723.20 3,175.36 5,955,490.37 543,197.75 9.99 2,723.20 MWD OWSG (4) j 9,722.12 81.49 202.61 5,984.75 5,869.75 -2,751.18 3,163.98 5,955,462.33 543,186.52 13.40 2,751.18 MWD OWSG (4) 9,753.20 77.29 203.56 5,990.47 5,875.47 -2,779.28 3,152.01 5,955,434.17 543,174.70 13.84 2,779.28 MWD OWSG (4) 9,781.32 73.81 206.70 5,997.49 5,882.49 -2,803.92 3,140.45 5,955,409.47 543,163.28 16.43 2,803.92 MWD OWSG (4) 9,809.62 72.04 208.39 6,005.80 5,890.80 -2,827.91 3,127.95 5,955,385.42 543,150.90 6.47 2,827.91 MWD OWSG (4) 9,846.00 72.04 208.39 6,017.02 5,902.02 -2,858.35 3,111.49 5,955,354.89 543,134.61 0.00 2,858.35 PROJECTEDto TD Annotation 11202019 1:33:10PM Page 5 COMPASS 5000.14 Build 85H Baker � PRINT DISTRIBUTION LIST Hughes COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1F -07L1-01 FIELD Greater Kuparuk Area 218014 3164 1 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 700 G Street. Anchorage, Alaska 99510 to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR - RES BHI DISTRICT Alaska --- LOG DATE November 6, 2019 AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(_bakerhughes.com TODAYS DATE December 11, 2019 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V 1 BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 1900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC Attn: Natural Resources Technician II 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division of Oil & Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 FIELD / FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, I SURVEY REPORT LOGS CGM, Final Surveys) (Compass) _TOF PRINTS 9 UF PKIN I b # OF COPIES # OF COPIES 1# OF COPIES 4 4 4 4 RECEIVED 4 4 TOTALS FOR THIS PAGE: 0 1 2 0 0 To R C:k LE WD 1 NOV 2 2 2M ---- --- Baker Hughes date: Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 November 20, 2019 _-------- --------- --- - - -- - _- - ,Please find enclosed the directional sur 1R-23L1PB1 i 1R-23L1PB2 1R-23L1PB3 i 1F -07L1 1F -07L1-01 (5) Total prints Enclosed for each well(s): j1 hardcopy print of dire( 1 compact disk containir I Harvey Finch, Baker Hughes, Wellplanner Harvey. Finch@ bakerhughes.com 21 8074 31 407 Letter of Transmittal :From: Harvey Finch Baker Hughes 795 East 94th Avenue Anchorage, Alaska 99515 218074 31487 X ConocoPhillips ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 1F Pad 1 F -07L1-01 50-029-20830-61 Baker Hughes INTEQ Baker Hughes Definitive Survey Report 20 November, 2019 II ConocoPhillips ConocoPhillips Definitive Survey Report Date Company: ConocoPhillips Alaska Inc—Kuparuk Local Co-ordinate Reference: Well 1 F-07 Project: Kuparuk River Unit TVD Reference: 1 F-07 @ 115.00usft (1 F-07) Site: Kuparuk 1F Pad MD Reference: 1 F-07 @ 115.00usft (1 F-07) Well: 1 F-07 North Reference: True Wellbore: 1F-071-1-01 Survey Calculation Method: Minimum Curvature Design: 'IF -071-1-01 Database: EDT 14 Alaska Production Project Kuparuk River Unit, North Slope Alaska, United States Date Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Survey (Wellbore) Map Zone: Alaska Zone 04 1F-07 (1F-07) Well 1 F-07 1F-071_1 MWD -INC (1F-071-1) Well Position +N/ -S 0.00 usft Northing: 7,665.00 +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 1 F -07L1-01 Magnetics Model Name Sample Date BGGM2018 12/1/2019 Design 1F-071-1-01 Audit Notes: Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,958,196 36 u sft Latitude: 540,008 25 u sft Longitude: usft Ground Level: Declination Dip Angle (I (I 16.30 80.82 Version: 1 0 Phase: ACTUAL Tie On Depth: 7,64991 Vertical Section: Depth From (TVD) (usft) 115.00 Survey Program Date From To (usft) (usft) Survey (Wellbore) 200.00 7,200.00 1F-07 (1F-07) 7,205.00 7,320.65 1F-071_1 MWD -INC (1F-071-1) 7,350.28 7,64991 1 F-071_1 MWD (1 F-071-1) 7,665.00 9,809.62 1 F-01 L1-01 MWD (1 F-0711-01) +N/ -S (usft) 0.00 +E/ -W (usft) 0.00 Tool Name Description BOSS -GYRO Sperry -Sun BOSS gyro multishot MWD-INC_ONLY (INC>10') MWD-INC_ONLY_FILLER (INC>10') MWD OWSG OWSG MWD - Standard MWD OWSG OWSG MWD - Standard Direction (I 180.00 Survey Start Date 8/25/2000 10/30/2019 10/30/2019 11/4/2019 Baker Hughes ✓; 70' 17'4&221 N 149' 40'33.704 W 0.00 usft Field Strength (nT) 57,393 Survey End Date 10/3012019 11/2/2019 11/6/2019 11/20/2019 1:33.1OPM Page 2 COMPASS 5000.14 Build 85H Co n ocoP h i l l i ps Baker Hughes COnocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc Kuparuk Local Co-ordinate Reference: Well 1 F-07 Project: Kuparuk River Unit TVD Reference: 1F-07 @ 115.00usft (1F-07) Site: Kuparuk 1 F Pad MD Reference: 1 F-07 @ 115.00usft (1 F-07) Well: 1 F-07 North Reference: True Wellbore: 1F-071-1-01 Survey Calculation Method: Minimum Curvature Design: 1F-071-1-01 Database: EDT 14 Alaska Production Survey 11/20/2019 1:33:10PM Page 3 COMPASS 5000.14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) V) (usft) (usft) (usft) (usft) (°/loll') Survey Tool Name Annotation (ft) (ft) (ft) 7,649.91 97.67 233.75 6,020.94 5.905.94 -847.25 3,576.65 5.957,368.24 543,589.01 45.27 847.25 MWD OWSG (3) TIP 7,665.00 96.93 241.00 6.019.02 5,904.02 -855.31 3,564.05 5,957,360.11 543,576.45 47.91 855.31 MWD OWSG (4) KOP 7,701.00 100.17 234.39 6,013.66 5,898.66 -874.32 3,533.98 5,957,340.95 543,546.49 20.26 87432 MWD OWSG (4) 7,730.75 103.19 233.01 6,00764 5,892.64 891.56 3,510.50 5,957,323.59 543,523.10 11.12 891.56 MWD OWSG (4) 7,759.84 100.61 232.40 6,001.64 5,886.64 -908.81 3,487.86 5,957,306.22 543,500.55 9.10 908.81 MWD OWSG (4) 7,791.18 97.14 230.93 5,996.81 5,881.81 -928.01 3,463.58 5,957,286.89 543.476.38 12.00 928.01 MWD OWSG (4) 7,819.96 93.64 228.92 5,994.10 5,879.10 -946.45 3,441.66 5,957,268.33 543.454.56 14.01 946.45 MWD OWSG (4) 7,850.33 93.25 225.37 5,992.28 5,877.28 -967.07 3,419.44 5,957,247.60 543,432.45 11.74 967.07 MWD OWSG (4) 7,880.96 93.63 221.83 5,990.44 5,875.44 -989.21 3,398.35 5,957,225.35 543,411.49 11.60 989.21 MWD OWSG (4) 7,901.18 93.13 218.16 5,989.25 5,874.25 -1.004.67 3,385.38 5,957,209.82 543,398.60 18.29 1,004.67 MWD OWSG (4) 7,931.11 92.55 210.63 5.987.76 5.872.76 -1.029.32 3,368.51 5,957,185.09 543,381.86 25.20 1,029.32 MWD OWSG (4) 7,960.96 93.13 206.06 5,986.28 5,871.28 -1,055.55 3,354.36 5,957,158.78 543,367.85 15.41 1,055.55 MWD OWSG (4) 7,990.33 92.24 200.41 5,984.90 5,869.90 -1,082.50 3,342.79 5,957,131.78 543,356.43 19.45 1,082.50 MWD OWSG (4) 8,019.84 92.18 194.75 5,983.76 5,868.77 -1,110.60 3,333.89 5,957,103.63 543,347.68 19.17 1,110.60 MWD OWSG (4) 8,050.86 94.12 192.15 5,982.06 5,867.06 -1,140.72 3,326.68 5,957,073.48 543,340.63 10.45 1,140.72 MWD OWSG (4) 8,081.31 95.23 189.08 5,979.58 5,86458 -1,170.54 3,321.09 5,957,043.63 543,335.20 10.69 1,170.54 MWD OWSG (4) 8,116.09 93.94 187.39 5,976.80 5,861.80 -1,204.85 3,316.13 5,957,009.30 543,330.42 6.10 1,204.85 MWD OWSG (4) 8,145.42 90.95 185.69 5.975.55 5,860.55 -1,233.96 3,312.79 5.956,980.17 543,327.24 1172 1,233.96 MWD OWSG (4) 8,176.22 88.86 187.44 5,975.60 5,860.60 -1.264.55 3,309.27 5.956,949.56 543,323.88 8.85 1,264.55 MWD OWSG (4) 8,206.38 91.14 189.28 5,975.60 5,860.60 -1,294.39 3,304.89 5,956,919.71 543,319.66 9.71 1,294.39 MWD OWSG (4) 8,231.40 90.98 190.95 5,975.13 5,860.13 -1,319.02 3,300.49 5,956,895.06 543,315.39 6.70 1,319.02 MWD OWSG (4) 8,263.06 90.55 190.89 5,974.71 5,859.71 -1,350.10 3,294.50 5,956,863.95 543.309.56 1.37 1,350.10 MWD OWSG (4) e 8,292.68 92.12 194.52 5,974.02 5,859.02 -1,378.98 3,287.98 5,956,835.03 543,303.21 13.35 1,378.98 MWD OWSG (4) 8,317.24 88.25 194.23 5,973.94 5,858.94 -1,402.77 3,281.89 5,956,811.22 543,297.24 15.80 1,402.77 MWD OWSG (4) 8,351.59 86.10 196.00 5,975.64 5,860.64 -1,435.89 3,272.94 5,956,778.06 543,288.47 8.10 1,435.89 MWD OWSG (4) 8,382.95 83.60 195.33 5,978.45 5,863.45 -1,465.96 3,264.51 5,956,747.94 543,280.20 8.25 1,465.96 MWD OWSG (4) 8,412.95 87.39 197.00 5,980.81 5,865.81 -1,494.67 3.256.19 5,956,719.19 543,272.03 13.80 1,494.67 MWD OWSG (4) 8,442.55 89.05 196.32 5,981.73 5,866.73 -1,523.02 3,247.70 5.956,690.80 543,263.70 6.06 1,523.02 MWD OWSG (4) 8,473.43 87.54 191.43 5,982.64 5,867.64 -1,552.97 3,240.30 5,956,660.81 543,256.46 16.57 1,552.97 MWD OWSG (4) 8,505.48 87.05 189,89 5,984.16 5,869.16 -1,584.43 3,234.38 5,956,629.32 543,250.70 5.04 1,584.43 MWD OWSG (4) 11/20/2019 1:33:10PM Page 3 COMPASS 5000.14 Build 85H ConocoPhillips Baker Hughes ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc Kuparuk Local Co-ordinate Reference: Well 1 F-07 Project: Kuparuk River Unit ND Reference: 1 F-07 @ 115.00usft (1 F-07) Site: Kuparuk 1 F Pad MD Reference: 1 F-07 @ 115.00usft (1 F-07) Well: 1 F-07 North Reference: True Wellbore: 1F-071-1-01 Survey Calculation Method: Minimum Curvature Design: 1F-071-1-01 Database: EDT 14 Alaska Production Survey Map Map Vertical - MD Inc Azi TVD TVDSS +N/ -S +E1 -W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 8,534.03 85.48 186.86 5,986.02 5,871.02 -1,612.61 3,230.23 5,956,601.12 543,246.70 11.93 1,612.61 MWD OWSG (4) 8,565.72 85.21 184.77 5,988.59 5,873.59 -1,644.04 3,227.03 5,956,569.69 543,243.67 6.63 1,644.04 MWD OWSG (4) 8,593.13 82.77 179.50 5,991.46 5,876.46 -1,671.26 3,226.01 5,956,542.45 543,242.80 21.09 1,671.26 MWD OWSG (4) 8,622.80 85.14 177.98 5,994.59 5,879.59 -1,700.76 3,226.66 5,956,512.97 543,243.60 9.47 1,700.76 MWD OWSG (4) 8,653.26 87.39 173.32 5,996.57 5,881.57 -1,731.06 3,228.97 5,956,482.68 543,246.07 16.96 1,731.06 MWD OWSG (4) 8,682.82 93.04 171.87 5,996.46 5,881.46 -1,760.36 3232.78 5,956;453.41 543.250.04 19.73 1,760.36 MWD OWSG (4) 8,711.63 89.66 169.71 5,995.78 5,880.78 -1,788.78 3,237.39 5,956,425.01 543,254.80 13,92 1,788.78 MWD OWSG (4) 8,741,86 92.18 171.90 5,995.30 5,880.30 -1,818.62 3,242.22 5,956,395.21 543,259.78 11.04 1,818.62 MWD OWSG (4) 8,773.10 90.18 172.51 5,994.65 5,879.65 -1,849.56 3,246.45 5,956,364.29 543,264.18 6.69 1,849.56 MWD OWSG (4) 8,802.92 94.67 174.26 5,993.39 5,878.39 -1,879.14 3,249.88 5,956,334.72 543,267.77 16.16 1,879.14 MWD OWSG (4) 8,831.38 89.42 170.61 5,992.38 5,877.38 -1,907.32 3,253.63 5.956,306.57 543,271.67 22.46 1,907.32 MWD OWSG (4) 8,863.18 88.86 167.62 5,992.85 5,877.85 -1,938.54 3,259.63 5,956,275.38 543,277.84 9.56 1,938.54 MWD OWSG (4) 8,892.21 90.52 164.54 5,993.01 5,878.01 -1,966.72 3,266.61 5,956,247.25 543,284.97 12.05 1,966.72 MWD OWSG (4) 8,922.96 93.16 163.14 5,992.02 5,877.02 -1,996.23 3,275.17 5,956,217.78 543,293.68 9.72 1,996.23 MWD OWSG (4) 8,952.80 97.30 160.67 5,989.30 5,874.30 -2,024.47 3,284.39 5,956,189.60 543.303.05 16.14 2,024.47 MWD OWSG (4) 8,982.10 95.20 158.13 5,986.11 5,871.11 -2,051.73 3,294.64 5,9567162.40 543,313.44 11.21 2,051.73 MWD OWSG (4) 9,019.68 96.94 162.53 5,982.14 5,867,14 -2,086.91 3,307.22 5,956,127.29 543,326.20 12.53 2,086.91 MWD OWSG (4) 9,052.03 93.01 16311 5,979.33 5,864.33 -2,117.69 3,316.73 5,956,096.56 543,335.88 12.28 2,117.69 MWD OWSG (4) 9,082.58 91.47 166.45 5,978.14 5,863.14 -2,147.14 3,324.75 5,956,067.15 543,344,05 12.03 2,147.14 MWD OWSG (4) 9,112.90 92.67 170.35 5,977.04 5,862.04 -2,176.82 3.330.84 5,956,037.51 543,350.30 13.45 2,176.62 MWD OWSG (4) 9,142.46 91.35 174.85 5,976.01 5,861.01 -2,206.11 3,334.64 5,956,008.25 543,354.26 15.86 2,206.11 MWD OWSG (4) 9,172.82 87.57 178.03 5,976.29 5,861.29 -2,236.40 3,336.53 5,955,977.97 543,356.31 16.27 2,236.40 MWD OWSG (4) 9,201.81 89.94 180.88 5,976.92 5,861.92 -2,265.37 3,336.80 5,955,949.00 543.356.74 12.78 2,265.37 MWD OWSG (4) 9,235.39 93.04 184.11 5,976.05 5,861.05 -2,298.90 3,335.34 5,955,915.47 543.355.45 13.33 2,298.90 MWD OWSG (4) 9,266.71 93.28 188.92 5,974.32 5,859.32 -2,329.96 3,331.79 5,955,884.39 543,352.07 15.35 2,329.96 MWD OWSG (4) ' 9,296.84 91.63 192.18 5,973.03 5,858.03 -2,359.55 3,326.28 5,955,854.78 543,346.72 12.12 2,359.55 MWD OWSG (4) 9,327.04 90.77 194.40 5,972.40 5,857.40 -2,388.94 3,319.34 5.955,825.36 543,339.94 7.88 2,388.94 MWD OWSG (4) 9,358.56 91.72 197.96 5,971.71 5,856.71 -2.419.19 3,310.56 5,955,795.06 543,331.32 11.69 2,419.19 MWD OWSG (4) 9,388.03 89.66 200.54 5,971.36 5,856.36 -2,447.01 3,300.85 5,955,767.19 543,321.75 11.20 2,447.01 MWD OWSG (4) 9,422.15 91.26 204.78 5,971.08 5,856.08 -2,478.49 3,287.71 5,955,735.65 543,308.78 13.28 2,478.49 MWD OWSG (4) 9,452.02 87.72 206.75 5,971.35 5,856.35 -2,505.38 3,274.73 5,955,708.69 543,295.95 13.56 2,505.38 MWD OWSG (4) 11/20/2019 1:33:10PM Page 4 COMPASS 5000.14 Build 85H Annotation Baker Hughes 11/20/2019 1:33:10PM Page 5 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc Kuparuk Local Co-ordinate Reference: Well 1 F-07 Project: Kuparuk River Unit TVD Reference: 1 F-07 @ 115.00usft (1 F-07) Site: Kuparuk 1 F Pad MD Reference: 1 F-07 @ 115.00usft (1 F-07) Well: 1 F-07 North Reference: True Wellbore: 'IF -071-1-01 Survey Calculation Method: Minimum Curvature Design: 1F-071-1-01 Database: EDT 14 Alaska Production Survey Map Vertical - MD Inc Azi TVD TVDSS +N/ -S +E/-W +E! -W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°/100') Section Survey Tool Name (ft) (ft) (ft) 9,481.72 86.62 204.98 5,972.82 5,857.82 -2,532.07 3,261.79 5,955,681.93 543,283.15 7.01 2,532.07 MWD OWSG (4) 9,511.70 88.49 205.92 5,974.09 5,859.09 -2,559.12 3,248.92 5,955,654.82 543,270.42 6.98 2,559.12 MWD OWSG (4) 9,542.13 89.08 205.19 5,974.74 5,859.74 -2,586.56 3,235.79 5,955,627.31 543,257.45 3.08 2,586.56 MWD OWSG (4) 9,573.02 88.83 204.02 5,975.30 5,860.30 -2,614.64 3,222.93 5,955,599.17 543,244.74 3.87 2,614.64 MWD OWSG (4) 9,602.58 87.64 203.94 5,976.21 5,861.21 -2,641.64 3,210.93 5,955,572.11 543,232.88 4.03 2,641.64 MWD OWSG (4) 9,633.60 87.08 203.67 5,977.64 5,862.64 -2,669.99 3,198.42 5,955,543.69 543.220.52 2.00 2,669.99 MWD OWSG (4) 9,664.83 86.47 204.13 5,979.40 5,864.40 -2,698.50 3,185.79 5,955,515.12 543.208.04 2.44 2,698.50 MWD OWSG (4) 9,691.71 85.45 201.64 5,981.29 5,866.29 -2,723.20 3,175.36 5,955,490.37 543,197.75 9.99 2,723.20 MWD OWSG (4) 9,722.12 81.49 202.61 5,984.75 5,869.75 -2,751.18 3,163.98 5,955,462.33 543,186.52 13.40 2,751.18 MWD OWSG (4) 9,753.20 77.29 203.56 5,990.47 5,875.47 -2,779.28 3,152.01 5,955,434.17 543,174.70 13.84 2,779.28 MWD OWSG (4) 9,781.32 73.81 206.70 5,997.49 5,882.49 -2,803.92 3,140.45 5,955,409.47 543,163.28 16.43 2,803.92 MWD OWSG (4) 9,809.62 72.04 208.39 6,005.80 5,890.80 -2,827.91 3,127.95 5,955,385.42 543,150.90 8.47 2,827.91 MWD OWSG (4) 9,846.00 72.04 208.39 6,01202 5,902.02 -2,858.35 3,111.49 5,955,354.89 543,134.61 0.00 2,858.35 PROJECTED to TD Annotation Baker Hughes 11/20/2019 1:33:10PM Page 5 COMPASS 5000.14 Build 85H THE STATE Alaska Oil and Gas ofALASKA Conservation Commissi®n GOVERNOR BILL WALKER James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1F -07L1-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-074 Surface Location: 1331' FNL, 27' FWL, SEC. 20, TI IN, R1OE, UM Bottomhole Location: 4203' FNL, 2172' FEL, SEC. 20, TI IN, RI OE, UM 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fox: 907.276.7542 www.aogcc.alaska.gov Dear Mr. Ohlinger: Enclosed is the approved application for the permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 182-156, API No. 50-029-20830-00- 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, Hollis S. French Chair r� DATED this S day of July, 2018. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSiuN PERMIT TO DRILL 20 AAC 25.005 1%EI ®ED JUN 2 0 209$ 1 a. Type of Work: . 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑ Lateral ❑✓ Stratigraphic Test ❑ Development - Oil Service - Winj ❑ Single Zone ❑� Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑✓ , Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska Inc Bond No. 5952180 KRU 1F-071-11-01 3. Address: 6. Proposed Depth:- r y �cSC� ' 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 9,800' yZ>Sg,TVD-5844' Kuparuk River Pool / 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1331' FNL, 2T FWL, Sec. 20, T11N, R10E, UM � ADL 25652 irf Kuparuk River Oil Pool Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 2151' FNL, 1680' FEL, Sec 20, T11 N, R1 OE, UM LONS 80-259 7/9/2018 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 4203' FNL, 2172' FEL, Sec 20, T11 N, R10E, UM 2480' 29025' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10, KB Elevation above MSL (ft): 115' 15. Distance to Nearest Well Open Surface: x- 540008 y- 5958196 ' Zone- 4 GL / BF Elevation above MSL (ft): 74' to Same Pool: 612', 1F-16 16. Deviated wells: Kickoff depth: 7600' feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 100 degrees Downhole: 3869 Surface: 3279 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" 4.6# L-80 ST -L 2595' 7205' 5887' 9800' 5844' 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): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 8060' 6717' 7942' 6617' 7585' Casing Length Size Cement Volume MD TVD Conductor 45' 16" 295 sx AS11 80' 80' Surface 2224' 10-3/4" 1100 sx ext. perm. 250 sx Perm C 2259' 2189' Production 8013' 17" 1 000s Class G 8045' 6705' Perforation Depth MD (ft): 7184'-7244', 7255'- 7260' Perforation Depth TVD (ft): 5984'- 6033", 6043'- 6047' 7268'- 7282', 7393'-7405' 6053'- 6065", 6157'- 6167' 7420'- 7,446', 7453'- 7458' 6179'- 6201', 6207'- 6211' Hydraulic Fracture planned? Yes ❑ No ❑, 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program TimDepth ❑ Analysis Shallow dui ❑✓ Divertter Sketch Dri li geFluid Progrv. Seabed Report am 20 AAC 25.050 regot ementse✓ 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: Keith Herring Authorized Name: James Ohlinger Contact Email: Keith. E. Herrin CO .cont Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4321 Authorized Signature: Date: Commission Use Only Permit to Drill __C7 API Number: Permit Approval See cover letter for other Number: 50 -p Z / , � Date: 30 requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: _LuP�l�✓p ,Qp�� %�� Ta 5/60013' Samples req'd: YesNolo/Mud log req'd: Yes❑ No[ i J HzS measures: Yes No ❑ : Directional svy req'd: Yes 9 No ❑ Spacing exception req'd: Yes ❑ Noff Inclination -only svy req'd: Yes❑ No [+]' Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ORIGINAL S6 it Form�and / Form 10-401 Revised 5/2017 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Attachments in Duplicate ConocoPhilli s p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 18, 2018 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill two laterals out of the KRU 1 F-07 (PTD# 182-156) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in July 2018. The objective will be to drill two laterals KRU 1 F-071_1 and 1F-071_1-01 targeting the Kuparuk C -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20.—'— AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to this application are the following documents: - Permit to Drill Application Forms (10-401) for 1 F-071_1 and 1 F-071_1-01 - Detailed Summary of Operations - Directional Plans for 1 F-071_1 and 1 F-071_1-01 - Current wellbore schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, Keith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska x- Kuparuk CTD Laterals 1F-071-1 and 1F-071-1-01 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b))................................................................................................................... 2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3))................................................................................................................................................. 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005 (c)(4)).. ............................................................................................................................................... 2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)).................................................................................................................................................. 2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)).................................................................................................................................................. 3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7)).................................................................................................................................................. 3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)).................................................................................................................................................. 3 9. Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9)).................................................................................................................................................. 4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................ 4 11. Seabed Condition Analysis............................................................................................................4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................ 4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4 13. Proposed Drilling Program............................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 5 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 5 15. Directional Plans for Intentionally Deviated Wells....................................................................... 5 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 5 16. Attachments.................................................................................................................................... 6 Attachment 1: Directional Plans for 1 F -07L1 and 1 F -07L1-01 laterals............................................................................6 Attachment 2: Current Well Schematic for 1 F-07............................................................................................................6 Attachment 3: Proposed Well Schematic for 1 F -07L1 and 1 F -07L1-01 laterals..............................................................6 Page 1 of 6 June 18, 2018 PTD Application: 1 F -07L1 and 1 F-071_1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1F -07L1 and 1 F -07L1-01. 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 C sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1F -07L1 and 1F-071_1-01. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,000 psi. Using the maximum formation pressure in the area of 3,869 psi in 1 L-05 (i.e. 12.62 ppg EMW), the maximum potential surface pressure in 1 L-05 assuming a gas gradient of 0.1 psi/ft, would be 3,279 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1 F-07 was measured to be 2,645 psi (8.34 ppg EMW) on 2/24/2017. The maximum downhole pressure in the 1 F-07 vicinity is the 1 L-05 at 3,869 psi (12.62 ppg EMW) measured on 4/08/2013. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) Offset injection wells to 1 F-07 are currently injecting gas, there is a probability of encountering freegaswhile drilling the 1 F-07 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 1 F-07 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 1 F-07 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 June 18, 2018 PTD Application: 1 F-071_1 and 1 F -07L1-01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 1F-071-1 7,600' 10,500' 5,914' 5,989' 2-3/8", 4.7#, L-80, ST -L slotted liner; 0' 80' 1640 630 Surface aluminum billet on to 1F-071-1-01 7,205' 9,800 5,887' 5,844' 2-3/8", 4.7#, L-80, ST -L slotted liner; 2,189' 7930 6620 Production 7" shorty deployment sleeve on to Existing Casing/Liner Information Category OD Weight (ppf)MD Grade Connection Top Btm MD Top TVD Btm TVD Burst Collapse psi Conductor 16" 62.5 H-40 Welded 0' 80' 0' 80' 1640 630 Surface 10-3/4" 45.5 K-55 BUTT 0' 2,259' 0' 2,189' 7930 6620 Production 7" 26.0 K-55 BTC 0' 8,045' 0' 6,704' 7240 5410 Tubing 3-1/2" 9.3 J-55 I BTC IPC 0' 1 7,338' 0' 6,112' 1 10160 10540 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 11.8 ppg NaBr completion fluid in order to provide formation over -balance and shale stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation 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 1 F-07 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 June 18, 2018 PTD Application: 1 F-071-1 and 1 F-071-1-01 Pressure at the 1F-07 Wincinw 17210' Mn_ R00R' TVn1 [kinn MPn 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 Well KRU 1 F-07 is a Kuparuk A -sand & C -sand producer equipped with 3-1/2" tubing and 7" production casing. A rig workover will be conducted prior to any Pre -CTD Sidetrack work. The CTD sidetrack will utilize two laterals to target the C sand to the north and south of the 1 F-07 parent wellbore. The laterals will increase recovery and add additional resources. Pre -CTD Work 1. RU Slickline: Pull sheared SOV, Drift dummy whipstock 2. RU E -Line: RIH and set whispstock on depth 3. Prep site for Nabors CDR3-AC rig. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPS, test. 2. 1 F -07L1 Sidetrack (C4 sand - north) a. Mill 2.80" window at 7,210' MD. b. Drill 3" bi-center lateral to TD of 10,500' MD. c. Run 2-3/8" slotted liner with aluminum billet from TD up to 7,600' MD. Page 4 of 6 June 18, 2018 Pumps On 1.8 bpm) Pumps Off C -sand Formation Pressure 8.34 2,645 psi 2,645 psi Mud Hydrostatic 8.6 2,685 psi 2,685 psi Annular friction i.e. ECD, 0.08psi/ft) 575 psi 0 psi Mud + ECD Combined no chokepressure) 3,260 psi Overbalanced —615psi) 2,644 psi Overbalanced --40psi) Target BHP at Window 11.8 3,685 psi 3,685 psi Choke Pressure Required to Maintain Target BHP 425 psi 1000 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 Well KRU 1 F-07 is a Kuparuk A -sand & C -sand producer equipped with 3-1/2" tubing and 7" production casing. A rig workover will be conducted prior to any Pre -CTD Sidetrack work. The CTD sidetrack will utilize two laterals to target the C sand to the north and south of the 1 F-07 parent wellbore. The laterals will increase recovery and add additional resources. Pre -CTD Work 1. RU Slickline: Pull sheared SOV, Drift dummy whipstock 2. RU E -Line: RIH and set whispstock on depth 3. Prep site for Nabors CDR3-AC rig. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPS, test. 2. 1 F -07L1 Sidetrack (C4 sand - north) a. Mill 2.80" window at 7,210' MD. b. Drill 3" bi-center lateral to TD of 10,500' MD. c. Run 2-3/8" slotted liner with aluminum billet from TD up to 7,600' MD. Page 4 of 6 June 18, 2018 PTD Application: 1 F-071_1 and 1 F-071_1-01 1 F -07L 1 -0 1 Lateral (C4 sand - south) a. Kick off of the aluminum billet at 7,600'' MD. b. Drill 3" bi-center lateral to TD of 9,800' MD. c. Run 2-3/8" slotted liner with liner top from TD up to 7,205' MD. 4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig 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 double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. - Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. - Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. - When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. - The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA un -deployment, the steps listed above are observed, only in reverse. Liner Running - The 1 F-07 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. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AA 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) Page 5 of 6 June 18, 2018 PTD Application: 1 F -07L1 and 1 F -07L1-01 - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1 F-071-1 29,950' 1F-071-11-011 29,025' - Distance to Nearest Well within Pool Lateral Name Distance Well 1 F -07L1 1554' 1 E-28AL1 1 F-071-1-01 612' 1F-16 16. Attachments Attachment 1: Directional Plans for 1 F -07L 1 and 1 F -07L 1-01 laterals Attachment 2. Current Well Schematic for 1F-07 Attachment 3: Proposed Well Schematic for 1 F -07L 1 and 1 F -07L 1-01 laterals Page 6 of 6 June 18, 2018 ConocoPhillips Project: Kuparuk River Unit Site: Kuparuk 1F Pad Azimuths to True Narth Magnetic Nodh 16.89• Magnetic Field WELLBORE DETAILS. 1F -07L1 REFERENCE INFORMATION Parent Wellbore. 1 F-07 Cc-orduale (WE) Reference: Well 1F-07, True North Well: 1F-07 sfreNth:57e62.9enT Tie on MD: 7200.00 Vertical (TVD) Reference: 1F-07 C 115.00u0 (1F-07) Section (VS) Reference: Slot - (O,OON, O.00E) Wellbore: 11F-071-11 Plan: 1F -07L1 w 06 1F-07/1 F-071-1 P ( ) Dip Angle: 60.66• Da, 911=18 Measured Depth Reference: 1F-07 @ 115,00ustt (1F-07) — Modal: BGGM2017 Calculation Method: Minimum Curvature BA ER F�UGHES a GE company ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk IF Pad 1 F-07 1 F -07L1-01 Plan: 1 F-071-1-01_wp02 Standard Planning Report 29 May, 2018 BSE BA 0 GE company ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 F-07 Mean Sea Level 1 F-07 @ 115.00usft (1 F-07) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) - System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor BA ER 1 UGNES a GE company Site Kuparuk 1 F Pad Site Position: Northing: 5,958,365.15 usft Latitude: 70° 17'49.903 N From: Map Easting: 539,591.86 usft Longitude: 149° 40'45.817 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.30 ° Well 1 F-07 Well Position +N/ -S 0.00 usft Northing: 5,958,196.36 usft - Latitude: 70° 17'48.221 N +E/ -W 0.00 usft Easting: 540,008.25 usft Longitude: 149° 40' 33.704 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft i Wellbore 1F-071-1-01 `---- -- -- -�I Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) (1) (nT) BGGM2017 5/23/2018 17.05 80.88 57,463 Design 1F-071-1-01_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,600.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 180.00 Plan Sections ConocoPhillips Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kuparuk River Unit Site: Kuparuk 1 F Pad Well: 1 F-07 Wellbore: 1 F -07L1-01 Design: 1 F-07L1-01_wp02 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 F-07 Mean Sea Level 1 F-07 @ 115.00usft (1 F-07) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) - System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor BA ER 1 UGNES a GE company Site Kuparuk 1 F Pad Site Position: Northing: 5,958,365.15 usft Latitude: 70° 17'49.903 N From: Map Easting: 539,591.86 usft Longitude: 149° 40'45.817 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.30 ° Well 1 F-07 Well Position +N/ -S 0.00 usft Northing: 5,958,196.36 usft - Latitude: 70° 17'48.221 N +E/ -W 0.00 usft Easting: 540,008.25 usft Longitude: 149° 40' 33.704 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft i Wellbore 1F-071-1-01 `---- -- -- -�I Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) (1) (nT) BGGM2017 5/23/2018 17.05 80.88 57,463 Design 1F-071-1-01_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,600.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 180.00 Plan Sections Measured TVD Below Dogleg Build Tum Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (°) (°j (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (°) Target 7,600.00 93.88 222.58 5,913.75 -818.63 3,575.39 0.00 0.00 0.00 0.00 7,715.00 100.84 218.50 5,899.02 -905.21 3,501.30 7.00 6.05 -3.55 330.00 7,865.00 95.47 209.37 5,877.71 -1,028.27 3,418.59 7.00 -3.58 -6.08 240.00 8,090.00 95.27 193.56 5,856.53 -1,236.07 3,336.88 7.00 -0.09 -7.03 270.00 8,440.00 92.72 169.13 5,831.77 -1,582.43 3,328.89 7.00 -0.73 -6.98 265.00 8,740.00 90.75 190.04 5,822.56 -1,880.61 3,331.02 7.00 -0.66 6.97 95.00 9,015.00 88.08 170.98 5,825.38 -2,154.29 3,328.57 7.00 -0.97 -6.93 262.00 9,275.00 89.74 189.11 5,830.36 -2,413.15 3,328.37 7.00 0.64 6.97 85.00 9,500.00 88.12 204.78 5,834.59 -2,627.67 3,263.03 7.00 -0.72 6.96 96.00 9,800.00 88.25 225.79 5,844.20 -2,871.07 3,090.81 7.00 0.04 7.00 90.00 5/29/2018 1:43:54PM Page 2 COMPASS 5000.14 Build 85 - ConocoPhillips BA_ j(ER ConocoPhillips Planning Report F-' IGHES BAT GE company Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 1 F-07 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 F-07 @ 115.00usft (1 F-07) Site: Kuparuk IF Pad North Reference: True Well: 1 F-07 Survey Calculation Method: Minimum Curvature Wellbore: IF -071-1-01 Measured Design: 1 F -07L1-01 _wp02 5/29/2018 1:43:54PM Page 3 COMPASS 5000.14 Build 85 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) (°1100ft) (°) (usft) (usft) I 7,600.00 93.88 222.58 5,913.75 -818.63 3,575.39 818.63 0.00 0.00 5,957,396.85 543,587.60 TIP/KOP 7,700.00 99.93 219.04 5,901.73 -893.71 3,510.53 893.71 7.00 -30.00 5,957,321.44 543,523.15 7,715.00 100.84 218.50 5,899.02 -905.21 3,501.30 905.21 7.00 -30.43 5,957,309.89 543,513.97 Start 7 dls 7,800.00 97.82 213.30 5,885.24 -973.13 3,452.15 973.13 7.00 -120.00 5,957,241.71 543,465.19 7,865.00 95.47 209.37 5,877.71 -1,028.27 3,418.59 1,028.27 7.00 -120.84 5,957,186.41 543,431.93 3 7,900.00 95.47 206.91 5,874.38 -1,058.98 3,402.16 1,058.98 7.00 -90.00 5,957,155.60 543,415.66 8,000.00 95.40 199.88 5,864.90 -1,150.29 3,362.65 1,150.29 7.00 -90.23 5,957,064.10 543,376.65 8,090.00 95.27 193.56 5,856.53 -1,236.07 3,336.88 1,236.07 7.00 -90.90 5,956,978.19 543,351.34 4 8,100.00 95.20 192.86 5,855.61 -1,245.76 3,334.61 1,245.76 7.00 -95.00 5,956,968.48 543,349.12 8,200.00 94.55 185.86 5,847.10 -1,344.01 3,318.42 1,344.01 7.00 -95.06 5,956,870.16 543,333.45 i 8,300.00 93.83 178.88 5,839.79 -1,443.60 3,314.30 1,443.60 7.00 -95.66 5,956,770.56 543,329.86 8,400.00 93.05 171.91 5,833.79 -1,543.03 3,322.31 1,543.03 7.00 -96.17 5,956,671.18 543,338.40 8,440.00 92.72 169.13 5,831.77 -1,582.43 3,328.89 1,582.43 7.00 -96.59 5,956,631.82 543,345.19 6 8,500.00 92.35 173.31 5,829.11 -1,641.66 3,338.04 1,641.66 7.00 95.00 5,956,572.65 543,354.65 8,600.00 91.70 180.29 5,825.57 -1,741.38 3,343.61 1,741.38 7.00 95.19 5,956,472.97 543,360.76 8,700.00 91.03 187.26 5,823.19 -1,841.07 3,337.04 1,841.07 7.00 95.43 5,956,373.26 i 543,354.71 8,740.00 90.75 190.04 5,822.56 -1,880.61 3,331.02 1,880.61 7.00 95.60 5,956,333.69 543,348.91 6 8,800.00 90.17 185.89 5,822.08 -1,940.01 3,322.71 1,940.01 7.00 -98.00 5,956,274.25 543,340.91 8,900.00 89.19 178.95 5,822.64 -2,039.86 3,318.49 2,039.86 7.00 -98.03 5,956,174.39 543,337.23 9,000.00 88.23 172.02 5,824.90 -2,139.46 3,326.35 2,139.46 7.00 -97.99 5,956,074.84 543,345.62 9,015.00 88.08 170.98 5,825.38 -2,154.29 3,328.57 2,154.29 7.00 -97.84 5,956,060.03 543,347.91 7 j 9,100.00 88.61 176.91 5,827.83 -2,238.74 3,337.53 2,238.74 7.00 85.00 5,955,975.63 543,357.32 9,200.00 89.25 183.88 5,829.70 -2,338.66 3,336.85 2,338.66 7.00 84.83 5,955,875.72 543,357.17 9,275.00 89.74 189.11 5,830.36 -2,413.15 3,328.37 2,413.15 7.00 84.70 5,955,801.20 543,349.09 8 9,300.00 89.56 190.85 5,830.52 -2,437.77 3,324.04 2,437.77 7.00 96.00 5,955,776.56 543,344.89 9,400.00 88.83 197.81 5,831.93 -2,534.59 3,299.31 2,534.59 7.00 95.99 5,955,679.62 543,320.68 9,500.00 88.12 204.78 5,834.59 -2,627.67 3,263.03 2,627.67 7.00 95.89 5,955,586.35 543,284.90 9 9,600.00 88.14 211.78 5,837.86 -2,715.64 3,215.71 2,715.64 7.00 90.00 5,955,498.14 543,238.06 9,700.00 88.18 218.78 5,841.08 -2,797.18 3,158.02 2,797.18 7.00 89.77 5,955,416.31 543,180.80 j 91800.00 88.25 225.79 5,844.20 -2,871.07 3,090.81 2,871.07 7.00 89.55 5,955,342.06 543,114.00 Planned TD at 9800.00 - 5/29/2018 1:43:54PM Page 3 COMPASS 5000.14 Build 85 - ConocoPhillips BAT ER ConocoPhillips Planning Report F f U HES E a GE company Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 1 F-07 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 F-07 @ 115.00usft (1 F-07) Site: Kuparuk 1 F Pad North Reference: True Well: 1 F-07 Survey Calculation Method: Minimum Curvature Wellbore: 1F-071-1-01 5,955,826.00 1,683,377.00 Design: 1 F-071-1-01_wp02 plan misses target center by 1139902.4lusft at 7600.00usft MD (5913.75 TVD, -818.63 N, 3575.39 E) Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting - Shape (I V) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1F -071-1-01_T03 0.00 0.00 5,825.00 -8,457.741,143,452.20 5,955,826.00 1,683,377.00 70° 2' 16.700 N 140° 30'11.762 W plan misses target center by 1139902.4lusft at 7600.00usft MD (5913.75 TVD, -818.63 N, 3575.39 E) Point 1F -071-1-01_T01 0.00 0.00 5,865.00 -71468.831,143,488.46 5,956,815.00 1,683,408.00 70° 2'26.247 N 140° 30'6.466 W plan misses target center by 1139932.47usft at 7600.00usft MD (5913.75 TVD, -818.63 N, 3575.39 E) Point 1F-07 CTD Polygon Nor 0.00 0.00 0.00 -6,708.841,143,695.53 5,957,576.00 1,683,611.00 70° 2' 33.320 N 140° 29'57.301 W plan misses target center by 1140150.69usft at 7600.00usft MD (5913.75 TVD, -818.63 N, 3575.39 E) Polygon Point 1 0.00 0.00 0.00 5,957,576.00 1,683,611.00 Point 0.00 -172.08 202.12 5,957,405.02 1,683,814.01 Point 3 0.00 -376.42 262.04 5,957,201.02 1,683,875.01 Point 4 0.00 -654.08 190.57 5,956,923.01 1,683,805.03 Point 5 0.00 -722.18 -170.83 5,956,852.99 1,683,444.03 Point 6 0.00 -595.80 -430.19 5,956,977.98 1,683,184.03 Point? 0.00 -242.57 -465.33 5,957,330.98 1,683,147.01 Point 8 0.00 710.28 -228.28 5,958,284.99 1,683,378.96 Point 9 0.00 2,740.02 -324.59 5,960,313.98 1,683,271.86 Point 10 0.00 2,617.95 64.81 5,960,194.00 1,683,661.87 Point 11 0.00 708.18 169.75 5,958,285.00 1,683,776.96 Point 12 0.00 0.00 0.00 5,957,576.00 1,683,611.00 1 F -071-1-01T02 0.00 0.00 5,829.00 -7,959.751,143,463.85 5,956,324.00 1,683,386.00 70° 2' 21.517 N 140° 30' 9.283 W plan misses target center by 1139910.83usft at 7600.00usft MD (5913.75 TVD, -818.63 N. 3575.39 E) Point 1F-07 CTD Polygon SOL 0.00 0.00 0.00 -7,973.061,143,708.81 5,956,312.00 1,683,631.00 70° 2'21.027 N 140° 30'2.379 W plan misses target center by 1140171.20usft at 7600,00usft MD (5913.75 TVD, -818.63 N, 3575.39 E) Polygon Point 1 0.00 0.00 0.00 5,956,312.00 1,683,631.00 Point 0.00 610.18 169.24 5,956,923.01 1,683,796.97 Point 3 0.00 894.79 247.74 5,957,208.01 1,683,873.95 Point 4 0.00 1,117.22 171.91 5,957,430.01 1,683,796.94 Point 5 0.00 1,271.22 -14.30 5,957,583.00 1,683,609.94 Point 0.00 1,266.35 -419.37 5,957,575.98 1,683,204.94 Point? 0.00 1,021.64 478.67 5,957,330.98 1,683,146.95 Point 8 0.00 676.45 449.48 5,956,985.98 1,683,177.97 Point 0.00 -782.43 -504.18 5,955,526.97 1,683,131.04 Point 10 0.00 -1,578.74 -842.42 5,954,728.95 1,682,797.08 Point 11 0.00 -1,733.80 1154.19 5,954,575.98 1,683,186.09 Point 12 0.00 1,276.72 270.76 5,955,033.98 1,683,367.07 Point 13 0.00 -819.66 -81.33 5,955,492.00 1,683,554.04 Point 14 0.00 0.00 0.00 5,956,312.00 1,683,631.00 1F -071-1-01_T04 0.00 0.00 5,835.00 -8,946.461,143,388.59 5,955,337.00 1,683,316.00 70° 2' 12.049 N 140° 30' 15.677 W plan misses target center by 1139842.18usft at 7600.00usft MD (5913,75 TVD, -818.63 N, 3575.39 E) Point 1F -07L1 -01_T05 0.00 0.00 5,844.00 -9,189.581,143,217.27 5,955,093.00 1,683,146.00 70° 2'9.941 N 140° 30'21.593 W plan misses target center by 1139672.63usft at 7600.00usft MD (5913.75 TVD, -818.63 N, 3575.39 E) Point 5/29/2018 1:43:54PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 F-07 Mean Sea Level 1 F-07 @ 115.00usft (1 F-07) True Minimum Curvature BAKER UGMES a 6E company Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,800.00 5,844.20 2 3/8" 2.375 3.000 Pian Annotations ConocoPhillips Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup1 Project Kuparuk River Unit Site: Kuparuk 1 F Pad Well: 1 F-07 Wellbore: IF -071-1-01 Design: 1F -07L1-01 Wp02 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 F-07 Mean Sea Level 1 F-07 @ 115.00usft (1 F-07) True Minimum Curvature BAKER UGMES a 6E company Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,800.00 5,844.20 2 3/8" 2.375 3.000 Pian Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 7,600.00 5,913.75 -818.63 3,575.39 TIP/KOP 7,715.00 5,899.02 -905.21 3,501.30 Start 7 dis 7,865.00 5,877.71 -1;028.27 3,418.59 3 8,090.00 5,856.53 -1,236.07 3,336.88 4 8,440.00 5,831.77 -1,582.43 3,328.89 5 8,740.00 5,822.56 -1,880.61 3,331.02 6 9,015.00 5,825.38 -2,154.29 3,328.57 7 9,275.00 5,830.36 -2,413.15 3,328.37 8 9,500.00 5,834.59 -2,627.67 3,263.03 9 9,800.00 5,844.20 -2,871.07 3,090.81 Planned TD at 9800.00 5/29/2018 1:43:54PM Page 5 COMPASS 5000.14 Build 85 N'-' Baker Hughes INTEQ BA_ (ER ConocoPhillips Travelling Cylinder Report UGHES a GE company Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Reference Site: Kuparuk 1F Pad Site Error. 0.00 usft Reference Well: 1 F-07 Well Error. 0.00 usft Reference Wellbore 1F-071-1-01 Reference Design: 1 F-07L1-01_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 F-07 1 F-07 @ 115.00usft (1 F-07) 1 F-07 @ 115.00usft (1 F-07) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Reference 1F-07L1-01_wp02 Filtertype: GLOBAL FILTER APPLIED: All weilpaths within 2004 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,600.00 to 9,800.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,168.50 usft Error Surface: Pedal Curve Survey Tool Program Date 5/29/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description 200.00 7,200.00 1 F-07 (1 F-07) BOSS -GYRO Sperry -Sun BOSS gyro muitishot 7,200.00 7,600.00 1 F-07L1_wp06 (1 F-071-1) MWD MWD - Standard 7,600.00 9,800.00 1F-071-1-01_wp02(1F-071-1-01) MWD MWD - Standard Casing Points IMeasured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 9,800.00 5,959.20 2 3/8" 2-3/8 3 Summary Kuparuk 1F Pad- 1F-07- 1 F-07 - 1F-07 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) Vertical (usft) Vertical Kuparuk 1 F Pad offset Toolface + Offset Wellbore Centre Casing - Centre to No Go 1 F-05 - 1 F-05 - 1 F-05 Depth Depth Depth Depth Out of range 1 F-06 - 1 F-06 - 1 F-06 +NIS +H -W Note Size Centre Distance Out of range 1 F-07 - 1 F-07 - 1 F-07 7,605.53 6,925.00 498.81 10.70 493.92 Pass - Major Risk 1 F-07 - 1 F-071_1 - 1 F -07L1 _wp06 (usft) r) (usft) (usft) (usft) Out of range 1 F-08 - 1 F-08 - 1 F-08 6,925.00 5,771.68 0.53 0.00 -78.67 Out of range 1 F-16 - 1 F-16 - 1 F-16 9,450.00 8,025.00 616.69 208.08 426.63 Pass - Major Risk 1 F-16 - 1 F -16A - 1 F -16A 9,459.12 8,075.00 613.02 203.94 423.53 Pass - Major Risk 1 F-16 - 1 F-16AL1 - 1 F-16AL1 9,459.12 8,075.00 613.02 203.84 423.66 Pass - Major Risk 1F-16-1F-16AL1-01-1F-16AL1-01 9,459.12 8,075.00 613.02 203.84 423.66 Pass - Major Risk 1 F-16 - 1 F-16AL1-02 - 1 F-16AL1-02 9,459.12 8,075.00 613.02 203.90 423.66 Pass - Major Risk 1 F-20 - 1 F-20 - 1 F-20 0.00 -82.63 -508.52 3.225.92 3 Out of range 1 F-20 - 1 F-20PB1 - 1 F-20PB1 558.71 Pass - Major Risk 7,640.18 6,025.18 6,825.00 5,691.40 Out of range Offset Design Kuparuk 1F Pad- 1F-07- 1 F-07 - 1F-07 Offset Site Error: 0.00 usft Survey Program: 200 -BOSS -GYRO Rule Assigned: Major Risk Offset Well Error. 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference offset Toolface + Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +NIS +H -W Note Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (I (usft) (usft) r) (usft) (usft) (usft) 7,605.53 6,028.36 6,925.00 5,771.68 0.53 0.00 -78.67 -520.66 3,268.84 3 498.81 10.70 493.92 Pass - Major Risk, CC, ES, SF 7.613.80 6,027.71 6,900.00 5,751.52 0.57 0.00 -80.08 -516.62 3,254.62 3 520.36 10.83 515.33 Pass - Major Risk 7,622.33 6,026.97 6,875.00 5,731.42 0.61 0.00 -81.39 -512.57 3,240.31 3 542.10 10.95 536.93 Pass - Major Risk 7,631.12 6,026.13 6,850.00 5,711.38 0.66 0.00 -82.63 -508.52 3.225.92 3 564.00 11.07 558.71 Pass - Major Risk 7,640.18 6,025.18 6,825.00 5,691.40 0.70 0.00 -83.79 -504,46 3,211.46 3 586.03 11.17 580.63 Pass- Major Risk 7,649.52 6,024.11 6,800.00 5,671.47 0.75 0.00 -84.89 -500.39 3,196.93 3 608.18 11.26 602.67 Pass - Major Risk 7,659.15 6,022.90 6,775.00 5,651.61 0.77 0.00 -85.94 -496.33 3,182.30 3 630.42 11.40 624.77 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 5/29/2018 10:40:28AM Page 2 COMPASS 5000.14 Build 85 O M tMii a E d Co 3 a o. (ui/ljsn Oct) (+)quoN/(-)glnoS (ui/)jsn cg) gldaQ lzoiljan onlL p O M JM p m O O O 0 rn CU d p a c O c cd Ca m Uc 4 F -)M V eco t�Nw v ko N N O� t O N 0 U) .6 tO NORM rr aZ O N M N N N O � N N N N 73 N N N N 0 0 0 0 0 0 0 0 0 0 0 O J 0 0 0 0 0 0 0 0 0 0 LL Q Cj O O �[J to N to N O H M V'ti tO Q)tD N QSO M N N N N a)O 0 0 0 0 0 0 0 0 0 a0 N O O O O O O O O O O F- Q O N r-.: r r �OO a)Nm t� M� M M A 0q N O�q M O N tlJ u* c2 O00 tT� C N � "t MN NNcO O� + �M 0 M M 0") N - 7CO p m m m m m m m m M M UJ u O J W O U)M I I M a ^f t Q O "I" t O N N 0 N N t O 0 Z N Lo N 0 o N O at M n N wLC)} O NMN N tO a O O O N N Q N N N CV J J w U)�N e -M n 00 N 0000 U)� O tO M M U! N CM(D pM ai CM L O > 0NNMM<T � N N N G O N N N N f J 0 o t-- MLq U) L0 N N M M O O O a> VLci NN O C (O a) h p> O N N N N N CNN V'Nr I+O t-�N CD M O O A N O N O O O N p rnoa)0)ma .0ww LLJo + p0000000000 g0000000000 C; vi iri 000 1616 6 C o� Co C:- t oo COI NOC ION ([]N Co Nrnrnrnrn NO O U�NMa �O�Na�O Z O (ui/)jsn cg) gldaQ lzoiljan onlL KUP PROD 1 F-07 ConocoF IIIPS Well Attributes Max Angie & MD JTD Alaska, Inc, LA16m.,Wellbore 122 API/l1W Field Name Wellbore S acus nd r) I Act St. (ftKB) 500292083000 KUPARUK RIVER UNITPROD 44.83 5,700.00 8,060.0 Comment H2S (ppm) DateAnnotation SSSV: TRDP 40 9/10/2016 End Date Last WO: 9/10/1984 KB-Grd IN) Rig Release Date 40.59 10/21/1982 1F-07,1'14 17204:27PM sc .-maoc ladua Annotation Depth (ftKB) End Date Annotation Last Mod By End Date HANGER, 223 Last Tag. SLM 7,396.0 8/10/2017 Rev Reason: TAG & GLV C/O (#6&#7) pproven 12/4/2017 Casing Stnngs Casing Description OD (in) ID (in) Top (ftKB) Set Depth (f KS) Set Depth (TVD)... WVLen (I Grade Top Thread CONDUCTOR 16 15.250 35.0 80.0 80.0 65.00 H-40 WELDED Casing Description OD (in) ID (jn) Top (ft)(B) Set Depth (ft(B)Set Depth (TVD)... WULen (I... Grade Top Thread SURFACE 103/ 9,950 34.2 2,258.7 2,189.0 45.50 K-55 BUTT Casing Description OD (In) ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtfLen (I... Grade Top Thread PRODUCTION 7 6.276 32.1 8,045.0 6.704.5 26.00 K-55 BTC Tubing Strings CONDUCTOR. 35.0-800 Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (R. Set Depth (T 1 (,,. Wt 1111) Grade Top Connection TUBING 3112 2.992 22,3 7.338.4 6,112.2 9.30 J-55 BTCIPC SAFETY VLV. 1.855 1 Completion Details Nominal ID Top (ftKB) Top (ND) (ftKB) Top Ind (°) Item Des Co. (in) 22.3 22.3 0.10 HANGER FMC GEN II HANGER 3.500 GAS LIFT. 1,933.3 1,855.1 1,836.1 23.46 SAFETY VLV OTIS OLS SAFETY VALVE w/ X NIPPLE PROFILE ON 2.813 TOP 7,005.4 5,837.0 35.16 SBR OTIS SBR w/ X NIPPLE PROFILE 2.813 7,030.9 5,857.9 34.97 PACKER OTIS RH RETRIEVABLE PACKER (HYD SET) 4.000 7,172,9 5,974.9 34.10 BLAST RINGS BLAST RINGS (4) 2.992 SURFACE: 34.2-2,258 7- 7,310,8 6,089.2 34.02 LOCATOR OTIS STRAIGHT SLOT LOCATOR 3.000 GAS LIFT: 3.1452 7,312.0 6,090.2 34.02 PACKER OTIS WD PERMANENT PACKER 4.000 7,315.9 6,093.4 34.01 MILL OTIS MILL OUT EXTENSION 4.350 GAS LIFT: 4,3266 7,331.9 6,106.8 33.96 NIPPLE OTIS 2.81"XNS POLISHED BORE NIPPLE w/ 2.75" NO 2.813 GO GAS LIFT. 5,466.0 7,337.8 6,111.6 33.95 SOS OTIS SHEAR OUT SUB, ELMD TTL @7333' during 4.470 PPROF on 3/22/2008 GAS LIFT; 6.277, Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ND) Top Incl Top (ftKB) (ftKB) (°) Des Com Run Date ID (in) 7,182.0 5,982.5 34.06 PATCH 10/13/2006- SET TTS LOWER PACKER ELEMENT 10/15/2006 1.625 GAS LIFT, 6.9652 OF A PATCH AT 7202.5' BASED ON SWS LDL. PACKER MID ELEMENT SET DEPTH: 7202.5' 10/15/2006 - SET UPPER TTS PKR & SPACER se'; 7.0054 ASS 'Y (DAL: 25.08', MIN ID: 1.625") @ 7182' SLM. NOTE: PACKER HAD AN ALUMINUM PINNED FOR 3600 PSI DIFFERENTIAL. PACKER, 7,0309 - PRODUCTION: 7,067 6 PRODUCTION:70676 7,585.0 6,318.2 32.88 FISH Vann Gun Downhole 9/10/1984 Perforations & Slots PRODUCTION, 7,136.0 Shot Dens Top (ND) Bt. (ND) (shotsM Top (ftKB) Bt. (ftKB) (ftKB) (ftKB) Zone Date t) Type Co. 7,184.0 7,244.0 5,984.1 6,033.9 C-4, iF-07 9/1/1984 12.0 RPERF 5" DA; 90 deg ph 7,184.0 7,244.0 5,9841 6,033.9 C-4, 1F-07 10/21/1982 12.0 IPERF 5" Vann Guns PATCH: 7.182.0 RPERF: 7,184.0-7.244 0 7,255.0 7,260.0 6,0430 6,047.2 UNIT B, 1F-07 9/1/1984 12.0 RPERF 5" D& 90 deg ph I P E R F: 7 ,184.0-7, 2 44.0 FRAC C -SAND; 7.1840 I 7,255.0 7,260.0 6,043.0 6,047.2 UNIT B, IF -07 10/21/1982 12.0 (PERF 5" Vann Guns RPERF: 7,255 0-7,260 0 IPERF:7.2550:7260.0 7,268.0 7,282.0 6,053.8 6,065.4 UNIT B, IF -07 9/1/1984 12.0 RPERF 5" DA: 90 deg ph RPE'F, 7,266.0-7,282 0 IPERF: 7.2680-7282.0L- 7,268,0 7,282.0 6,053.8 6,065.4 UNIT B, IF -07 10/21/1982 12.0 (PERF 5" Vann Guns 7,393.0 7,405.0 6,157.5 6,167.4 A-4, IF -07 10/1012006 6.0 RPERF 2.5"HSD HJ RDX, 60 PRODUCTION: T, 34 deg. ph 7,393.0 7,405.0 6,157.$ 6,167.4 A-4, 1F-07 10/21/1982 12.0 (PERF 5" Vann guns LOCATOR, 73108 7,420.0 7,446.0 6,179.9 6,201.6 A-4,117-07 10/21/1982 12.0 IPERF 5" Vann guns PACKER; 7,312.0 7,453.0 7,458.0 6,207,5 6,211.6 A-4, 117-07 10/21/1982 12.0 IPERF 5" Vann guns MILL; 7.315 9 Stimulations & Treatments Proppant Designed (Ib) Proppant In Formation (Ib) Date I 9/23/2000 NIPPLE, 7,331.9 Stimulations & Treatments Vol Clean Pump Sig # Top (ftKB) Btm (ftKB) Date SiiMTreat Fluid (bbl)Vol Slurry (bb8 SOS. T3378 1 7,184.0 7,244.0 9/23/2000 Proppant Designed (Ib) Proppant In Formation (Ib) Date 10/27/2006 Stimulations & Treatments Vol Clean Pump Sig # Top (ftKB) Bim (ftKB) Date Stim/Treat Fluid (bb8 Vol Slurry (bb8 IPERF:73930-74050 R PERF: 7, 393.0-7405.0 1 7,393.0 7,4$8.0 10/27/2006 Mandrel Inserts FRAC A -SAND, 7.393 0 St IPERF: 7420 0-7 446 0 ati IPERF, 74530-74580 N Top (ND) Top (ftKB) (ftK8) Make Model OD (in) Valve Latch Port Size TRO Run S- Type Type (in) (psi) Run Date Com 1 1,933.3 1,907.1 OTIS OVAL 1 GAS LIFT GLV BK 0.156 1,311.0 12/2/2013 2 3,145.2 2,895.3 OTIS OVAL 1 GAS LIFT GLV BK 0.156 1,298.0 12/2/2013 FISH: 7.0 3 4,326.6 3,785.9 OTIS OVAL D 1 GAS LIFT GLV BK 0.188 1.323.0 12/2/2013 1 4 5,466.0 4,683.6 OTIS OVAL D 1 GAS LIFT GLV 8K 0.188 1,310.0 12/2/2013 PRODUCTION: 32.1-8,045 0� 16" 65# H-40 shoe @ 80' MD 10-3/4" 45# K-55 shoe) (cD 2259' MD KOP @ 7190' MD KOP @ 7210' MD C -sand perfs EEO 7184'- 7244' MD B -sand 7255'- 7282' MD Perf Pup Poor Boy Overshot sand perfs 17393'- 7458' MD 7" 26# K-55 shoe @ 8045' MD 1F-07 Proposed CTD Schematic PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ TBD 3-1/d' X landing nipple at moa' MD (2.813" min ID) Baker 3-1/2" PBR )coo' MO (3" ID) Baker FHL Packer @ =oe MD (4" ID) REMAINING COMPLETION LEFT IN HOLE OTIS WD Permanend Packer @ 7312' MD (4" ID) OTIS MOE @ 7316' MD (4.35" ID) OTIS XNS nipple @ 7332' MD (2.813" ID) OTIS SOS @ 7338' MD Northern Solutions Wedge * 3-1/2" 9.3# L-80 Base Pipe * 5.905" OD (12.9' long) * —40' Total Length * 0.625" Bore thru Upper Tray * 1.125" Bore thru Lower Section orww 759' MU ?1w MV 1F-071-1-01 wp02 ` TD @ 9,800' MD Top of Liner @ 7205' MD 00 - - --------------------------- 1F-071_1 wp06 TD @ 10,500' MD op of Liner @ 7600' MD i 907.570.2410 (Mobile) 700 G Street, ATO — 664 Keith.E.Henr n22conocophillips.com ConoCO�11il pS NaSkka From: Davies, Stephen F (DOA) <steve.davies(@alaska.gov> Sent: Tuesday, June 26, 2018 7:41 AM To: Herring, Keith E <Keith. E.HerringPconocophiIIips.com> Subject: [EXTERNAL]KRU 1F-071_1 (PTD 218-073) - Request Keith, I'm currently the only geologist at the AOGCC, so it will save me time if CPAI could provide proposed directional survey data for KRU 1F -07L1 in electronic form. If this is inconvenient, don't worry about it; it just cuts down application permit -processing time for everyone. Regards, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies(@alaska.gov. From: Davies, Stephen F (DOA) Sent: Monday, May 7, 2018 4:25 PM To: 'Herring, Keith E' <Keith. E.Herring(@conocophillips.com> Subject: RE: [EXTERNAL]KRU 3M-23AL4 (PDT # 218-055) - Request Thank you Keith. This will speed application processing. Regards, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies(@alaska.gov. From: Herring, Keith E To: Davies, Stephen F (DOA) Subject: RE: [EXTERNAL]RE KRU 1F -07L1 (PTD 218-073) - Question Date: Tuesday, June 26, 2018 11:52:04 AM Attachments: imaae001.ona Steve, The perforations in the original wellbore KRU 1F-07 will remain open to the Kuparuk River Oil Pool during drilling operations and after completion of the KRU 1F-071_1 and 1F -07L1-01 laterals. Keith From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Tuesday, June 26, 2018 11:46 AM To: Herring, Keith E <Keith.E.Herring@conocophilIips.com> Subject: [EXTERNAL]RE KRU 1F -07L1 (PTD 218-073) - Question Keith, Will perforations in the original wellbore KRU 1F-07 be isolated before KRU 1F-071_1 and KRU 1F - 07L1 -01 are drilled and completed? Or will those perforations remain open to the Kuparuk River Oil Pool after KRU 11F-071_1 and KRU 1F -07L1-01 are drilled and completed? Regards, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC Is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies(@alaska.gov. From: Herring, Keith E [mai Ito: Keith. E.HerringPconocophiIIips.com] Sent: Tuesday, June 26, 2018 8:11 AM To: Davies, Stephen F (DOA) <steve.davies(@alaska.gov> Subject: RE: [EXTERNAL]KRU 1F -07L1 (PTD 218-073) - Request Good morning Steve, Please see the attached. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) TRANSMITTAL LETTER CHECKLIST WELL NAME: �� , 71— �— PTD: %t/ VDevelopment Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: ice' POOL: � Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Pea�it LATERAL No. Z— , , API No. 50-&2!V- - Com- Com' ) (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -) from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 1F-071-1-01 _ Program DEV Well bore seg ❑�/ PTD#: 2180740 Company CONOCOPHILLIPS ALASKA, INC. Initial Class/Type DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.030G.1_.A),Q.2.A-D) NA_ - 1 Permit fee attached NA_ 2 Lease number appropriate_ Yes _ Entire well within ADL0025652 3 Unique well name and number Yes 4 Well located in a_defined_pool Yes Kuparuk River Oil Pool, governed by Conservation Order No. 432D 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 432D has -no in_terwell_spacing _restrictions. Wellbore will be more than 500' 6 Well located proper distance_ from other wells - Yes from an external property line_ where -ownership or landownership_ changes. As proposed, well will 7 Sufficient acreage avail_able in -drilling unit_ _ _ _ _ Yes_ _ _ _ _ _ _ co_nfo_rm to spacing requirements. 8 If -deviated, is -wellbore plat -included - Yes - - - - - - - 9 Operator only affected party Yes - -- 10 Operator has -appropriate_ bond in force Yes .. - Appr Date 11 Permit. can be issued without conservation order_ - - Yes 12 Permit_can be issued without administrative approval Yes SFD 6/26/2018 -- 13 Can permit be approved before l5 -day wait. - Yes _ 14 Well located within area and strata authorized by Injection Order # (put 10# in c- - - - - - (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_ - ------------------ 18 Conductor string_provided - - NA_ - CTD sidetrack_ in the reservoir - comingle_production with parent well Engineering 19 Surface -casing- protects all -known- USDWs - - NA 20 CMT -vol adequate -to circulate on conductor_& surf_csg NA_ Slotted liners only 21 CMT_v_ol_ adequate -to tie -in -long string to -surf csg_ - - - - - - - - - - NA_ Slotted liners only - - - - - 22 CMT_will coverall known -productive horizons_ - - - NA_ slotted liners only_- window exiting_in the reservoir - - - - 23 .Casing desians adequate for C, T, B &- permafrost_ Yes .. - - - - - - - - - - 24 Adequate tankage_or reserve pit - - - - -- Yes ---- 25 If_a_ re -drill, has. a 10-403 for abandonment been approved N_A_ - - - - - Comingled_ production with parent well 26 Adequate wellbore separation_proposed- - - - - Yes - - - - - - - - - - - - - - - - - - 27 -If _diverter required, does it meet regulations_ - - - - - - - N -A_ - - - - - - - CTD sidetrack_ from existing producing wellbore - - - Appr Date 28 Drilling fluid- program schematic _&_ equip -list -adequate - - - - .. - Yes - - - - - - - Managed pressure drilling/KWF available _for _liner -running _ MGR 6/28/2018 29 BO_PEs,_do they meet regulation - - - - - - - - - - - - - - - - - - - - Yes 30 BOPS -press rating appropriate; test to -(put psig in comments) - - Yes - - - - - 31 Choke manifold complies w/API_RP-53 (May 84)_ _ _ _ _ - - - - - Yes ... - - - - - - - - - - - - 32 Work will occur without operation shutdown_ - - - - - - - - - - - - - - - - - - - - Yes - - 33 Is Presence of H2S gas probable- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - Standard_Kupar_uk H2S detectors required _ _ - - - - - - - - - - - - - - - - - 34 Mechanical -condition of wells within AOR verified (For service well only) - - - - NA_ Well is a_planned_producer - - - - - - 35 Permit can be issued w/o hydrogen -sulfide measures - - - - - --- - - - - - - - - - - - - - - No- Wells _on_1F-Pad are 1-12S -bearing. 1-12S measures required._ - - _ _ - - - - - - - _ - - _ - Geology 36 _D_ata_presented on potential overpressure zones_ - - - - - - - - - - - - - - Yes - - - - - - Expected reservoir -pressure is 8.3-8_.4 ppg_E_MW;_will be drilled -using 8.6_ppg mud, coiled- Appr Date 37 Seismic -analysis of shallow gas_zones- - - - - - - - - - - - - - - - - - - - - - - - _ - .. NA - - - tubing, and managed pressure drilling practice. Equivalent circulating density will be kept SFD 6/26/2018 38 Seabed condition survey -(if off -shore) _ - - - _ _ - - - - - - NA_ _ _ at_11.8ppd EMW-while drilling to stabilize shale. NOTE: Free gas maybe encountered while 39 Contact-name/phone for weekly -progress reports_ [exploratory only] - - - - - - - - - - - - - N_A_ - - - drilling this lateral. Geologic Engineering Public Commissioner: Date: Commissioner: Date Corpmissioner Date