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218-073
DATA SUBMITTAL COMPLIANCE REPORT 2/25/2020 Permit to Drill 2180730 Well Name/No. KUPARUK RIV UNIT 1 F -07L1 Operator ConocoPhillips Alaska, Inc. API No. 50-029-20830-60-00 MD 9607 TVD 6066 Completion Date 11/6/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log No X Samples No / Directional Survey Yes DATA INFORMATION List of Logs Obtained: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED C 31486 Digital Data ED C 31486 Digital Data ED C 31486 Digital Data ED C 31486 Digital Data Log 12/13/2019 31486 Log Header Scans ED C 31640 Digital Data ED C 31640 Digital Data ED C 31640 Digital Data ED C 31640 Digital Data ED C 31640 Digital Data ED C 31640 Digital Data ED C 31640 Digital Data ED C 31640 Digital Data ED C 31640 Digital Data ED C 31640 Digital Data ED C 31640 Digital Data ED C 31640 Digital Data ED C 31640 Digital Data (from Master Well Data/Logs) Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 11/22/2019 Electronic File: 1 F-071-1 EOW - NAD27.pdf 11/22/2019 Electronic File: 1F-071-1 EOW - NAD27.txt 11/22/2019 Electronic File: 1F-071-1 EOW NAD83.pdf 11/22/2019 Electronic File: 1F-071-1 EOW NAD83.txt 0 0 2180730 KUPARUK RIV UNIT 1F-071-1 LOG HEADERS 7059 9607 12/13/2019 Electronic Data Set, Filename: 1F-071-1 GAMMA RES.Ias 12/13/2019 Electronic File: IF -071-1 2MD Final.cgm 12/13/2019 Electronic File: 1F-071-1 5MD Final.cgm 12/13/2019 Electronic File: 1 F-071-1 5TVDSS Final.cgm 12/13/2019 Electronic File: 1F-071-1 21VID Final.pdf 12/13/2019 Electronic File: 1F-071-1 5MD Final.pdf 12/13/2019 Electronic File: IF -071-1 5TVDSS Final.pdf 12/13/2019 Electronic File: 11F-071-1 EOW - NAD27.pdf 12/13/2019 Electronic File: 1F-071-1 EOW - NAD27.txt 12/13/2019 Electronic File: 1F-071-1 Final Surveys TD 9607.csv 12/13/2019 Electronic File: 1F-071-1 Final Surveys TD 9607.xlsx 12/13/2019 Electronic File: 1F-071-1 Survey Listing.txt 12/13/2019 Electronic File: 1F -07L1 Surveys.txt AOGCC Page I of 3 Tuesday, February 25, 2020 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2020 Permit to Drill 2180730 Well Name/No. KUPARUK RIV UNIT 1F-071-1 Operator ConocoPhillips Alaska, Inc. API No. 50-029-20830-60-00 MD 9607 TVD 6066 Completion Date 11/6/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 31640 Digital Data 12/13/2019 Electronic File: 1 F - 07L 1 _25_tapescan_B H I_CTK.txt ED C 31640 Digital Data 12/13/2019 Electronic File: 1F- F- 07L15_ta pes ca n_B H I _C T K. txt 071-15 — ta ED C 31640 Digital Data 12/13/2019 Electronic File: 1F-071-1_output.tap ED C 31640 Digital Data 12/13/2019 Electronic File: 1F-071-1 2MD Final.cgm.meta.tif ED C 31640 Digital Data 12/13/2019 Electronic File: 1F-071-1 5MD Final.cgm.meta.tif ED C 31640 Digital Data 12/13/2019 Electronic File: 1F-071-1 5TVDSS Final.cgm.meta.tif Log 31640 Log Header Scans 0 0 2180730 KUPARUK RIV UNIT 1F -07L1 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report 0 Production Test Information NA Geologic Markers/Tops Y� COMPLIANCE HISTORY Completion Date: 11/6/2019 Release Date: 7/3/2018 Description Comments: Directional / Inclination Data 6 Mud Logs, Image Files, Digital Data Y /� Core Chips Y& Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files 0 Core Photographs Y/6 Daily Operations Summary 0 Cuttings Samples Y/6 Laboratory Analyses Y /0 Date Comments AOGCC Page 2 of 3 Tuesday, February 25, 2020 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2020 Permit to Drill 2180730 Well Name/No. KUPARUK RIV UNIT 11F-071-1 Operator ConocoPhillips Alaska, Inc. API No. 50-029-20830-60-00 MD 9607 TVD 6066 Completion Date 11/6/2019 Completion Status 1-0I1- Current Status 1-0I1- UIC No Compliance Reviewed By: Date: AOGCC Page 3 of 3 Tuesday, February 25, 2020 Baker 2�1 PRINT Hughes COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1F -07L1 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(a)bakerhughes.com STATUS COMPANY 218073 3 164 0 DISTRIBUTION LIST 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 Ito acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE November 3, 2019 TODAYS DATE December 11, 2019 Revision Final Replacement: No Details: Rev. Requested by: FIELD / FINAL CD/DVD FINAL ATO 708 PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) lu # OF PRINTS 4 # OF COPIES # OF COPIES # OF COPIES ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) Attn: Ricky Elgarico ATO 708 700 G Street PERSON ATTENTION Anchorage, AK 99510 RECEIVED lu 4 4 4 4 4 4 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 RECEIVED 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 1333 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 1 AOGC TOTALS FOR THIS PAGE: 0 1 2 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG- 1a. Well Status: Oil FA ' Gas[] SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 1b. Well Class: Development E 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: 218-073 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 10/31/2019 15. API Number: 50-029-20830-60-00 ' 4a. Location of Well (Governmental Section): Surface: 1331' FNL, 27" FWL, Sec 20, T11N, R10E, UM Top of Productive Interval: 1899' FNL, 1833' FEL, Sec 20, T11 N, R10E, UM Total Depth: 405' FNL, 1929' FEL, Sec 20, T11N, R10E, UM 8. Date TD Reached: 11/2/2019 16. Well Name and Number: KRU 1F-071-1 9. Ref Elevations: KB:115 GL:74 . BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil 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- 543433 y- 5957648 Zone- 4 Total Depth: x- 543324 y- 5959141 Zone- 4 11. Total Depth MD/TVD: , 9607/6066 ' 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 [I (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: . 7205/6002 - 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 GR/Res 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH TVD WT. PER GRADE SETTING DEPTH MD HOLE SIZE CASING FT TOP BOTTOM TOP BOTTOM AMOUNT 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 1000sx Fondu & 250sx Permafrost C 7 26 K-55 32 8045 32 6704 8112 450sx Class G & 250sx Permafrost C 23/8 4.6 L-80 7666 9607 6019 6066 3 Slotted Liner 24. Open to production or injection? Yes FZ] No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER@: 7205-9607 MD and 6002-6066 TVD COMPLETION DTE 4 - 1 RI (/ in 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 E]No E]i Per 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: Gas -MCF: 2z? 1 5.50 : Water -Bbl: , (`FSZ 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 Gravitv - API (corr): 25 3 Form 10-407 Revised 5/2017 j/7 -L !Z/�(�`�g CONTI UED O PAGE 2 � Suomit ORIGINIAL only,,. �1� / RB DEC 1 12019 , t) ' (� t r l� 28. CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 2 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 7205 6002 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk C TD 9607 6066 Formation at total depth: Ku aruk C 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, paleontological report, r)roduction or well test results, r 20 AAC 2.70. 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 En ineer Contact Email: James.C.Ha es co .com Authorized Contact Phone: 263-6927 Signature: Date: //� 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 10-3/4" 45# K-55 shoe @ 2259' MD KOP @ 7190' MD KOP @ 7210' MD �^ C -sand perfs t- -- --1 h 7184'- 7244' MD 7255'- � 7255' 7282' MD 2019 Tubing Tail 7,248' MD Original Tubing 7,300 - 7,345' MD A -sand perfs 17393'- 7458' MD 7" 26# K-55 shoe @ 8045' MD COMPLETION 3-M." 9.3# L-80 EUE Brd Tubing to surface 3-1/." Camco MMG gas lift mandrels @ 2,619', 4,190', 5.216', 6,022', 6,551', 8 6,921' MD. Baker 3-1/." PBR 6,948' MD (3" ID) Baker FHL Packer @ 6,972' MD (4" ID) 3-1/." X landing nipple at 7,014' MD (2.613" 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 11F-071-1-01 wp03 TD @ 9,826' MD Top of Liner @ 7202' MD 117-071-1 wp07 TD @ 9,608' MD Top of Liner @ 7666' MD KUP PROD WELLNAME 1F-07 �! IQWell Attribu'ConocoPhillip5Name Wellbore API/UWI WelAlaska, InC.KI IPARI IK RIVER I INIT SDD� , DDD PR NONE WELLBORE 1 F-07 Max Anglir 7 TD cl (°) MD,. . 4.83 5,70.00 Act Bt. (ftKB) 8,060.0 FEnd Date -Gd (ft) 7/30/2019 40.59 Rig Release Date 10/21/1982 1F -07,11/25r2019 2:41:33 PM Last Tag Vertical schematic (actual) Annotation Depth (ftKB) 1 End Date Wellbore I Last Mod By """""""""' HANGER; 2e.4 "".- .......- Last Tag: RKB (EST 62' RAT HOLE) 7,520.0 6/13/2019 1F-07 condijw Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set Whipstock 10/22/2019 1F-07 Itamaj Casing Strings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (ND)... Wt/Len (I... Grade Top Thread #CONDUCTOR�35.0-80.0 Annular Fluid - Diesel; 30.4- .2.000.0; 7272019 Annular Fluid - Diesel; 30.4- 2,000.0; 727no1s CONDUCTOR 16 15.25 35.0 80.0 80.0 65.00 H-40 WELDED Casing Description OD (in) ID (in) SURFACE 10 3/4 9.95 Top (ftKB) Set Depth (ftKB) Set Depth (ND)... WVLen (L.. Grade Top Thread 34.2 2,258.7 2,189.0 45.50 K-55 BUTT Casing Description PRODUCTION OD (in) ID (in) 7 6.28 Top (ftKB) Set Depth (ftKB) Set Depth (ND)... WULen (I... Grade Top Thread 32.1 8,045.0 16,704.1 26.00 K-55 BTC Tubing Strings SURFACE; 34.2-2,258.7 Tubing Description 3.5"TUBING-2019 String Ma... 31/2 10 (in) 2.99 Top (ftKB) 28.4 Set Depth (ft.. 7,248.1 Set Depth (ND) (... 6,037.3 Wt (Ib/ft) 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 - 9.9# NaCl Bnne Top (ND) Top Incl Nominal With CRW 132 Cousbn inhibit.; 2,1x70.0E,971.9; Top (ftKB) (ftKB) (°) Item Des Co. ID (in) 7262ots Annular Fluid- 9.9# NaCl Bnne 28.4 28.4 0.13 HANGER FMC 11" x 3 1/2" Gen 5 Tubing Hanger W/ 3.5" EUE 8rd Lift thread 2.900 With CRW 132 Comsen inhibitor; 10.99, W26/ 6,947.1 5,789.5 35.84 LOCATOR Baker gbh -22 locator sub 3.000 GAS LIFT Mandrel; 5,216.7 6,948.1 5,790.3 35.82 SBE Baker 80-00 seal assembly 21.73' OAL +2' off tag 3.980 6,950.1 5,792.0 35.80 SBR Baker 80-00 PBR 4.000 GAS LIFT Mandrel; 6,022.0 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 31/2" x 2.813" X nipple Profile (SN:)2727A33 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 1WEDGE SBE; 6,948.1 7,221.21 6,015.01 33.99 INIPPLE - X I HES 3 1/2" x 2.813" X nipple Profile (SN:) 1 2.813 SBR; 6,950.1 Tubing Description String M...... ... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (TVD) il- Wt Qbi t) 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 BTCIPC NIPPLE - X; 7,014.3 Completion Details Top (ND) Top Incl Nominal Annular Fluid -9.9# Bnne; 6,971.9.7,320.0; 7222019 Top (ftKB) (ftKB) (°) Item Des Com 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; 7,201.4 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; 7,184.0 IPERF; 7,184.�Wedge; 7,208.8- Inner Wedge; 7,208.8 Top (ftKB) Top (ND) (ftKB) Top Incl (°) Des Co. Run Date ID (in) 7,208.8 6,004.7 33.98 Inner Wedge F 1350 Inner Wedge Kick Off Assembly. set top at 10/22/201 0.000 NIPPLE - X; 71221.2 XO Threads - Tubing; 7,222.1 7204.3' Tied in to K1 Marker (7208.8' tied in to 9 Completion). DAL 12.1' Max OD 2.625" RockScreen; 7,221.0 3.25 SLOTTED LINER WITH ORANGE PEEL WEDGE 7,221.0 6,014.8 33.99 RockScreen .75" -X-lockw/ 2.625" RockScreen w/ .188 slots (59" 8/25/2019 OAL) 0.000 BOTTOM - Tubing; 7,223.1 7,254,0 6,042.2 34.01 Broken Blast 7/26/2019 0.000 RPERF; 7,255.0-7,260.0 IPERF; 7,255.0-7,260.0 RPERF; 7,288.0-7,282.0 Rings from Original Completion IPERF; 7,268.0.7,282.0 Broken Blast Rugs from Original 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; 7,300.0 7,323.0 6,099.4 33.99 CEMENT BAKER H1 CEMENT RETAINER W/ BALL 6/13/2019 1.130 PRODUCTION -Mandrel; 7.301.6 RETAINER - GUTTED REMAOVED, 2.77" OD X 1.16' LENGTH Perforations & Slots LOCATOR; 7,318.9 Shot PACKER; 7,320.1 CEMENT RETAINER - GUTTED; 7,323.0 MILL; 7,324.0 Top (ftKB) St. (ftKB) Top (ND) Btm (ND) (ftKB) (ftKB) Dens (shotslft Linked Zone Date ) Type Com 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 C4, 1F-07 9/1/1984 12.0 RPERF 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 9/1/1984 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; 7.345s 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 7,393.0 7,405.0 6,157.5 6,167.4 A-4, lF-07 10/21/1982 12.0 IPERF 5" Vann guns 7,393.0 7,405.0 6,157.5 6,167.4 A-4, 1F-07 10/10/2006 6.0 RPERF 2.5" HSD HJ RDX, 60 deg. ph RPERF; 7,393.0-7,405.0 IPERF; 7,393.47,405.0 7,420.0 7,446.0 6,179.9 6,201.6 A-4, 1F-07 10/21/1982 12.0 IPERF 5" Vann guns 7,453.0 7,458.0 6,207.5 6,21113,A -1,1F-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 Date Proppant Designed (1b) Proppant In Formation (Ib) IPERF; 7,453.0-7,4580 9/23/2000 Stg # StartDate Top Depth (ftKB) Son (RKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 1 9/23/2000 7,184.0 I I 7,244.0 Start Data Proppant Designed (lb) Proppant In Formation (lb) 10/27/2006 I S;# Start Date Top Depth (ftKB) Btm (ftKB) Link to Fluid System Vol Clean (bbl)Vol Slurry (bbq L1-01 Laterel; 7.202.09,626.0 /27 1 10/2006 7,393.0 7,458.0 PRODUCTION; 32.1-B4O45.0� KUP PROD WELLNAME 1F-07 WELLBORE 1F-07 ConotoPhillipsIs Maska,Inc. Annotation End Date --- Last W0: 7/30/2019 iF-07, 112520192:4134 PM Mandrel Inserts varscal wl--x (—I) St all ......................... HANGER; 20.4...E ,. ......... on Top (TVD) Valve Latch Port Size TRO Run N Top (PoCB) (ftKB) Make Model OD (in) Sew Type Type (in) (psi) Run Date Com 1 2,619.4 2,484.6 Camco MMG 11/2 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 6,022.0 5,082.1 lCamoo MMG 1112 GAS LIFT GLV RK 0.188 1,235.0 8/19/2019 �CONDUCTOR��35.0-80.0 51 6,550.7 5,476.5 Camco MMG 1 1 1/2 GAS LIFT GLV RK 0.188 1,227.018119/2019 Annular Fluid - Diesel; 30.4- 6 6,921.8 5,769.1 Camco MMG 11/2 GAS LIFT OV RK 0.188 0.0 8/18/2019 2,000.0; 7/27/2019 Annular Fluid -Diesel; -30.4 7 7,301.6 6,081.6 OTIS OVAL 1 PROD DMY BK 0.000 0.0 9/26/2006 Prod 2,000.0; 7272019 Uctio n mand rel SURFACE; 34.2-2,258.7.. inacc essibl GAS LIFT Mandrel; 2,619.4 GAS LIFT Mandrel; 4,189.8 a due Annular Fluid - 9.9q NaCl Brine l0 With CRW 132 Consion orang inhib8w; 2,000.0$971.9; e 7262019 peel Annular Fluid -9.9C NaCl Bnne at With CRW 132 Cortsion hibhor; 2,000.06,971.9; BTM 7262019 Of GAS LIFT Mandrel; 5,216.7 1,iner Notes: General & Safety End Date Annotation GAS LIFT Mandrel; 6,022.0 8/28/2019 NOTE: View Schematic w/ Alaska Schematic10.0 GAS LIFT Mandrel; 6,550.7 GAS LIFT Mandrel; 6,921.8 LOCATOR; 6,947.1 SBE; 6,948.1 SBR; 8,950.1 PACKER; 6,972.0 NIPPLE - X; 7,014.3 Annular Fluid - 9.9p Snne; 6,971.9-7,320.0; 7222019 TANDEM WEDGE; 7,1874 NIPPLE - X; 7,201.4 TANDEM WEDGE; 7,207.2 RPERF; 7,184.0-7,244.0 FRAC C -SAND; 7,184.0 (PERF; 7,164.0-7,244.0 Inner Wedgs; 7,208.8 NIPPLE - X; 7,221.2 XO Threads - Tubinp; 7,222.1 R-kSueen; 7,221.0 3.25" SLOTTED LINER WITH ORANGE PEEL WEDGE BOTTOM - Tubing; 7,223.1 RPERF; 7,255.0-7,2600 IPERF; 7,255.D -7,260o RPERF; 7,268.0-7,292.0 IPERF; 7,268.0-7,282.0 I Broken Blast Ringe from Onginal Cornpleaon; 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; 7,393.0-7,405.0 IPERF; 7,393.0-7,405.0 FRAC A -SAND; 7,393.0 IPERF; 7,420.0-7,446.0 IPERF; 7,453.0-7,458.0 Lt -01 Lalaral; 7,202.0-9,8264 PRODUCTION, 32.1-8,045.0 1►' ConocoPhillips Alaska, Inc. KUP PROD WELLNAME 1F-07 Well Aftribu' Wellbore AP#U WI H2S (ppm) I Date 40 9/10/2016 WELLBORE 1 F -07L1 Date I KB-Grd (ft) 1 Rig Release 40.59 10/21/1982 1F-071-1, 11/25120192:41:34 PM Casing Strings Vertical schematic (actua) Casing Description 1-1 Lateral GD (in) 2 3/8 ID (in) 1.99 Top (ftKB) Set Depth (ftKB) Set Depth (ND)... 7,666.4 9,608.0 WVLen (I... Grade 4.60 L-80 lop 7hreatl ST L ...................... .. .. HANGER: 28.4 Frac Summary Start Date Proppant Designed (lb) Proppant In Formation (lb) 9/23/2000 I Stg # Start Date Top Depth (ftKB) Btm III Link to Fluid System Vol Clean (bbl) VOI Slurry (bbp 1 9/23/2000 7,184.0 7,244.0 Start Date Proppant Designed (lb) Proppant In Formation (lb) wCONDUCTOR�35.f}90.0 10/27/2006 Date Top Depth (ftKB) Bt.(ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Annular Fluid - Oiesel; 30.4- z,OrDC D; 727/2019 Annular Fluid -Diesel; 30.4- 71t,*Start 10/27/2006 7,393.0 7,458.0 2,000.0; 7/27/2019 SURFACE, 34.2-2,258.7 GAS LIFT Mandrel; 2,619.4 GAS LIFT Mandrel; 4,189.8 Annular Fluid - 9.9# NaCl Bnne WRh CRW 132 Correion inhibitor, 2,000.0-,971.9, 7/2612019 Annular Fluid - 9.9# NaCl Brine WM CRW 132 Corrsion 46ftor; 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; 6921.8 LOCATOR, 6,947.1 SBE 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; 7/22/2019 TANDEM WEDGE; 7,187.4 NIPPLE - X, 7,201.4 TANDEM WEDGE; 7,207.2 (PERF; 7,184.0.7,244.0 RPERF; 7,184.0.7244.0 FRAC C -SAND; 7,184.0 Inner Wedge; 7,208.8 NIPPLE - X, 7,221 2 XO Threads - Tubing; 7,222 1 Rock&mmn; 7,22 0 3.25" SLOTTED LINER WITH ORANGE PEEL WEDGE BOTTOM -Tubing; 7,223.1 IPERF; 7,25 5.0.7,2600 RPERF; 7,255 .0.7,260.0 IPERF; 7,268.0.7,282.0 RPER F; 7,268.0-7,282 0 I Broken Blast Rings from Onginal 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; 7.340.1 SOS, 7,345 9 IPERF; 7,393.0.7,405.0 RPERF; 7 393.0.7 405 0 FRAC A -SAND; 7,393.0 IPERF; 7,4M 0-7.446 0 IPERF; 7,453.0.7,458.0 PROD TION; 32.1-8,045.0 1-1-01 Lateral; 7,202.0.9,826 4 1 1-1 Lateral; 7,666.4-9,608.0 ` Operations Summary (with Timelog Uepths) w " y a' 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 1.00 MIRU WHDBOP RURD P Continue to rig up working RU check 0.0 0.0 00:00 110/30/2019 01:00 list, greese valves, flood up. Passing shell test to 4000 psi. Page 1111 ReportPrinted: 11/13/2019 Operations Summary (with Timelog Depths) >s 1F-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) 10/30/2019 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#1, 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 lbs, 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 2/11 ReportPrinted: 11/13/2019 v Uperations Summary (with Timelog Depths) ` 1F-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 (WEI) End Depth (WB) 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 3/11 ReportPrinted: 11/13/2019 Operations Summary (with Timelog Depths) 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 (WB) 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 Ibs. 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 P OBD, 1.88 bpm at 4,806 psi, OB 7,851.0 7,902.9 04:00 06:06 Diff=874, WHP=284, BHP=3,738, IA=607, OA=531 Page 4111 Report Printed: 11/13/2019 - Uperations Summary (with Timelog Depths) 1 F-07 • • M 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) 11/1/2019 11/1/2019 0.20 PROD1 DRILL TRIP P Directional 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 FROM 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 PROM 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 FROM 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 PROM 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 PROD1 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 PROM 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 PROM 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 FROM 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 PROM 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 PROD1 DRILL WPRT P Wiper up hole to the EOB, PUW 29 k, 8,310.0 7,910.0 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 FROM 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 FROM 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 PROD1 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 PROM 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: 11/13/2019 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) 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 PROM 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 PROD1 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 PROM 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 1 1RBIH Page 6/11 Report Printed: 71/13/2019 Operations Summary (with Timelog Depths) tw 1F-07 • ! M 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 (WB) 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 PROD! 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 PROD1 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 ReportPrinted: 11/13/2019 - Uperations Summary (with Timelog Depths) 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) 11/3/2019 11/3/2019 1.50 COMPZ1 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 PROD2 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 PROD2 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 ReportPrinted: 11/13/2019 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) 11/4/2019 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: 11/13/2019 Uperations Summary (with Timelog Vepths) 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) 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 bpm 9,826.4 9,826.4 13:18 13:33 out, 967 psi, PUW 25 k, Page 10/11 ReportPrinted: 11/13/2019 Uperations Summary (with Timelog Depths) 1 F-07 . .. Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (WB) 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 P/T 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 �WHIDBOP Start nipple down. Rig Release @ 24:00 Hrs Page 11111 Report Printed: 11/13/2019 Winston, Hugh E (CED) From: Hayes, James C <James.C.Hayes@conocophillips.com> Sent: Tuesday, December 10, 2019 10:45 AM To: Winston, Hugh E (CED) Subject: RE: [EXTERNAL]KRU 1F-071-1 and 1F-071-1-01 Well completion Report Huey, I owe you two apologies here. First I totally missed your email with two reports. After looking at the numbers you are correct, they are incorrect values. I'm not sure how they were inputted so high. The correct values for both laterals can be found below. Now do I need to correct these forms on my end and resubmit them? 14 hr test= Oil -Bbl: 222 bbls, Gas -MCF: 550 MSCF, & Water -Bbl: 1,752 bbls Oil Gravity — API (corr): 25.3 Thanks, James Hayes C: +1918.914.9609 From: Winston, Hugh E (CED) <hugh.winston@alaska.gov> Sent: Tuesday, December 10, 2019 10:02 AM To: Hayes, James C <James.C.Hayes@conocophillips.com> Subject: RE: [EXTERNAL]KRU 1F-071-1 and 1F-071-1-01 Well completion Report Hi James, Just following up on this. Were you able to verify these numbers? Thanks Huey From: Winston, Hugh E (CED) Sent: Tuesday, December 3, 2019 9:06 AM To: Hayes, James C <James.C.Haves @conocophillips.com> Subject: RE: [EXTERNAL]KRU 1F-071-1 and 1F-071-1-01 Well completion Report Here they are. The two reports are for 1F-071-1 and 1F-071-1-01. The numbers in question are the oil, gas and water volumes for the test period of 14 hours which are larger than the 24 hour calculated volumes, and additionally the oil gravity. Thanks Huey From: Hayes, James C <James.C.Haves @conocophi IIips.com> Sent: Monday, December 2, 2019 6:31 PM To: Winston, Hugh E (CED) <hugh.winston@alaska.Rov> Subject: RE: [EXTERNAL]KRU 1F-071-1 and 1F-071-1-01 Well completion Report Huey, I have no problem helping you get the correct number. Our meter was just recently calibrated so there might be a difference in values. Could I ask a favor though, so I don't waste your time, could you please send me what you are looking at. I'm a little confused how you have two reports. Having what you are looking at will help me get you the right data. Thanks, James Hayes C: +1918.914.9609 From: Winston, Hugh E (CED) <hugh.winston@alasl<a.gov> Sent: Monday, December 2, 2019 3:14 PM To: Hayes, James C <James.C.Hayes@conocophillips.com> Subject: [EXTERNAL]KRU 1F-071-1 and 1F-071-1-01 Well completion Report Hi James, I've received two well completion reports with information I believe is erroneous. In Box 27 of the above referenced wells completion reports the production for test period numbers are much larger than the 24 hour calculated volumes and the test period is shorter than 24 hours. Can you verify these numbers please? Additionally the API gravity should be a number in the range of 10 to 70 degrees. Would you please verify this number as well? Thanks Huey Winston Statistical Technician Alaska Oil and Gas Conservation Commission hugh.winston@alaska.gov 907-793-1241 ConocoPhillips ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk IF Pad 1 F -07L1 50-029-20830-60 Baker Hughes INTEQ Definitive Survey Report 20 November, 2019 Baker Hughes ConocoPhilli ps eakn Hughes g ConoeoPhiilips 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 (IF-07) Well: 1 F-07 North Reference: True Wellbore: 1F -07L1 Survey Calculation Method: Minimum Curvature Design: 1 F-071_1 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 +N/ -S 0.00 usft Northing: 5,958,196.36usft Latitude: 70° 17'48.221 N +EI -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 usft Wellbore 1 F-071_1 Magnetics Model Name Sample Date Declination Dip Angie Field Strength 11 (`) (nT) BGGM2018 12/1/2019 16.30 80.82 57,393 Design 1F-071.1 a Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,200.00 Vertical Section: Depth From (TVD) +W -S +E/ -W Direction (usft) (usft) (usft) 0 115.00 0.00 0.00 0.00 Survey Program Date From To Survey Survey (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 (1F-07Ll) MWD -INC ONLY (INC>10°) MWD-INC_ONLY_FILLER (INC,10°) 10/30/2019 10/30/2019 7,350.28 9,566.07 1F-071.1 MWD (1 F-071-1) MWD OWSG OWSG MWD - Standard 10/30/2019 11/2/2019 11202019 1:32:11 PM Page 2 COMPASS 5000.14 Build 85H ConocoPhillips 8ak,Hgt-g ConocoPhillips Definitive Survey Report Company: ConowPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1 F-07 Project: Kuparuk River Unit TVD Reference: 1F-07 @ 115.00usg (1F-07) Site: Kuparuk IF Pad MD Reference: 1 F-07 @ 115.00usft (IF -07) Well: 1F-07 North Reference: True Wellbore: 1F-071-1 Survey Calculation Method: Minimum Curvature Design: 1 F-0711 Database: EDT 14 Alaska Production , Survey Map Map Vertical MD Inc AZI TVD TVDSS +NIS +EJ -W DLS (usft) (9 1°I (ush) (usft) (usn) Milt) Northing Easting (°1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 7,200.00 33.97 107.11 5,997.41 5,882.41 -565.37 3,419.38 5,957,649.26 543,430.26 0.53 -565.37 MWD-INC_ONLY(INC>10°)(2) TIP 7,205.00 33.97 107.10 6,001.56 5,886.56 -566.19 3,422.05 5,957,648.45 543,432.93 0.11 -566.19 MWD-INC_ONLY(INC>10°)(2) KOP 7 7,230.38 38.50 109.00 6,022.02 5,907.02 -570.85 3,436.31 5,957,643.87 543,447.21 18.39 -570.85 MWD-INC_ONLY(INC>10°)(2) Interpolated Azimuth 7,259.74 51.95 112.00 6,042.66 5,92266 -578.19 3,455.76 5,957,636.63 543,466.70 46.37 -578.19 MWD -INC _ONLY (INC>10°)(2) Interpolated Azimuth 7,290.38 63.63 114.40 6,058.96 5,943.96 -588.42 3,479.53 5,957,626.53 543,490.52 38.69 -588.42 MW0.1NC_ONLY(INC>10°)(2) Interpolated Azimuth 7,320.65 75.39 115.00 6,069.54 5,954.54 100.25 3,505.24 5,957,614.84 543,516.29 38.89 -600.25 MWD -INC _ONLY (INC>10°)(2) Interpolated Azimuth 7,350.28 86.59 115.45 6,014.17 5,959.17 -612.70 3,531.61 5,957,602.53 543,542.79 37.83 -612.70 MWD OWSG (3) j£t( 7,379.99 101.31 116.87 6,072.13 5,957.13 125.73 3,558.20 5,957,589.64 543,569.39 49.77 -625.73 MWD OWSG (3) 7,410.19 102.88 130.42 6,065.78 5,950.78 -642.04 3,582.73 5,957,573.46 543,593.99 44.17 -642.04 MWD OWSG (3) i 7,440.31 102.57 143.34 6,0%11 5,944.11 163.44 3,602.76 5,957,552.17 543,614.14 41.85 -663.44 MWD OWSG (3) 3 7,470.20 101.78 155.99 6,052.79 5,937.79 -688.60 3,617.48 5,957,527.09 543,628.99 41.45 -688.60 MWD OWSG (3) 7,499.76 101.03 168.52 6,046.92 5,931.92 -716.14 3,626.29 5,957,499.60 543,637.95 41.63 -716.14 MWD OWSG (3) 7,529.59 100,54 181.75 6,041.31 5,926.31 -745.27 3,628.77 5,957,470.49 543,640.58 43.60 -745.27 MWD OWSG (3) ti 71559.95 100.26 194.16 6,035.61 5,920.81 -774.78 3,624.64 5,957,440.96 543,636.60 40.28 -774.78 MWD OWSG (3) 7,589.39 99.47 206.07 6,030.75 5,915.75 -801.96 3,614.67 5,957,413.73 543,626.79 39.88 -801.96 MWD OWSG (3) 7,619.74 100.00 220.13 6,025.59 5,910.59 -826.95 3,598.38 5,957,388.65 543,610.63 45.69 126.95 MWD OWSG (3) 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 14225 MWD OWSG (3) tl 7,680.55 96.06 248.45 6,017.26 5,902.26 -861.90 3,550.09 5,957,353.45 543,562.53 47.92 -661.90 MWD OWSG (3) 3 7,699.31 4 9341 258.58 6,015.70 5,900.70 -867.20 3,532.19 5,957,348.06 543,544.66 55.63 -867.20 MWD OWSG (3) 7,725.51 95.41 270.62 6,013.68 5,898.68 -869.65 3,506.23 5,957,345.47 543,518.72 46.45 -869.65 MWD OWSG (3) I 7,756.17 95.72 284.84 6,010.69 5,895.69 -865.56 3,476.07 5,957,349.40 543,488.54 46.17 -865.56 MWD OWSG (3) x {) 7,785.36 96.28 297.82 6,007.63 5,892.63 -855.03 3,449.09 5,957,359.79 543,461.50 44.26 -855.03 MWD OWSG (3) 7,815.65 93.32 311.35 6,005.08 5,890.08 137.93 3,424.30 5,957,376.75 543,436.63 45.57 -837.93 MWD OWSG (3) 7,840.49 91.94 325.21 6,003.94 5,888.94 -819.45 3,407.83 5,957,395.14 543,420.06 56.01 -819.45 MWD OWSG (3) 7,870.16 86.13 340.62 6,004.44 5,889.44 -793.13 3,394.37 5,957,421.38 543,406.46 55.48 -793.13 MWD OWSG (3) 7,901.85 91.08 352.48 6,005.21 5,890.21 -762.39 3,387.02 5,957,452.09 543,398.95 40.53 -762.39 MWD OWSG (3) 3 71931.97 92.21 355.26 6,004.35 5,889.35 -732.45 3,383.80 5,957,482.00 543,395.57 9.96 -732.45 MWD OWSG (3) 7,961.67 89.97 354.93 6,003.78 5,888.78 -702.87 3,381.27 5,957,511.57 543,392.88 7.62 -702.87 MWD OWSG (3) 71991.81 92.33 356.42 6,003.18 5,888.18 -672.82 3,378.99 5,957,541.60 543,390.44 9.26 -672.82 MWD OWSG (3) $ 8,021.87 93.53 355.86 6,001.64 5,88664 -642.87 3,376.97 5,957,571.53 543,388.26 4.40 -642.87 MWD OWSG (3) 111202019 1.'32:11 PM Page 3 COMPASS 5000.14 Build 65H ConocoPhillips ConocoPhillips Definitive Survey Report Baker Hughes Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1 F-07 Project: Kuparuk River Unit TVD Reference: 1 F-07 rQ 115.00usft (1F-07) Site: Kuparuk 1 F Pad MD Reference: 1 F-07 @ 115.00usft (1 F-07) Well: 1F-07 North Reference: True Wellbore: 1F -07L1 Survey Calculation Method: Minimum Curvature Design: 7-071-1 Database: EDT 14 Alaska Production Survey Aftp Map Vertical MD Inc AN TVD TVDSS +WS +E/.W Northing Fasting DLS Section Jus 1°1 1°I (usft) (usft) (usft) (usft) (^1100•) Survey Tool Name Annotation (ft) (ft) (ft) 8,051.87 93.50 355.82 5,999.80 5,884.80 -613.01 3,374.80 5,957,601.38 543,385.93 0.17 -613.01 MWD OWSG (3) 8,081.52 94.37 355.52 5,997.77 5,882.77 -583.51 3,372.57 5,957,630.86 543,383.54 3.10 -583.51 MWD OWSG (3) 8,111.07 92.43 355.17 5,996.02 5,881.02 -554.11 3,370.17 5,957,660.25 543,380.99 6.67 554.11 MWD OWSG (3) 8,144.02 91.11 355.35 5,995.00 5,880.00 -521.29 3,367.45 5,957,693.05 543,378.10 4.04 -521.29 MWD OWSG (3) E 8,172.17 94.15 356.53 5,993.71 5,878.71 -093.25 3,365.46 5,957,721.08 543,375.96 11.58 -093.25 MWD OWSG (3) 8,199.08 93.48 354.31 5,991.92 5,876.92 -466.48 3,363.32 5,957,747.83 543,373.67 8.60 466.48 MWD OWSG (3) 8,228.87 90.43 352.71 5,990.90 5,875.90 -036.91 3,359.95 5,957,777.39 543,370.15 11.56 -036.91 MWD OWSG (3) i 8,260.38 91.32 354.26 5,990.42 5,875.42 -005.60 3,356.38 5,957,808.67 543,366.41 5.67 -005.60 MWD OWSG (3) 8,290.17 89.17 355.33 5,990.29 5,875.29 -375.94 3,353.67 5,957,838.31 543,363.55 8.06 -375.94 MWD OWSG (3) 8,320.98 87.33 355.71 5,991.23 5,876.23 -345.24 3,351.27 5,957,869.00 543,360.98 6.10 -345.24 MWD OWSG (3) 8,351.41 86.53 355.94 5,992.86 5,877.86 -314.93 3,349.06 5,957,899.29 543,358.61 2.74 -314.93 MWD OWSG (3) 8,381.18 90.09 359.39 5,993.74 5,878.74 -285.21 3,347.85 5,957,929.00 543,357.24 16.65 -285.21 MWD OWSG (3) 8,412.44 88.99 0.38 5,993.99 5,878.99 -253.95 3,347.78 5,957,960.25 543,357.01 4.73 -253.95 MWD OWSG (3) 8,441.05 86.75 2.19 5,995.05 5,880.05 -225.37 3,348.42 5,957,988.83 543,357.50 10.06 -225.37 MWD OWSG (3) 8,471.19 86.65 4.77 5,996.79 5,881.79 -195.34 3,350.25 5,958,018.87 543,359.16 8.55 -195.34 MWD OWSG (3) 8,501.09 82.61 3.21 5,999.59 5,884.59 -165.65 3,352.32 5,958,048.57 543,361.08 14.48 -165.65 MWD OWSG(3) 9 8,531.63 81.66 3.82 6,003.77 5,888.77 -135.46 3,354.18 5,958,078.77 543,362.77 3.69 -135.46 MWD OWSG (3) 8,560.76 84.07 5.11 6,007.38 5,892.38 -106.64 3,356.43 5,958,107.59 543,364.87 9.37 -106.64 MWD OWSG (3) t 8,591.50 84.47 6.57 6,010.45 5,895.45 -76.22 3,359.54 5,958,138.03 543,367.82 4.90 -76.22 MWD OWSG (3) 8,621.49 83.97 6.67 6,013.47 5,698.47 46.58 3,362.98 5,958,167.69 543,371.10 1.70 46.58 MWD OWSG (3) 8,651.79 86.07 7.09 6,016.10 5,901.10 -16.61 3,366.60 5,958,197.67 543,374.56 7.07 -16.61 MWD OWSG (3) 8,681.60 87.20 8.10 6,017.85 5,902.85 12.89 3,370.53 5,958,227.18 543,378.33 5.08 12.89 MWD OWSG (3) 8,710.36 88.89 8.91 6,018.83 5,903.84 41.31 3,374.78 5,958,255.63 543,382.43 6.52 41.31 MWD OWSG (3) s 8,741.47 86.83 7.75 6,020.00 5,905.00 72.07 3,379.28 5,958,286.41 543,386.77 7.60 72.07 MWD OWSG (3) 8 8,771.04 85.63 7.92 6,021.94 5,906.94 101.30 3,383.31 5,958,315.66 543,390.64 4.10 101.30 MWD OWSG (3) I 8,801.89 86.59 7.32 6,024.03 5,909.03 131.81 3,387.39 5,958,346.18 543,394.55 3.67 131.81 MWD OWSG (3) 1 8,831.34 8748 7.00 6,025.56 5,910.56 16099 3,391.05 5,958,375.38 543,398.06 3.21 160.99 MWD OWSG (3) 8,862.27 85.76 5.09 6,027.38 5,912.38 191.69 3,394.30 5,958,406.09 543,401.15 8.30 191.69 MWD OWSG (3) 8,892.20 84.64 3.21 6,029.89 5,914.89 221.43 3,396.46 5,958,435.85 543,403.15 7.29 221.43 MWD OWSG (3) 8,921.49 84.46 2.83 6,032.67 5,917.67 250.55 3,398.00 5,958,464.97 543,404.53 1.43 250.55 MWD OWSG (3) 8,951.75 84.99 2.90 6,035.45 5,920.45 280.65 3,399.50 5,958,495.07 543,405.88 1.77 280.65 MWD OWSG (3) 11202019 1:32:11PM Page 4 COMPASS 5000.14 Build 85H Survey 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 (IF -07) Well: 1F-07 North Reference: True Wellbore: 11F-071-1 Survey Calculation Method: Minimum Curvature Design: 1F-071-1 Database: EDT 14 Alaska Production Survey 11Q0/2019 1:32:11PM Page 5 COMPASS 5000.14 Build 85H Map Map Vertical MD (usit) Inc (°) Azi (') TVD (usR) TVDSS (usft) +NIS (usR) +EI -W (usR) Northing Easting DLS ('DLS Section Survey Tool Name Annotation (R) (ft) (R) 8,981.09 80.41 359.90 6,039.18 5,924.18 309.73 3,400.22 5,958,524.15 543,406.44 18.61 309.73 MWD OWSG (3) `y 9,011.67 82.65 359.83 6,043.68 5,928.68 339.97 3,400.15 5,958,554.39 543,406.21 7.33 339.97 MWD OWSG (3) S 9,043.03 84.16 358.81 6,047.28 5,932.28 371.12 3,399.78 5,958,585.54 543,405.67 5.80 371.12 MWD OWSG (3) 9,070.26 85.54 357.92 6,049.73 5,934.73 398.23 3,399.00 5,958,612.64 543,404.75 6.02 398.23 MWD OWSG(3) 9,101.78 87.91 356.52 6,051.53 5,936.53 429.66 3,39748 5,958,644.05 543,403.06 8.73 429.66 MWD OWSG (3) 9,131.42 89.94 356.08 6,052.08 5,937.08 459.23 3,395.56 5,958,673.61 543,400.99 7.01 459.23 MWD OWSG (3) 9,161.85 89.63 355.89 6,052.20 5,937.20 489.58 3,393.43 5,958,703.95 543,398.70 1.19 489.58 MWD OWSG (3) 9,191.55 91.11 355.07 6,052.01 5,937.01 519.19 3,391.09 5,958,733.54 543,396.20 5.70 519.19 MWD OWSG (3) 9,221.45 89.26 355.82 6,051.91 5,936.91 548.99 3,388.72 5,958,763.33 543,393.67 6.68 548.99 MWD OWSG (3) 9,251.68 89.02 355.83 6,052.36 5,937.36 579.14 3,386.52 5,958,793.46 543,391.31 0.79 579.14 MWD OWSG (3) 9,281.82 89.20 354.83 6,052.83 5,937.83 609.18 3,384.07 5,958,823.48 543,388.69 3.37 609.18 MWD OWSG (3) 9,311.85 89.32 354.05 6,053.22 5,938.22 639.06 3,381.16 5,958,853.35 543,385.62 2.63 639.06 MWD OWSG (3) 9,341.35 87.57 351.73 6,054.02 5,939.02 668.32 3,377.51 5,958,882.58 543,381.82 9.85 668.32 MWD OWSG (3) 3 9,371.23 87.79 350.81 6,055.23 5,940.23 697.83 3,372.98 5,958,912.07 543,377.13 3.16 697.83 MWD OWSG (3) 9,401.59 86.77 349.63 6,056.67 5,941.67 727.71 3,367.82 5,958,941.92 543,371.82 5.13 727.71 MWD OWSG (3) 9,431.55 87.88 349.05 6,058.07 5,943.07 757.13 3,362.29 5,958,971.30 543,366.13 4.18 757.13 MWD OWSG (3) 9,462.19 84.87 345.99 6,060.01 5,945.01 786.97 3,355.68 5,959,001.11 543,359.37 13.99 786.97 MWD OWSG (3) 9,492.53 86.99 346.57 6,062.16 5,947.16 816.37 3,348.51 5,959,030.46 543,352.03 7.24 816.37 MWD OWSG (3) 9,518.87 88.74 34745 6,063.14 5,948.14 842.02 3,342.59 5,959,056.08 543,345.98 7.44 842.02 MWD OWSG (3) 9,551.21 87.70 345.74 6,064.15 5,949.15 873.46 3,335.10 5,959,087.48 543,338.32 6.19 873.46 MWD OWSG (3) ) 9,566.07 87.82 345.11 6,064.73 5,949.73 887.83 3,331.36 5,959,101.82 543,334.51 4.31 887.83 MWD OWSG (3) E, 9,607.00 87.82 345.11 6,066.28 5,951.28 927.36 3,320.85 5,959,141.29 543,323.79 0.00 927.36 PROJECTED to TD 11Q0/2019 1:32:11PM Page 5 COMPASS 5000.14 Build 85H NOV 2 2 2019 Baker Hughes Date: To: Abby Bell AOGCC 333 West 7t" Ave, Suite 100 Anchorage, Alaska 99501 21 8073 31486 Letter of Transmittal November 20, 2019 :From: Harvey Finch Baker Hughes 795 East 94t" Avenue Anchorage, Alaska 99515 i ;Please find enclosed the directional survey data for the following wells i 1R-23UPB1 1R-23UPB2 1R-23L1PB3 1F -07L1 iF-07L1-01 (5) Total prints 1 Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Harvey Finch, Baker Hughes, Wellplanner Harvey.Finch@bakerhughes.com i 218073 31486 ConocoPhi I I i ps ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 1 F Pad 1 F -07L1 50-029-20830-60 Baker Hughes I NTEQ Baker Hughes Definitive Survey Report 20 November, 2019 ConocoPhillips Baker Hughes J ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit Site: Kuparuk 11' Pad Well: 1 F-07 Wellbore: IF -071_1 Design: IF -071_1 Project Kuparuk River Unit. North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 1 F-07 Local Co-ordinate Reference: Well 1F-07 TVD Reference: 1 F-07 @ 115.00usft (1 F-07) MD Reference: 1 F-07 @ 115.00usft (1 F-07) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Well Position +N/ -S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 1 F-071_1 Date Magnetics Model Name Sample Date (usft) BGGM2016 12/1/2019 Design 1 F-071_1 1 F-07 (1 F-07) Audit Notes: 7,320.65 1F-071_1 MWD -INC (1F -07L1) Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,958,196.36 usft Latitude: 540,008.25 usft Longitude: usft Ground Level: Declination Dip Angle (I (I 16.30 80.82 Version: 1 0 Phase: ACTUAL Tie On Depth: 7 200.00 Vertical Section: Depth From (TVD) (usft) 115.00 Survey Program Date From To (usft) (usft) Survey (Wellbore) 200.00 7,200.00 1 F-07 (1 F-07) 7.205.00 7,320.65 1F-071_1 MWD -INC (1F -07L1) 7,350.28 9,56607 1 F-071_1 MWD (1 F-071-1) +N/ -S (usft) 0.00 +EAW (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 Direction (1) 0.00 Survey Start Date 8/25/2000 10/30/2019 10/30/2019 70° 17'48.221 N 149° 40'33.704 W 0.00 usft Field Strength (nT) 57.393 Survey End Date 10/30/2019 11/2/2019 11/20/2019 1:32:11PM Page 2 COMPASS 5000.14 Build 85H Survey Baker Hughes 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: 1 F-071-1 Survey Calculation Method: Minimum Curvature Design: 1 F -07L1 Database: EDT 14 Alaska Production Survey Baker Hughes 11/20/2019 1:32:11 PM Page 3 COMPASS 5000.14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +N1S +EJ -W Northing Easting DLS Section (usft) V) (1) (usft) (usft) (usft) (usft) (11100') Survey Tool Name Annotation (ft) (ft) (ft) 7,200.00 33.97 107.11 5,997.41 5,882.41 -565.37 3,419.38 5.957,649.26 543,430.26 0.53 -565.37 MWD-INC_ONLY (INC>100) (2) TIP 7,205.00 33.97 107.10 6,001.56 5,886.56 -566.19 3,422.05 5,957,648.45 543,432.93 0.11 -566.19 MWD-INC_ONLY (INC>10°) (2) KOP 7,230.38 38.50 109.00 6,022.02 5,907.02 -570.85 3,436.31 5,957,643.87 543,447.21 18.39 -570.85 MWD -INC _ONLY (INC>10°)(2) Interpolated Azimuth 7,259.74 51.95 112.00 6,042.66 5,927.66 -578.19 3,455.76 5,957,636.63 543,466.70 46.37 -578.19 MWD -INC -ONLY (INC>100) (2) Interpolated Azimuth 7,290.38 63.63 114.40 6,058.96 5,943.96 -588.42 3,479.53 5,957,626.53 543,490.52 38.69 -588.42 MWD -INC _ONLY (INC>10°) (2) Interpolated Azimuth 7,320.65 75.39 115.00 6,069.54 5,954.54 -600.25 3,505.24 5,957,614,84 543.516.29 38.69 -600.25 MWD-INC_ONLY (INC>10°) (2) Interpolated Azimuth 7,35028 86.59 115.45 6,074.17 5,959.17 -612.70 3,531.67 5,957,602,53 543.542.79 37.83 -612.70 MWD OWSG (3) 7,379.99 101.31 116.87 6,072.13 5,957.13 -625.73 3,558.20 5,957,589.64 543,569.39 49.77 -625.73 MWD OWSG (3) 7,410.19 102.88 130.42 6,065.78 5,950.78 -642.04 3,582.73 5,957,573.46 543,593.99 44.17 -642.04 MWD OWSG (3) 7,440.31 102.57 143.34 6,059.11 5.944.11 -663.44 3,602.76 5,957,552.17 543,614.14 41.85 -663.44 MWD OWSG (3) 7,470.20 101.78 155.99 6.052.79 5,937.79 -68860 3,617.48 5.957,527.09 543,628.99 41.45 -688.60 MWD OWSG (3) 7,499.76 101.03 168.52 6,046.92 5,931.92 -716.14 3,626.29 5,957,499.60 543,637.95 41.63 -716.14 MWD OWSG (3) 7,529.59 100.54 181.75 6,041.31 5,926.31 -745.27 3,628.77 5,957,470.49 543,640.58 43.60 -745.27 MWD OWSG (3) 7,559.95 100.26 194.18 6,035.81 5,920.81 -774.78 3,624.64 5,957,440.96 543,636.60 40.28 -774.78 MWD OWSG (3) 7,589.39 99.47 206.07 6,030.75 5,915.75 -801.96 3,614.67 5,957,413.73 543,626.79 39.88 -801.96 MWD OWSG (3) 7,619.74 100.00 220.13 6,025.59 5,910.59 -826.95 3,598.38 5,957,388.65 543,610.63 45.69 -826.95 MWD OWSG (3) 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) 7,680.55 96.06 248.45 6,017.26 5,902.26 -661.90 3,550.09 5.957,353.45 543,562.53 47.92 -861.90 MWD OWSG (3) 7;699.31 93.41 258.58 6.015.70 5.900.70 -867.20 3,532.19 5,957,348.06 543,544,66 55.63 -867.20 MWD OWSG (3) 7,725.51 95.41 270.62 6,013.68 5,898.68 -869.65 3,50623 5,957,345.47 543,518.72 46.45 -869.65 MWD OWSG (3) 7,756.17 95.72 284.84 6,010.69 5,895.69 -865.56 3,478.07 5,957,349.40 543,488.54 46.17 -865.56 MWD OWSG (3) 7,785.36 96.28 297.82 6,007.63 5,892.63 -855.03 3,449.09 5,957,359.79 543,461.50 44.26 -655.03 MWD OWSG (3) 7,815.65 93.32 311.35 6,005.08 5,890.08 -837.93 3,424.30 5,957,376.75 543.436.63 45.57 -837.93 MWD OWSG (3) 7,840.49 91.94 325.21 6,003.94 5,888.94 -819.45 3,407.83 5,957,395.14 543,420.06 56.01 -819.45 MWD OWSG (3) 7,870.16 86.13 340.62 6,004.44 5,889.44 -793.13 3,394.37 5,957,421.38 543,406.46 55.48 -793.13 MWD OWSG (3) 7,901.85 91.08 352.48 6,005.21 5,890.21 -762.39 3,387.02 5,957,452.09 543,398.95 40.53 -762.39 MWD OWSG (3) 7,931.97 92.21 355.26 6,004.35 5,889.35 -732.45 3.383.80 5,957,482.00 543,395.57 9.96 -732.45 MWD OWSG (3) 7,961.67 89.97 354.93 6,003.78 5,888.78 -702.87 3,381.27 5,957,511.57 543,392.88 7.62 -702.87 MWD OWSG (3) 7,991.81 92.33 356.42 6,003.18 5,888.18 -672.82 3,378.99 5,957,541.60 543,390.44 9.26 -672.82 MWD OWSG (3) 8,021.87 93.53 355.86 6,001.64 5,886.64 -642.87 3,376.97 5,957,571.53 543,388.26 4.40 -642.87 MWD OWSG (3) 11/20/2019 1:32:11 PM Page 3 COMPASS 5000.14 Build 85H ConocoPhillips Baker Hughes v, 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 IF Pad MD Reference: 1 F-07 @ 115.00usft (1 F-07) Well: 1F-07 North Reference: True Wellbore: 1F-071-1 Survey Calculation Method: Minimum Curvature Design: 1F-071-1 Database: EDT 14 Alaska Production Survey Map Map Vertical -- MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DILS Section (usft) (°) f°) fusft) (usft) (usft) (usft) (°1100') 0 Survey Tool Name Annotation (ft) (ft) (ft) 8,051.87 93.50 355.82 5,999.80 5,884.80 -613.01 3,374.80 5,957,601.38 543,385.93 0.17 -613.01 MWD OWSG (3) 8,081.52 94.37 355.52 5,997.77 5,882.77 -583.51 3,372.57 5,957,630.86 543,383.54 3.10 -583.51 MWD OWSG (3) 8,111.07 92.43 355.17 5,996.02 5,881,02 -55411 3,370.17 5,957,66025 543,380.99 6.67 -554.11 MWD OWSG (3) 8,144.02 91.11 355.35 5,995.00 5,880.00 -521.29 3,367.45 5,957,693.05 543,378.10 4.04 -521.29 MWD OWSG (3) 8,17217 94.15 356.53 5,993.71 5,878.71 493.25 3,365.46 5,957,721.08 543,375.96 11.58 493.25 MWD OWSG (3) 8,199.08 93.48 354.31 5,991_92 5,876.92 -466.48 3,363.32 5,957,74283 543.373.67 8.60 -466.48 MWD OWSG (3) 8,228.87 90.43 352.71 5,990.90 5,875.90 -436.91 3,359.95 5,957,777.39 543,370.15 11.56 -436.91 MWD OWSG (3) 8,260.38 91.32 354.26 5,990.42 5,875.42 405.60 3,356.38 5,957,808.67 543,366.41 5.67 -405.60 MWD OWSG (3) 8,290.17 89.17 355.33 5,990.29 5,875.29 -375.94 3,353.67 5,957,838.31 543,363.55 8.06 -375.94 MWD OWSG (3) ' 8,320.98 87.33 355.71 5,991.23 5,876.23 -345.24 3,351.27 5,957,869.00 543,360.98 6.10 -345.24 MWD OWSG (3) 8,351.41 86.53 355.94 5,992.86 5,677.86 -314.93 3,349.06 5,957,899.29 543,358.61 2.74 -314.93 MWD OWSG (3) 8,381.18 90.09 359.39 5,993.74 5,878.74 -285.21 3,347.85 5,957,929.00 543,357.24 16.65 -285.21 MWD OWSG (3) 8,412.44 88.99 0.38 5,993.99 5,878.99 -253.95 3,347.78 5,957,960.25 543,357.01 4.73 -253.95 MWD OWSG (3) 8,441.05 86.75 2.19 5,995.05 5,880.05 -225.37 3,348.42 5,957,988.83 543,357.50 10.06 -225.37 MWD OWSG (3) 8,471.19 86.65 4.77 5,996.79 5,881.79 -195.34 3,350.25 5,958,018.87 543,359.16 8.55 -195.34 MWD OWSG (3) 8,501.09 82.61 3.21 5,999.59 5,884.59 -165.65 3,352.32 5,958,048.57 543.361.08 14.48 -165.65 MWD OWSG (3) 8,531,63 81.66 3.82 6,003.77 5,888.77 -135.46 3,354.18 5,958,078 77 543,362.77 3.69 -135.46 MWD OWSG (3) 8,560.76 84.07 5.11 6,007.38 5,892.38 -106.64 3,356.43 5,958,107.59 543,364.87 9.37 -106.64 MWD OWSG (3) 8,591.50 84.47 6.57 6,010.45 5,895.45 -76.22 3,359.54 5,958,138.03 543,367.82 4.90 -76.22 MWD OWSG (3) 8,621.49 83.97 6.67 6,013.47 5,898.47 -46.58 3,362.98 5.958,167.69 543,371.10 1.70 -46.58 MWD OWSG (3) 8,651.79 86.07 7.09 6,016.10 5,901.10 -16.61 3,366.60 5,958,197.67 543,374.56 7.07 -16.61 MWD OWSG (3) 8,681.60 87.20 8.10 6,017.85 5,902.85 12.89 3,370.53 5,958,227.18 543,378.33 5.08 12.89 MWD OWSG (3) 8,710.36 88.89 8.91 6,018.83 5,903.84 41.31 3,374.78 5,958,255.63 543,382.43 6.52 41.31 MWD OWSG (3) 8,741.47 86.83 7.75 6,020.00 5,905.00 72.07 3,379.28 5,958,286.41 543,386.77 7.60 72.07 MWD OWSG (3) 8,771.04 85.63 7.92 6,021.94 5,906.94 101.30 3,383.31 5,958,315.66 543,390.64 4.10 101.30 MWD OWSG (3) 8,801.89 86.59 7.32 6,024.03 5,909.03 131.81 3,387.39 5,958,346.18 543,394.55 3.67 131.81 MWD OWSG (3) 8,831.34 87.48 7.00 6,025.56 5,910.56 160.99 3,391.05 5,958,375.38 543,398.06 3.21 160.99 MWD OWSG (3) 8,862.27 85.76 5.09 6.027.38 5,912.38 191.69 3,394.30 5,958,406.09 543,401.15 8.30 191.69 MWD OWSG (3) 8,892.20 84.64 3.21 6,029.89 5,914.89 221.43 3,396.46 5,958,435.85 543,403.15 7.29 221.43 MWD OWSG (3) 8,921.49 84.46 2.83 6,032.67 5,917.67 250.55 3,398.00 5,958,464.97 543,404.53 1.43 250.55 MWD OWSG (3) 8,951.75 84.99 2.90 6,035.45 5,920.45 280.65 3,399.50 5,958,495.07 543.405.88 1.77 280.65 MWD OWSG (3) 11/20/2019 1:32:11PM Page 4 COMPASS 5000.14 Build 85H ConocoPhillips Baker Hughes4 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 1F Pad MD Reference: 1 F-07 @ 115.00usft (1 F-07) Well: 1 F-07 North Reference: True Wellbore: 1 F-071-1 Survey Calculation Method: Minimum Curvature Design: 1 F-071-1 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) () (1) (usft) (ustt) (usft) (usft) (°1100') Survey Tool Name (ft) (ft) (ft) $981.09 80.41 359.90 6,039.18 5,924.18 309.73 3,400.22 5,958,524.15 543,406.44 18.61 309.73 MWD OWSG (3) 9,011.67 82.65 359.83 6,043.68 5,928.68 339.97 3,400.15 5,958,554.39 543,406.21 7.33 339.97 MWD OWSG (3) 9,043.03 84.16 358.81 6,047.28 5,932.28 371.12 3,399.78 5,958,585.54 543,405.67 5.80 371.12 MWD OWSG (3) 9,070.26 85.54 357.92 6,049.73 5,934.73 398.23 3,399.00 5,958,612.64 543,404.75 6.02 398.23 MWD OWSG (3) 9,101.78 87.91 356.52 6,051.53 5,936.53 429.66 3,397.48 5,958,644.05 543,403.06 8.73 429.66 MWD OWSG (3) 9,131.42 89.94 356.08 6,052.08 5,937.08 459.23 3,395.56 5,958,673.61 543.400.99 7.01 45923 MWD OWSG (3) 9,161.85 89.63 355.89 6,05220 5,937.20 489.58 3,393.43 5,958,703.95 543.398.70 1.19 489.58 MWD OWSG (3) 9,191.55 91.11 355.07 6,052.01 5,937.01 519.19 3,391.09 5,958,733.54 543,396.20 5.70 519.19 MWD OWSG (3) 9,221.45 89.26 355.82 6,051.91 5,936.91 548.99 3,388.72 5,958,763.33 543,393.67 6.68 548.99 MWD OWSG (3) 9,251.68 89.02 355.83 6,052.36 5,937.36 579.14 3,386.52 5,958,793.46 543,391.31 079 579.14 MWD OWSG (3) 9,281.82 89.20 354.83 6,052.83 5,937.83 609.18 3384.07 5,958,823.48 543,388.69 3.37 609.18 MWD OWSG (3) 9,311.85 89.32 354.05 6,053.22 5,938.22 639.06 3,381.16 5,958,853.35 543,385.62 2.63 639.06 MWD OWSG (3) 9,341.35 87.57 351.73 6,054.02 5,939.02 668.32 3,377.51 5,958,882.58 543,381.82 9.85 668.32 MWD OWSG (3) 9,371.23 87.79 350.81 6,055.23 5,940.23 697.83 3,372-98 5,958,912.07 543,377.13 3.16 697.83 MWD OWSG (3) 9,401.59 86.77 349.63 6,056.67 5,941.67 727.71 3,367.82 5,958,941.92 543,371.82 5.13 727.71 MWD OWSG (3) 9,431.55 87.88 349.05 6,058.07 5,943.07 757.13 3,362.29 5,958,971.30 543.366.13 4.18 757.13 MWD OWSG (3) 9,462.19 84.87 345-99 6,060.01 5,945.01 786.97 3,355.68 5,959,001.11 543,359.37 13.99 786.97 MWD OWSG (3) 9,492.53 86.99 346.57 6,062.16 5,947.16 816.37 3,348.51 5,959,030.46 543,352.03 7.24 816.37 MWD OWSG (3) 9,518.87 88.74 347.45 6,063.14 5,948.14 842.02 3.342.59 5,959,056.08 543,345.98 7.44 842.02 MWD OWSG (3) 9,551.21 87.70 345.74 6,064.15 5,949.15 873.46 3.33510 5,959,087.48 543,338.32 6.19 873.46 MWD OWSG (3) 9,566.07 87.82 345.11 6,064.73 5,949.73 887.83 3,331.36 5,959, 101 .82 543,334.51 4.31 887.63 MWD OWSG (3) 9,607.00 87.82 345.11 6,066.28 5,951.28 927.36 3,320.85 5,959,141.29 543,323.79 0.00 927.36 PROJECTED to TD Annotation 11/20/2019 1:32:11PM Page 5 COMPASS 5000.14 Build 85H THE STATE Alaska Oil and Gas Of ALASKA Conservation Commission I IL 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 1 F -07L 1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-073 Surface Location: 1331' FNL, 27' FWL, SEC. 20, TI IN, R1OE, UM Bottomhole Location: 4798' FNL, 1714' FEL, SEC. 17, TI IN, R10E, UM 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 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 A DATED this 3rday of July, 2018. STATE OF ALASKA ALAor\A OIL AND GAS CONSERVATION COMMISaiON PERMIT TO DRILL 20 AAC 25.005 IUN 2 0 2018 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 ElLateral ❑✓ 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 Q . Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska Inc Bond No. 5952180 KRU 1F-071_1 3. Address: 6. Proposed Depth: TVD; &/0,y 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 10,500' 5989' Kuparuk River Pool / 4a. Location of Well (Governmental Section): 7. Property Designation: l LGt Kuparuk River Oil Pool Surface: 1331' FNL, 27' FWL, Sec. 20, T11 N, R10E, UM ADL 25652 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 1899' FNL, 1830' 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: 4798' FNL, 1714' FEL, Sec 17, T11N, R1 OE, UM 2480' 29950' 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- 5958196Zone- 4 GL / BF Elevation above MSL (ft): 74' Ito Same Pool: 1554', 1E-28AL1 16. Deviated wells: Kickoff depth: 7210' feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 103 degrees Downhole: 3869 . Surface: 3279 ✓. 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.6# L-80 ST -L 2900' 7600' 5914' 10500' " 5989' 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" 1000sx Class G 8045' 6704' Perforation Depth MD (ft): 7184'- 7244', 7256- 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 Q BOP Sketch 20. Attachments: Property Plat ❑ Drilling Program ❑ v. Depth Plot ❑ ❑ Shallow ❑ Diverter Sketch Seabed Report Drilling Fuid Program 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Keith Herring Authorized Name. James Ohlinger Contact Email: Keith.E.Herrin co .Com Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4321 Authorized Signature: Date: Commission Use Only Permit to Drill /L API Number: %/ Permit Approval See cover letter for other l J ii 3�i requirements. Number: ! ( 50- Date: C Z�%" (J(� 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: LfI /lO n� /000 Samples req'd: Yes ❑No[� Mud log req'd: YesNo HZS Yes [✓�NoEl J measures: Directional svy req'd: Yes [/No❑ J Spacing exception req'd: Yes ❑ Noy Inclination -only svy req'd: Yes ❑ No [f Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BYI Approved by: COMMISSIONER THE COMMISSION Date: - 3 I ( E. ORIGINAL Form 10-401 Revised 512017 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) ;4tbft dForm and Attachments in Duplicate 10-11, ConocoPhillips 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 1 F-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, eith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals APA 1 F-071-1 and 1F-071-1-01 1W Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(1) 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-071-1 and 1 F-071-1-01 laterals............................................................................6 Attachment 2: Current Well Schematic for 1 F-07............................................................................................................6 Attachment 3: Proposed Well Schematic for 1 F-071-1 and 1 F-071-1-01 laterals..............................................................6 Page 1 of 6 June 18, 2018 PTD Application: 1 F-071_1 and 1 F-071_1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(17 and 20 AAC 25.005(b)) The proposed laterals described in this document are 1 F-071_1 and 'IF -071-1-01. The laterals will be classified as "Development -Oil' wells. 2. Location Summary (Requirements of 20 AAC 25.005(c) (2)) These laterals will target the C sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1 F-071_1 and 1 F-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 free gas while 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-071_1-01 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 -07L1 7,600' 10,500' • 5,914' 5,989' 2-3/8", 4.7#, L-80, ST -L slotted liner,- iner;aluminum 0' 80' 1640 630 Surface aluminumbillet 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' 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 1 F-07 Window (7210' MD, 6006' TVD) Using MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU I 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 o ,2 y j r /16 r i ce' Te ©V VC p r .400A2F7`E.V9` -/-O 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 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, 0.08 si/ft 575 psi 0 psi Mud + ECD Combined no chokepressure) 3,260 psi Overbalanced —615psi) 2,644 psi Overbalanced —40 psi)' 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 I 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 o ,2 y j r /16 r i ce' Te ©V VC p r .400A2F7`E.V9` -/-O 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 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 tote 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 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) Page 5 of 6 June 18, 2018 PTD Application: 1 F-071-1 and 1 F-071-1-01 — 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 1F -07L1 29,950' 1 F -07L1-01 29,025' — Distance to Nearest Well within Pool Lateral Name Distance Well 1 F -07L1 1554' 1 E-28ALl 11F -07U-01 612' 1F-16 16. Attachments Attachment 1: Directional Plans for 1F -07L1 and 1F -07L1-01 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 I ME meq$ � ■ a A0 Q 0 c Lw .. . .� , . . . / / t «O mmTION/(941o2 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 F Pad 1 F-07 1 F -07L1 Plan: 1 F -07L1 wp06 Standard Planning Report 29 May, 2018 BER 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 (IF -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 I UGHES 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: 0.000 in Grid Convergence: 0.30 ° Well 1 F-07 I 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 j Wellbore 1 F-071-1 i Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (°) (nT) BGGM2017 9/1/2018 16.89 80.88 57,454 i i Design 1 F-071-1_wp06 ConocoPhillips Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 F Pad Well: 1 F-07 Wellbore: IF -07L1 Design: 1 F-07L1_wp06 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 (IF -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 I UGHES 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: 0.000 in Grid Convergence: 0.30 ° Well 1 F-07 I 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 j Wellbore 1 F-071-1 i Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (°) (nT) BGGM2017 9/1/2018 16.89 80.88 57,454 i i Design 1 F-071-1_wp06 Audit Notes: Version: Phase: PLAN Ire On Depth: 7,200.00 I Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction Dogleg (usft) (usft) (usft) (°) Depth 0.00 0.00 0.00 0.00 Plan Sections Measured TVD Below Dogleg Build Tum Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) i (°) (°) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (°) Target 7,200.00 33.97 107.11 5,882.41 -565.37 3,419.38 0.00 0.00 0.00 0.00 7,210.00 33.98 107.08 5,890.70 -567.01 3,424.72 0.20 0.10 -0.30 -59.20 7,235.00 38.34 108.96 5,910.88 -571.58 3,438.74 18.00 17.45 7.50 15.00 71381.21 103.00 122.98 5,956.95 -631.86 3,554.39 45.00 44.22 9.59 15.00 7.600.00 93.88 222.58 5,913.75 -818.63 3,575.39 45.00 -4.17 45.53 84.00 7,900.00 90.08 357.72 5,892.53 -737.29 3,355.66 45.00 -1.27 45.05 86.00 8,300.00 90.07 25.72 5,892.00 -349.52 3,436.13 7.00 0.00 7.00 90.00 8,600.00 90.06 4.72 5,891.65 -61.66 3,514.47 7.00 0.00 -7.00 270.00 1 8,800.00 88.85 18.67 5,893.55 133.69 3,554.92 7.00 -0.61 6.97 95.00 9,200.00 84.31 350.99 5,917.86 527.55 3,588.43 7.00 -1.14 -6.92 260.00 9,400.00 84.48 5.05 5,937.50 725.96 3,581.58 7.00 0.08 7.03 90.00 9,700.00 84.85 343.96 5,965.72 1,021.58 3,553.14 7.00 0.12 -7.03 270.00 10,100.00 90.11 11.50 5,983.67 1,416.91 3,537.68 7.00 1.32 6.88 80.00 10,400.00 88.67 350.55 5,986.91 1,715.17 3,543.03 7.00 -0.48 -6.98 266.00 10,500.00 88.68 357.55 5,989.22 1,814.54 3,532.68 7.00 0.01 7.00 90.00 5/2912018 1:43:16PM Page 2 COMPASS 5000.14 Build 85 - ConocoPhillips BA_ ITER Conoco Planning Report t f UGHES a 6E company Database: EDT Alaska Sandbox Local Coordinate Reference: Well 1F-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 -07L1 Depth Inclination Azimuth Design: 1F-07L1_wp06 +El -W Section Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N1 -S +El -W Section Rate Azimuth Northing Easting j (usft) I (') (') (usft) (usft) (usft) (usft) ('MOOft) (1) (usft) (usft) 7,200.00 33.97 107.11 5,882.41 -565.37 3,419.38 -565.37 0.00 0.00 5,957,649.26 543,430.26 TIP 7,210.00 33.98 107.08 5,890.70 -567.01 3,424.72 -567.01 0.20 -59.20 5,957,647.64 543,435.61 KOP 7,235.00 38.34 108.96 5,910.88 -571.58 3,438.74 -571.58 18.00 15.00 5,957,643.14 543,449.65 End 18 d1s, Start 45 dis 7,300.00 66.95 116.86 5,949.95 -592.09 3,485.51 -592.09 45.00 15.00 5,957,622.89 543,496.52 � 7,381.21 103.00 122.98 5,956.95 -631.86 3,554.39 -631.86 45.00 10.05 5,957,583.49 543,565.60 4 7,400.00 103.74 131.64 5,952.60 -642.93 3,568.91 -642.93 45.00 84.00 5,957,572.50 543,580.19 j 7,500.00 102.46 177.89 5,928.70 -728.43 3,609.10 -728.43 45.00 86.01 5,957,487.23 543,620.82 j 7,600.00 93.88 222.58 5,913.75 -818.63 3,575.39 -818.63 45.00 97.06 5,957,396.85 543,587.60 5 7,700.00 95.57 267.72 5,905.06 -859.46 3,487.34 -859.46 45.00 86.00 5,957,355.56 543,499.77 7,800.00 93.99 312.86 5,896.27 -825.77 3,396.32 -825.77 45.00 89.92 5,957,388.76 543,408.58 7,900.00 90.08 357.72 5,892.53 -737.29 3,355.66 -737.29 45.00 93.89 5,957,477.02 543,367.46 End 45 d1s, Start 7 dis 8,000.00 90.08 4.72 5,892.39 -637.37 3,357.79 -637.37 7.00 90.00 5,957,576.93 543,369.06 8,100.00 90.08 11.72 5,892.26 -538.46 3,372.09 -538.46 7.00 90.01 5,957,675.91 543,382.83 8,200.00 90.07 18.72 5,892.13 -442.03 3,398.33 -442.03 7.00 90.02 5,957,772.47 543,408.56 8,300.00 90.07 25.72 5,892.00 -349.52 3,436.13 -349.52 7.00 90.03 5,957,865.17 543,445.86 7 8,400.00 90.07 18.72 5,891.88 -257.00 3,473.93 -257.00 7.00 -90.00 5,957,957.88 543,483.16 8,500.00 90.07 11.72 5,891.76 -160.57 3,500.18 -160.57 7.00 -90.01 5,958,054.43 543,508.89 8,600.00 90.06 4.72 5,891.65 -61.66 3,514.47 -61.66 7.00 -90.02 5,958,153.41 543,522.66 8 8,700.00 89.46 11.70 5,892.07 37.25 3,528.75 37.25 7.00 95.00 5,958,252.39 543,536.40 8,800.00 88.85 18.67 5,893.55 133.69 3,554.92 133.69 7.00 94.97 5,958,348.95 543,562.06 9 8,900.00 87.65 11.77 5,896.60 230.07 3,581.15 230.07 7.00 -100.00 5,958,445.47 543,587.78 9,000.00 86.48 4.86 5,901.73 328.83 3,595.60 328.83 7.00 -99.79 5,958,544.29 543,601.691 9,100.00 85.36 357.94 5,908.85 428.48 3,598.03 428.48 7.00 -99.44 5,958,643.94 543,603.60 9,200.00 84.31 350.99 5,917.86 527.55 3,588.43 527.55 7.00 -98.94 5,958,742.95 543,593.47 10 9,300.00 84.35 358.02 5,927.75 626.54 3,578.91 626.54 7.00 90.00 5,958,841.88 543,583.42 9,400.00 84.48 5.05 5,937.50 725.96 3,581.58 725.96 7.00 89.30 5,958,941.31 543,585.56 � 11 9,500.00 84.52 358.02 5,947.09 825.40 3,584.24 825.40 7.00 -90.00 5,959,040.75 543,587.70 9,600.00 84.64 350.99 5,956.55 924.44 3,574.72 924.44 7.00 -89.33 5,959,139.72 543,577.64 9,700.00 84.85 343.96 5,965.72 1,021.58 3,553.14 1,021.58 7.00 -88.66 5,959,236.74 543,555.55 12 9,800.00 86.10 350.87 5,973.62 1,118.82 3,531.44 1,118.82 7.00 80.00 5,959,333.85 543,533.34 9,900.00 87.40 357.76 5,979.30 1,218.10 3,521.57 1,218.10 7.00 79.45 5,959,433.07 543,522.94 i 10,000.00 88.75 4.64 5,982.66 1,317.96 3,523.66 1,317.96 7.00 79.06 5,959,532.93 543,524.50 1 10,100.00 90.11 11.50 5,983.67 1,416.91 3,537.68 1,416.91 7.00 78.83 5,959,631.94 543,538.00 13 10,200.00 89.62 4.52 5,983.90 1,515.87 3,551.61 1,515.87 7.00 -94.00 5,959,730.96 543,551.39 10,300.00 89.14 357.54 5,984.99 1,615.79 3,553.40 1,615.79 7.00 -93.98 5,959,830.88 543,552.65 10,400.00 88.67 350.55 5,986.91 1,715.17 3,543.03 1,715.17 7.00 -93.91 5,959,930.19 543,541.76 14 10,500.00 88.68 357.55 5,989.22 1,814.54 3,532.68 1,814.54 7.00 90.00 5,960,029.50 543,530.871 Planned TD at 10500.00 5/29/2018 1: 43 16P Page 3 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 BA ER BAT a GE company Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (e) (1 (usft) (usft) (usft) (usft) (`/100ft) (I (usft) (usft) 5/29/2018 1:43:16PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup1 Project Kuparuk River Unit Site: Kuparuk IF Pad Well: 1 F-07 Wellbore: IF -071-1 Design: 1 F-07L1_wp06 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 BA ER BAT a GE company Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (e) (1 (usft) (usft) (usft) (usft) (`/100ft) (I (usft) (usft) 5/29/2018 1:43:16PM Page 4 COMPASS 5000.14 Build 85 Targets ConocoPhillips -7,973.061,143,708.81 B,:E 1,683,631.00 ConocoPhillips Planning Report UGHES hitlmiss target Dip Angle Dip Dir. a GE company Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 1 F-07 Easting Company: ConocoPhillips (Alaska) Inc. -Kup1 TVD Reference: Mean Sea Level (usft) Project: Kuparuk River Unit MD Reference: 1 F-07 @ 115.00usft (1 F-07) 0.00 Site: Kuparuk 1F Pad North Reference: True 1,683,611.00 70' 2'33.320 N 140'29'57.301 W Well: 1F-07 Survey Calculation Method: Minimum Curvature Point 4 Wellbore: IF -07L1 1,117.22 171.91 5,957,430.01 1,683,796.94 Design: 1 F-07L1_wp06 0.00 0.00 0.00 Targets 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 Target Name Polygon hitlmiss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting Shape (') (") (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1F-07 CTD Polygon Nor 0.00 0.00 0.00 -6,706.841,143,695.53 Point 3 5,957,576.00 1,683,611.00 70' 2'33.320 N 140'29'57.301 W plan misses target center by 1140117.53usft at 7500.00usft MD (5928.70 TVD, -728.43 N, 3609.10 E) 1,683,873.95 Polygon Point 4 0.00 1,117.22 171.91 5,957,430.01 1,683,796.94 Point 1 0.00 0.00 0.00 5,957,576.00 1,683,611.00 Point 2 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 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 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 1F-07 CTD Polygon Sou 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 1140138.14usft at 7500.00usft MD (5928.70 TVD, -728.43 N, 3609.10 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 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 -454.19 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_T03 0.00 0.00 5,893.00 -7,055.741,143,481.66 5,957,228.00 1,683,399.00 70' 2'30.267 N 140' 30'4.877 W plan misses target center by 1139890.12usft at 7500.00usft MD (5928.70 TVD, -728.43 N, 3609.10 E) Point IF -071-1-T01 0.00 0.00 5,960.00 -6,933.651,143,654.33 5,957,351.00 1,683,571.00 70' 2'31.198 N 140' 29'59.443 W plan misses target center by 1140062.12usft at 7500.00usft MD (5928.70 TVD, -728.43 N, 3609.10 E) Point 1F -071-1_T05 0.00 0.00 5,902.00 -5,989.901,143,721.36 5,958,295.00 1,683,633.00 70' 2'40.262 N 140' 29'53.464 W - plan misses target center by 1140124.40usft at 7500.00usft MD (5928.70 TVD, -728.43 N, 3609.10 E) - Point 1F -071-1_T04 0.00 0.00 5,892.00 -6,479.451,143,626.75 5,957,805.00 1,683.541.00 70' 2' 35.648 N 140' 29'58.266 W plan misses target center by 1140032.15usft at 7500.00usft MD (5928.70 TVD, -728.43 N, 3609.10 E) - Point 1F-07L1_T07 0.00 0.00 5,983.00 -5,000.411,143,649.62 5,959,284.00 1,683,556.00 70' 2'49.974 N 140' 29'51.231 W plan misses target center by 1140048.53usft at 7500.00usft MD (5928.70 TVD, -728.43 N, 3609.10 E) Point 1F-071-1_702 0.00 0.00 5,929.00 -7,047.101,143,735.74 5,957,238.00 1,683;653.00 70' 2'29.977 N 140' 29'57.619 W plan misses target center by 1140144.15usft at 7500.00usft MD (5928.70 TVD, -728.43 N, 3609.10 E) Point 1F -071-1_T08 0.00 0.00 5,989.00 4,504.401,143,659.26 5,959,780.00 1,683,563.00 70' 2'54.775 N 140' 29'48.816 W - plan misses target center by 1140056.42usft at 7500.00usft MD (5928.70 TVD, -728.43 N, 3609.10 E) 5/29/2018 1:43:16PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1F-07 Mean Sea Level 1F-07 @ 115.00usft (1F-07) True Minimum Curvature IlA (E 1- UGHES a GE company 1F -07L1 -TOB 0.00 0.00 5,947.00 -5,492.791,143,711.01 5,958,792.00 1,683,620.00 70° 2'45.103 N 140° 29'51.612 W plan misses target center by 1140111.86usft at 7500.00usft MD (5928.70 TVD, -728.43 N, 3609.10 E) Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 10,500.00 5,989.22 2 318" 2.375 3.000 Plan Annotations 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-071-1 Design: 1 F-07L1_wp06 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1F-07 Mean Sea Level 1F-07 @ 115.00usft (1F-07) True Minimum Curvature IlA (E 1- UGHES a GE company 1F -07L1 -TOB 0.00 0.00 5,947.00 -5,492.791,143,711.01 5,958,792.00 1,683,620.00 70° 2'45.103 N 140° 29'51.612 W plan misses target center by 1140111.86usft at 7500.00usft MD (5928.70 TVD, -728.43 N, 3609.10 E) Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 10,500.00 5,989.22 2 318" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NIS +E/ -W (usft) (usft) (usft) (usft) Comment 7,200.00 5,882.41 -565.37 3,419.38 TIP 7,210.00 5,890.70 -567.01 3,424.72 KOP 7,235.00 5,910.88 -571.58 3,438.74 End 18 dls, Start 45 dis 7,381.21 5,956.95 -631.86 3,554.39 4 7,600.00 5,913.75 -818.63 3,575.39 5 7,900.00 5,892.53 -737.29 3,355.66 End 45 dis, Start 7 dls 8,300.00 5,892.00 -349.52 3,436.13 7 8,600.00 5,891.65 -61.66 3,514.47 8 8,800.00 5,893.55 133.69 3,554.92 9 9,200.00 5,917.86 527.55 3,588.43 10 9,400.00 5,937.50 725.96 3,581.58 11 9,700.00 5,965.72 1,021.58 3,553.14 12 10,100.00 5,983.67 1,416.91 3,537.68 13 10,400.00 5,986.91 1,715.17 3,543.03 14 10,500.00 5,989.22 1,814.54 3,532.68 Planned TD at 10500.00 5/29/2018 1:43:16PM Page 6 COMPASS 5000.14 Build 85 - Baker Hughes INTEQ BA_ �fER ConocoPhillips Travelling Cylinder Report HUGHES a GE company Company: ConocoPhillips (Alaska) Inc. -Kupl Project Kuparuk River Unit Reference Site: Kuparuk 1 F Pad Site Error. 0.00 usft Reference Well: 1 F-07 Well Error. 0.00 usft Reference Wellbore 1F-071_1 Reference Design: 1 F-07L1_wp06 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) 1F-07 @ 115,00usft (1F-07) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Reference 1 F-071-1_wp06 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,200.00 to 10,500.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,238.50 usft Error Surface: Pedal Curve Survey Tooi Program Date 5/29/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description j 200.00 7,200.00 1 F-07 (1 F-07) BOSS -GYRO Sperry -Sun BOSS gyro multishot 7,200.00 10, 500.00 1 F-07 L1 _wp06 (1 F-071-1) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 10,500.00 6,104.22 23/8" 2-3/8 3 i Summary Site Name Offset Well - Wellbore - Design Kuparuk 1F Pad 1 F-05 - 1 F-05 - 1 F-05 1 F-06 - 1 F-06 - 1 F-06 1 F-07 - 1 F-07 - i F-07 1 F-07 - 1 F-071_1-01 - 1 F-071_1-01 _wp02 1 F-08 - 1 F-08 - 1 F-08 1F -14 -1F -14-1F-14 1F-16-iF-16-1F-16 1 F-16 - 1 F-1 6A - 1 F-1 6A 1 F-16 - 1 F-16AL1 - 1 F-16AL1 1 F-16 - 1 F-16AL1-01 - 1 F-16AL1-01 1 F-16 - 1 F-16AL1-02 - 1 F-16AL1-02 1F -19 -1F -19-1F-19 1 F-19 - 1 F-191-1 - i F-191-1 1 F-19 - 1 F-191-1-01 - 1 F-191-1-01 1F-19- 1F-191-1PB1 - 1F-1911 Pat 1 F-20 - 1 F-20 - 1 F-20 1 F-20 - 1 F -20P B 1- 1 F -20P B 1 Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) 8,087.04 7,125.00 72.59 8,087.04 7,125.00 72.59 No -Go Allowable Distance Deviation Warning (usft) from Plan (usft) Out of range Out of range 15.99 62.03 Pass - Major Risk 6.23 71.72 Pass - Minor 1 /10 Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Offset Design Kuparuk 1 F Pad - 1 F-07 - 1 F-07 - 1 F-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 Tmtface + Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N! -S +E/ -W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (") (usft) (usft) lint) 7,224.99 6,017.94 7,225.00 6,018.14 0.05 0.16 -57.15 -569.47 3,432.74 3 0.35 1.14 -0.70 FAIL - Major Risk 7,249.59 6,036.80 7,250.00 6.038.87 0.06 0.33 -56.05 -573.56 3,446.11 3 3.01 2.39 0.66 Pass - Major Risk 7,272.46 6,051.56 7,275.00 6,059.59 0.07 0.49 -54.68 -577.63 3,459.49 3 10.01 3.83 6.22 Pass - Major Risk 7,292.54 6,061.83 7,300.00 6,080.30 0.07 0.65 -53.56 -581.68 3,472.88 3 20.95 5.06 15.95 Pass -Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 5/29/2018 10: 16 24A Page 2 COMPASS 5000.14 Build 85 HE 3 m CL T u (ui/ljsu Orb) (+)qljoN/(-)4inoS (ui/3jsu S8) gldaQ leoupan onil a� CS M Om J O) N p a N O v n o r U) m o F - c CI -s a c O C C O N 2M V QF --Y W ttn W noo-�2 �j rrmm MON mo c0 �MOLOmcON mmCO�Occ'>O �-� ul t n n m n rn M r c! ] r t6 Ln C aZ to to to co ao M to r o m r (O CV N OOOOOO OO O 0 c> U O N 0 0 0 0 O J 0 0 0 0 0 0 0 0 0 m O 11 A`Lr) O OO t D O mmrnrrnLornrmtom N N N N M O O O O O O O O O O O O O O O N O N 0 0 0 0 0 0 0 0 0 0 0 0 0 poo oo Lo r-- rr-- a, 0) Q) m M r N M m m M m M r n M M m— C 0� c O m O m 01V m�tA Inco V atm MnMN 03W C N+ N M t O n t n Mt n m m c O Cl) It M R V V KJ m M V10 10 N m N CD M M M M M M M M M M M M M Cl) M J wCD 0 (n n m m M m .0 m r v Q p ! M Oto m co Cl! l{'J cO 1p O) LQ Ln It % Ztrir��ao�ai�M�tri��triv W Q + c 0 c 0 n Ma� M R c O� N N N t o T t b� M t o r O m J W (j)vnmrnncn oco tnmtnrIC! rnN crlt00C14 C DM 04 (V M n n c M C M �O > m 0) c O O Q) O; O l m M c O m m m �01In cm[f tA t00M taOc aj t00 ZLOO^m c O m m N N N n 0) c O m O c O t f ^a.-ornO�tnrrnlp0 oC tn1n On Ln n m N N n LO V of O t n M r O r O O O�4 CV LO N M M M M M U r m v o m m r CO c 0) O) M O m 0 0 0 m M C' m <- <o m p Oj m m m m Cl) M M O D 7 O O) O) m.0 O W p + 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O N O 0 0 0 0 0 0 0 0 0 0 0 0 0 m O O O O O O OR O O O Ocn On N�r NMn t' -n.0 m m rn rn 01 o 0 0 NO O U— N M r t 0 CO n m m O � � 2 � Z p l •- e (ui/3jsu S8) gldaQ leoupan onil KUP PROD 1 F-07 COnocoPhllilps I Well Attributes Max Angle & MD TD Alaska,1F1C. Wellbore API/lAM Field Name Wellbore Sta us nd (°) MD (KKB) Act etm (ftKB) 500292083000 KUPARUK RIVER UNrr PROD 44.83 5,700.00 8,060.0 Comment H2S (ppm) Date SSSV: TRDP 40 9/10/2016 Annotation End Date Last Wb: 9/10/1984 KB-Grd (ft) Rig Release Date 40,591"o"10/21/198 1F-07.12/4/20172.04:27 PM emw sc manc actua 1 Annotation Depth (ftKB) End Date Annotation Last Mod By End Data HANGEFF. 22.3 Last Tag: SLM 7,396.0 8/10/2017 Rev Reason: TAG 8 GLV C/O (#6 & #7) PPM12/4/2017 casing Strings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread CONDUCTOR 16 15.250 35.0 80,0 80.0 65.00 H-40 WELDED Casing Description OD (in) ID (in) Top (Itl(B)Sat Depth (ftKB) Set Depth (TVD)... WtlLen (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) 10 (rn) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (t... Grade Top Thread PRODUCTION 7 6.276 32.1 8,045.0 6,704.5 26.00 K-55 BTC Tubing Strings CONDUCTOR: 35.080.0 Tubing Description String Ma... ID (I Top (ftKB) Set Depfh (ft.. Set Depth (TVD) (... Wt (Ib/h) Grade Top Connection TUBING 3 1/2 2.992 22.3 7,338.4 6,112.2 9.30 J-55 BTC IPC SAFETY VLV: 1,855.1 Completion Details Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Ind r) Item Des Co. (in) 22.3 22.3 0.10 HANGER FMC GEN II HANGER 3.500 GAS UFT: 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 SSR 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 UFT, 3,145.2 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. 4,326.6 7,331.9 6,106.8 33.96 NIPPLE OTIS 2.61"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 (TVD) Top Incl Top (ftKB) (ftKB) (") Des Co. 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 SBR; 7,005.4 ASS'Y (OAL: 25.08', MIN ID: 1,625") @ 7182' SLM. NOTE: PACKER HAD AN ALUMINUM PINNED FOR 3600 PSI DIFFERENTIAL. PACKER', 7,030 9 - PRODUCTION, 7,0676 7,585.0 6,318.2 32.88 FISH I Vann Gun Downhole 9/10/1984 Perforations & Slots PRODUCTION', 7.136.0 Shot Dens Top (TVD) Sit. (TVD) (shotslf Top (ftKB) Bt. (ftKB) (ftKB) (ftKB) Zone Date t) Type Com 71184.0 71244.0 51984.1 6,033.9 C-4, 1F-07 9/1/1984 12.0 RPERF 5" DA; 90 deg ph 7,184.0 7244.0 5,984.1 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 6,043.0 6.047.2 UNIT B, 1F-07 9/1/1984 12.0 RPERF 5" DA; 90 deg ph IPERF: 1.164.0-7,244.0 FRAC c -SAND; 7,164.0 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 REFIRE:50-72 60 0 IPERF;72550-70 .260 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 RPERF, 7,268.0-12820 _ IPERF, T26S.0-7,2820E 7,268.0 7,282.0 6,053.8 6,065.4 UNITS, IF -07 10/21/1982 12.0 IPERF 5" Vann Guns 7,393.0 7,405.0 6,157.5 6,167.4 A-4, 1F-07 10/10/2006 6.0 RPERF 2.5" HSD HJ FOX, 60 PRODUCTION, 7.293.4 deg. ph 7,393.0 7,405.0 6,157.5 6,167.4 A-4. 1F-07 10/21/1982 12.0 IPERF 5" Vann guns LOCATOR: 7,310.8 7,420.0 7446,0 6,179.9 6,201.6 A -4,1F-07 10/21/1982 12.0 IPERF 5" Vann guns PACKER, 7,312.0 7,453.0 7,458.0 6,2075 6,211.6 A -4,1F-07 10/21/1982 12.0 IPERF 5" Vann guns MILL, 7,315 9 Stimulations & Treatments Proppant Designed (lb) Proppant In Formation (lb) Data I 9!23/2000 NIPPLE: 7,331 9 Stimulations & Treatments Vol Clean Pump Stg # Top (ftKB) Btm (ftKB) Date StiMTreat Fluid (bbl) Vol Slurry (bbl) SOS: 7,3378 1 7,184.0 7,244.0 9/23/2000 Proppant Designed (Ib) Proppant In Formation (lb) Date I 10/27/2006 Stimulations & Treatments Vol Clean Pump Stg # Top (ftKB) etm (ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry (bbl) IPERF', 7,3930-74050 R PER F:7 393 0-7.405.0 11 7.393.01 7,458.0 11012712006 Mandrel Inserts FRAC A -SAND; 7,393.0 St IPERF: 7 4]00-i 446.0 ati IPERF', 7 453.0-7,458.0 NTop (TVD) Top (ftKB) (ftKe) Make Model 00 (in) Sen; Valve Type Latch Port Size Type (in) TRO Run (psi) Run Date Com 1 1,933.3 1,907.1 OTIS OVAL D 1 GAS LIFT GLV BK 0.156 1,311.0 12/2/2013 2 3,145.2 2,895.3 OTIS OVAL D 1 GAS LIFT GLV BK 0.156 1,298.0 12/2/2013 FISH: 7,585.0- 3 4,326.6 3,785.9 OTIS OVAL D 1 GAS LIFT GLV BK 0.188 1,323.0 12/2/2013 4 5,466.0 4,683.6 OTIS OVAL D 1 GAS LIFT GLV BK 0.188 1,310.0 12/2/2013 PRODUCTION', 321-8.045.0 16" 65# H-40 shoe @ 80' MD 10-3/4" 45# K-55 shoe) (d. 2259' MD KOP@7190'MD KOP @ 7210' MD C -sand perfs 7184'- 7244' MD B -sand 7255'- 7282' MD Perf Pup Poor Boy Overshot A -sand perfs 7393' - 7458' MD 7" 26# K-55 shoe @ 8045' MD IF -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-%" X landing nipple at fonoc' MD (2.813" min ID) Baker 3-1/2" PBR moot' MD (3" ID) Baker FHL Packer @ f000c' 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 7497' Mn f ISO, ME) Me, MD 1F-071-1-01 wp02 TD @ 9,800' MD Top of Liner @ 7205' MD O O -- - - -------------------------- 1F-071-1 wp06 TD @ 10,500' MD Top of Liner @ 7600' MD 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: image001.pno 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-071_1-01 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@conocophiIli ps.com> Subject: [EXTERNAL]RE KRU 1F-071_1 (PTD 218-073) - Question Keith, Will perforations in the original wellbore KRU 1F-07 be isolated before KRU 117-071_1 and KRU 1F - 07L1 -01 are drilled and completed? Or will those perforations remain open to the Kuparuk River Oil Pool after KRU 1F-071_1 and KRU 1F-071_1-01 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.eov. From: Herring, Keith E [mailto:Keith.E.Herring(@conocophillips.com] Sent: Tuesday, June 26, 2018 8:11 AM To: Davies, Stephen F (DOA) <steve.davies(@alaska.gov> Subject: RE: [EXTERNAL]KRU 1F-071_1 (PTD 218-073) - Request Good morning Steve, Please see the attached. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 Keith.E.Herringga conocophillips.com ConoC© hifflip5 Alaska From: Davies, Stephen F (DOA) <steve.davies(@alaska.gov> Sent: Tuesday, June 26, 2018 7:41 AM To: Herring, Keith E <Keith. E.HerringCcDconocophillips.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-071_1 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.eov. From: Davies, Stephen F (DOA) Sent: Monday, May 7, 2018 4:25 PM To: 'Herring, Keith E' <Keith. E.HerringPconocophiIIips.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. TRANSMITTAL LETTER CHECKLIST WELL NAME: kX�c 1 - 0 %Z PTD: 2/9_ 0 7,3 / Development Service _ Exploratory Stratigraphic Test _ Non -Conventional FIELD: POOL: [mac% /� / 4/e_ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. S API No. 50-=- - j�- DD (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. (Co many 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-07L1Program DEV Well bore seg El PTD#:2180730 Company CONOCOPHILLIPS ALASKA INC. Initial Class/Type DEV/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 _N_onconven. gas conforms to AS31.05.030Q.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 interwell_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. Asproposed,well will 7 Sufficient acreage_ available in -drilling unit Yes conform 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 15 -day wait.. - - Yes - - - - - - - - - - - - - - - - - 14 Well located within area and_strata authorized by Injection Order # (put_ 10# in- comments) (For NA. 15 All wells _within _1/4_mile area of review identified (For service well only)_ NA. 16 Pre -produced injector: dur_ation_of pre production Less_ than_ 3 months_ (For -service well only) NA. . 18 _Conductor string -provided - - - - - - - - - - -NA_ CTD sidetrack-_c_omingl_ed pr_oduction-with-parent-well Engineering 19 Surface casing protects all -known- USDWs Su9 NA_ --- 20 CMT_v_ol adequate to circ_ul_ate_on conductor_& surf_csg - - - - - NA_ Slotted liners - - - - - - - - - - - - - - - - - - - - 21 CMT_v_ol_ adequate to tie-in longstring to -surf csg_ - - - - - - - - - - - NA_ Slotted liners only - - - - - - - - - - - - - - - - - - - - - - - - 22 _C_MT_will coverall knownn-productive horizons_ NA_ Slotted liners only - window -exiting in the -reservoir - - 23 _Casing designs adequate for CJ, B &_ permafrost_ - - - - - - - - NA. - 24 Adequate tankage_or reserve pit Yes 25 .If_a_ re -drill, has_ a 1.0-403 for abandonment been approved - - - - - - - - - - NA_ - - - - - - Comingle production_with parent well - - - - - - - - - 26 Adequate wellbore separation -proposed - Yes - - - - - 27 If_diverter required, does it meet regulations - - NA_ - - - - - CTD Sidetrack from existing producing wellbore_ - - - - - . Appr Date 28 Drilling fluid program schematic-&- equip -list_adequat_e_ - - - - - - - - Yes - - - - - Managed pressure drillin /KWF available _for- liner- running MGR 6/28/2018 29 _B_OPEs,-do they meet regulation - - - - - - - - - - - - - - - - - - - - Yes _ - - .. . 30 _B_OPE_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 1-12S gas probable- - - - - - - Yes Standard Kuparuk H2S detectors required - - - - - - 34 Mechanical -condition of wells within AOR verified (For service well only) NA Well is a -plan ned-producer - - - - - - 35 Permit_ can be issued w/o hydrogen_ sulfide measures - - - - - - - No- .. Wells_o_n_1F-Pad are -1 -12S -bearing, H2S- measures required._ - - - - - Geology 36 _Data -presented onP otential overpressure zones - Yes - Expected reservoir -pressure is 8.3-8.4 ppg_EMW;_will be- drilled using 8 6ppg 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 1.8 ppd EMW while drilling to stabilize shale. NOTE:_ Free gas -may -be encountered while_ - - - - - - - - 39 Contact name/phone for weekly -progress reports- [exploratory only] - - - - - - - - - - - - - N_A_ - - - - - - - drilling this- lateral. - - - - - - - - - - - - - - - Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date r,ts 7131
