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217-126
DATA SUBMITTAL COMPLIANCE REPORT 1126/2018 Permit to Drill 2171260 Well Name/No. KUPARUK RIV UNIT 2K.04L1 MD 13852 TVD 6228 REQUIRED INFORMATION Mud Log No v Completion Date 10/26/2017 DATA INFORMATION List of Logs Obtained: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED C 28771 Digital Data ED C 28771 Digital Data Log C 28771 Log Header Scans Operator CONOCOPHILLIPS ALASKA, INC. API No. 50.103-20099-60-00 Completion Status -1-OIL Current Status 1 -OIL UIC No Samples No✓ Log Log Run Interval Scale Media No Start Stop 0 0 ED C 28776 Digital Data 10209 13852 ED C 28776 Digital Data ED C 28776 Digital Data ED C 28776 Digital Data ED C 28776 Digital Data ED C 28776 Digital Data ED C 28776 Digital Data ED C 28776 Digital Data ED C 28776 Digital Data ED C 28776 Digital Data ED C 28776 Digital Data ED C 28776 Digital Data ED C 28776 Digital Data ED C 28776 Digital Data Directional Survey Yes (from Master Well Data/Logs) OHI CH Received Comments 11/7/2017 Electronic File: 2K -04L1 EOW - NAD27.pdf, 11/7/2017 Electronic File: 2K -04L1 EOW - NAD27.txt 2171260 KUPARUK RIV UNIT 2K -04L1 LOG HEADERS 11/9/2017 Electronic Data Set, Filename: 2K-041-1 GAMMA RES.Ias 11/9/2017 Electronic File: 2K -04L1 21VID Final Log.cgm 11/9/2017 Electronic File: 2K-041_1 51VID Final Log.cgm 11/9/2017 Electronic File: 2K-041_1 5TVDSS Final Log.cgm 11/9/2017 Electronic File: 2K-041_1 2MD Final.pdf -• P 11/9/2017 Electronic File: 2K-041_1 5MD Final.pdf 11/9/2017 Electronic File: 2K -04L1 5TVDSS Final.pdf 11/9/2017 Electronic File: 2K -04L1 EOW - NAD27.pdf. - 11/9/2017 Electronic File: 2K-041_1 EOW - NAD27.txt. 11/9/2017 Electronic File: 2K-041_1 Final Surveys TD • 13852.csv 11/9/2017 Electronic File: 2K-041_1 Final Surveys TD, 13852.xlsx 11/g/2017 Electronic File: 2K -04L1 Survey Listing.txt . 11/9/2017 Electronic File: 2K-041_1 Surveys.txt 11/9/2017 Electronic File: 2K- 04L1_25_tapescan_BHI_CTK.txt , AOGCC Pagel orl, Friday, January 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/26/2018 Permit to Drill 2171260 Well Name/No. KUPARUK RIV UNIT 2K-041-1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20099-60-00 MD 13852 TVD 6228 Completion Date 10/26/2017 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 28776 Digital Data 11/9/2017 Electronic File: 2K- 04L1_5_tapescan_BHI_CTK.t# - ED C 28776 Digital Data 11/9/2017 Electronic File: 2K-04L1output.tap- ED C 28776 Digital Data 11/9/2017 Electronic File: 2K -04L1 2MD Final Log.tir ED C 28776 Digital Data 11/9/2017 Electronic File: 2K -04L1 5MD Final Log.tif . ED C 28776 Digital Data 11/9/2017 Electronic File: 2K-041_1 5TVDSS Final.tif Log C 28776 Log Header Scans 0 0 2171260 KUPARUK RIV UNIT 2K-041.1 LOG HEADERS Well Cores/Samples Information: - Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report UY Production Test Information' NA Geologic Markers/Tops a COMPLIANCE HISTORY Completion Dale: 10/26/2017 Release Date: 9/26/2017 Description Comments: Directional / Inclination Data Mechanical Integrity Test Information Y / NA Daily Operations Summary O Date Comments Compliance Reviewed By: iAI (I('(Page 2oflz� Mud Logs, Image Files, Digital Data Yu Composite Logs, Image, Data Files V Cuttings Samples Y/� Core Chips y' Core Photographs Y / Laboratory Analyses Y/ A Date Friday, January 26, 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil ❑� ' Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG[-] WDSPL ❑ No. of Completions: 1 b. Well Class: Development 2 Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. - 6. Date Comp., Susp., or Aband.: 10/26/2017 14. Permit to Drill Number/ Sundry: 217-126 3. Address: P.O. Box 100360 Anchorage, AK 99610-0360 7. Date Spudded: 10/10/2017 15. API Number: 50-103-20099-60-00 4a. Location of Well (Governmental Section): Surface: 5058' FNL, 94' FEL, Sec 2, T1 ON, R8E, UM Top of Productive Interval: 1481' FNL, 1782' FEL, Sec 3, T1 ON, R8E, UM Total Depth: 3862' FNL, 644' FEL, Sec 3, T1 ON, R8E, UM 8. Date TO Reached: 10/14/2017 16. Well Name and Number: KRU 2K -04L1 9. Ref Elevations: KB:154.0 GL: 118.5 , BF: 17. Field / Pool(s): Kuparuk River Field/Kuprauk River Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25589, ADL 25588 ' 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498310 y- 5938525 Zone- 4 TPI: x- 491342 y- 5942107 Zone- 4 Total Depth: x- 492480 y- 5939725 Zone- 4 11. Total Depth MD/TVD: 13852/6228' 19. DNR Approval Number: LONS 85-096 12. SSSV Depth MD/fVD: N/A 20. Thickness of Permafrost MD/TVD: 1550/1496 5. Directional or Inclination Survey: Yes E (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 1 21. Re-drill/Lateral Top Window MD/TVD: 10479/6128 r 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 RECEIVED GR/Res NOV Z 1 2017 AGGGG 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE AMOUNT CEMENTING RECORD PULLED 16 62.5 H-40 36 115 36 115 - 179 sx AS I 95/8 36 J-55 35 4026 35 2913 121/4 1069 SX AS 111, 297 sx Class G 7 26 L-80 33 2345 33 2057 81/2 834 sx AS 1 7 26 J-55 2342 10836 2055 6269 81/2 73 sx Class G 23/8 4.6 L-80 10530 13384 6145 6230 3 Slotted Liner 24. Open to production or injection? Yes ❑� No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER @ COMPLE-PON 10642-12140 MD and 6147-6141 TVD r)A TF_ 12341-13384 MD and 6149-6230 1 o /Z� �-4, VERIFIED" L-1, 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 10,515 10229/6019 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 10/2612017 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 11/7/2017 Hours Tested: 20 Inns Production for Test Period Oil -Bbl: 412 Gas -MCF: 282 Water -Bbl: 1578 Choke Size: 176 Gas -Oil Ratio: 848 Flow Tubing Press. 287 Casino Press: 1 Calculated 24 -Hour Rate Oil -Bbl: 4 Gas -MCF: 372 Water -Bbl: 18 Oil Gravity-API(corr): 22.1 Form 10-407 Revised 5/2017 �L /y1Z y' J j7Z- CONTINUEQ ON PAGE 2 S ,•/ , 2 2017 Submit ORIGINIAL o � 8 �a 11111's RBB«�� G�1 28. CORE DATA Conventional Corals): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑+ If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1550 1496 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 10479 6128 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk A TD 13852 6228 Formation at total depth: Ku aruk A 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematics Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontolooical report. production or well test results, per 20 AAC 25,070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: William Lon Authorized Title: Staff CTD Engineer Contact Email: William.R.Lon co .com Authorized Contact Phone: 263 4372 Signature: Date: 111,211-17 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 1b: 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 2K-04 As -Drilled CM Schematic D 115' MD I ]" 288 L-80 Tieback 230.5' MD 9.519" 388 JS5 shoe 4026' MD C4santl parts 10.402'-10,424'MD op of Wetlge � 10,4]9' MD BBnd perfE 10.402'- 1,01 MD 112" B.38 L-80 EUE BN Tubing to surface 3-12" Camw MMG gas lift mandrels @ 31]5', 5502', 7198', 8514', 9185',10145' MD Baker FHL PeckerW PBR a 10229' MD Cameo D nipple at 10314' MD (2.813' min ID) Northam Solution Wedge Assembly 10454' MD 1112" X -tipple at 10489 MD (2.813' min ID) Nodbem Solution Wedge AswmbN 10495' MD 112' X-nii at 10509' MD (2.813" min ID) 2�IV Stored Liner 1033ir-12.851 Yl) 2W I.l TD. 13,85T MD 23IB"SMMOLine 1D53Y-13,a MD (Bead Fife 12.14 V -12,341' MD) Cnaeu mime 10.00 Mo Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Oepth Start Tme End Toe Our (nr) Phase Op Code AcWty Code Time P -T -X Operation (We) End Deph (NCB) 10/7/2017 10/7/2017 5.00 MIRU MOVE MOB P Trucks on location (2A -pad), 0.0 0.0 18:00 23:00 move/spot shop & halfway house over to 2K -pad, pull subs off of well, install jeeps 1017/2017 10/8/2017 1.00 MIRU MOVE MOB P Move rig down road 0.0 0.0 23:00 00:00 10/8/2017 10/8/2017 1.00 MIRU MOVE MOB P Continue Moving Rig to next 0.0 0.0 00:00 01:00 1 destination 2K -pad 10/8/2017 10/8/2017 4.00 MIRU MOVE MOB P Remove jeeps, spot subs over well 0.0 0.0 01:00 05:00 10/8/2017 10/8/2017 1.00 MIRU WHDBOP NUND P RU surface equipment (nipple up), 0.0 0.0 05:00 06:00 install tiger tank line, install fuseable cap, " Rig accept 06:00 10/8/2017 10/8/2017 3.00 MIRU WHDBOP RURD P C/O stack riser, collect RKB's, remove 0.0 0.0 06:00 09:00 & replace R1 (leaking on previous well). Unchain Injector cart and storage reel. 10/8/2017 10/8/2017 3.00 MIRU WHDBOP RURD P Unsecure cumi, grease stack, Grease 0.0 0.0 09:00 12:00 Romeo valves, flood up, test on R1 to 4000 psi. - good, PJSM - for testing BOP's 10/8/2017 10/8/2017 1.00 MIRU WHDBOP BOPE P Test t 0.0 0.0 12:00 13:00 Start shell test 12:15, bleeding down, three atempts, Suspect R1, open R3, B5, B6 B7, B8, C6, C7, against closed C8, observe leek at the stack. Cylcle R1, no fluid at the stack, atempt high to 4500 psi, leaking off, bleed down cycle swab 1 reatempt high test, looks good, bleed down. Start test. Had to run out but got a pass. - moving on 10/8/2017 10/8/2017 - 4.30 MIRU WHDBOP BOPE P Continue on testing BOPE. tests 2- 12 0.0 0.0 13:00 17:18 10/8/2017 10/8/2017 2.70 MIRU WHDBOP ROPE P Crew change, PJSM, continue on 0.0 0.0 17:18 20:00 testing ROPE. test 13 - 18, draw down, down w/ BOP testing - BOP Test time 8.0 hrs 10/8/2017 10/812017 0.50 MIRU WHDBOP SFTY T Low level H2S observed on Sentry 0.0 20:00 20:30 gas monitoring system of 10 ppm and slowly climbing to 13 ppm, send non- essential and valve crew to muster area, contacted ERT, contacted the Pad Operator. Operator used sniffer wand to confirm cellar was clear of H2S, upon investigation found a steam leak that was spraying onto H2S sensor in cellar. Called AAR in doghouse, discussed station bill and the great command and conrtol of rig personnel during false alar. 10/8/2017 10/8/2017 1.00 MIRU WHDBOP CTOP P PJSM, test inner reel iron, pac-off, 0.0 0.0 20:30 21:30 driller side PDL, and tiger tank line. 10/8/2017 10/912017 2.50 MIRU WHDBOP MPSP P PJSM, rig up ASRC lubricator, PT 0.0 0.0 21:30 00:00 - 2,500 psi, pull 3" ISA BPV, 1,500 psi WHP, rig down lubricator. blow down surface lines. 10/9/2017 10/9/2017 0.50 PRODt WHPST PULD P Prep for Pressure Deploy, valve 0.0 0.0 00:00 00:30 checklist, PJSM pressure deploy Page 1IM8 ReportPrinted: 111112017 Operations Summary (with Timelog liepths) 2K-04 Conoc• Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End ime Dtv (hr) Phase Op Cade Activity Cade Time P-T-X Operafion start Depth ME) End Depth (W9) 10/9/2017 10/9/2017 1.00 PRODt WHPST PULD P PU/MU milling BHA# 1 in PDL 0.0 0.0 00:30 01:30 10/9/2017 10/9/2017 1.50 PROD1 WHPST PULD P Pressure deploy window milling BHA# 0.0 74.3 01:30 03:00 1, MU UQ to CoilTrak tools, surface test (good test), inspect pac-off 10/9/2017 10/9/2017 2.00 PROM WHPST TRIP P RIH, w/window milling BHA# 1, 2.80 74.3 9,950.0 03:00 05:00 OD whipstock mill, string reamer, x- treme motor, 9' pup joint 10/9/2017 10/9/2017 1.70 PRODt WHPST DLOG P Log the HRZ down to the pinch point. 9,950.0 10,480.0 05:00 06:42 tag @ 10,480 corrected. Bring sea water returns from the TT back inside to the pits 10/9/2017 10/9/2017 1.30 PROD1 WHPST CIRC P Increase rate to drilling, 1.80 bpm, 9,950.0 10,480.0 06:42 08:00 attempt to bring BHP up to 12.0 ppg @ the window. Ecperiencing losses. Stop pinching the choke at 10.6 ppg at the window returns stailized at 0.6 bpm out - 50% consult with town, build 50 bbl Ultra hivis pill. 10/9/2017 10/9/2017 1.50 PROM WHPST CIRC P Start pumping UHV pill 150 k cp LSRV 10,330.0 10,394.0 06:00 09:30 down the coil @ 1.8 bpm (45 bbls total) WH 61 psi, IA 240, OA 3 psi, CT 3955 psi, down hole annular 3205 psi 10.2 ppg at the window, returns 1.63 bpm curently targeting 1 for 1 returns. Pump 46 bbls UHV, chase with seawater. Start reudcing the rate at 23 bbls out. Building WH / BHP. @ 43 bbls away built WH to 1366 psi, and 0.4 bpm, 12.96 ppg at the window 10/9/2017 10/9/2017 0.20 PROM WHPST CIRC P Open choke targeting 12.0 ppg at the 10,394.0 10,382.0 09:30 09:42 window stage pums rate up to 1.8 bpm in, 1.7 bpm out holding 12.0 ppg at the window. 10/9/2017 10/9/2017 0.70 PROD1 WHPST DISP P Start displacing well to 8.6 ppg Power 10,384.0 10,448.0 09:42 10:24 Pro SF. Returns fell off as UHV pill pushed away. 1.80 bpm in 1.54 bpm out. Annular 3808 psi. 10/912017 10/912017 0.20 PROM WHPST WPST P Park, close EDC, down on pumps 10,448.0 10,479.2 10:24 10:36 with trapped pressure, pressure at the window bleed to 11.4 ppg, dry tag 10479' PU wt 30 k Itis, set rate at 1.81 bpm, holding 12.0 ppg RBIH, CT 4699 psi, WH 433 psi, 1.80 bpm in , 1.46 bpm out, CT RIH Wt 10- 12klbs off bottom FS 436 psi, oriented 330 ° ROHS, 10/9/2017 10/9/2017 7.00 PROM WHPST WPST P Start slacking weight, 0.56 k lbs, and 10,479.2 10,484.5 10:36 17:36 seeing motor work, 510 psi diff @ 10479.2 Swap to auto drill @ 14:00 10/9/2017 10/9/2017 0.70 PROM WHPST WPST P Power failure due to High-line crew, 10,484.5 10,484.5 17:36 18:18 bring rig back online. PUW 31 k, bring - pump back online Page 2118 ReportPrinted: 111112017 Operations Summary (with Timelog Uepths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Scan Time End Tune our (hr) Phase Op Code Activity Cotle Time P -T-% Operation (MB) End Depth (WB) 10/9/2017 10/9/2017 2.15 PROD1 WHPST WPST P BOBM, 1.78 bpm at 4,500 psi FS, 10,484.5 10,486.0 18:18 20:27 BHP 3803, WHIP 103, IA 253, OA 4, CTSW=11 k, DHWOB=3.3 k "• Note: Popped out of casing at 10,486' with the mill and 10,487' with string reamer. 10/9/2017 10/9/2017 2.25 PROD1 WHPST WPST P Mill/drill formation at 5-36 fph, 1.78 10,486.0 10,504.0 20:27 22:42 bpm at 4,661 psi OB, BHP 3,796, WHP 102, IA 253, OA 4, CTSW=10.4 k, DHWOB=2.6 k, "' Note: 10,486'sample showing 5% sand, 10,502' sample showing 20% sand, NBI showing 1.24' jump at 10,503' 10/9/2017 10/9/2017 1.15 PROD1 WHPST WPST P Let weight drill off, PUW 30 k, ream 10,504.0 10,504.0 22:42 23:51 window area as milled, 30', 60% and 150°. dry drift was clean. 10,491'to 10,504- 10/9/2017 10/10/2017 0.15 PROD1 WHPST TRIP P PUH, 10,458' Open EDC, POOH 10,504.0 9,279.0 23:51 00:00 10/10/2017 10/10/2017 1.50 PROD1 WHPST TRIP P Continue POOH, PJSM @ 1,500' 9,279.0 79.3 00:00 01:30 while POOH 10/1012017 10/10/2017 1.50 PROD1 WHPST PULD P PUD and LD window milling BHA# 1, 79.3 0.0 01:30 03:00 Mills gauged 2.79 no-go 10/1012017 10/10/2017 1.25 PRODt DRILL PULD P PJSM, PD build section BHA# 2 0.0 72.0 03:00 04:15 10/10/2017 10/10/2017 2.00 PROD1 DRILL TRIP P Stab INJH, surface test CoilTrak tools 72.0 10,230.0 04:15 06:15 (good -test), tag up reset counters, RIH 10/10/2017 10/10/2017 0.25 PROD1 DRILL DLOG P Log the K1 marker correction of minus 10,230.0 10,306.3 06:15 06:30 4.0' 10/1012017 10/1012017 025 PROD1 DRILL TRIP P Continue IH 10,306.3 10,504.0 06:30 06:45 10/10/2017 10/10/2017 1.00 PROD1 DRILL DRLG P Drill build per plan. 10,504.0 10,593.0 06:45 07:45 10/10/2017 10110/2017 0.75 PROD1 DRILL DRLG P PUH to lie -in to Kt and log RA tags 10,593.0 10,593.0 07:45 08:30 +0.5' correction. See slight "bobble" pulling thru window. TOWS=10,479', BOWS=10486'. 10/10/2017 10/10/2017 3.25 PROD1 DRILL DRLG P Resume drilling build section. 10,593.0 10,826.0 08:30 11:45 WHP=96 PSI, ANN=3873 psi, IA=250, OA=1, PUMP=4900psi@1.8 bpm, WOB=2.5, ROP=95' 10/10/2017 10/10/2017 0.50 PROD1 DRILL WPRT P Pump 5/5 sweep, pull 100'short wiper 10,826.0 10,826.0 11:45 12:15 to 10726'. RBIH. 10/10/2017 10/1012017 1.25 PROD1 DRILL DRLG P Drill build to 10,885'. WHP=122 PSI, 10,826.0 10,885.0 12:15 13:30 IA=253, 0A=1, PUMP=4849 PSIQ1.8 BPM, ANN=3884 PSI, WOB=1.47, ROP=114'. 10/10/2017 10/10/2017 2.25 PROD1 DRILL TRIP P Pull out of hole for lateral drilling 10,885.0 64.8 13:30 15:45 BHA#3. Above window,open EDC. 10/10/2017 10/10/2017 1.35 PROD1 DRILL PULD P At surface. PUD build BHA#2 64.8 0.0 15:45 17:06 10/10/2017 10/1012017 1.74 PROD1 DRILL PULD P Crew change, PJSM, PU/MU/PD AL1 0.0 78.3 17:06 18:50 lateral BHA# 3 10/1012017 10/10/2017 0.25 PROD1 DRILL PULD P Stab INJH onto CoilTrak tools, surface 78.3 78.3 18:50 19:05 test (good -test), tag up/reset counters. Page 3118 ReportPrinted: I1/T1_2017 Operations Summary (with Timelog uepths) A 9 M;. 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth StartTime EM nine Our (hr) Phase Op code Ac" Code Time P-T.X Operation M(s) EM Depth (ftKa) 10/10/2017 10/10/2017 2.00 PROD1 DRILL TRIP P RIH, @ 501'test agitator (good-test), 78.3 10,237.0 19:05 21:05 continue IH 10/10/2017 10/10/2017 0.25 PROD1 DRILL DLOG P Log the K1 marker correction of minus 10,237.0 10,344.0 21:05 21:20 7.0' 10/10/2017 10/10/2017 0.42 PROD1 DRILL TRIP P Continue RIH 10,344.0 10,885.0 21:20 21:45 10/10/2017 10/11/2017 2.25 PROD1 DRILL DRLG P OBD, 1.75 bpm at 5,083 psi FS, Diff 10,885.0 11,125.0 21:45 00:00 864 psi, BHP 3,886, WHP 145, IA 254, OA 2, CTSW=2 k, DHWOB=1.9 k, ROP 135-215 fph 10/11/2017 10/11/2017 1.25 PROD1 DRILL DRLG P OBD, 1.80 bpm at 5,274 psi, Diff 11,125.0 11,300.0 00:00 01:15 1,010 psi, BHP 3,928, WHIP 146, IA 255, OA 2, CTSW=6 k, DHWOB=0.5 k, ROP 130 fph 10/11/2017 10/1112017 0.25 PRODi DRILL WPRT P Wiper up hole PUW 36 k 11,300.0 10,900.0 01:15 01:30 10/11/2017 10/11/2017 0.25 PROD1 DRILL WPRT P Wiper back in hole RIW 7 k 10,900.0 11,300.0 01:30 01:45 10/11/2017 10/11/2017 5.75 PRODt DRILL DRLG P BOBD, 1.79 bpm at 5,222 psi FS, Diff 11,300.0 11,690.0 01:45 07:30 1,010 psi, BHP 3,899, WHP 153, IA 255, OA 2, CTSW minus 2.0 k, DHWOB=2 k, ROP 138 fph 10/11/2017 10/11/2017 0.30 PRODt DRILL WPRT P Wiper up hole. PUW=34k. 11,690.0 10,890.0 07:30 07:48 10/11/2017 10/11/2017 0.30 PRODt DRILL WPRT P Wiper back in hole. RIW=9k 10,890.0 11,690.0 07:48 08:06 10/11/2017 10/11/2017 6.00 PROD1 DRILL DRLG P BOBD. 1.80 bpm at 5675 psi, 11,690.0 12,090.0 08:06 14:06 Diff--1358 psi, BHP=3957, WHP=166, IA=257, OA=2, CTSW=2.2, DHWOB=1.5k, ROP=80 fph 10/11/2017 10/11/2017 0.60 PROD1 DRILL WPRT P Tie-in wiper up hole. PUW=34k 12,090.0 10,497.0 14:06 14:42 10/11/2017 10/11/2017 0.60 PROM DRILL WPRT P Tie-in wiper back in hole. RIW=9.5k 10,497.0 12,090.0 14:42 15:18 +6' correction 10/11/2017 10/11/2017 4.00 PRODt DRILL DRLG P BOBD. 1.80 bpm at 5813 psi, Diff 12,090.0 12,302.0 15:18 19:18 1372 psi, BHP 3979, WHP 130, IA 257, OA 2, CTSW=-0.6, DHWOB=1.62k, ROP=65 fph 10/11/2017 10/11/2017 0.20 PROD1 DRILL WPRT P Unable to obtain clean survey, PUH 12,302.0 12,302.0 19:18 19:30 PUW 34 k 10/11/2017 10/12/2017 4.50 PROD1 DRILL DRLG P BOBD, 1.77 bpm at 5,000 psi FS, 12,302.0 12,485.0 19:30 00:00 BHP 3,974, WHP 273, IA 259, OA 2, CTSW=minus 5 k, DHWOB=1.1 k, ROP 40 fph 10/12/2017 10/12/2017 0.25 PROD1 DRILL DRLG P OBD, 1.78 bpm at 5,341 psi, Diff BHP 12,485.0 12,490.0 00:00 00:15 4,008, WHP 271, CTSW=minus 5 k, DHWOB=1.0 k, ROP=26 fph 10/12/2017 10/12/2017 0.50 PROM DRILL WPRT P Wiper up hole PUW 38 k 12,490.0 11,690.0 00:15 00:45 10/12/2017 10/12/2017 0.25 PROD1 DRILL WPRT P Wiper back in hole,.RIW 3 k 11,690.0 12,490.0 00:45 01:00 10/12/2017 10/12/2017 3.30 PROM DRILL DRLG P BOBD, 1.8 bpm at 5,250 psi, Diff 12,490.0 12,641.0 01:00 04:18 1,069 psi, BHP 4,040, WHP 244, IA 258, OA 2, CTSW=3.85 k, DHWOB=1.1 k, ROP 65 fph 10/12/2017 10/12/2017 0.50 PROD1 DRILL DRLG P OBD, 1.77 bpm at 5,277 psi, BHP 12,641.0 12,655.0 04:18 04:48 4,062, WHP 255, IA 258, OA 2, CTSW= minus 2.6 k, DHWOB=1.0 k, ROP 50 fph Page 4118 Report Printed: 11/1/2017 Operations Summary (with Timelog uepths) AN ft � � 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time EM Time dr(hr) Phase Op Code ANuly Tim m P -T -X Ope'ahm De ale(rt rt B) - End Depth (NCa) 10/12/2017 10/12/2017 7.20 PROD1 DRILL DRLG P Drilling break, increase AP to form 12,655.0 12,748.0 04:48 12:00 4,062 psi to 4,145 psi to keep one for one. PUW 32 k, RBIH, continue drilling ahead, 1.77 bpm at 5,402 FS, BHP 4,140, WHIP 338, IA 258, OA 2, CTSW= 5.0 k, DHWOB=1.0 k, ROP 30-90 fph -10/12/2017 10/12/2017 3.00 PRODI DRILL DRLG P Hard drilling continuing @12748', 12,748.0 12,764.0 12:00 15:00 have lubed system w/ I% LoTorq. ROP=2.5'/hr. Pumping 1.76 Bpm @5341 psi, CTSW=-5.21 K, WOB=3.13k, BHP=4132, DIF=1054, WHP=329, IA=261, OA=4. Pumping 5/5 sweeps as needed. Last PUW=34K. 10/12/2017 10/12/2017 2.00 PROM DRILL DRLG P Hard drilling continuing. ROP=6- 12,764.0 12,771.0 15:00 17:00 157hr. Pumping 1.77 Bpm @5427 psi, CTSW=-3.21K, WOB=2.94k, BHP=4142, DIF=1060, WHP=313, IA=264, OA=8. Pumping 5/5 sweeps as needed. 10/12/2017 10/12/2017 3.50 PROM DRILL DRLG P OBD, 1.80 bpm at 5,279 psi FS, BHP 12,771.0 12,798.0 17:00 20:30 4,143, WHIP 383, IA 259, OA 7, Discussed with town plan forward, slow ROP, crossing fault with no ROP change, w/excessive weight on bit, 10/12/2017 10/12/2017 2.25 PROD1 DRILL TRIP P Pump 1 0x1 0 sweep, POOH, pumping 12,798.0 78.3 20:30 22:45 1.86 bpm at 4,672 psi, chasing sweep to surface, PJSM while POOH at 1,500'. perform jog back in hole 300' (from 1000'- 1,300'), tag up space out. "' Note: Static Pressure Survey at the window 12.689 ppg/4,025 psi AP 10/12/2017 10/13/2017 1.25 PRODt DRILL PULD P PUD, drilling BHA# 3 78.3 0.0 22:45 00:00 Note: Bit Grade 6-4... 10/132017 10/13/2017 1.75 PROD1 DRILL PULD P PJSM, PD drilling BHA# 4, stab INJH, 0.0 78.3 00:00 01:45 surface test BHI CoilTrak tools (good - test), 10/13/2017 10/132017 1.75 PROD1 DRILL TRIP P RIH, testing agitator at 300' (good- 78.3 10,250.0 01:45 03:30 test) 10/13/2017 10/132017 0.25 PROD1 DRILL DLOG P Log the K1 marker correction of plus 10,250.0 10,295.0 03:30 03:45 2.0' 10/132017 10/13/2017 0.25 PROD1 DRILL TRIP P Continue RIH 10,295.0 10,500.0 03:45 04:00 10/13/2017 10/13/2017 0.25 PROD1 DRILL DLOG P Log the RA marker correction of minus 10,500.0 10,531.0 04:00 04:15 11.0' 10/132017 10/13/2017 1.25 PRODt DRILL TRIP P Continue IHTB 10,531.0 12,798.0 04:15 05:30 10/13/2017 10/13/2017 2.75 PROD1 DRILL DRLG P BOBD, 1.78 bpm at 5,878 psi, Diff 12,798.0 12,920.0 05:30 08:15 1386 psi, BHP 4392, WHP 653, IA 261, OA 4, CTSW=-5.38 k, DHWOB=1.4 k, ROP 35 fph. Gas at shaker, take returns outside to tiger tank for 20 bbls until it cleaned up, bring back inside. 10/13/2017 10/13/2017 0.25 PROW DRILL WPRT P Wgt check to 12847'. PUW=34k 12,920.0 12,920.0 08:15 08:30 1 I Page 5118 ReportPrinted: 1111/2017 Operations Summary (with Timelog Uepths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start OepN Start Time End Time Ow (W) Phase Op Cade Activity CDde Time P -T -x Operation Me) End Mph (WB) 10/13/2017 1011312017 4.90 PROD1 DRILL DRLG P BOBD. 1.79 bpm @ 5823 psi, 12,920.0 13,200.0 0830 13:24 BHP=4268, DI "-429, WHTP=367, IA=261, OA=3, CTSW=-1.8, WOB=1.04, ROP=97'. Note: MWD having difficulties getting accurate surveys (inclination still accurate); send info to Sperry to process. 10/13/2017 10/13/2017 0.30 PROD1 DRILL WPRT P Wiper up hole. PUW=35k. 13,200.0 12,350.0 13:24 13:42 10/13/2017 10/13/2017 0.40 PROD1 DRILL WPRT P Wiper back in hole.RIW=4K 12,350.0 13,200.0 13:42 14:06 10/13/2017 10/1312017 4.00 PROD1 DRILL DRLG P BOBD.1.77 bpm @ 5759 psi, 13,200.0 13,330.0 14:06 18:06 BHP=4264, D1f=1358, WHTP=352, IA=262, OA=3, CTSW=-3.6, WOB=1.0, ROP=31'. 10/13/2017 10/13/2017 1.80 PROD1 DRILL DRLG P OBD, 1.75 bpm at 5,517 psi, BHP 13,330.0 13,425.0 18:06 19:54 4,257, WHP 422, IA 263, OA 5, CTSW= minus 1.75 k, DHWOB= 1.3 k, ROP 30 fph 10/13/2017 10/13/2017 0.40 PROD1 DRILL WPRT P 400' wiper up hole, PUW 39 k 13,425.0 13,425.0 19:54 20:18 10/13/2017 10/13/2017 3.15 PRODi DRILL DRLG P OBD, 1.6 bpm at 5,579 psi, BHP 13,425.0 13,494.0 20:18 23:27 4,288, WHP 410, IA 263, OA 5 10/13/2017 10/14/2017 0.55 PRODt DRILL WPRT P 600' wiper up hole PUW 39 k 13,494.0 13,494.0 23:27 00:00 10/14/2017 10/14/2017 9.40 PROD1 DRILL DRLG P OBD, 1.56 bpm at 5,060 psi, Diff 970, 13,494.0 13,782.0 00:00 09:24 BHP 4,279, WHP 432, IA 263, OA 5, CTSW= minus 5.0 k, DHWOB= 1.0 k, ROP 60 fph 10114/2017 10114/2017 0.30 PROD1 DRILL DRLG P Temporarily stuck pipe @ 13,782'; 13,782.0 13,782.0 09:24 09:42 pop'd free at 70k (last PUW=42k). 5/5 sweep in pipe, PUH slowly and wait for sweep to exit. 10114/2017 10114/2017 1.30 PROD1 DRILL WPRT P Wiper to window. 13,782.0 10,521.0 09:42 11:00 10114/2017 10/14/2017 1.10 PROD1 DRILL WPRT P Wiper back in hole. Tie-in correction 10,521.0 13,782.0 11:00 12:06 +14.5' 10/14/2017 10/14/2017 3.00 PROD1 DRILL DRLG P BOBP. 1.42 bpm at 4,844 psi, 13,782.0 13,852.0 12:06 15:06 BHP=4,342, Dif=925, WHP=470, IA=262, OA=3, CTSW= minus 2k, DHWOB= 0.88k, ROP 40 fph 10/14/2017 10/14/2017 3.50 PROM DRILL TRIP P TD well at 13852' (corrected). Pump 13,852.0 78.3 15:06 18:36 10/10 low/high sweep. Chase out of hole to swab. 10114/2017 10/14/2017 0.15 PRODi DRILL TRIP P Tag up at surface, reset counters 78.3 78.3 18:36 18:45 10/14/2017 10/14/2017 1.70 PROD1 DRILL TRIP P RIH 78.3 10,245.0 18:45 20:27 10/14/2017 10/14/2017 0.20 PROD1 DRILL DLOG P Log the K1 Marker correction of minus 10,245.0 10,290.0 20:27 20:39 8.0' 10/14/2017 10/14/2017 0.15 PROD1 DRILL TRIP P Continue RIH 10,290.0 10,465.0 20:39 20:48 10114/2017 10/14/2017 0.50 PROD1 DRILL TRIP P Perform Static Pressure Survey, shut 10,465.0 10,465.0 20:48 21:18 down pump holding 12.7 ppg ECD at the window, annnular pressure increased to 4073 psi, bring pump on circulate bottoms up to confirm back side is clear, shut down again and montior well. annular pressure 4,077 psi 112.885 ppg. discuss plan forward with TE, Page 6118 Report Printed: 11/112017 . operations Summary (with Timelog uepths) 2K-04 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 (ft e) End Depth (MB) 10/14/2017 10114/2017 0.75 PRODI DRILL CIRC P Bring pump on-line, 1.8 bpm at 5,930 10,465.0 10,465.0 21:18 22:03 psi, circulate bottoms up to confirm back side is Gear, shut down again and montior well. annular pressure 4,077 psi 112.885 ppg. discuss plan forward with TE, 10/14/2017 10/15/2017 1.95 PRODI DRILL TRIP T Jog coil in tubing, while weighting up 10,465.0 10,465.0 22:03 00:00 1 1 fluid 10/15/2017 10/15/2017 0.75 PRODI DRILL TRIP T Continue weighting up completion fluid 10,465.0 10,465.0 00:00 00:45 12.9 ppg - 13.1 ppg 10115/2017 10/15/2017 2.15 PROD? DRILL TRIP P RIH, no correction at RA marker. 10,465.0 13,852.0 00:45 02:54 10/15/2017 10115/2017 0.60 PROD1 DRILL TRIP P Confine TD, line up and circulate 50 13,852.0 13,852.0 02:54 03:30 bbl beaded completion fluid down coil. PUW 41 k 10/15/2017 10/15/2017 3.00 PRODI DRILL DISP P POOH, laying in 13.1 ppg beaded liner 13,652.0 71.5 03:30 06:30 running pill. - 10/15/2017 1011512017 0.40 PRODI DRILL PULD P At surface. Open up @ riser and 71.5 0.0 06:30 06:54 perform flow check. No Flow. Perform PJSM. Fill hole; took 1.5 bbls to fill after 13 mins static. 10115/2017 10/15/2017 0.80 PRODI DRILL PULD P Undeploy drilling BHA #4. Prep to 0.0 0.0 06:54 07:42 function lest BOPE. Fill hole; 1.6 bbls to fill. Minimal wear on bit; one cutter chipped minimal erosion on nose (rated 1-2) 10/15/2017 10/15/2017 1.10 PRODI DRILL PULD P Function test BOPE. Service blocks. 0.0 0.0 07:42 08:48 1 10/15/2017 10/15/2017 1.00 COMPZ1 CASING PULD P PJSM for running liner. Begin making 0.0 0.0 08:48 09:48 up liner. Filling hole every 5 its; -1 bbl to fill (10. bbls since flow check). Losses -3.5 bbl/hr. 10115/2017 10/15/2017 0.30 COMPZ1 CASING SFTY P Perform Kick While Running Liner 0.0 0.0 09:48 10:06 Drill. 10/15/2017 10/15/2017 2.40 COMPZ1 CASING PULD P 2 0.0 2,681.7 10:06 12:30 10/15/2017 10/15/2017 0.90 COMPZ1 CASING PULD P PU Baker CoilTrak BHA w/ GS and L1 2,681.7 2,726.7 12:30 13:24 liner assembly. 10/15/2017 10/152017 1.10 COMPZ1 CASING RUNL P Run in hole with liner. RIW=8k. 2,726.7 10,426.7 13:24 14:30 10/15/2017 10/15/2017 0.25 COMPZI CASING RUNL P Tie in to window flag and correct 10,426.7 11,146.0 14:30 14:45 minus 20.6', 7700' EOP and 10,426.72 end of liner. PUW 40k, RIW=12k. 10/15/2017 10/152017 5.00 COMPZ1 CASING RUNL P Friction out @ 11146; PUW=43k. 11,146.0 11,850.0 14:45 19:45 Work liner to bottom. 10/15/2017 10/16/2017 4.25 COMPZ1 CASING RUNL P Line up down the backside, pumping 11,850.0 12,580.0 19:45 00:00 min rate, continue to work liner to bottom, pulling up 100-150' gaining 10 -40' per run 10/162017 10/162017 3.50 COMPZ1 CASING RUNL P Continue working liner to bottom, 12,580.0 12,784.0 00:00 03:30 10/16/2017 10/1612017 5.00 COMPZ1 CASING RUNL P Line back down the coil, continue 12,784.0 13,038.0 03:30 08:30 working liner down hole, 10/16/2017 10116/2017 1.50 COMPZI CASING RUNL P Continue to work liner to bottom. 13,038.0 13,061.0 08:30 1000 gaining T-10' at a time; slow going. Page 7118 ReportPrinted: 11/1/2017 AN, ft Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Shed Depth Start Tone End Time Oer(h) Phase Op Code Ardvity Code Time P -T -X Operation (W) End Depth(XKe) 10/16/2017 10/16/2017 0.60 COMPZI CASING RUNL P Begin lubing up KW fluid, 1%776 and 13,061.0 13,075.0 10:00 10:36 1% LoTorq. Circulate @1.0 bom to verify we can surface fluids; losses -30%. Confer with town, begin mixing up beaded liner pill. 10/16/2017 10/16/2017 1.75 COMPZI CASING RUNL P Online bull -heading 13.1 beaded -pill 13,075.0 13,145.0 10:36 12:21 down CTxlbg annuli 0.18 bpm, 0.18 bpm, 500 psi WHP max. Resume working liner to bottom. 10/1612017 10/16/2017 3.00 COMPZI CASING RUNL P Shut down to add lubes to beaded pill. 13,145.0 13,145.0 12:21 15:21 (note: Lead 20 bbls of 50 bbl bead pill not tubed). 10/16/2017 10/16/2017 5.90 COMPZI CASING RUNL P Back online bullheading beaded pill, 13,145.0 13,384.0 15:21 21:15 0.15 bpm, WHP=475, BHP=4600. PUW=43k.Conflnue to work liner to bottom. 10116/2017 10/16/2017 0.15 COMPZI CASING RUNL P Bring pump on-line, 1.45 bpm at 6,400 13,384.0 10,660.4 21:15 21:24 psi, PUW 31 k 10/16/2017 10/16/2017 0.15 COMPZI CASING TRIP P Set depths, PUH to log tie in. 10,660.4 10,440.0 21:24 21:33 10/16/2017 10/16/2017 0.25 COMPZ1 CASING DLOG P Log the RA marker cometion of Plus 10,440.0 10,455.0 21:33 21:48 41.5' 10/16/2017 10/16/2017 0.15 COMPZI CASING TRIP P RBIH, tag TOL at 10701.5', bring 10,455.0 10,701.5 21:48 21:57 pump on-line 1.4 bpm at 6,100 psi, PUW 31 k 10/16/2017 10116/2017 1.75 COMPZI CASING TRIP P POOH, pumping pipe displacement 10,701.5 44.2 21:57 23:42 10/16/2017 10/17/2017 0.30 COMPZI CASING OWFF P At surface check well for flow, PJSM 44.2 44.2 23:42 00:00 10117/2017 10/17/2017 0.15 COMPZI CASING OWFF P At surface, check well for flow, PJSM 44.2 44.2 00:00 00:09 10/172017 10/17/2017 0.75 COMPZI CASING PULD P Check Coil, flat spot found - Tector 44.2 0.0 00:09 00:54 Meter read 0.164 inch, Continue to Lay down setting tools on a dead well. 10/172017 10/17/2017 0.75 COMPZ1 CASING SVRG P Service reel, INJH, DOMS inspection, 0.0 0.0 00:54 01:39 and check pac-off. 10/172017 10117/2017 0.50 COMPZ1 CASING PULD P MU, Lt upper Liner segment with 0.0 232.1 01:39 02:09 OHA Billet. 10/172017 10/17/2017 2.50 COMPZI CASING RUNL P RIH, "OPEN EDC", pumping 0.34 bpm 232.1 10,410.0 02:09 04:39 at 697 psi with Open Hole Anchored Billet, 4 jls of 2-318" slotted liner, and ported bullnose. 10/172017 10/1712017 0.25 COMPZI CASING RUNL P Log the Kt marker correction of minus 10,410.0 10,454.0 04:39 04:54 4.5', PUW 32 k, RIW 12 k 10/17/2017 10/1712017 0.30 COMPZ1 CASING RUNL P Continue RIH, lag TOL at 10,701' 10,454.0 10,701.5 04:54 05:12 10/17/2017 10/17/2017 0.25 COMPZ11 CASING RUNL P PUH, orient TD high side, set back 10,701.5 10,530.0 05:12 05:27 down, DHWOB=1.7 k, bring pump up for a shear, tool did not shear, pressure 7,000 psi, attempt to pressure up twice with no shear, establish injection 1.00 bpm with 0.8 bppm returns, call BOT, decision was made to PUH, PUW 29 k 10117/2017 10/17/2017 2.00 COMPZI CASING TRIP P POOH, pumping pipe displacement 10,530.0 69.8 05:27 07:27 10/17/2017 10/17/2017 1.00 COMPZ1 CASING PULD P At surface; perform flow check. Begin 69.8 0.0 07:27 08:27 undeploying upper liner; running BHA #6 Page 8118 ReportPrinted: 111112017 . Operations Summary (with Timelog uepths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth StartTime Ertl Time Dur Mr) Phase op Code Aptivity Code Time P -T -X operation (ftKB) End Depth(NCB) 10/17/2017 10/17/2017 1.00 PROD2 DRILL KOST P Make up L1-01 build BHA #7 0.0 72.0 08:27 09:27 10/17/2017 10/17/2017 2.40 PROD2 DRILL KOST P Run in hole with L1-01 build BHA #7. 72.0 10,240.0 09:27 11:51 Slow down to 80 FPM pushing fluid away 10/17/2017 10/17/2017 0.20 PROD2 DRILL KOST P Log Kt for 4 correction 10,240.0 10,279.2 11:51 12:03 ' 10/17/2017 10/17/2017 0.20 PROD2 DRILL KOST P RIH to 10,450 10,279.2 10,450.0 12:03 12:15 10/17/2017 10/17/2017 1.80 PROD2 DRILL KOST P Displace well to 8.9 PPG drilling fluid, 10,450.0 10,450.0 12:15 14:03 System #2, Shut EDC 10/17/2017 10/17/2017 0.20 PROD2 DRILL KOST P Trip in well, clean pass through 10,450.0 10,526.0 14:03 14:15 window. Initial dry tag @ 10526 10/17/2017 10/17/2017 1.00 PROD2 DRILL KOST P PUH, PUW=28K, Pumps on @ 1.8 10,526.0 10,536.0 14:15 15:15 BPM @ 4992 PSI FS, BHP=4113, Light tag @ 10526 then looks like puching down hole. TOB is supposed to be at 10530. Continue working in with low - no DHWOB very little motor work. Some aluminum on shaker 10/17/2017 10/17/2017 0.60 PROD2 DRILL DRLG P 10536', Drill Ahead, Low differential, 10,536.0 10,558.0 15:15 15:51 High WOB 10/17/2017 10/17/2017 0.15 PROD2 DRILL WPRT P PUH to drift billet area to 10,515. 10,558.0 10,558.0 15:51 16:00 Drifted clean up and down 10/17/2017 10/17/2017 2.50 PROD2 DRILL DRLG P OBD, CWT =9K, WOB=1.5K, 10,558.0 10,855.0 16:00 18:30 annular = 4851 psi, call TD of build at 10,855' 10/17/2017 10/17/2017 1.90 PROD2 DRILL TRIP P POOH, open EDC at 10,459', pre -job 10,855.0 72.0 18:30 20:24 while POOH, tag up, space out, WHP = 1350 psi 10/17/2017 10/17/2017 1.90 PROD2 DRILL PULD P PUD BHA V, checks not holding, 72.0 0.0 20:24 22:18 close EDC, bit came out a 2-1 10117/2017 10/17/2017 1.30 PROD2 DRILL PULD P PD BHA #8 (agitator, 0.5° AKO motor, 0.0 78.0 22:18 23:36 RB Hughes bit), slide in cart, MU coil 10/17/2017 10/18/2017 0.40 PROD2 DRILL TRIP P Begin RIH with BHA #8, surface test 78.0 296.0 23:36 00:00 agitator, vibrating, though not overly aggressive, continue RIH 10/1812017 10/18/2017 1.70 PROD2 DRILL TRIP P Continue RIH with BHA #8, swapping 296.0 10,240.0 00:00 01:42 1 1 to mud System #3 10/18/2017 10/18/2017 0.50 PROD2 DRILL DLOG P Log K1 for -5.5' correction 10,240.0 10,289.0 01:42 02:12 10118/2017 10/18/2017 0.40 PROD2 DRILL TRIP P Continue RIH, obtain SBHP at 10,289.0 10,855.0 02:12 02:36 window, close choke, shut down pump, 10,451' bit depth, puts sensor at 6098' TVD, EMW = 12.86 ppg, PUW = 30K, RIW = 9K 10/18/2017 10/18/2017 1.90 PROD2 DRILL DRLG P OBD pumping 1.7 bpm, free spin = 10,855.0 11,055.0 02:36 04:30 970 psi, CWT = 6K, WOB = 2.9K, annular = 4102 psi, WHP = 345 psi, circ pressure = 5564 psi PU for new parameters with new mud all the way around. PUW = 31 K, RBIH, free spin = 650 psi, annular = 4196 psi Page 9118 ReportPrinted: 111112017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sart OepN Stan Time Erd Tme aur (lv) Pham Op Code ActiWly Code Time P -T -X Operation (ftK8) EM Oeph(Po(B) 10/18/2017 10/18/2017 3.40 PROD2 DRILL DRLG P BHA wiper, pump low/hi sweeps, 11,055.0 11,317.0 04:30 07:54 PUW = 32K, BOBD pumping 1.8 bpm, free spin = 950 psi, CWT = 3K, WOB = 2K, annular = 4239 psi, dp = 1315 psi, circ pressure = 5546 psi, Surface weight low. Confer with town. Add 1 % LoTork to new mud system. Gain 5K Surface weight 10/18/2017 10/18/2017 0.30 PROD2 DRILL WPRT P 11317', Wiper trip to 10,900', 11,317.0 11,317.0 07:54 08:12 PUW=33K, Clean up and down 10/18/2017 10/18/2017 4.10 PROD2 DRILL DRLG P 11,317', Drill. 1.79 BPM @ 5302PSI 11,317.0 11,702.0 08:12 12:18 FS, BHP=4300, RIW=1K, DHWOB=2.4K, ROP=-100FPH 10118/2017 10/18/2017 0.60 PROD2 DRILL WPRT P 11702', Wiper to 10,900', PUW=36K, 11,702.0 11,702.0 12:18 12:54 Clean trip up and down 10/18/2017 10/18/2017 5.40 PROD2 DRILL DRLG P 11702', Drill, 1.79 BPM @ 5313 PSI 11,702.0 12,111.0 12:54 18:18 FS, BHP=4290, RIW=-1.1K, DHWOB=2.4K, ROP= -105 FPH 10/1812017 10/18/2017 0.70 PROM DRILL WPRT P WT up -hole, PUW=31K 12,111.0 10,490.0 18:18 19:00 10/182017 10/18/2017 0.10 PROD2 DRILL DLOG P Log RA tag for+7.5' correction 10,490.0 10,510.0 19:00 19:06 10/18/2017 10/18/2017 0.60 PROD2 DRILL WPRT P WT in-hole, RIW = 5K 10,510.0 12,111.0 19:06 19:42 - - 10/18/2017 10119/2017 4.30 PROD2 DRILL DRLG P BOBD, FS = 950 psi, pumping 1.78 12,111.0 12,422.0 19:42 00:00 bpm, CWT= -5.5K, WOB =2K, annular = 4264', circ pressure = 5673 psi, WHP = 494 psi, pumping sweeps as required, multiple PU's to continue drilling, begin sending beaded pill, 72 fph average over interval 10119/2017 10/19/2017 1.90 PROD2 DRILL DRLG P Continue drilling from 12,422', beaded 12,422.0 12,513.0 00:00 01:54 pill had moderate effect (effect short lived in OH), CWT = -5K, WOB = 1.9K though quickly falls off, annular = 4262 psi, WHP = 491 psi Continue sending pills (1%776, 1% LoTorq, & Alpine beads), PU's as required to continue drilling (PUWs -41 K) 10119/2017 10/1912017 0.30 PROM DRILL WPRT P WT up -hole, PUW = 40K 12,513.0 11,564.0 01:54 02:12 1 10119/2017 10/19/2017 0.30 PROM DRILL WPRT P WT in-hole, RIW = 5K 11,564.0 12,513.0 02:12 02:30 101192017 10/19/2017 2.00 PROD2 DRILL DRLG P BOBD, pumping 1.8 bpm, CWT= -6K, 12,513.0 12,592.0 02:30 04:30 WOB = 1.4K, annular = 4269 psi, circ pressure = 4778 psi, WHP = 480 psi 10/19/2017 10/19/2017 1.80 PROD2 DRILL DRLG P OBD, continue to pump LoVis sweeps 12,592.0 12,690.0 04:30 06:18 followed by beaded pills, CWT =- 8.7K, WOB = 1.2K, annular = 4354 psi, WHP = 588 psi 10/1912017 10/19/2017 0.10 PROD2 DRILL WPRT P 12690, BHA wiper, PUW=36K 12,690.0 12,690.0 06:18 06:24 10/192017 10/19/2017 1.00 PROD2 DRILL DRLG P 12690', Drill, 1.81 BPM @ 5248 PSI 12,690.0 12,766.0 06:24 07:24 FS, BHP=4340, RIW=-7K, DHWOB=I.6K - Page 10118 Report Printed: 11/1/2017 . Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tune End Tune Oka(hr) Phase Op Cade Activity Gods Tune P -TA Operation Std Cam lflKe) End Depth (Poco) 10/19/2017 10/19/2017 0.50 PROD2 DRILL WPRT P 12766', 1000'wipertrip, PUW=36K, 12,766.0 12,766.0 07:24 07:54 Trouble getting back to bottom from close to bottom 10/19/2017 10/19/2017 5.20 PROW DRILL DRLG P 12766', Drill, 1.79 BPM @ 5154 PSI 12,766.0 12,940.0 07:54 13:06 FS, BHP=4250, Low diff press, low rop, low surface weight, multiple pick ups to keep drilling 10/19/2017 10/19/2017 1.40 PROD2 DRILL WPRT P Pump sweeps, 10 X 10, chase out of 12,940.0 10,470.0 13:06 14:30 hole 10/1912017 10/192017 0.20 PROD2 DRILL DLOG P Log RA far+13' 10,470.0 10,520.0 14:30 14:42 10/19/2017 10/19/2017 0.10 PROD2 DRILL WPRT P PUH to clear window 10,520.0 10,469.0 14:42 14:48 10/192017 10/19/2017 0.20 PROD2 DRILL OTHR P 10469', Stop and obtain static 10,469.0 10,469.0 14:48 15:00 pressure, Pressure sender@ 6103TVD, BHP stable @ 4065PSI, EMW=12.85 10/19/2017 10/19/2017 1.70 PROD2 DRILL WPRT P Continue wiper trip to swab 10,469.0 78.0 15:00 16:42 10/19/2017 10/192017 1.90 PROM DRILL WPRT P RBIH 78.0 12,238.0 16:42 18:36 10/192017 10/19/2017 0.60 PROD2 DRILL DLOG P Log Kt for+8' correction, check & 12,238.0 12,470.0 18:36 19:12 clean injector counter, obtain SBHP, bit depth = 12,470', sensor TVD = 6103', EMW =12.81 ppg 10/19/2017 10/19/2017 1.00 PROD2 DRILL WPRT P Continue RIH, clean run to bottom, 12,470.0 12,946.0 19:12 20:12 confirm TD at 12,946' 10/19/2017 10/20/2017 3.80 PROD2 DRILL DISP P POOH laying in 13.1 ppg liner pill & 12,946.0 78.0 20:12 00:00 KWF to surface, paint flags at 11818.3'& 9278.3', begin Flow check well 10/20/2017 10202017 1.20 PROD2 DRILL PULD P Crew change, continue flow check, 78.0 0.0 00:00 01:12 good, PJSM, LD BHA #8 over a dead - well, 2 bbl/hr losses, RB Hughes bit came out a 1-1 Slide back cart, begin clean up of gdpper.blocks out of critical path (due to pipe coating) 10/20/2017 10/20/2017 0.80 COMPZ2 CASING PUTB P PJSM, L1-01 Liner Run #1 (non- 0.0 440.0 01:12 02:00 ported bull nose, 29 jnts slotted liner, shorty deployment sleeve) Gripper blocks look good, minimal cleaning required, work was out of critical path 10/20/2017 10/2012017 0.50 COMPZ2 CASING RGRP T Change out elevators 440.0 440.0 02:00 0230 10/20/2017 10/20/2017 0.80 COMPZ2 CASING PUTB P Continue PU Liner, Drill: kick while 440.0 1,156.0 02:30 03:18 running liner (good) 10/20/2017 10/20/2017 1.20 COMPZ2 CASING PULD P PJSM, PU BHA#9, liner running tools, 1,156.0 1,200.0 03:18 04:30 slide in cart, MU coil, EDC closed, tag up, reset counters 10202017 10/202017 1.60 COMPZ2 CASING RUNL P RIH with liner Run #1 1,200.0 10,400.0 04:30 06:06 10/20/2017 10/202017 0.10 COMPZ2 CASING DLOG P Correct to flag for -17.9' 10,400.0 10,382.1 06:06 06:12 I Page 11118 ReportPrinted: 11/1/2017 Operations Summary (with Timelog Liepths) 2K-04 • Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time EM Thne Ow (hr) Please Op Code Acivily Code Tune P-T-X Operation Start Depth (110) End DePO(MB) 10/20/2017 10/20/2017 2.10 COMM CASING RUNL P Continue in well, Unable to slow down 10,382.1 12,946.0 06:12 08:18 and tie in without stacking out @ 11630', P/U and continue in hole, first setdown @ 12,450'. Work pipe down to 12946 10/20/2017 10/20/2017 2.40 COMM CASING TRIP P 12946, At bottom, pump at 1.5 @ 12,946.0 27.0 08:18 10:42 6000PSI, PUW=26K, Trip out. Log RA for +12.5'Paint EDP flags @ 10410 10/20/2017 10/20/2017 0.70 COMM CASING PULD P At surface, Flow check well, PJSM, 27.0 0.0 10:42 11:24 Lay down BHA #9 Liner running tools - ' Prep floor for liner ops 10/20/2017 10/20/2017 2.10 COMM CASING PUTB P M/U BHA#10, L1-01 upper liner 0.0 1,149.4 11:24 13:30 segment with ported bullnose, 28 Jts slotted liner, 2 pups, OH anchor billet. Perform BOP drill. 10/20/2017 10/20/2017 1.00 COMPZ2 CASING PULD P PJSM, P/U OH Anchor billet, P/U coil 1,149.4 . 1,211.1 13:30 14:30 track, WU to liner, M/U to coil and surface test 10/20/2017 10/20/2017 1.80 COMPZ2 CASING RUNL P Trip in hole, EDC open 1,211.1 10,424.0 14:30 16:18 - 10/20/2017 10/20/2017 - 0.10 COMPZ2 CASING DLOG P Tie into 10411 EDP flag for+12.9 10,424.0 10,436.0 16:18 16:24 10/20/2017 10/20/2017 3.30 COMPZ2 CASING RUNL T Continue in well, stop at 10457 close 10,436.0 11,790.0 16:24 1942 EDC. Continue in, lost comms with tools, PUH slowly 10400', confer with town, decison made to RIH & set anchor blind Set down at 11,628'4 times (slips likely hanging up on BOW), PUW's - 50K, get by on 5th attempt, arrived at setting depth, bring up pumps, sheared off anchor, PUW = 30K, putting TOB at - 10,640' 10/20/2017 10/20/2017 1.90 COMM CASING TRIP P POOH 11,790.0 78.0 19:42 21:36 10/20/2017 10/20/2017 0.90 COMPZ2 CASING PULD P PJSM, flow check well, good, check 78.0 0.0 21:36 22:30 coil, good, LD BHA #10 (using new LD over dead well checklist) 10/20/2017 10/21/2017 1.50 COMPZ2 CASING CIRC P MU nozzle, roll coil to fresh water, jet 0.0 0.0 22:30 00:00 the stack, LD nozzle, slide back cart Note: a-line anchor pulled out of anchor carrier, last coil cut was on 10/7 at-12:00 Ins, no slack managemnt was documented as less than 30' of coil was cut. 10/21/2017 10/21/2017 1.50 COMM WHDBOP RURD P Prepping for BOPE test, test inner reel 0.0 OD 00:00 01:30 valve & stripper, grease tree, fluid pack 10/21/2017 10/21/2017 2.50 COMM WHOBOP BOPE P Test BOPE (start time 1:30 his), 0.0 0.0 01:30 04:00 witness waived by Jeff Jones of AOGCC. Test up through Test #7 10/21/2017 10/21/2017 0.20 COMPZ2 WHDBOP BOPE P (Test #8) Difficulty holding pressure 0.0 0.0 04:00 04:12 against Bleeder2, isolate from Romeo 2 & Bleeder 2, test Charlie 1 & 9, will come back to test Bleeder 2 and Romeo 2 10/21/2017 10/21/2017 1.80 COMPZ2 WHDBOP BOPE P Continue testing from Test to test 0.0 0.0 04:12 06:00 1 13 Page 12118 ReportPrinted: 11/1/2017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End T ne our (hr) Phase op (title Activity Code Trine P -T -X operation Start Depth Me) End Depth (MB) 10/21/2017 10/21/2017 3.00 COMPZ2 WHDBOP BOPE P Continue testing from step 13 to 15, 0.0 0.0 06:00 09:00 Perform draw down test. Check N2 levels, Test gas alarms 10/21/2017 10/21/2017 1.00 COMM WHDBOP BOPE T Change out Bleeder 2 and retest, 0.0 0.0 09:00 10:00 good, End BOPE test @ 10:00 for 8.5 hours 10/21/2017 10/21/2017 1.00 COMM CASING CTOP T Remove UQC, E -line right there, Cut 0.0 0.0 10:00 11:00 CTC off. Boot wire, Stab on well. Line up to reverse circulate 10/21/2017 10/21/2017 0.50 COMPZ2 CASING CTOP T Pump a -line back into CT, 2.5 BPM @ 0.0 0.0 11:00 11:30 4700 PSI - Hear wire move. Unstab injector 10121/2017 10/21/2017 1.50 COMPZ2 CASING CTOP T PJSM, R/U hydraulic tubing cutter, Cut 0.0 0.0 11:30 13:00 208' CT to find E -line. R/D cutter then hand cul 4' (total CT cut 212) 10/2112017 10/21/2017 1.00 COMPZ2 CASING CTOP T PJSM, Prep coil for CT connector and 0.0 0.0 13:00 14:00 install. Pull test to 35K 10/21/2017 10/2112017 1.00 COMPZ2 CASING CTOP T PJSM test a -line, rehead UQC and 0.0 0.0 14:00 15:00 test all good, PT to 4500 PSI 10/21/2017 10/21/2017 1.30 COMPZ2 CASING CIRC T Install nozzle, stab injector on well. 0.0 0.0 15:00 16:18 Circulate forward displacing CT back to 13.1 PPG KFormate 10/21/2017 10/2112017 1.30 COMM CASING PULD T PJSM, M/U BHA #11, OH anchor & 0.0 72.9 16:18 17:36 billet 10/21/2017 10/21/2017 1.80 COMM CASING RUNL T RIH with BHA#11 72.9 10,245.0 17:36 19:24 10/21/2017 10/21/2017 0.20 COMPZ2 CASING DLOG T Tie in for a -8' correction 10,245.0 10,298.0 19:24 19:36 10/21/2017 10/21/2017 0.40 COMPZ2 CASING RUNL T Continue RIH, oriented 150" ROHS as 10,298.0 10,643.0 19:36 20:00 per plan, tag TOL at 10,643', bring up pump, shear off anchor, putting TOB at -10,631' 10/21/2017 10/21/2017 1.80 COMPZ2 CASING TRIP T POOH, tag up, flow check well 10,643.0 73.0 20:00 21:48 10/21/2017 10/21/2017 0.60 COMPZ2 CASING PULD T PJSM, LD BHA#11, reconfigure tools 73.0 0.0 21:48 22:24 10/21/2017 10/21/2017 0.60 PRODS STK PULD P PU BHA#12 L1-02 KO/Build 0.0 72.0 22:24 23:00 Assembly (2.0° AKO motor, RR Hughes, 1-1 b8 from L1 [at) 10/21/2017 10/22/2017 1.00 COMPZ2 STK TRIP P Open EDC, RIH with BHA#12 72.0 4,200.0 23:00 00:00 10/22/2017 10/22/2017 1.10 PROD3 STK TRIP P Continue RIH 4,200.0 10,240.0 00:00 01:06 10/22/2017 10/22/2017 0.30 PRODS STK DLOG P Log K1 for -10' correction 10,240.0 10,288.0 01:06 01:24 10/22/2017 1022/2017 0.10 PRODS STK TRIP P Continue RIH 10,288.0 10,430.0 01:24 01:30 10/22/2017 10/22/2017 1.30 PRODS STK DISP P Displace well to 8.8 ppg PowerPro, 10,430.0 10,430.0 01:30 02:48 close EDC 10/222017 10/22/2017 0.30 PRODS STK TRIP P RIH, zero WOB, dry tag TOB at 10,430.0 10,629.3 02:48 03:06 10,631, PUW = 31 K, bring up pumps, RBIH 10/222017 10/222017 1.30 PRODS STK KOST P Stalled a couple times at 10,629.3' 10,629.3 10,635.0 03:06 04:24 getting on billet, begin milling off billet, CWT= 8K, WOB= 1.2K, annular= 4109 psi, circ pressure = 4947 psi, experienced a couple more stalls at -10,630' Page 13/18 ReportPrinted: 1111/2017 . Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tme End Time Our (hr) Me.. Op Code Ackly Code Time P -T -x Opaiason Stapth (rt De MKB) End Depth (flKB) 10/22/2017 10/22/2017 3.80 PRODS DRILL DRLG P Drilling in formation on L1-02 build 10,635.0 10,930.0 04:24 0812 section, CWT =8K, WOB=1.1 K, annular = 4158 psi, WHP = 486 psi, dry drifted billet area up & down, clean 10/22/2017 10/22/2017 2.30 PRODS DRILL TRIP P Call EOB, Trip out for lateral drilling --To-,93o.0 56.3 08:12 10:30 BHA # 13, AVG DLS=33.9°, Open EDC @ 10,433'. 10/2212017 10/22/2017 1.00 PRODS DRILL PULD P Tag up and space out. PJSM, PUD 56.3 0.0 10:30 11:30 BHA #12 10/22/2017 10/22/2017 1.70 PRODS DRILL PULD P PJSM, PD BHA#13. Lt -02 Lateral 0.0 78.3 11:30 13:12 BHA with .5° motor, Agitator, and RR Hughs Bi Center. MN to coil and surface test 10/22/2017 10/22/2017 2.50 PRODS DRILL TRIP P Trip in hole, EDC open, Pump .4 BPM. 78.3 10,250.0 13:12 15:42 Test agitator @ 300'- Good 10/22/2017 10/22/2017 0.10 PRODS DRILL DLOG P Log K-1 for -9', PUW=32K 10,250,0 10,283.0 15:42 15:48 10/22/2017 1012212017 0.20 PRODS DRILL TRIP P Continue in well, clean through 10,283.0 10,930.0 15:48 16:00 window and past billets 10/22/2017 10/22/2017 4.00 PRODS DRILL DRLG P 10930', Drill ahead, 1.75 BPM @ 10,930.0 11,330.0 16:00 20:00 540OPSI FS, BHP=4221, RIW=6.8K, DHWOB=I.6K, ROP=-120FPH Begin swapping to mud system #4 at ' -11,075', add 1 % LoTorq to system, additional lube hit the bit at 11,295' (Squatting heavy on bit to get pointed down for geo's) 10/22/2017 10/2212017 0.30 PRODS DRILL WPRT P WT up -hole, PUW = 34K 11,330.0 10,650.0 20:00 20:18 10/2212017 10/22/2017 0.20 PRODS DRILL WPRT P WT down -hole, RIW = 7K 10,650.0 11,330.0 20:18 20:30 10/2212017 10/23/2017 3.50 PRODS DRILL DRLG P BOBD, pumping 1.8 bpm, FS = 1095 11,330.0 11,710.0 20:30 00:00 psi, CWT = 4K, WOB = 2K, annular = 4170 psi, WHP = 504 psi, circ pressure = 5348 psi, dp = 1328 psi, 109 fph average over interval 10/23/2017 10/23/2017 0.30 PRODS DRILL DRLG P Continue drilling from 11,710,CWT=- 11,710.0 11,730.0 00:00 00:18 4K, WOB 1.6K, annular = 4298 psi, pump sweeps 10/23/2017 10/23/2017 0.30 PRODS DRILL WPRT P WT up -hole, PUW = 34K 11,730.0 10,892.0 00:18 00:36 10/23/2017 10/23/2017 0.30 PRODS DRILL WPRT P WT in-hole, RIW = 7K 10,892.0 11,730.0 00:36 00:54 10/23/2017 10/23/2017 3.10 PRODS DRILL DRLG P BOBD, pumping 1.8 bpm, FS = 1020 11,730.0 11,958.0 00:54 04:00 psi, CWT = 1.4K, WOB = 1.81K, annular= 4184 psi, WHP = 416 psi, Circ pressure = 5385 psi, begin to pump 5x5 sweeps at 11,957', 74 fph average ROP over interval 10/23/2017 10/23/2017 1.70 PRODS DRILL DRLG P Continue drilling ahead, pumping 1.8 11,958.0 12,134.0 04:00 05:42 bpm, CWT =-6K, WOB = 1.21K, annular= 4246 psi 10/23/2017 10/23/2017 1.90 PRODS DRILL WPRT P 12134', Wiper trip #3to window with 12,134.0 12,134.0 05:42 07:36 tie in for+8', PUW=36K, Clean trip up and down 10/23/2017 10/23/2017 2.80 PROD3 DRILL DRLG P 12138', Drill, 1.52 BPM @ 4577 PSI 12,138.0 12,368.0 07:36 10:24 FS, BHP=4271, RIW=-6.2, DHWOB=2.9K. Pumping reduced rate to arrest build Page 14118 Report Printed: 1111/2017 . uperations Summary (with Timelog uepths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log S Start Time End nma our(hr) Phase Op Code Activity Code Time P -T-% Opeition (N(9)Pm End Depth 10/23/2017 10/23/2017 0.20 PROD3 DRILL WPRT P BHA Wiper, PUW=42K 12,368.0 12,368.0 10:24 10:36 10/23/2017 10/23/2017 1.70 PROD3 DRILL DRLG P 12368', Drill, 1.79 BPM @ 5311 PSI 12,368.0 12,461.0 10:36 12:18 FS, BHP=4254. RIW=-5.5K, DHWOB=I K, Multiple BHA Wipers, Hard to maintain steady state drilling 10/23/2017 10/23/2017 0.70 PROD3 DRILL WPRT P 12461, 1000'wiper, PUW=42K, Clean 12,461.0 12,461.0 12:18 13:00 trip up and down 10/23/2017 10/23/2017 2.60 PROD3 DRILL DRLG P 12461', Drill, 1.79 BPM @ 5636PSI 12,461.0 12,606.0 13:00 15:36 FS, BHP=4316 10123/2017 10/23/2017 0.20 PROD3 DRILL WPRT P 12,606, BHA wiper, stacking, 12,606.0 12,606.0 15:36 15:48 PUW=42K 10/23/2017 10123/2017 2.60 PROD3 DRILL DRLG P 12,606', drill, 1.67 BPM @ 515OPSI 12,606.0 12,736.0 15:48 18:24 FS, BHP=4310RIW=-3.5', DHWOB=I.4K 10/23/2017 10/23/2017 1.30 PROD3 DRILL WPRT P Pull BHA Wiper, PUW=39K, Unable to 12,736.0 12,736.0 18:24 19:42 get back in hole. Convert wiper trip to 1000'er 10/23/2017 10/23/2017 1.20 PROD3 DRILL DRLG P 12736', Drill, 1.77 BPM @ 5580 PSI 12,736.0 12,798.0 19:42 20:54 FS, BHP=4290, RIW=6K, DHWOB=I.1K 10123/2017 10/23/2017 0.50 PROD3 DRILL WPRT P BHA wiper, stacking, PUW=43K, recip 12,798.0 12,796.0 20:54 21:24 for second BHA wiper 10/23/2017 10123/2017 0.30 PRODS DRILL DRLG P 12798', Drill, 1.72 BPM @ 5350 PSI 12,798.0 12,809.0 21:24 21:42 FS, BHP=4335 10/23/2017 10/23/2017 0.40 PROD3 DRILL WPRT P 12809, pull 300' wiper, PUW=56K 12,809.0 12,809.0 21:42 22:06 1012312017 10/23/2017 1.00 PROD3 DRILL DRUG P 12,809 Drill, 1.79 BPM @ 5515 PSI 12,809.0 12,838.0 22:06 23:06 FS, BHP=4260, Multiple small pick UPS 10/23/2017 10/23/2017 0.20 PROD3 DRILL WPRT P Pull BHA wiper, PUW=42K, 10 BBI 12,838.0 12,838.0 23:06 23:18 beaded pill down coil 10/23/2017 10/24/2017 0.70 PROD3 DRILL DRLG P 12,838', Drill, 1.8 BPM @ 5515 PSI 12,838.0 12,864.0 23:18 00:00 FS, BHP=4332 10/24/2017 10/24/2017 3.20 PROD3 DRILL DRLG P Continue drilling from 12,864', CWT = 12,864.0 13,000.0 00:00 03:12 -4K, WOB = 1.5K, annular = 4289 psi, WHIP = 462 psi, reached TD at 13,000', PUW = 34K 10/24/2017 10/24/2017 0.90 PROD3 DRILL WPRT P Pump sweeps, chase to window 13,000.0 10,470.0 03:12 04:06 10/24/2017 10/24/2017 0.20 PROD3 DRILL DLOG P Obtain SBHP, bit depth = 10,470', 10,470.0 10,470.0 04:06 04:18 sensor TVD = 6103', annular drops to 4063 psi, EMW = 12.8 ppg 10/24/2017 10/24/2017 1.70 PROD3 DRILL WPRT P Continue wiper to swab 10,470.0 -78-0- 8004:18 04:18 06:00 10/24/2017 10/24/2017 2.00 PROD3 DRILL WPRT P RBIH 78.0 10,238.0 06:00 08:00 ' 10/24/2017 10/24/2017 0.30 PROD3 DRILL DLOG P Log 1<1 for -13'correction 10,238.0 10,281.0 08:00 08:18 10/24/2017 10/24/2017 1.60 PROD3 DRILL WPRT P Continue RIH, clean down, confirm TD 10,281.0 13,010.0 08:18 09:54 at 13,010' 10/24/2017 10/2412017 0.90 PROD3 DRILL DISP P Lay in 13+ ppg liner running pill to 13,010.0 10,490.0 09:54 10:48 window, log RA for +4.5' correction 10124/2017 10/24/2017 1.10 PROD3 DRILL DISP P RBIH to TD pumping .3 bpm 10,490.0 13,010.0 10:48 11:54 (gathering data on liner running pill as requested), RIW improved, PUW = 38K Page 15/18 ReportPrinted: 11/112017 uperations Summary (with Timelog L,epths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log S1eaThe End rime DWM Phase Op Cade ANvey Code rime P -T -X Ope�etion Sten DVM MW Depth MS)10/24/2017 10/24/2017 2.00 PROD3 DRILL DISP P POOH pumping just over pipe 13,010.0 78.0 11:54 13:54 displacement to window (.3 bpm), then bring KWF to surface as normal, paint EOP flags (for 1 or 2 liner runs as requested), flow check well, good 10/24/2017 10/24/2017 1.60 PRODS DRILL PULD P PJSM, LD BHA #13, bit came out a 2- 78.0 0.0 13:54 15:30 2 10124/2017 1024/2017 4.10 COMPZ3 CASING PUTS P Prep to run liner, PJSM, PU L1-02 0.0 2,508.0 15:30 19:36 liner (Non -ported bullnose, 3 pups, 63 jnts slotted liner, & shorty deployment sleeve), "Installed safety joint for crew change - Safety joint drill 10242017 10/24/2017 1.00 COMPZ3 CASING PULD P PU BHA #14, Liner Running BHA, 2,508.0 2,576.0 19:36 20:36 swap out upper checks, inspect pack offs- good, stab on bump up, set counters, tool test good, EDC is closed. 1024/2017 1024/2017 1.40 COMPZ3 CASING RUNL P RIH pumping 0.7 bpm, using red and 2,576.0 10,370.0 20:36 22:00 green flags. 10/24/2017 10/242017 0.20 COMPZ3 CASING DLOG P Tie into red flag for -15' correction. 10,370.0 10,355.0 22:00 22:12 10/24/2017 1024/2017 0.40 COMPZ3 CASING RUNL P PU 42 k lbs, -11 k WOB, continue to 10,355.0 11,598.0 22:12 22:36 RIH. 10/24/2017 10125/2017 1.40 COMPZ3 CASING RUNL P SD@ 11,598', CT -6 k lbs, WOB 4 k 11,598.0 11,751.0 22:36 00:00 lbs, Pick up, PU Wt 49 k LBS, WOB - 22k lbs. Work pipe I liner toward bottom with multiple pick ups, 50 plus 10252017 10/25/2017 1.50 COMM CASING RUNL P Continue to work liner to bottom. One 11,751.0 12,458.0 00:00 01:30 good run from 11,688' to 12,115' at 60 fl/min. Work pipe, 13 PU's and a a good run from 12,115'-12,459', Work pipe, multiple Pi lost ground to 12,197'then RBIH to 12,458' 10/25/2017 10252017 0.50 COMPZ3 CASING RUNL P Injector noise, possible slipped chains, 12,458.0 12,474.0 01:30 02:00 bit depth 12,440', 9864' form core — (01:31). Continue to work liner slowly to bottom. 10/25/2017 1025/2017 2.00 COMPZ3 CASING RUNL P Continue to work liner slowly to 12,474.0 12,612.0 02:00 04:00 bottom. 2 am to 3 am averaged 74 ft/hr 3 am to 4 am averaged 6 It/hr then made 43 feet in 2 m 10/25/2017 10/25/2017 0.50 COMPZ3 CASING RUNL P Consult with town, made 43 feet in 2 12,612.0 12,592.0 04:00 04:30 minutes while conversing 12,656'. Continue to work liner to bottom. Tried a longer pick up 10/25/2017 10252017 0.50 COMM CASING RUNL P Struggle to get back down to depth of 12,592.0 12,666.0 04:30 05:00 12,656 for— 35 min. Worked liner 10125/2017 10/252017 2.50 COMPZ3 CASING RUNL P Continue to work liner. Discuss with 12,666.0 12,750.0 05:00 07:30 town, attempt longer PU's (>50'), pumping pipe displacement down backside, then RIH faster. Begin to pump down the backside, closed choke, holding —250 psi WHP while RIH to decent effect. Continual PU to gain footage Page 16118 Report Printed: 11/1/2017 . ,LL Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time EM Time Dur(hr) Phase Op Code Activity Code Time p-T4 Operation start Depth (aKB) End Depth(WB) 10/25/2017 10/25/2017 2.20 COMPZ3 CASING RUNL P Continue to work liner from 12,750', 12,750.0 12,800.0 07:30 09:42 difficulty working past 12,750', gel by, difficutly working past 12,785', get by, difficutly working past 12,800' 10/25/2017 10/25/2017 2.00 COMPZ3 CASING RUNL P Continue to work liner from 12,800', 12,800.0 12,812.0 09:42 11:42 line back down coil, attempt various speeds from 50 fpm down to 5 fpm, - attempt picking up slack to just below breakover weight & feathering in, attempt coming up to diffent depths before RBIH, attempt pumping down the back side, attempt sling shoting coil, continue to have difficulty passing 12,800- 10/25/2017 10125/2017 1.70 COMPZ3 CASING RUNL P Continue to work liner from 12,812', 12,812.0 12,833.0 11:42 13:24 difficulty working past 12,833' 10/2512017 10/2512017 0.10 COMPZ3 CASING RUNL P Confer with town, decison made to 12,856.0 10,325.0 13:24 13:30 pump off liner, tie in, await used mud arrival to rig, pump 50 bbl mud down coil, follow with 50 bbl seawater, bullhead 30 bbl of seawater down the backside to push mud into OH, latch back on with GS, continue to work liner. Pumped off liner 10/25/2017 10/2512017 2.70 COMPZ3 CASING WAIT T PUH to lie in, tie in for +28' correction, 10,325.0 10,100.0 13:30 16:12 putting BOL at 12,861', TOL at 10,329, — Obtain SBHP, pressure = 4128 psi, TVD at sensor = 6201 psi, EMW = 13 ppg, wait on used mud from 1B-Pad. 10/25/2017 10/25/2017 2.80 COMM CASING DISP T Begin pumping 50 bbl PowerPro down 10,100.0 10,100.0 16:12 19:00 coil, follow with 50 bbl of seawater, displacing KWF to surface 10/25/2017 10125/2017 0.40 COMPZ3 CASING DISP T 10,100.0 10,325.0 19:00 19:24 10/25/2017 10/25/2017 0.60 COMPZ3 CASING TRIP T Line up pumps to the coil, RIH, pump 12,856.0 12,856.0 19:24 20:00 - 5 bbls seawater out the coil while RIH and latch up. Down on pumps, PU 65 k lbs, no movement - 20 k WOB. Line up down the back side, RBIH, set down -3 k lbs Ct Wt. 10125/2017 10/25/2017 0.20 COMPZ3 CASING RUNL T Work pipe, Ct Wt -11 to 60 k lbs , 12,856.0 12,856.0 20:00 20:12 WOB from 8 k lbs to -20 k lbs while pumping min rate down the back side against a closed choke. RIH / PUH rate 25 to 75 ft/ min. Consult w town. Pumped - 20 bbls total seawater down back side out of planned 30 bls. 10/25/2017 10/2512017 0.10 COMPZ3 CASING RUNL T Line up down the coil, stack 4 k WOB, 12,856.0 10,314.4 20:12 20:18 PU, 26 k lbs, released and left liner ( 2531.21) on bottom. Best corrected depth putting BOL at 12,861', TOL at 10,329, 10/25/2017 10/25/2017 2.90 COMPZ3 CASING DISP P Displace well to seawater while 10,314.0 48.0 20:18, 23:12 POOH. Pump 30 bbls to the coil for FP, lay in from 2500' and to surface. 10/25/2017 10/26/2017 0.80 COMPZ3 CASING PULD P Bump up, PUD BHA # 14 10,314.0 48.0 23:12 00:00 Page 17/18 ReportPrinted: 111112017 a ; Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Cur(hr) Phase Op Code Activity Code Time P44 Operetlon Dth 5 MMIM ) End nepm(ttKB) 10/26/2017 10/26/2017 0.70 COMPZ3 CASING PULD P Continue to PUD and UD BHA #14. 48.0 0.0 00:00 00:42 10/26/2017 10/26/2017 1.30 DEMOB WHDBOP MPSP P Pull QTS, up valve crew lubricator, Set 0.0 0.0 00:42 02:00 BPV, UD lubricator "" Well head 1,420 psi under the BPV. 10126/2017 10/2612017 1.00 DEMOB WHDBOP CIRC P Reinstall QTS, jet stack, install night 0.0 0.0 02:00 03:00 cap. Blow down steam lines. Blow down surface lines. 10/26/2017 10/26/2017 1.00 DEMOB WHDBOP RURD P Complete blow down of lines, pull 0.0 0.0 03:00 04:00 night cap, vac down stack, add MetOH to stack above BPV. Called DTH to remove TT hard line. reinstall night cap and attach slings for BOP storagettravel. 10/2612017 10/26/2017 1.00 DEMOB WHDBOP NUND P Nipple down BOP stack, check tree 0.0 0.0 04:00 05:00 flange bolts. ""Rig Release @ 6:00 AM 10/26/2017 10/26/2017 3.50 DEMOB WHDBOP RURD P RDMO, PUTZ, etc, continue to work 0.0 0.0 05:00 08:30 -19997B ' RD checklist 10/26/2017 10/26/2017 2.50 DEMOB P NES trucks arrive at 2K -Pad, PJSM, 0.0 0.0 08:30 11:00 - dg up sows to pits & sub, load up shop & 1/2 way house, move off 2K -Pad Page 18/18 ReportPrinted: 11/112017 r ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K -04L1 50-103-20099-60 Baker Hughes INTEQ Definitive Survey Report 25 October, 2017 jF (ER a GE company ConocoPhillips B'rrucHES 0 ConocoPhillips Definitive Survey Report Company: ConowPhllllps(AlaSka) Inc. -Kup2 pro(ea: Kuparuk River Unit Sim: Kuparuk 2K Pad Well: 2K-04 Wellbore: 2K -"L1 Design: 2K -04L1 Project Kupamk 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 Local Cmordinate Reference: Wall 2K-04 TVD Reference: 2K-04 @ 154 Damn (2K -D4) MD Reference: 2K-04 @ 15400usft (2K-04) North Reference: True Survey Calculated Method Minimum Curvature Doetatee: EDT Alaska Suncook Well 2K-04 Longitude: 150° D' 49.136 W Well Position >•Ni 0 00 usfl Northing: (1) .IS -W 0.00 u5ft Ea4ing: Position Uncertainty 000 usft Wellhead Elevation: Wallbore 2K-NL1 lush) (1) Magnetics Model Name Sample Data 000 BGGM2017 13500 10/14017 Dealgn 2K-0411 Date 101252017 Audit Notes: from Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,936.525A6usft 498,310 06usn usfl Declination 19 1730 Latitude: 70° 14 35784 N Longitude: 150° D' 49.136 W Ground Level: 118.50 us% Dip Angle Field Strength (1) ren 8084 57,474 Version: 1.0 Phase: ACTUAL Tie On Depth: 10,40000 Vertical Section: Depth From (17.9)) s•Nl4i aE/-W Moisten (mal (usft) lush) (1) 35.50 000 0.00 13500 Survey Program Date 101252017 from To Survey Sunday (usft) (mal Suney(Wellbars) Tool Name Description Start Dam End Date 200.00 1040000 2K-o4(2K-04) BOSS -GYRO Spent' -Sun BOSS gyro multishoi 1/1212001 10,479.00 10,54073 2K-041.1 MWD-INC(2KNL1) MWD dealStandard10)1012017 10/10)209 10,570.74 13,816.21 2K -04L1 MWD(2K-04L1) MWD MWD -Standard 1(H012017 10115)2017 f02Y201712 3227PM Page 2 COMPASS SOW 14 Build 85 ✓ ConocoPhillips 9 ConocoPhilli s p Definitive Survey Report Company: ConocDPlulhps(,kni Inc.-Kup2 Local CoarC{nate Reference: Mil 2K-04 Project Kuparuk River Unit TVD Re mnce: 21K -04@154.01(2K-04) Site: Kupamk 2K Pad MO Reference 2K-04®15000uaR(2K-04) Welt. 21( 4 North Reference: True Williams: 2K64L1 Survey Calculation whe6: Minimum Curvature Design: 2K -04L1 Oataaaae: EDTAIaska Sandbox Survey Map Map WoRmil MO Inc Pzi TVD TVDSS +NI .vm Nontim, Enron, DLS Section Survey Tool Name lush) ) (1) CI 111 (usN) (-am NaRI la) IN) 1.1100') nt) 10.40000 6397 312.90 4091.16 5,940.16 3,53860 6,911.51 5,942065.46 49"Alro3 360 -7.38949 MWD (2; 10.47900 6.14 305.61 1.10 5,97410 3,612.98 $96.78 5,942,100.61 491,34160 169 JAW NMI 10,51012 71 259.50 6,1.4.81 5,90501 3.59583 6.99160 5942,iZ2.4] 491,316.M Vol -0,46.55 12 (2) 10,510.]3 8124 2946 6.148.6 5.992.66 3,86.6 -],020.62 5942135.65 491,250.95 36.81 -7,51619 MWII(2) 1057074 9101 28009 6,14089 Semen 3619.6 -7,041 5,942,148.40 4912613 W71 -7,543.59 MIND (3) lo,8W61 9].6 27820 6,148.78 5,91 3826.Bo -7,0]]36 5,91215348 491,234.23 40.]6 -],5698 NAM (3) 10,616 IS 85 282.99 0143.34 59634 3.82].13 -7,107.55 5,94215382 /91,212.01 50.00 -7,550.66 MWD(3) 10.63087 W42 N9.0 0140.6 59666 3,620.20 -7,138.32 5,9Y1,1as oo 491,17526 4381 -7,66.01 MWD(3) 10,6906 Q 236.50 0138.78 5984.]6 3,695.8] -],162.]5 5,942.133.57 491,148.& 45.47 -0,6152] MWD(3) 10,]20]0 6.00 =62 8,138.52 5,984.52 3,6740 -7,10559 5,942.114.11 491125.6 40.6 -7,61765 MMAD(3) 10,750.6 00.6 2%25 6,130.6 5.90463 3,562.94 -7,202.99 5,94200085 491,16.59 40.6 -7,6126 MAR) (3) 10.780.6 632 19702 6.IM79 5,904.79 3,535.13 -7,21459 5,84206195 191.09698 3751 -].6120 MAR) (3) 10.807 99 6.79 1683 6,139.00 5.905.00 3.608.74 -7,220.16 5,942,03547 191,09141 3].]7 -7,5648 MJaD(3) 10,8416 9203 1]4.5] 6,130.18 Safe '16 3475 71 -7,220.67 5942,0OZN 191,000.98 376 -7,551,41 NAND (3) 1087129 9193 1690 8,13740 5,96 .10 3.446.05 -7,21520 5941,972.76 191095.6 326 -7,538.61 MWD(3) to aloo26 9101 15039 8,136.59 5902.59 3,41688 -],205.45 5.94194341 491,16.10 21.21 -751090 MID (3) 10,9316 6.85 101.89 6,136.6 5,962.38 3,3640 -],1516] 5,911,91613 491,117.07 12.41 -7,481 MVA(3) 106221 6.32 1635 6,1MM 5,62.6 3,36257 -],179.]7 5,921,86.51 491,13176 15.12 -7,454.56 Men) (3) 10,00336 655 148.14 6,137.16 5,96.18 3,33580 -7,16.6 5,941,62.53 491,1476 751 -7,42437 Moll 11,M37 6.13 118.6 6,138.6 5,98403 3,31053 -0.1476 esi X 491,166 512 -7,3956 1001 11,6213 W]1 14].6 0138.32 5,984.32 3,2634 -0,132.14 5.94181307 491,1]9.3] 9.92 -7,36.90 MWD(3) 11,6239 9135 146.49 6,13778 5983.]8 3,260 92 -],115]5 5.941787.6 491,195.78 5.6 -7,33741 M Tb 1111218 9.25 TdiM 6.13736 5.96 .36 3,3.'6.26 -7,09.6 5,941,]&1.01 49121240 5.64 -],36.1] Mv4D(3) 11,14253 9123 1456 0.19.97 6.982.97 3,211.32 -7,00165 5,941,]]86 491.22984 321 -7,278.23 MWD(3) 11,1627 6.32 141.53 0135.87 5,98287 3,195.23 -7,070.31 5,91181 .0 491,241.10 106 -726.83 MAID (3) 11,19321 07.33 141.9 6,13].]0 5,9678 317046 -7.051,79 5,941.59].19 491,25989 106 -7,22022 MAD(3) fl,222.]9 0].9 14026 6.13916 5,905.16 3,14748 -],63.23 5,9416]4121 491,27&24 5.54 -7,19884 MMD(3) 11,252.0 612 13635 6,14081 5,9681 3124.99 -0,013.20 5,941,85171 491,2926 13.W -].16]9 ARMS (3) 11,262.9 8579 133.89 6,14285 5,96.65 3,103.74 8,92.0] 5,94189.16 49131938 013 -7,138.82 NAM) (3) 11,312.6 659 13210 6,144.82 59982 3,083.51 $97042 5,941,61023 491.31103 690 -7,109.20 WD (3) 1011?/ 17123227PM Pape3 Nvrotation TIP NOP IntamoiateEfMmorth Interpelate6Azimulh First Clean Survey COMPASS 506014Jibed 86 ConocoPhillips ConocoPhillips Definitive Survey Report Company. ConocoPbillips(AWska) Inc. -Kup2 Local Cocrclii Reference: Mil2K-04 Pro)eot Kuparuk River Unit WD Reference: 2K-D4®15400us6(2K-04) Stx,'. Kupamk 2K Pad an Reference: 2K-04 @ 154.00ush(21K-04) Well. 21(4)4 North Relerenu: Tri Wellbore: 2K -04L1 Survey Calculation MaMa6: Minimum Cerv8W1a De519R. 2K-0411 Database: EDT Alaska Sandbox 1015201712: 32 27p Page 4 egµ¢x WREs 2Nlnotetron COMPgSS 5000.14 9.1085 Map Map wit a it MD tyMll IM 11I mTMD 1°1 Want lueRl Tai NWS lusRl NFJ-W ival4l R°led EaState,State,VMOOI) OLS season survey Toni Rano M N (R) 1134261 8.07 12965 6.146.53 5992.53 30639] {,928] 5,941,5$0.69 491,363.81 8.23 -0,07941 MWO (3( 11,3]245 81.18 127.79 OWN 6,90.8 3045.33 4,924.58 594157203 491,365.85 631 -],049]9 MJA(3) 11,403.0 80.59 126.30 614992 5.995.22 3,0665 Swi 5,941,553.36 491,41158 661 -7,01910 MWD(3) 11.435.32 9012 IN 17 614950 5,995.50 3007.83 -,87415 5,941,534.53 491,437.27 AN 4,981.62 MWD(3) 1146238 91.93 124,n 6.149.10 5,995.10 2992.14 $85211 5.941,51684 491,45930 8.57 -,961.94 MWD(3) 1149269 9145 12399 6,149.20 5,994.20 2,975.04 -SN7AO 5,941$01.74 491.404.31 208 6,931,16 MNIJ(31 1152220 91.75 12185 8,147.38 5, 3.38 2959.97 6,0@37 5.941,485.65 491509.13 7.27 6,932,24 MJu➢(3) 11,55270 82.49 11(1.09 614636 5.99235 294332 4778.21 5,941,47001 491,535.19 630 4072.75 MM (3) 11,585.25 93.56 118.01 6,14453 5990.53 292734 4,747,91 5,941,454.02 491,563,48 5.12 -,84143 MWD(3) 11,619.19 91.'6 118.% 6,14252 591 2911.59 4,71702 5,941439.25 491,593.48 642 Saba 08 MWD (3) 11.00.27 WAS 11446 6,141.04 5,90704 2,898.19 4,689.92 6.941,40606 491,62146 784 6,779.81 MM (3) 1169515 9132 11149 6139.98 5,9096 2881.50 4,65782 5.941.411.24 491,653.55 8.06 6,74707 MWD(3) 11,71165 9193 11062 6.139.23 5,965.23 2.675.07 4833.10 5Ixl 1]2 491,67827 3.94 6,8319 MbD(3) 11,742.5 NO3 109.41 8,138.17 5,91 2,88149 460.09 5,941,391.14 491,29726 384 SON 29 MND(3) 11,78.65 65.91 165.95 613766 5907.60 28507 4,575.48 5,941,381.n 491,73590 1076 ANSAO MWD(3) 11,802.73 WS 106.73 6,137.52 598.52 2846.37 -6.0771 5,9413730 4917064 226 -,64191 MWD(3) 11,032.5 9141 18.05 613700 5.9800 283702 4,51843 5,941383.65 491.792.92 10N A61530 MWD(3) 11.896.59 91.67 11512 6,139.03 5,9028 2,82400 -.48698 5941,350.84 491,824.36 15.5 6,583.86 MWD(3) 11,89459 93.15 11666 6,13553 5,98153 201190 446180 5,941,338.41 491,64954 8.24 455741 M✓vD(3) 11,@25 9120 12161 6,13520 5.981.20 2,78.15 6,437.35 5,941,324.70 491,87398 1807 46]0.49 MVD(3) 11.95283 aSO 12510 SINN SUN 99 2,78151 4,41211 5941,308 13 491 12.0 450287 MYrD(3) 11,9800 80.8 12920 8,135.38 5,981.30 2,764.51 4389.73 5,941,291.13 491,92159 14.0 -,4738 MM (3) 12,01412 8.47 131.94 6.136.10 Sam is 274271 -,364.74 501.289.32 491,946.57 1108 4439.94 MWD(3) 1202.81 SO 14 1P.16 6136.75 5,982.75 28255 -ami 5.906.249.18 491,965.60 1493 6,41146 "D (3) 12(48 8813 IN" 6,137.52 SON 52 26M Sit 6,323.09 5,94192525 491,965.21 609 4,379.33 MWD(3) 12,101.86 89.92 13861 6,136.69 5,984.89 2,67832 6.305.26 5,941,M193 492065.03 45 4,35235 MWD(3) 12.133X7 0Set 13711 6,140.65 5.9011.07 2,855.13 4284.27 5.01 ,181.73 492,02701 5.02 -,321.11 MND(3) 12,16195 MIN 13530 614206 5,988.07 264.42 4284.44 5.01161.( 492,046&1 630 em.11 mvi 12,19507 W45 13502 6,144.97 5,%0.97 261067 4240.86 5,94113726 492(041 641 4258.97 MM (3) 12.23.29 N71 1..48 6,145.90 59919.4 259111 4,221.13 5.941117.71 492093]3 493 -,231X1 MWD(3) 12,25145 69M 132.65 6146.30 5992.30 29171 6,200.73 50109030 49211053 7.32 6.20305 MWD(3) 1015201712: 32 27p Page 4 egµ¢x WREs 2Nlnotetron COMPgSS 5000.14 9.1085 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConacoPhllllps(Alaska) Inc.-Kup2 Local CoSMinate Reference: Project Kuparok River Unit ND Reference: Sire: Kuperuk 2K Pad Mo Rafe....: Well: 21K-04 North Reference: Wellbore: 211 Survey Gl[ulallon Metal Oealgn: 2K -04L1 Database: Survey MR 2K 2K-04 @ 154.001(21< 4) 21K-04 @ 154.00ue8 (21<64) TNG Minimum Curvature EDTAlaska Sandbox 10Q6201712,32:27 M Pegs 5 SR a I IIGIffS Annotation COMPASS WOO 14l iltl 85 Map kWF Ver l MD (.an) Inc (°1 Aal TVD TVDSS .NIS +El Eaetl.9 DO ection SSurvey Tool Nam. 1°1 luae) Nall (-am (oast))admitting lel 011) (-nal Irtl 12.281 AS 90.15 131.62 6,146.35 5.902.36 2 m 31 81]6.18 5941,0]].90 492,1330] 375 4x1866 MWO(3) 123138] 8]]0 131.13 0,146.96 5wa96 ;530.16 6,154.17 5,941,056.74 492152.00 7,81 $,14074 evvK)RR 1234339 8542 131.71 8,148.]3 6994.23 Si 4132.07 5,941,60].25 49218.16 ].9] 6,11134 sivi 12,372 47 64.25 13049 0,15134 5,887 34 249162 6,11025 5.941,010.20 492,200.90 am 8,082.44 MR) 12,402.25 53.60 12850 6,154.46 6,000.98 2,47.79 6,08]40 5,940,999.37 492,22363 692 8052.97 all (3) 1243232 62.8] 12650 8,150.60 SON IS, 2454.59 -6,063 72 5,960,901.17 492247 50 6.69 802336 del (3) 12.4618] 52.M 12516 6.161.75 8,00].]5 2437,42 80399] 5960,903.99 492,27124 4.90 5,994.42 60023(31 12,49237 8249 12736 6.16592 6,o11Y1 2419.% 8,01557 5,840,960.12 492ma" 683 6.99453 MWD(3) 12,625.97 84.19 129.04 6,189.74 6,015.74 2,30833 -swam allool246 492322.65 209 -5,933.42 eRVl 12,5508 85.41 13316 61]190 6,017.93 2,383.11 5.97035 5,skinte 6 492.340.04 883 -5,8'6.29 MWO(3) 12,58557 as,% 13248 6,17423 6,020.21 Swed] 5,911.41 5.990.88363 492,238]] 0.53 5,8715 Real (3) 1261236 8.11 13525 6.17553 6,02183 234153 5,925.12 5.960.6688 49238606 10.35 5,845.40 "D (3) 1264260 85.71 13].]5 612].20 eacom 2319M -5904.34 5940.&6.10 492,406.83 8.36 881522 Won (3) 12,01 84.68 13659 6,17855 0,02555 2286.98 -580400 5484IMM 49242].60 7.21 5,]0489 Iffim ) 12,701.13 86.69 141.58 6,18166 8,027.60 227553 -Sal 5,940,802.08 492445.0] 1279 -5,75202 sival 12,]322] 850] 144.39 6183.90 6,029.90 2,250.8 5,04743 5,940 SO 482463.72 1023 -5.]'8.2] Sell 122821] 9323 145.57 6, Issas 6,032.95 2,22638 S.83da6 597,752.92 492,400.70 230 -5896.97 Ronald (3) 12,N2 39 aim WAS 6190.83 6,036.81 2201.53 5,81361 5,940.780] 492,49253 5.04 -5,60].56 MWD(3) 1282233 8.8 14689 61107 5.041.50 217681 -5,797.37 5940,703.32 492,513.]6 250 5,830.61 M✓vD(3) 1205233 7891 14902 6,20112 6,047.12 215183 -5,]01.]0 5840684] 492,529.34 256 5,609.90 MND(3) 1266456 008 15126 0,206.82 6,052.82 2128.31 -576593 a04a,wass 492545.16 898 -5,58.24 anal 1281281 82.61 15394 6,21090 6.056 so 206051 5]5309 5,040020.05 492558.02 11.36 -555[82 Rana (3) 129428 &47 team 6214.27 6,[62] 2,07250 877.563 5.940.59904 492,5]054 999 -5,524.68 MWD(3) 12,97481 95.8 15839 621700 Som of 2,043.05 5728.21 5,940,$69.59 491,58282 7.85 5,49515 MO (3) 13,603.10 8932 16245 6.21821 6,044.21 2,01643 -5.216.00 5,940,542.9] 4$592.20 19m 5.45963 all (3) 13031.65 M45 164.11 5.210.55 6.069.55 1,amm -5,299.62 5,940,512.56 49ttle0i 5.24 -5,44187 AM (3) 13,02.33 0012 108.80 6,21866 acal 1,969.42 -5,]02]8 5.940486.97 492800.29 1023 -5,41299 All 13.60612 92.15 123.23 6,21295 6,06395 1,92420 5699.59 5,940,45074 4928741 18.13 -5,360]1 MWD(3) 13.130.00 89123 1]4.39 6,21255 6063.55 1892.51 5.693.15 5,940,41806 492,61290 968 -5.360.60 MD (3) 13,16132 Sol 182] 6210.20 SON 28 1,00131 -,69080 5,940,307.85 492,620.45 221 5,340.01 MJJD(3) 13.19357 85.85 17594 6,m,= SON SO 108.18 5.60.9.41 5,940355.8 492,622.83 607 5.31524 evi(3) 10Q6201712,32:27 M Pegs 5 SR a I IIGIffS Annotation COMPASS WOO 14l iltl 85 .� ConocoPhillips 13FJ4 O corloi Definitive Survey Report DCf1ES Compel ConoccPhillips(Alaska) Inc.-Kup2 Local Coominete Reference: Well 21K-04 Project: Kupamk River Und ND Reference: 2K-"(0154.00usR(2K54) Site: Kuperuk2KP8d MO Reference: 2K-04@154.00usR(2K-04) Well: 2)(4 North Reference: True WaIICme: 2K -"Lt Survey Calculation Needed: Minimum Curvalum Deepn: 2K-0411 Datawl EUTAlaska Sandbox ' Survey 1025201712: 32 27M Pepe 6 COMPASS 500714 Balm 85 Map Map Vertical MD Inc I°I Ari (°) ND TVD33 +WS +El4N NortMng Same, DLS Section Survey Tool Name Annotator, loan) def) (bell IasRl IR1 (ft) IRI lot 13M 35 83.45 176.17 6,=77 6,W 77 1.799.60 -5,685.37 5W0,326.1fi 492,62466 810 -6293.38 MWD (31 13.MM 0308 178,76 6,2.'5.31 60]231 1,76 1 5,66505 5,94085.27 492,625.98 11,82 5,271.31 MKD(3) 13,203.16 85.24 179.8 62833 6.075.33 1j40.19 S,fi".53 5,940,29575 492,626.49 T" -5.250.07 MWD(3) 13.310.95 Sol 18080 &231.8 6,077.22 1,71247 5,604.54 5940,239.03 4926'$48 8.32 -5.230.47 MAD (3) 13,341M 91.11 18169 6,23174 6.07774 1,602.8 5.60519 5940,20878 na?.M81 14.12 521).55 MIND (3) 13,3718 93.44 18300 6.M 55 6076.55 1,65220 -5,611 5940.17877 492624.56 9.02 5189.8 MWD(3) 13.1018 M07 18538 6,228." 607404 1,68.33 -5,E98.85 5,910148.93 492691.34 775 5,1W65 all (3) 13,43576 9.55 low 6,226.55 Sol 158830 5,693.52 5,91011489 49z91>47 1654 5,14902 MWD (3) 134".01 95.63 150.50 ebbaW 6.070." 1,530.61 5,898.65 5,90007.19 492.812.33 477 -5,133.07 VIAL 13.490.8 A4.24 19265 681.33 6,06]33 1,535" -570379 5940,05182 49260710 9.9 -5,11862 NN D(3) 13,53303 Seen 1997 6.2118 61063.8 1.49369 -5,71395 5.907.08.28 19{59701 661 6Mse deem (3) 13, 564.49 94 19702 6,214.72 Sol 1,463.55 -5,M.59 5.939.593.15 49258937 651 6)01.37 "0(3) 13,59577 93.44 200 So 8,21248 6,058.40 1.43 .9 6,]31.70 5,M,oa.65 492578.25 1277 5.06765 MWD(3) 13,624.17 918 Mae 6211,M 6,057.33 t.40.36 -5742.33 5,939,933.05 492,558.62 10.39 5.055.59 MJUD(3) 13.500.32 89.39 19&85 621114 8,05714 1,373.13 5,763.96 5039.Bl 49255698 507 -5,08.81 MWo(3) 13,89921 8773 199.93 6,21187 6,057.07 1,3587 6763A 5,939.87249 492,54l 725 6.027.08 ever, (3) 13,71806 07.9 8180 6,213.44 6,059.41 1,31897 -5,77378 5,93,"5.59 492537.16 894 5015.33 MWD (3) 13,74&47 "50 8328 6,215.90 Gam 90 1,29.97 -5,78641 5,93,"7.50 492525.52 6.50 -5,00376 IMM (3) 1377849 83.&5 20518 6,21&70 Got 70 1,265.55 57%.85 5,MINU 18 49251400 7.43 -0,99387 NNAll 13,801.63 W05 26810 68195 6.057.% 1,24035 6,806.% 5939.767.60 49250196 5.01 4,904.62 MWD(3) 13,816.21 Win, 8740 6,923.47 6.069.47 1,23011 6,81414 5,939,751175 4@p0]8 12" 4,9819 MWD(3) 13,&5220 02.18 37.48 6,8833 6,07434 I'losi -5.83050 5,939]25.30 492,483.41 000 4,970.37 PROJECTED to TO 1025201712: 32 27M Pepe 6 COMPASS 500714 Balm 85 BA ER 0 PRINT DISTRIBUTION LIST F UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 2K -04L1 RECEIVEL FIELD Greater Kuparuk Area NOV B q 2Q17 COUNTY North Slope Borough C BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider(obakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX HALL NOT DEL]WR TO P.O. 90X) PERSON ATTENTION V BP North Slope. EOA, PBOC, PR&20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 v- 21 7126 CD/DVD FINAL 28776 PRELIM LOGS (las, dlis, PDF, META, e sign and return one copy of this transmittal form to: IcoPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) DATA LOGGED 3 Street. \\ /9 /201-T forage, Alaska 99510 M. K. BENDER LOG TYPE GR - RES LOG DATE October 24, 2017 TODAYS DATE November 7, 2017 Revision Details: Rev. Requested by: --- FIELD I FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES l#OFGOPIES Ij lu 4 4 4 a 2 ConocoPhillips Alaska Inc. 0 O O O O Attn: Ricky Elgarico A'10 708 700 G Street Anchorage, AK 99510 3 Exxon Mobil. Alaska Q Q Q 0 Q Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC 0 1 1 1 O Alto: Makana Bender 333 W. 7th Ave, Suite 100 .Anchorage, Alaska 99501 5 DNR - Division ofOil & Gas #e* 0 0 1 1 O Ann: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 `... Stamp "confidential" on all material deliver to DNR 6 BP Exploration(Alasks) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 0 1 1 1 1 1 1 0 TOTALS FOR THIS PAGE: 0 2 3 3 0 ConocoPhillips RECEIVED NOV 0 9 2017 AOGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K -04L1 Baker Hughes INTEQ Definitive Survey Report 25 October, 2017 BAd(ER UGHES a GE company 21 71 26 28 776 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kupamk 21K Pad Well: 2K-04 Wellbore: 2K-04LI Design: '2K-041_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 ConocoPhillips 2K-04 Definitive Survey Report Depth From (TVD) Local Co-ordinate Reference: Well 2K-04 TVD Reference: 2K-04 @ 154.00usft(2K-04) MD Reference: 2K-04 @ 154.00usft(2K-04) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT Alaska Sandbox Mean Sea Level Longitude: Using Well Reference Point Using geodetic scale factor Well 2K-04 Depth From (TVD) +N/ -S (usft) Well Position +NI -S 0.00 usft Northing: 5,938,525.46usft Latitude: (usft) +E/ -W 0.00 usft Eas0ng: 498,310.06usft Longitude: Position Uncertainty 21K-041_1 MWD (21<441-1) 0.00 usft Wellhead Elevation: usft Ground Level: Wellbore 2K -04L1 Magnetics Model Name Sample Date Declination Dip Angle Design Audit Notes: Version: Vertical Section: Survey Program From (usft) 200.00 10,479.00 10,570.74 EGGM2017 2K -04L1 (1) (`) 10/1/2017 17 30 80.84 1.0 Phase: ACTUAL Depth From (TVD) +N/ -S (usft) Direction 35 50 (usft) Date 10/25/2017 To (usft) Survey(Welibore) 10,400.00 2K-04 (2K-04) 10,540.73 21K-041_1 MWD -INC (2K-04LI) 13.816.21 21K-041_1 MWD (21<441-1) 70° 14'35.784 N 150° 0'49.136 W 118.50 usft Field Strength (nT) 57,474 Tie On Depth: 10.400.00 +N/ -S +E/ -W Direction - (usft) (usft) (1) 0.00 0.00 135.00 Survey Survey Tool Name Description Start Date End Date BOSS -GYRO Sperry -Sun BOSS gyro multishot 1/12/2001 MWD MWD - Standard 10/10/2017 10/1012017 MWD MWD'- Standard 10/10/2017 10/15/2017 10/25/2017 12:32:27PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips 8AI(ER0 ConocoPhillips Definitive Survey Report Dy�ES Company: Project: Site: Well: Wellbore: Design: Survey ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-04 2K-041-1 2K-0411 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2K-04 2K-04 @ 154.00usft (2K-04) 2K-04 @ 154.01(2K-04) True Minimum Curvature EDT Alaska Sandbox 1012 512017 12 32 27P Page 3 COMPASS 5000 14 Build 85 Map Map Vertical -. MD Inc An TVD TVDSS *N7 -S +EI -W Northing Easting DLS Section Survey Tool Name Annotation (usft) (1) (1) (usft) (usft) (usft) (usft) ('1100') 10,400.00 63.97 304.90 6034.16 5,940.16 3,538.80 -6,911.51 5,942.055.46 491,400.03 3.60 -7,389.49 MWit(2) TIP 10,479.00 65.14 305.61 6.128.1D 5,974.10 3,579.98 -6,959.76 5,942,1 D6.64 491,341.80 1.69 -7,459.80 MWD (2) KOP 10,510.72 71.56 299.05 6,139.81 5,985.81 3,595.80 6,994.60 5,942,122.47 491,316.96 27.01 -7,488.55 MWD (2) Interpolated Azimuth 10,540.73 81.24 294.00 6,146.86 5,992.86 3,60B.88 -7,020.62 5,942,135.55 491.290.95 36.84 -7,516.19 MWD(2) Interpolated Azimuth 10,570.74 91.01 288.89 6,148.89 5,994.89 3,619.80 -7,048.45 5,942,146.48 491,263.13 36.71 -7,543.59 MWD(3) First Clean Survey 10,600.61 97.05 278.28 6,146.78 5,992.78 3,626.80 -7,077.36 5,942,153.48 491234.23 40.78 -7,568.98 MM (3) 10,631.09 95.85 262.99 6,143.34 5,989.34 3,627.13 -7,107.55 5,942,153.82 491,20404 50.00 -7,590.56 MWD (3) 10,660.87 94.42 249.96 6,140.66 5,986.66 3,620.20 -7,136.32 5,942,146.90 491,175.26 43.84 -7,606.01 MWD(3) 10,690.60 92.89 236.50 6,138.76 5,984.76 3,606.87 -7,162.75 5,942,133.57 491,148.84 45.47 -0,615.27 MWD(3) 10,720.70 88.00 222.62 6,138.52 5,984.52 3,587.40 -7,185.59 5,942,114.11 491,125.99 48.88 -7,617.65 MWD (3) 10,750.80 90.83 208.25 6,138.83 5,984.83 3,562.94 -7,202.99 5,942,089.66 491,108.59 48.65 -7.612.66 MWD(3) 05,780.98 89.32 197.02 6,138.79 5.984.79 3,535.13 -7,214.59 5,942,061.85 491,096.98 37.54 -7,601.20 MWD (3) 10,807.99 89.79 186.83 6,139.00 5,985.00 3,508.74 -7,220.16 5,942,035.47 49109141 37.77 -7,586.48 MWD(3) 10,841.09 92.09 174.57 6,138.46 5,984.46 3,475.71 -7,220.57 5,942,002.44 491,090.99 37.68 -7.563.41 MWD(3) 10,871.29 91.93 164.90 6.137.40 5,963.40 3,446.05 -7,215.20 5,941,972.78 491,096.36 32.00 -7,538,64 MWD(3) 10,90226 91.04 158.39 6,136.59 5,982.59 3,416.68 -7,205.45 5.941,943.41 491,106.10 21.21 -7,510.98 MM (3) 10,931.98 89.85 154.89 6,136.36 5,982.36 3,389.40 -7,193.67 5,941,916.13 491,117.87 12.44 -7,483.36 MWD (3) _ 10,962.21 89.32 150.35 6,136.56 5,982.58 3,362.57 -7,179.77 5.941.889.30 491,131.76 15.12 -7,454.56 MWD(3) 10,993.36 88.55 148.14 6,137.16 5,983.16 3,335.80 -7,163.85 5,941,862.53 491,147.68 7.51 -7,424.37 MWD (3) 11,023.37 88.13 146.66 6,13803 5,984.03 3,310.53 -7,147.69 5,941,837.26 491,163.83 5.12 -7,395.08 MWD (3) 11,052.13 90.71 147.88 6,138.32 5,984.32 3,286.34 -7,132.14 5,941,813.07 491,179.37 9.92 -7,366.96 MWD (3) 11082.38 91.35 146.49 6,137.78 5,983]8 3,260.92 -7,115.75 5,941,787.65 491,195.76 5.06 -7,337.41 MWD 13) j 11,112.16 90.25 145.22 6,137.36 5,983.36 3,236.28 -7,099.03 5,941,763.01 491.212.46 5.64 -7,308.17 MWD(3) f 11,142.58 91.23 145.08 6,136.97 5,982.97 3,211.32 -7,081.65 5,941,738.05 491,229.84 3.25 -7,278.23 MWD (3) 11,162.27 89.32 144.53 6,1W.B7 5,982.87 3,195.23 -7,070.31 5,941,721.95 491,241.18 10.09 -7,258.83 MWD (3) 11,193.21 87.33 141.90 6,137.78 5,983.78 3,170.46 -7,051.79 5,941,697.19 491,259.69 10.66 -7,228.22 MM (3) 11,222.79 87.30 140.26 6,139.16 5,985.16 3,147.48 -7,033.23 5,941,674.20 491,278.24 5.54 -7,198.84 MWD(3) 11,252.95 86.44 136.35 6,140.81 5,986.81 3,124.99 -7,013.20 5,941,651.71 491,298.26 13.26 -7.168.79 MWD (3) 11,282.99 85.79 133.99 6.142.85 5,988.85 3,103.74 6,992.07 5,991,630.46 491,319.38 8.13 -7.138.82 MWD (3) 11312.69 86.59 132.10 6,144.82 5,990.82 3083.51 -6,970.42 5,941,610.23 491,341.03 6.90 -7,109.20 MWD (3) 1012 512017 12 32 27P Page 3 COMPASS 5000 14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co -circinate Reference: Project: Kuparuk River Unit ND Reference: Site: Kuparuk 2K Pad MD Reference: Well: 2K-04 North Reference: Wellbore: 2K-041.1 Survey Calculation Method: Design: 2K-0411 Database: Survey Well 2K-04 2K-04 @ 154.00usft (2K-04) 2K-04 @ 154.00usft (2K-04) True Minimum Curvature EDT Alaska Sandbox BAGHER Q UES Map Map Vertical MD Inc Azi TVD NDSS +N1S +E/ -W Northing Eating DLS Section Survey Tool Name Annotation (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) ( (°)1000 (ft) 11,342.61 86.87 129.65 6,146.53 5,992.53 3,63.97 -,947.83 5,941,590.68 491,363.61 8.23 -7,079.41 MM (3) 11,372.45 87.18 127.79 6,148.08 5,994.08 3,045.33 -6,924.58 5,941,5]2.03 491,386.85 6.31 -7,049.79 MM (3) 11,403.46 88.59 126.30 6,149.22 5.995.22 3,026.66 -6,899.85 5,941.553.36 491,411.58 6.61 -7.019.10 MM (3) 11,435.32 90.12 126.17 6,149.58 5,995.58 3,007.83 1.,874.15 5,941,534.53 491,437.27 4.82 6,987.62 MWD (3) j I 11,462.38 91.93 124.72 6,149.10 5,995.10 2,992.14 -6,852.11 5,941,516.84 491,459.30 8.57 -6,960.94 MWD (3) r i r 11,492.69 91.45 123.99 6,148.20 5,994.20 2,975.04 -6,827.10 5,941,501.74 491,484.31 2.88 -6,931.16 MWD (3) i j 11,522.28 91.75 121.86 6,147.38 5,993.38 2,958.97 -6,802.27 5,941,485.66 491,509.13 7.27 -6,902.24 MM (3) I L 11552.70 92.49 120.09 6,146.25 5,992.25 2,943.32 -6,776.21 5,941,470.01 491,535.19 6.30 -6,87275 MWD(3) 1 11,585.25 93.56 118.81 6,144.53 5,990.53 2,927.34 -6,747.91 5,941,454.02 491,563.48 5.12 -6,841.43 MWD(3) 1 11,619.19 93.25 116.65 6,142.52 5,988.52 2,911.58 1.,717.92 5941,438.25 491,593.46 6.42 -6,809.08 MWD (3) 11650.27 92.18 114.46 6,141.04 5,98204 2,898.19 -6,689.92 5,941,424.86 491,621.46 7.84 -6,779.81 MM (3) 11,685.15 9132 111.49 6,139.98 5,9B5.98 2,884.58 -6,657.82 5.941,411.24 491,653.55 am -6,747.50 MWD(3) S 11,711.65 91.90 110.62 6,139.23 5,985.23 2,875.06 1.,633.10 5,941,401.72 491678.27 3.94 -6,723.29 MWD(3) 11,742.55 92.03 109.44 6,138.17 5,984.17 2,864.49 -6,604.09 5,941,391.14 491,707.28 3.80 -6,695.29 MWD (3) 11,772.69 89.94 106.96 6,137.66 5,983.66 2,855.07 -6,575.46 5941,381.72 491,735.90 10.76 -6,668.40 MWD (3) I I j 11,802.73 90.58 106.73 6,137.52 5,983.52 2,846.37 1.,546.71 5,941,373.01 491764.64 2.26 -6,641.91 MWD (3) i 11,832.53 91.41 109.85 6,137.00 5,983.00 2,837.02 1.,518.43 5941,363.66 491.792.92 10.83 -6,615.30 MIND (3) E 11.866.59 91.87 115.12 6,136.03 5,982.03 2,824.00 -6,486.98 5,941350.64 491,824.36 15.53 -6,583.86 MWD (3) I i 11,894.59 90.15 116.66 6,135.53 5,981.53 2,811.78 -6,461.80 5,941,338.41 491,849.54 8.24 -6,557.41 MWD(3) { 11,922.59 91.20 121.61 6,135.20 5,981.20 2,798.15 -5437.35 5,941,32478 491.873.98 18.07 -6,530.49 MWD (3) 1 11,952.83 89.60 125.18 6,134.99 5980.99 2,781.51 -6,412.11 5,941.308.13 491,899.22 12.94 5500.87 MWD (3) V 11,980.94 86.83 129.28 6,135.38 5,981.38 2,764.51 -5389.73 5.941,291.13 491,921.59 14.84 -6,473.03 MWD (3) ) 12,014.12 88.47 132.94 6,136.16 5.982.16 2,742.71 -6,364.74 5,941,269.32 491,946.57 11.08 -6,439.94 MWO(3) i j 12,042.61 89.14 137.16 6,135.75 5,982.75 2,722.55 -6,344.62 5,941,249.16 491,966.68 14.99 -5411.46 MWD (3) 12,074.80 88.13 138.84 6,137.52 5,983.52 2,698.64 -6,323.09 5,941,225.25 491,988.21 6.09 6,379.33 MWD (3) ) 12,101.86 86.92 138.61 6,138.69 5,989.69 2,678.32 6,305.26 5,941,204.93 492,006.03 4.55 6,352.35 MWD (3) ' 12,133.20 85.88 137.11 6,140.66 5,986.66 2,655.13 6,284.27 5,941,18173 492,027.01 5.B2 -6,321.11 MWD (3) 12,161% 85.33 135.38 6,142.86 5,988.86 2,634.42 -6,264.44 5,941,161.02 492,046.83 6.30 6,292.44 MWD (3) i .. 12,195.50 8745 135.02 6,144.97 5,990.97 2,610.67 -6,240.86 5,941,137.26 492,070.41 6.41 -6,258.97 MWD (3) f 12223.29 8871 134.48 6,145.90 5991.90 2,591.11 6.221.13 5,941,117.71 492,090.13 4.93 1.,231.20 MWD(3) 12 251 .45 8966 132.65 6,14630 5,992.30 2,571.71 6,200.73 5,941,098.30 492,110.53 7.32 -6,203.05 MWD (3) COMPASS 5000.14 Bul7tl 85 1012512017 12 32 27PM Page 4 Survey ConocoPhillips 6AI(ee Conoco Phillip s UG D Definitive Survey Report Map Company: ConowPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Well 2K-04 Project: Kupamk River Unit ND Reference: 2K-04 @ 154.00usft (2K-04) Site: Kuparuk 2K Pad MD Reference: 2K-04 @ 154.00usft (2K-04) Well: 2K-04 North Reference: True Wellbore: 2K -04L7 Survey Calculation Method: Minimum Curvature Design: 2K -04L1 Database: EDT Alaska Sandbox Survey Map Map Vertical MO Inc Azi TVD NDSS +N/ -S +E/ -W DLS j (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Ea(11 (0100') Section Survey Tool Name Annotation (ft) (ft) (R) 12,281.86 90.15 13162 6,146.35 5,992.36 2,551.31 -5,178.18 5,941,077.90 492,133.07 3.75 -6,172.68 MWD(3) 12,313;87 87.70 131.13 6,146.96 5,992.96 2,530.16 -6,154.17 5,941,05674 492,157.08 7.81 5,140.74 MWD(3) 12,343.39 85.42 131.71 6,148.73 5,991 2,510.66 -6,132.07 5,941,037.25 492.179.16 7.97 5,111.34 MAD (3) 1 12,372.47 64.25 130.49 6,151.34 5,997.34 2,491.62 -6,110.25 5,941,018.20 492,200.98 5.80 5,082.44 MWD(3) 12,402.25 83.68 128.50 6,154.48 6,000.48 2.472.79 5,087.40 5,M.999.37 492,223.83 6.92 5,052.97 MWD(3) �'. 12,432.32 82.87 126.58 6,158.00 6.004.00 2,454.59 5,06312 5,940,961.17 492,247.50 6.89 5,023.36 MWD (3) - 12,461.87 82.54 125.16 6,161.75 6,00715 2,437.42 5,039.97 5,940,963.99 492,271.24 4.90 -5.994.42 MWD 13) 12,492.37 82.49 127.26 6,165.72 6,011.72 2,419.56 -6,015.57 5,940,946.12 492,295.64 6.83 -5,964.53 MWD (3j 12,526.97 84.19 129.04 6,169.74 6,015.74 2,398.33 5,988.55 5,940,924.89 492,322.65 7.09 -5.930.42 MWD (3) 12,550.79 85.41 130.76 6,171.90 6,017.90 2,383.11 -5,970.35 5,940,909.67 492,340.84 8.83 5,906]9 MWD (3) 12,585.57 86.90 132.48 6,174.23 6,020.23 2,3(1 -5,944.41 5,940,866.62 492,366.77 6.53 5,872.15 MWD (3) 12,612,36 87.11 135.25 6,175.63 6,021.63 2,341.53 -5,925.12 5,940,868.08 492,386.06 10.36 5,845.40 MWD (3) L 12,642.60 86.71 137.75 6,17]26 6,023.26 2,319.63 -5,904.34 5,940,846.18 492,406.83 8.35 5,815.22 MIND (3) i 12,673.07 84.68 138.59 6,179.55 6,025.55 2,296.99 5,884.08 5,940,823.54 492,427.09 7.21 5,784.89 MWD (3) 12,701.13 86.68 141.58 ( 18166 6,027.66 2,27553 -5,866.13 5,940,802.08 491 12.79 5,757.02 MWD (3) 12,732.27 85.07 144.39 6,183.90 6,029.90 2,250.73 -5,847.43 5,940,777.28 492,46312 10.38 5,726.27 MWD (3) 12,762.17 83.23 145.57 6,186.95 6,032.95 2,226.38 -5,830.36 5,990,752.92 492,480.78 7.30 5,695.97 MM (3) -. 12,792.39 81.99 146.46 6,190.83 6,036.83 2,201.53 5,813.61 5,940,728.00 492,497.53 5.04 5,667.56 MWD(3) 12,822.33 79.76 146.89 6,195.58 6,041.58 2,176.83 -5,797.37 5,940,703.37 492,513.76 TMI 5.638.61 MWD(3) ) i 12,852.23 76.91 149.02 6,201.12 6,047.12 2,151.93 -5,781.78 5,940,678.47 492,529.34 7.56 5.609.98 MWD (3) 12,884.58 80.78 151.28 6,206.82 6,052.82 2,124.31 -5,765.93 5,940,650.85 492,545.18 8.98 5,579.24 MWD (3) 12,912.81 82.61 15394 6,210.0 6,056.90 2,099.51 -5,753.09 5,940,626.05 492,558.02 11.36 5,552.62 MWD(3) 12,942.78 84.47 156.30 6,214.27 6,00027 2,07250 -5,740.56 5,940,599.04 492.570.54 9.99 5,524.66 MM (3) 12,974.81 85.76 158.39 6,217.00 6,063.00 2,043.05 -5,728.27 5,940,569.59 492.562.82 7.65 5,495.15 MWD (3) 13,003.10 89.32 162.45 6,218.21 6,064.21 2,016.43 -5,718.80 5,940,542.97 492,592.28 19.08 5,469.63 MWD (3) 13,034.85 89.45 164.11 6,218.55 6,064.55 1,986.02 -5,709.67 5,W,512.56 492,601.41 5.24 5,441.67 MWD (3) , 13,062.33 90.12 166.84 6,218.66 6,064.66 1,959.42 -5,702.78 5,940,485.97 492,60829 10.23 5,417.99 MM (3) 13,098.12 92.15 173.23 6,217.95 6,06395 1,924.20 -5,696.59 5,940,45074 492,614.47 18.73 5,388.71 MWD(3) 13.130.00 89.29 174.39 6,217.55 6,063.55 1,892.51 -5,693.15 5,940,419.06 492,617.90 9.68 5,363.87 MWD (3) 13,161.32 88.04 176.27 6,218.28 6,06428 1,861.31 -5,690.60 5,940,387.86 492,620.45 7.21 -5,340.41 MAD (3) 13,193.57 85.85 17594 6,220.00 6,066.00 1829.18 -5,688.41 5,940,35573 492.622.63 6.87 -5,315.74 MVD (3) 10/25/2017 12'32: 27PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips BAt ERH Q ConocoPhillips Definitive Survey Report Company: Conocc Philips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2K-04 Project: Kuparuk River Unit TVD Reference: 2K-04 @ 154.00usft (2K-04) Site: Kupamk 2K Pad MD Reference: 2K-04 @ 154.000Sft (2K-04) Well: 2K-04 North Reference: True Wellbore: 2K -04L1 Survey Calculation Method: Minimum Curvature Design: 2K-0411 Database: EDTAlaska Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS -NIS -E/-W Northing Eastng DLS Section Survey Tool Name Annotation (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) ('/100') (ft) 13,223.35 83.45 176.17 6,222.77 6,068.77 1.79960 -5,686.37 5,940,326.16 492,624.66 8.10 5,293.38 MWD (3) 13,253.48 83.08 178.76 6,226.31 6,072.31 1,769.71 -5,685.05 5,940,296.27 492,625.98 8.62 5,271.31 MWD(3) 13,283.16 85.24 179.22 6,229.33 6,075.33 1,74019 5,684.53 5,940,26675 492626.49 7.44 5,250.07 MWD(3) 13,310.95 86.93 180.80 6,231.22 6.077.22 1,712.47 -5,684.59 5,948239.03 492,626.48 8.32 -5,230.47 MWD(3) 13,341.22 91.11 181.69 6,231.74 6,077.74 1.682.22 5,685.19 5,940,20878 492.625.81 14.12 -5.209.55 MWD(3) 13,371.29 93.44 183.08 6,230.55 6,076.55 1,652.20 5,685.44 5,940,178.77 492,624.56 9.02 5,189.20 MWD (3) 13,401.29 93.07 185.38 6,228.84 6,074.84 1,622.33 5,688.65 5,998148.90 492,622.34 7.75 5,169.65 MM (3) i 13,435.76 94.55 190.90 6,226.55 6,072.55 1,588.30 5,693.52 5,948114.88 492,617.47 16.54 5,149.02 MWD(3) 13,464.03 95.63 190.09 6,224.04 6,070.04 1,560.61 -5,698.65 5,940,087.19 492,612.33 4.77 5.133.07 MWO (3) 13,490.26 96.24 192.65 6,221.33 6,067.33 1,535.04 -5,703.79 5,940.06162 492,607.18 9.98 5,118.62 MWD(3) 13,533.03 94.61 199.97 6,217.29 6,063.29 1,493.69 -5,713.95 S,940,020.28 492,597.01 6.61 -5,096.58 MWD(3) 13,564.49 94.76 197.02 6,214.72 6,060.72 1,463.55 5,722.59 5,939,990.15 492,588.37 6.51 -5,081.37 MM (3) 13,595.77 93.44 200.80 6,212.48 6.058.48 1,434.04 -5,732.70 5,939,960.65 492,578.25 12.77 5,067.66 MWD (3) 13,624.17 91.20 198.88 6.211.33 6,05733 1407.35 5,742.33 5,939,933.96 492,568.62 10.38 5,055.59 MVJD(3) 13,660.32 89.39 198.65 6,211.14 6,057.14 1,373.13 5,753.96 5,939,899.74 492.556.98 5.05 5,039.61 MWD (3) 13,689.21 87.73 199.93 6,211.87 6,057.87 1,345.87 -5,763.50 5,939,872.49 492,54744 7.25 5,027.08 MWD (3) 13,718.05 66.04 201.88 6,213.44 6,059.44 1,318.97 -5,773.78 5,939.845.59 492.537.16 8.94 5,015.33 MWD(3) 13,748.47 84.68 203.26 6,215.90 6,061.90 1,290.97 -5,785.41 5,939,817.60 492,525.52 6.36 5,003.76 MM (3) 13.776.49 63.85 205.18 6,218.70 6,064.70 1,265.55 -5,796.85 5,939.792.18 492,514.08 7.43 4,993.87 MWD(3) 13,804.63 82.85 206.18 6,221.96 6,067.96 1,240.36 5,808.96 5,939,767.00 492,501.96 5.01 4,984.62 MWD (3) 13,816.21 82.18 207.48 6,223.47 6,069.47 1,230.11 -5,814.14 5,939,756.75 492,496.78 12.54 4981.04 MWD(3) 13852.00 82.18 207.48 6,228.33 6,074.34 1,198.65 5,830.50 5,939.725.30 492,480.41 0.00 497037 PROJECTEDtc TD 10/252017 12:32:27PM Page 6 COMPASS 5000.14 Build 85 BATE a G E Company To: Letter of Transmittal Date: DATA LOGGED November 6, 2017 A rt izo» M. K. BENDER Makana Bender AOGCC 333 West 7' Ave, Suite 100 Anchorage, Alaska 99501 From: Yosha Ragbirsingh / Michael Soper Baker Hughes, a GE Company 795 East 941h Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following welI(s): 2K -04L1 21 7 1 2 6 2 8 7 7 1 4- 21K-041-1 -01 -2K-041-1-01 2 1 7 1 2 7 28 77 2 21K-041-1 oz 2 1 7 1 2 8 28 7 7 3 RECEIVED NOV 0 7 209 AOGCC (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BHGE.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BHGE.com ConocoPhillips RECEIVED NOV 0 7 2017 AOGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K -04L1 50-103-20099-60 Baker Hughes INTEQ Definitive Survey Report 25 October, 2017 BAF�UGHES aGEcompany 217126 28 77 1 Project Kuparuk River Unit, North Slope Alaska, United States Map System: ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2K Pad MD Reference: Well: 2K-04 North Reference: Wellbore: 21K-041_7 Survey Calculation Method: Design: 2K -04L7 Database: 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) Depth From (TVD) Map Zone: Alaska Zone 04 (usft) Well 2K-04 35.50 Well Position +Nf-S 0.00 Usk Northing: From .E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 2K -04L7 2K-04 (2K-04) Magnetics Model Name Sample Date BGGM2017 10/1/2017 Design 2K -04L1 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: 1/12/2001 Depth From (TVD) 10/10/2017 10/10/2017 (usft) 10/15/2017 35.50 Survey Program Date 10/25/2017 r From To (usft) (usft) Survey (Wellbore) 200.00 10,400.00 2K-04 (2K-04) 10,479.00 10,540.73 21K-041.1 MWD -INC (21K-0411) 70,57074 13,816.21 2K -04L1 MWD (21K-0411) Well 2K-04 2K-04 @ 154.00usft (2K-04) 21K-04 @ 154.00usft (2K-04) True Minimum Curvature EDT Alaska Sandbox Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,938,525.46 usft 498,310,06usft usft Declination (°I 17.30 Tie On Depth: 10,400 00 +N/ -S (usft) 0.00 Tool Name BOSS -GYRO MWD MWD +E/.W (usft) 0.00 Description Sperry -Sun BOSS gyro multishot MWD - Standard MWD - Standard BA UG l�UGNFS 0 Latitude: 70° 14' 35.784 N Longitude: 150° C'49.136 W Ground Level: 118.50 usft Dip Angle Field Strength (°I (nT) 80.84 57474 Direction (°1 i 135.00 Survey Survey Start Date End Date 1/12/2001 10/10/2017 10/10/2017 10/10/2017 10/15/2017 1025,2017 12:32:27PM Page 2 COMPASS 5000.14 Build 85 iWHFPS a Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth First Clean Survey 10252017 12:32:27PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc Kup2 Local Co-ordinate Reference Well 2K-04 Project Kupamk River Unit TVD Reference: 2K-04 @ 154.00usft (21 Site: Kupamk 2K Pad MD Reference: 21 @ 154.01 (2K-04) Well: 21 North Reference: True Wellbom: 21 Survey Calculation Method: Minimum Curvature Design: 21 Database: EDT Alaska Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1 -S +E/ -W (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Ea ('D UU) Section Survey Tool Name (ft)IN) 111 (065.46 10,40000 63.97 304.90 6,094.16 5,940.16 3,538.80 6,911.51 5,942,. 491,1. 400.03 360 -7,389.49 MWD (2) 10,479.00 65.14 30561 6,128.10 5,974.10 3,579.98 6,969.76 5,942,10664 491,341.80 169 -7,45980 1(2) 10,510.72 71.56 299.50 6,139.81 5,985.81 3,595.80 6,999.60 5,942,122.47 491,316.96 27.01 -7,488.55 1(2) 10,540.73 8124 294.00 6,146.86 5,992.86 3,608.88 -7.020.62 5,942,135.55 491,290.95 3684 -7,516.19 1(2) 10,570.74 91.01 288.89 6,148.89 5,994.89 3,619.80 -7,048.45 5,942,146.48 491,263.13 36.71 -7,543.59 1(3) 10,600.61 97.05 278.28 6,146.78 5,992.78 3,626.80 -7,077.36 5,942,153.48 491,234.23 4078 -7,568.98 1(3) 10,631.09 95.85 262.99 6,143.34 5,98934 3,627.13 -7,107.55 5,942,153.82 491,204.04 50.00 -7,590.56 1(3) 10,660.87 94.42 249.96 6,140.66 5,986.66 3,620.20 -7,136.32 5,942,146.90 491,175.26 43.84 -7,606.01 1(3) 10,690.60 92.89 236.50 6,138.76 5,984.76 3,506.87 -7,162.75 5,942,133.57 491,148.84 45.47 -7,615.27 1(3) 10,720.70 88.00 222.62 6,138.52 5,984.52 3,587.40 -7,185.59 5,942,114.11 491,125.99 48.88 -7,61765 1(3) 10,750.80 90.83 2(18.25 6,138.83 5,984.83 3,562.94 -7,202.99 5,942,089.66 491,108.59 48.65 -7,612.66 1(3) 10,780.98 89.32 197.02 6,13879 5,984.79 3,535.13 -7,214.59 5,942,061.85 491,096.98 37.54 -7,60120 1(3) 10,807.99 89.79 185.83 6,139.00 5,985.00 3,508.74 -7220.16 5,942,035.47 491,091.41 37.77 -7,586.48 MWD (3) 10,841.09 92.09 174.57 6,13846 5,984.46 3475.71 .7,220.57 5,942,002.44 491,090.99 37.68 -7,563.41 MWD (3) 10,871.29 91.93 164.90 6,137.40 5,98340 3,446.05 .7,215.20 5,941,97278 491,096.36 32.00 -7,538.64 1(3) 10,902.26 91.04 158.39 6,136.59 5,982.59 3,416.68 -7,205.45 5,941,943.41 491,106.10 21.21 -7,510.98 MAD (3) 10,931.98 89.85 154.89 6,136.36 5,982.36 3,389.40 -7,193.67 5,941,916.13 491,117.87 12.44 -7,483.36 1(3) 10,962.21 89.32 150.35 6,136.58 5,962.58 3,362.57 -7,179.77 5,941,889.30 491,131.76 15.12 -7,454.56 1(3) 10,993.36 88.55 148.14 6,137.16 5,983.16 3,335.80 -7,163.85 5,941,862.53 491,147.68 7.51 -7,424.37 1(3) 11,23.37 88.13 146.66 6,138.03 5,984.03 3,310.53 -7,147.69 5,941,837.26 491,163.83 5.12 -7,395.08 113) 11,052.13 9071 147.88 6,138.32 5,984.32 3,286.34 -7,132.14 5,941,81307 491,179.37 9.92 -7,366.98 MWD (3) 11,082.38 91.35 146.49 6,13778 5,983.78 3,260.92 -7,115.75 5,941,787.65 491,195.76 506 -7,337.41 1(3) 11,112.16 90.25 145.22 6,137.36 5,983.36 3,236.28 -7,099.03 5,941,763.01 49121246 564 -7,308.17 MWD (3) 11,142.58 91.23 14508 6,136.97 5,962.97 3,211.32 -7,08165 5,941,738.05 491,229.84 3.25 -7,278.23 1(3) 11,162.27 89.32 144.53 6,136.87 5,962.87 3,195.23 -7,070.31 5,941,72195 491,241.18 10.09 -7,258.83 1(3) 11,19321 87.33 141.90 6,137.78 5,963.78 3,170.46 -7,051.79 5,941,697.19 491,259.69 1066 -7,228.22 1(3) 11,222.79 87.30 140.26 6,139.16 5,985.16 3,147.48 -7,033.23 5,941,674.20 491,278.24 5.54 -7,198.84 1(3) 11,252.95 86.44 136.35 6,140.81 5,965.81 3,124.99 -7,013.20 5,941,65171 491,298.26 1326 -7,168.79 1(3) 11,282.99 85.79 133.99 6,142.85 5,988.85 3,103.74 8,992.07 5,941,630.46 491,319.38 8.13 -7,138.82 1(3) 11,31269 86.59 132.10 1 5,990.82 3,083.51 -6,970.42 5.941,61023 491,341.03 6.90 -7,109.20 1(3) iWHFPS a Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth First Clean Survey 10252017 12:32:27PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc -Kup2 Local Co-ordinate Reference: Well 2K-04 Project: Kuparuk River Unit TVD Reference: 2K-04 @ 154.00usft (2K-04) Site: Kuparuk 2K Pad MD Reference: 2K-04 @ 154.00usft (2K-04) Well: 2K-04 North Reference: True Wellbore: 2K -04L1 Survey Calculation Method: Minimum Curvature Design: 21K-0411 Database: EDT Alaska Sandbox Survey Annotation �ER ! WNES 10/25/2017 12:32:27PM Page 4 COMPASS 5000.14 Build 85 I Map Map Vertical MD Inc Azl TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) (°) (°) Waft) (waft) (waft) (usft) (°1100') Survey Tool Name (ft) (ft) (ft) 11,342.61 86.87 12965 6,146.53 5,992.53 3,053.97 8947.83 5,941,590.68 491,363.61 8.23 -7,07941 MWD(3) 11372.45 87.18 127.79 6,148.08 5,994.08 3,095.33 -6,924.58 5,941,57203 491,386.85 6.31 -7,049.79 MWD (3) 11,403.46 88.59 126.30 6,149.22 5,995.22 3,02666 -6,899.85 5,941,553.36 491,411.58 6.61 -7,019.10 MWD(3) 11,435.32 90.12 126.17 6,149.58 5,995.58 3,007.83 -6,874.15 5,941,534.53 491,437.27 4.82 -6,987.62 MM (3) 11,462.38 91.93 124.72 6,149.10 5,995.10 2,992.14 -6,852.11 5,941,518.84 491,459.30 8.57 -6,960.94 MWD(3) 11.49269 91.45 123.99 6,148.20 5,994.20 2,975.04 -6,827.10 5,941,501.74 491,484.31 2.88 -6,931.16 MWD(3) 11,522,28 91.75 121.83 6,147.38 5,993.38 2,958.97 -6,802.27 5,941485.66 491,509.13 7.27 -6,902.24 MWD(3) 11,552]0 92.49 12009 6,146.25 5,992.25 2,943.32 6,776.21 5,941,470.01 491,535.19 6.30 45,872.75 MWD (3) 11,585.25 93.56 118.81 6,144.53 5,990.53 2,927,34 -6,747.91 5,941,454.02 491,563.48 5.12 -6,841.43 MWD (3) 11,619.19 93.25 11665 6,142.52 5,988.52 2,911.58 -6,717.92 5,941,438.25 491,593.46 6.42 -6,809.08 MWD(3) 11,650.27 92.18 11446 6,141.09 5,987.04 2,898.19 -6,689.92 5,941,42466 491,621,46 7.84 -6,779.81 MWD (3) 11,685.15 91.32 111.49 6,139.98 5,985.98 2,884.58 45,657.82 5,941,411.24 491,653.55 8.86 8,747.50 MWD (3) 11,71165 91.90 110.62 6,139.23 5,985.23 2,875.W 43,633.10 5,941,401.72 491,678.27 3.94 8,723.29 MM (3) 11,742.55 92.03 109.44 6,138.17 5,984.17 2,864.49 8,604.09 5,941,391.14 491,707.28 3.84 8,695.29 MWD (3) 11,772.69 89.94 106.96 6,137.66 5,983.66 2,855.07 -6,575.46 5,941,381.72 491,735.90 10.76 8,668.40 MM (3) 11,802.73 90.58 106.73 6,137.52 5,983.52 2,846.37 8,546.71 5,941,373.01 491,764.64 2.26 8,641.91 MWD (3) 11,832.53 91.41 10985 6,13700 5,983.00 2,837.02 -6,518.43 5,941,363.66 491,792.92 10.83 8,615.30 MWD(3) 11,866.59 91.87 115.12 6,136.03 5,982.03 2,824.0 8,486.98 5,941,350.64 491,824.36 15.53 -6,583.86 MWD (3) 11,894.59 90.15 116.66 6,135.53 5,981.53 2,811.78 8,461.80 5,941,338.41 491,849.54 8.24 -6,557.41 MWD (3) 11,922.59 91.20 12161 6,135.20 5,981.20 2,798.15 -6,437.35 5,941,324.78 491,873.98 18.07 45,53049 MWD (3) 11,952.83 890 125.18 6,134.99 5,980.99 2,781.51 8,412.11 5,9413W.13 491,899.22 12.94 8,500.87 MWD(3) 11960.94 88.83 129.28 6,135.38 5,981.38 2,764.51 45,389.73 5,941,291.13 491,921.59 14.84 -6,473.03 MWD (3) 12,014.12 88.47 132.94 6,136.16 5,982.16 2,742.71 8,364.74 5,941,269.32 491,946.57 11.08 8,439.94 MM (3) 12,042.61 89.14 137.16 6,136.75 5,982.75 2,722.55 -6,344.62 5,941,249.16 491,96668 14.99 -6,411.46 MM (3) 12,074.80 88.13 138.84 6,137.52 5,983.52 2,698.64 45,323.0 5,941,225.25 491,988.21 6.09 -6,379.33 MWD (3) 12,101.86 86.92 138.61 6,13869 5,984.69 2,678.32 $305.26 5,941,204.93 492,006.03 4.55 8,35235 MWD (3) 12,133.20 85.88 137.11 6,140.66 5,986.66 2,655.13 8,284.27 5,941,181.73 492,027.01 5.82 8,321.11 MWD(3) 12,161.96 85.33 135.38 6,142.86 5,988.86 2,634.42 -6,264.44 5,941,161,02 492,046.83 6.30 -6,292.44 MM (3) 12,195.50 8745 135.02 6,144.97 5,990.97 2,610.67 -6,240.86 5,941,137.26 492,070.41 6.41 8,258.97 MM (3) 12,22329 W71 13448 6,145.0 5,991.90 2,591.11 -6.221.13 5,941,117.71 492,090.13 4.93 8,231.20 MWD (3) 12,251.45 89.66 132.65 6,14630 5,99230 2,57171 8,200 73 5,941,096.30 492,110.53 7.32 -6,203.05 MWD (3) Annotation �ER ! WNES 10/25/2017 12:32:27PM Page 4 COMPASS 5000.14 Build 85 I ConocoPhillipsEe Es 0 sfucH ConocoPhilli p Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuperuk River Unit Site: Kuparuk 2K Pad Well: 2K-04 Wellbore: 2K-041-1 Design: 2K-0411 Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2K-04 2K-04 @ 154.00usR (2K-04) 2K-04 @ 154.00usR (2K-04) True Minimum Curvature EDT Alaska Sandbox Annotation 10/252017 12.32.27PM Page 5 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azl TVD TVDSS +NI -S +El -W Northing EaIft) DLS Section lust) (1) 1°I (usR) (usR) (usR) (usR) (°1106q Survey Tool Name (ft) (ft) (ft) 12,28186 WAS 131.62 6,146.35 5,992.36 2,551.31 -6,178.18 5,941,077.90 492,133.07 3.75 -,172.68 MM (3) 12,313.87 87.70 131.13 6,146.96 5,992.96 2,530.16 -6,154:17 5,941,0%,74 492,157.08 7,81 6,140.74 MWD (3) 12,343.39 8542 13171 6,148.73 5,994.73 2,510.66 6,132.07 5,941,037.25 492,179.16 797 6,111.34 MWD (3) 12,372.47 84.25 130.49 6,151.34 5,99.34 2,491.62 6,110.25 5,941,01820 492,200.98 5.80 6,082.44 MWD(3) 12,402.25 83.66 128.50 6,154.48 6,000.48 2,47279 6,08740 5,940999.37 492,223.83 6.92 6,052.97 MWD(3) 12,432.32 82.87 126.58 6158.00 6,004.00 2,454.59 6,063.72 5,940,981.17 492,247.50 6.89 6,023.36 MM (3) 12,461.87 82.54 125.16 6,161.75 6,007.75 2,437.42 6,039.97 5,940,963.99 492,271.24 4.90 -5,994.42 MWD (3) 12,492.37 82.49 127.26 6,165.72 6,01172 2,419.56 6,015.57 5,940,946.12 492,295.64 6.83 -5,964.53 MWD(3) 12,526.97 84.19 129.04 6,16974 6,015.74 2,398.33 -5,988.55 5,940,924.89 492,322.65 7.09 -5,93042 MM (3) 12,550.79 85.41 130.76 6,171.90 6,017.90 2,383.11 -5,970.35 5,940,909.67 492,340.84 8.83 -5,906.79 MWD (3) 12,585.57 86.90 13248 6,174.23 6,020.23 2,360.07 -5,944.41 5,940,886.62 492,366.77 6.53 -5,872.15 MWD(3) 12,612.36 87.11 135.25 6,175.63 6,021.63 2,341.53 5,925.12 5,940,868.08 492,386.06 10.36 -5,845.40 MWD (3) 12,642.60 86.71 137.75 6,177.26 6,023.26 2,319.63 -5,90434 5,940.W 18 492,405 83 8.36 -5,815.22 MWD(3) 12,67307 8468 138.59 6,179.55 6,025.55 2,296.99 5,884.08 5,940,82354 492,427.09 721 -5,784.89 MWD (3) 12,701.13 86.68 141.58 6,181.66 6,027.66 2,275.53 -5,866.13 5,940,802.08 492,44503 12.79 -5,757.02 MWD (3) 12,732.27 85.07 144.39 6,183.90 6,029.90 2,25073 -5,647.43 5,940,777.28 492,46372 10.38 -5,726.27 MWD (3) 12,762.17 83.23 145.57 6,18695 6,032.95 2,226.38 -5,830.36 5,940752.92 492,480.78 7.30 5,696.97 MWD (3) 12,792.39 81.99 146.46 6,190.83 6,036.83 2,201.53 -5,813.61 5,940,728,07 492,497.53 5.04 5,667.56 MWD(3) 12,822.33 79.76 146.89 6,195.58 6,041.58 2,176.83 -5,797.37 5,940703.37 492,513.76 7.58 5,63861 MWD (3) 12,852.23 78.91 14902 6,201.12 6,047.12 2,151.93 -5,781.78 5.940,678.47 492,529.34 7.56 -5,609.98 MM (3) 12,884.58 80.78 151.28 6,206.82 6,052.82 2.12431 5,765.93 5,940,650.85 492,545.18 8.98 -5,579.24 MM (3) 12,912.81 82.61 153.94 6,21090 6,06.90 2,099.51 -5,753.09 5,940,626.05 492,558.02 11.36 -5,552.62 NIM (3) 12,942.78 84.47 156.30 6,214.27 6,060.27 2,92.50 -5,740.56 5,940,599.04 492,570.54 9.99 -5,524.66 MWD(3) 12,974.81 85.76 158.39 6,217.00 6,063.00 2,043.05 5,72827 5,940,56959 492,582.82 765 -5,495.15 MWD(3) 13,00.10 89.32 162.45 6.21821 6,04.21 2,016.43 -5,718.80 5,940,542.97 492,59228 19.08 -5,469.63 MWD(3) 13,034.85 89.45 164.11 6,21855 6,04 .55 1,986.02 -5,709.67 5,940,512.56 492,601.41 5.24 5,441.67 MWD (3) 13,02.33 90.12 166.84 6,21866 6,04.66 1,959.42 -5,702.78 5,940,485.97 492,608.29 10.23 5,417.99 MWD(3) 13,098.12 92.15 173.23 6,217.95 6,03.95 1,924.20 -5,696.59 5,940,450.74 492,614.47 18.73 5,388.71 MWD(3) 13,130.0 89.29 174.39 6,217.55 6,063.55 1,892.51 -5,693.15 5,940,419.06 492,617.90 9.68 5,363.87 MWD(3) 13,161.32 88.04 176.27 6,218.28 6,064.28 1,861.31 -5,690.60 5,940,387.86 492,620.45 7.21 -5,340.01 MWD(3) 13,193.57 8585 175.94 6,22000 6,066.00 1829.18 -568841 5,940,35573 492,622.63 6.87 -5,315.74 MWD(3) Annotation 10/252017 12.32.27PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillipsER G3 ConocoPhilli sWxEs p Definitive Survey Report Company: ConowPhillips (Alaska) Inc. -Kup2 Project.. Kupamk River Unit Site: Kuparuk 2K Pad '_. Well: r 2K-04 Wellbore: 2K-0417 Design: 2K-0411 MD Inc 0,_--.�-1...,_ 4 Survey I Local Co-ordinate Reference: Well 21K-04 TVD Reference: 2K-04 @ 154.00usft (2K-04) MD Reference: 2K-04 @ 154.00usft (2K-04) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT Alaska Sandbox Annotation 10/25/2017 12:32:27PM Page 6 COMPASS WOO.. 14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +El -W Northing Easting DLS Section (usft) (°) V) (usft) (usft) (usft) (usft) (°1100') Survey Tool Name (ft) (ft) (ft) 13,223.35 83.45 176.17 6,222.77 6,068.77 1,79960 -5,666.37 5,940,326.16 492,624.66 8.10 -5,293.38 MAD (3) 13,253.48 83.08 178.76 6,226.31 6,072.31 1,7W71 -5,685.05 5,940,29627 492,625.98 8.62 5,271.31 MM (3) 13,283.16 85.24 179.22 6,229.33 6,075.33 1,740.19 -5,684.53 5,940,266.75 492,626.49 7.44 -5,25087 MAD (3) 13,310.95 86.93 180.80 6,231.22 6,077.22 1,712.47 -5,684.59 5,940,239.03 492,62648 8.32 5,230.47 MAD (3) 13,341.22 91.11 181.69 6,231.74 6,077.74 1,682.22 5,685.19 5,940,20678 492,625.81 14.12 -5,209.55 MWD(3) 13,371.29 9344 183.08 6,230.55 6,076.55 1,652.20 5,686.44 5,940,178.77 492,624.56 902 -5,189.20 MWD (3) 13,401.29 93.07 185.38 6,228.84 6,074.84 1,622.33 5,686.65 5,940,148.90 492,622.34 7.75 -5,169.65 MWD(3) 13,435.76 94.55 190.90 6,226.55 6,072.55 1,508.30 -5,693.52 5,940,114.88 492,617.47 16.54 -5,149.02 MM (3) 13,464.03 95.63 190.09 6,224.04 6,070.04 1,560.61 5,69865 5,940,087.19 492,612.33 4.77 -5,133.07 MWD (3) 13,490.26 96.24 192.65 6,221.33 6,067.33 1,535.04 -5,703.79 5,940,061.62 492,607.18 9.98 5,11662 MWD (3) 13,53383 94.61 199.97 6,217.29 6,063.29 1,493,69 -5,713.95 5,940,02028 492,59.01 6.61 -5,096.58 MWD (3) 13,564.49 94.76 197.02 6,214.72 6,060.72 1,463.55 -5,722.59 5,939,990.15 492,588.37 6.51 -5,081.37 MM (3) 13,595.77 93.44 200.80 6,212.48 6,058.48 1,434.04 -5,732.70 5,939,960.65 492,578.25 12.77 5,067.66 MM (3) 13,624.17 91.20 198.88 6,211.33 6,057.33 1,407.35 -5,742.33 5,939,933.96 492,568.62 10.38 5,055.59 MWD (3) 13,660.32 89.39 198.65 6,211.14 6,057.14 1,373.13 -5,753.96 5,939,899.74 492,556.98 5.05 -5,039.61 MWD (3) 13,689.21 87.73 199.93 6,21187 6,057.87 1,345.87 -5,763.50 5,939,872.49 492,547.44 7.25 -5,027.08 MAD (3) 13,718.05 86.04 201.88 6,21344 6,059.44 1,318.97 -5,773.78 5,939,845.59 492,537.16 8.99 -5,015.33 MWD (3) 13,74847 84.68 203.26 6,215.90 6,061.90 1,250.97 -5,785.41 5,939,81760 492,525.52 6.36 -5,003.76 MWD (3) 13,776.49 83.85 205.18 6,218.70 6,064.70 1,265.55 -5,796.85 5,939,792.18 492,514.06 7.43 4,993.87 MAD (3) 13,80463 82.85 206.18 6,221.96 6,067.96 1,240.36 5,808.96 5,939,767.00 492,501.96 5.01 4,98462 MWD (3) 13,816.21 82.18 207.48 6,223.47 6,069.47 1,230.11 5,814.14 5,939,756.75 492,496.78 12.54 4,981.04 MM (3) 13,852.00 82.18 207.48 6,228.33 6,074.34 1,198.66 5,830.50 5,939,725.30 492,480.41 0.00 4,970.37 PROJECTED to To Annotation 10/25/2017 12:32:27PM Page 6 COMPASS WOO.. 14 Build 85 THE STATE 0 ALAS1—A GOVERNOR BILL WALKER Kai Starck CTD Director ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K -04L1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-126 Surface Location: 5058' FNL, 94' FEL, SEC. 2, TI ON, R8E, UM Bottomhole Location: 3852' FNL, 654' FEL, SEC. 3, TI ON, R8E, UM Dear Mr. Starck: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. aogcc.alaska. gov Enclosed is the approved application for permit to re -drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit 188-119, API 50-103-20099-00- 00. Production should continue to be reported as a function of the original API number stated above. 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, r Hollis S. French lk� Chair DATED this Z(' day of September, 2017. STATE OF ALASKA i ALASKA OIL AND GAS CONSERVATION COMMIbbiON PERMIT TO DRILL 20 AAC 25.005 KLIUtIVtU SEF 07 2017 AOGCC 1a. Type of Work: 11b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG LJ Service - Disp ❑ 1c. Specify if well is proposed for: Drill ❑ Lateral- ❑� Stratigraphic Test ❑ Development - Oil ❑� , Service - Winj ❑ Single Zone ❑✓ Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska Inc Bond No. 5952180 KRU 2K -04L1 , 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 13850' - TVD6048' Kuparuk River Pool Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 5058' FNL, 94' FEL, Sec 2, T10N, RBE, UM W ADL 25589 uw �Js Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 1480' FNL, 1784' FEL, Sec 3, T1 ON, R8E, UM LONS 85-096 9/19/2017 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 3852' FNL, 654' FEL, Sec 3, T10N, R8E, UM 258e— s I a 11930' 4b. Location of Well (Stale Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 154' 15. Distance to Nearest Well Open Surface: x- 498310 Y- 5938525 Zone- 4 GL / BF Elevation above MSL (ft): 114' to Same Pool: 400'(2K-04) 16. Deviated wells: Kickoff depth: 10482 feet . 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 98 degrees ' Downhole: 4405 - Surface: 3803 ' 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" 4.7# L-80 ST -L 2975' 10875' 5981' 13850' 6048' 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): 10850' 6274' N/A 10737' 6231' 10542' Casing Length Size Cementvolume MD TVD Conductor/Structural 79' 16" 179 sx AS 1 115' 115' Surface 3991' 9-5/8" 1069 sx AS III & 297 sx Class G 4026' 2913' Production 2312' 7" 834 sx ASI 2345' 2057' Production 8493' 7" 73 sx Class G 10836' 6269' Perforation Depth MD (ft): 10402'-10424' Perforation Depth TVD (ft): _ 6095'- 6105' 10482'-10522' 6129'- 6146' Hydraulic Fracture planned? Yes❑ No 7 20. Attachments: Properly Plat ❑ SOP Sketch Drilling Program e T1 v. Depth Plot e Shallow Hazard B✓ e Divertter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: William Long Authorized Name: Kai Starck Contact Email: WiIItann.R.LonqaCOP.com Authorized Title: CTD Director Contact Phone: 263-4372 Authorized Signature: Date: Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: C2 50- 03- — 60 Date: a� requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: 610 fc73 f +c) ,¢s0� P b i5 ZS00 ,--,( Samples req'd: Yes Fy�1 NoA Mud log req'd: Yes ❑ No(K ff f% Irl ✓1 V/ Gr /" VCh f✓! ✓ f�5 t0 y�T IHg measures: Yes u No,❑f Directional svy req'd: Yes Nom❑l h{7iC Spacing exception req'd: Yes ❑ No L+'_I Inclination -only svy req'd: Yes ❑ Nou Post initial injection MIT req'd: Yes ❑ Nov APPROVED BY 9 I� I Approved by: COMMISSIONER THE COMMISSION Date: suomn Form and Form q�� 011 vise i i1 i�v kliorr months from the date of approval per 20 AAC 25.005(g) Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2017 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: RECEIVE® SEP 07 2017 ,a" 0\ GCC ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill three laterals out of the newly worked over KRU 2K-04 (PTD# 188-119) well using the coiled tubing drilling rig, Nabors CDR3-AC. ,� 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. The work is scheduled to begin September 2017. The objective will be to drill three laterals KRU 2K -04L1, 2K - 04L1 -01, and 21K-041-1-02 targeting the Kuparuk A -sands./ Attached to this application are the following documents: - Permit to Drill Application Forms (10-401) for 2K -04L1, 2K-041-1-01, and 2K -04L1-02 - Detailed Summary of Operations - Directional Plans for 2K -04L1, 2K-041-1-01, and 2K -04L1-02 - Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4372. Sincerely, William R. Long Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 2K -04L1, 21K-041-1-01, &. 2K-041-1-02 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(Q 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.................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(6)) ...................... ...................................................................... -................... ................................. 2 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)(6)) .................... ..... ..................................... ..... --.......................................................................... 3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))......................................................................................................._.......................................4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 2K-041-1, 2K-041-1-01, & 2K-041-1-02 laterals.........................................................6 Attachment 2: Current Well Schematic for 2K-04............................................................................................................6 Attachment 3: Proposed Well Schematic for 2K-041-1, 2K -04L1-01, & 2K -04L1-02 laterals...........................................6 Page 1 of 6 August 31, 2017 PTD Application: 2K -04L1, 2K-041-1-01, & 2K -04L1-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 21K-041-1, 2K-041-1-01, and 2K-041-1-02. All laterals will be classified as "Development -Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 forms for surface and subsurface coordinates of the 2K-041-1. 2K-041-1-01. and 21K-041-1-02 laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,500 psi. Using the maximum formation pressure in the area of 4,405 psi in 2M-14 (i.e. 13.8 ppg EMW), the maximum potential surface pressure in 2K-04, assuming a gas gradient of 0.1 psi/ft, would be 3,803 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 2K-04 was measured to be 3,784 psi (11.9 ppg EMW) on 7/12017. The maximum downhole pressure in the 2K-04 vicinity, is the 2M-14 at 4,405 psi (13.8 ppg EMW) from June 2017. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to 2K-04 have injected gas, so there is a chance of encountering free gas while drilling the 2K-04 laterals. If significant 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 2K-04 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 2K-04 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. 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 MD MD TVDSS TVDSS 21K-041-1 10,875' 13,850' 5,981' 6,048' 2W, 4.7#, L-80, ST -L slotted liner; aluminum billet on to 2K-041-1-01 10,580' 13,600' 5,996' 5,942' 2W, 4.7#, L-80, ST -L slotted liner; aluminum billet on to 21K-041-1-02 10,475' 13,000' 5,972' 5,943' 2%", 4.7#, L-80, ST -L slotted liner; de to ment sleeve on to Page 2 of 6 August 31, 2017 PTD Application: 2K -04L1, 21K-041-1-01, & 21K-041-1-02 Existing Casing/liner Information Category OD Weight Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded 36' 115' 36' 115' 1,640 670 Surface 9-5/8" 36 J-55 BTC 35' 4,026' 35' 2,913' 3,520 2,020 Production 7" 26 L-80 H dril563 33' 2,345 33' 2,057' 7,240 5,410 Production 7" 26 J-55 BTC 2,342' 10,836' 2,055' 6,269' 4,980 4,320 Tubing 3-1/2" 9.3 L-80 EUE 31' 10,515' 31' 6,143' 10,160 10,540 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 FloVis mud (8.7 ppg) - Drilling operations: Chloride -based FloVis mud (8.7 ppg)* pg) /This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. - Completion operations: The well will be loaded with 12.0 ppg NaBr completion fluid in order to provide formation over -balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process./Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 2K-04 laterals we will target a constant BHP of 12.0 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. Pressure at the 2K-04 Window 10482' MD, 6129' TV Usin MPD Page 3 of 6 August 31, 2017 Pumps On 1.5 bpm) Pumps Off A -sand Formation Pressure 11.9 3784 psi 3784 psi Mud Hydrostatic 8.7 2772 psi 2772 psi Annular friction i.e. ECD, 0.080psi/ft) 838 psi 0 psi Mud + ECD Combined no chokepressure) 3610 psi underbalanced -174psi) 2772 psi underbalanced -1012psi) Target BHP at Window 12.0 3824 psi 3824 psi Choke Pressure Required to Maintain Target BHP 214 psi 1052 psi Page 3 of 6 August 31, 2017 PTD Application: 2K -04L1, 2K -04L1-01, & 2K -04L1-02 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 2K-04 is a Kuparuk A -sand and C -sand producer equipped with 3-1/2" tubing and 7" production casing. A recent rig workover installed a 7" production tieback, new 3-1/2" tubing, and a tandem wedge design to facilitate three CTD laterals. The laterals will target the A -sands to the north and southeast of the 2K-04 parent wellbore. The project will improve the ultimate recovery in the parent pattern as well as provide offtake from a premised sheltered resource on the eastern side of a large 90 ft. sealing fault. Prior to CTD operations, slickline will conduct a dummy whipstock drift and E -line will obtain a jewelry log and set 3-1/2" Northern Solutions Whipstock at 10482' MD. The 2K -04L1 lateral will exit the 3-1/2" tubing and 7" casing at 10482' MD and TD at 13850' MD, targeting the A3 and A4 sands. It will be completed with 2-3/8" slotted liner from TD up to 10875' MD with an openhole anchored aluminum billet for kicking off the 2K-04LI-01 lateral. The 2K -04L1-01 lateral will drill north to a TD of 13600' MD targeting the A3 and A4 sands. It will be completed with 2-3/8" slotted liner from TD up to 10580' MD with an aluminum billet for kicking off the 2K -04L 1-02 lateral. The 2K -04L1-02 lateral will drill southeast to a TD of 13000' MD targeting the A4 sand. It will be completed with 2-3/8" slotted liner from TD up to 10475' MD with a deployment sleeve back into the 3- 1/2" tubing. Pre -CTD Work 1. Perform RWO to install new 3-1/2" tubing and tandem wedge design. 2. RU Slickline: Perform a dummy whipstock drift. 3. RU E -line: Obtain jewelry log and set 3-1/2" Northern Solutions Whipstock at 10482' MD. 4. Prep site for Nabors CDR3-AC. Page 4 of 6 August 31, 2017 PTD Application: 2K-041.1, 2K-041-1-01, & 21K-041-1-02 Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2K -04L 1 Lateral (A3/A4 sand -North) a. Mill 2.80" window at 10482' MD. b. Drill 3" bi-center lateral to TD of 13850' MD. c. Run 2-3/8" slotted liner with an openhole anchored aluminum billet from TD up to 10875' MD. 3. 2K -04L1-01 Lateral (A3/A4 sand -North) a. Kickoff of the aluminum billet at 10875' MD. b. Drill 3" bi-center lateral to TD of 13600' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 10580' MD. 4. 2K -04L1-02 Lateral (A4 sand -Southeast) a. Kickoff of the aluminum billet at 10580' MD. b. Drill 3" bi-center lateral to TD of 13000' MD. c. Run 2-3/8" slotted liner from TD up into the tubing tail at 10475' MD. 5. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Return to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. - Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. - Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via 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 2K-04 laterals will be displaced to an overbalancing completion fluid prior to running liner. See "Drilling Fluids" section for more details. - While running 2%" slotted liner, a joint of 2%" 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%" rams will provide secondary well control while running 2%" liner. Page 5 of 6 August 31, 2017 PTD Application: 2K-041-1, 2K-041-1-01, & 2K -04L1-02 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 (1R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 2K -04L1 11,930' 2K -04L1-01 11,970' 2K -04L1-02 11,970' - Distance to Nearest Well within Pool Lateral Name Distance Well 2K -04L1 400' 2K-04 21K-041-1-01 920' 2M-22 21K-041-1-02 920' 2M-22 16. Attachments Attachment 1: Directional Plans for2K-041-1, 2K -04L1-01, & 2K -04L1-02 laterals, Attachment 2: Current Well Schematic for 2K-04 Attachment 3: Proposed Well Schematic for 2K -04L1, 2K -04L1-01, & 2K -04L1-02 laterals. Page 6 of 6 August 31, 2017 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-04 2K-041-1 Plan: 2K-04L1_wp02 Standard Planning Report 24 July, 2017 BT�a GHES GE company ConocoPhillips Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupawk River Unit Site: Kupawk 2K Pad Well: 2K-04 Wellbore: 21K-0411 Design: 21K-0411_wp02 ConocoPhillips 2K-04 Planning Report Local Co-ordinate Reference: Well 2K-04 TVD Reference: Mean Sea Level MD Reference: 2K-04 @ 154.00usft (2K-04) North Reference: True Survey Calculation Method: Minimum Curvature Project Kupawk River Unit North Slope Alaska, United States Map System: US Stale 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 BAKER IGHES BAT GEmmpa Site Kuparuk 2K Pad 2K-04 Site Position: Northing: 5,938,600.18 usft Latitude: 70° 14'36.519 N From: Map Easting: 498,310.17usft Longitude: 150° 0'49.133 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: -0.01 ° Well 2K-04 Magnetics Model Name Sample Date Well Position +N/S 0.00 usft Northing: 5,938,525.46 usft Latitude: 70° 14'35.784 N (nT) +E/ -W 0.00 usft Easting: 498,310.06 usft Longitude: 150° 0'49.136 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 118.50 usft Wellbore 2K-041-1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2017 10/1/2017 17.30 80.84 57,474.37 Design 2K-04L1_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 10 400.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) V) _118.50 0.00 0.00 135.00 J 7242017 12:5625PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Planning Report �F�UGHES aGEmmpany Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 2K-04 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-04 @ 154.00usft (2K-04) Site: Kuparuk 2K Pad North Reference: True Well: 2K-04 Survey Calculation Method: Minimum Curvature Wellbore: 2K-041-1 Azimuth System Design: 2K-0411_wp02 Rate Rate Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-8 +E/ -W Rate Rate Rate TFO (usft) V) (I (usft) (usft) (usft) (.1100ft) (.1100ft) (°/10oft) V) Target 10,400.00 63.97 304.90 5,940.16 3,538.80 -6,911.51 0.00 0.00 0.00 0.00 10,482.00 65.18 305.64 5,975.36 3,581.57 -6,971.97 1.69 1.48 0.90 29.07 10,511.00 68.66 305.64 5,986.73 3,597.11 -6,993.65 12.00 12.00 0.00 0.00 10,585.07 98.00 289.53 5,995.30 3,630.42 -7,058.08 45.00 39.61 -21.75 330.00 10,675.00 94.79 248.92 5,984.85 3,629.14 -7,145.52 45.00 -3.57 -45.16 268.00 10,775.00 89.86 204.14 5,980.57 3,562.11 -7,216.12 45.00 -4.92 44.78 265.00 10,875.00 89.90 159.14 5,980.79 3,464.70 -7,218.92 45.00 0.04 -45.00 270.00 11,075.00 89.91 145.14 5,981.13 3,288.32 -7,125.69 7.00 0.00 -7.00 270.00 11,325.00 86.92 127.89 5,988.11 3,107.69 -6,954.40 7.00 -1.20 -6.90 260.00 11,525.00 90.59 114.37 5,992.48 3,004.58 -6,783.66 7.00 1.84 -6.76 285.00 11,625.00 92.98 120.96 5,989.36 2,958.20 -6,695.19 7.00 2.38 6.58 70.00 11,725.00 90.57 127.54 5,986.27 2,901.99 -6,612.63 7.00 -2.41 6.58 110.00 11,925.00 90.55 113.54 5,964.30 2,800.63 -6,440.80 7.00 -0.01 -7.00 270.00 12,025.00 86.54 107.80 5,986.84 2,765.37 -6,347.32 7.00 4.01 -5.74 235.00 12,250.00 86.67 123.57 6,000.25 2,668.33 -6,145.55 7.00 0.06 7.01 90.00 12,450.00 87.98 137.53 6,009.64 2,538.77 -5,994.14 7.00 0.65 6.98 85.00 12,700.00 83.60 154.52 6,028.12 2,332.88 -5,855.27 7.00 -1.75 6.80 105.00 12,800.00 89.67 158.02 6,033.99 2,241.55 -5,815.13 7.00 6.07 3.49 30.00 12,950.00 91.49 168.36 6,032.47 2,098.17 -5,771.80 7.00 1.21 6.89 80.00 13,100.00 93.28 178.71 6,026.21 1,949.46 -5,754.94 7.00 1.19 6.90 80.00 13,250.00 89.66 188.57 6,022.36 1,800.02 -5,764.47 7.00 -2.41 6.57 110.00 13,350.00 87.27 195.16 6,025.04 1,702.26 -5,785.00 7.00 -2.39 6.58 110.00 13,600.00 87.40 177.64 6,036.76 1,455.05 -5,812.72 7.00 0.05 -7.01 270.00 13,850.00 87.52 195.16 6,047.94 1,207.82 -5,840.44 7.00 0.05 7.01 90.00 7242017 12..56:25PM Page 3 COMPASS 5000.14 Build 85 I, ConocoPhillips BAER ConocoPhillips Planning Report UGHES a GE company Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 2K-04 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-04 @ 154.00usft (2K-04) Site: Kuparuk 2K Pad North Reference: True Well: 2K-04 Survey Calculation Method: Minimum Curvature Wellbore: 2K -04L1 Map Map Design: 2K -04L1 wp02 Azimuth System Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +EI -W Section Rate Azimuth Northing Easting (usft) (°) (1 (usft) (usft) (usft) (usft) (°7100ft) (°) (usft) (usft) 10400.00 63.97 304.90 5,940.16 3,538.80 -6,911.51 -7,389.49 0.00 0.00 5,942,065.46 491400.03 TIP 10,482.00 • 65.18 305.64 5,975.36 3,581.57 -6,971.97 -7,462.48 1.69 29.07 5,942,108.23 491,339.59 KOP 10,500.00 67.34 305.64 5,982.61 3,591.17 -6,985.36 -7,478.74 12.00 0.00 5,942,117.83 491,326.20 10,511.00 68.66 305.64 5,986.73 3,597.11 -6,993.65 -7,488.80 12.00 0.00 5,942,123.78 491,317.91 End 12 dis, Start 46 dis 10,585.07 98.00 289.53 5,995.30 3,630.42 -7,058.08 -7,557.90 45.00 -30.00 5,942,157.10 491,253.50 4 10,600.00 97.71 282.76 5,993.25 3,634.53 -7,072.28 -7,570.85 45.00 -92.00 5,942,161.21 491,239.31 10,675.00 94.79 248.92 5,984.85 3,629.14 -7,145.52 -7,618.83 45.00 -92.93 5,942,155.84 491,166.07 6 10,700.00 93.72 237.69 5,982.99 3,617.95 -7,167.76 -7,626.65 45.00 -95.00 5,942,144.66 491,143.83 10,775.00 89.86 204.14 5,980.57 3,562.11 -7,216.12 -7,621.36 45.00 -95.84 5,942,088.83 491,095.46 6 10,800.00 89.86 192.89 5,980.63 3,538.44 -7,224.05 -7,610.23 45.00 -90.00 5,942,065.16 491,087.52 10,875.00 89.90 159.14 5,980.79 3,464.70 -7,218.92 -7,554.46 45.00 -89.97 5,941,991.43 491,092.64 End 45 dis, Start 7 dls 10,900.00 89.90 157.39 5,980.83 3,441.48 -7,209.66 -7,531.49 7.00 -90.00 5,941,968.21 491,101.90 11,000.00 89.90 150.39 5,981.00 3,351.74 -7,165.68 -7,436.93 7.00 -90.00 5,941,878.47 491,145.85 11,075.00 89.91 145.14 5,981.13 3,288.32 -7,125.69 -7,363.82 7.00 -89.99 5,941,815.05 491,185.82 8 11,100.00 89.60 143.42 5,981.24 3,268.02 -7,111.09 -7,339.14 7.00 -100.00 5,941,794.75 491,200.41 11,200.00 88.39 136.52 5,982.99 3,191.51 -7,046.82 -7,239.59 7.00 -99.99 5,941,718.23 491,264.66 11,300.00 87.21 129.62 5,986.83 3,123.31 -6,973.87 -7,139.79 7.00 -99.87 5,941,650.03 491,337.59 11,325.00 86.92 127.89 5,988.11 3,107.69 -6,954.40 -7,114.97 7.00 -99.61 5,941,634.40 491,357.05 9 11,400.00 88.29 122.82 5,991.25 3,064.35 -6,893.30 -7,041.12 7.00 -75.00 5,941,591.04 491,418.14 11,500.00 90.13 116.06 5,992.64 3,015.23 -6,806.28 -6,944.85 7.00 -74.79 5,941,541.92 491,505.14 11,525.00 90.59 114.37 5,992.46 3,004.58 -6,783.66 -6,921.33 7.00 -74.69 5,941,531.26 491,527.75 10 11,600.00 92.38 119.31 5,990.53 2,970.74 -6,716.79 -6,850.12 7.00 70.00 5,941,497.41 491,594.61 11,625.00 92.98 120.96 5,989.36 2,958.20 -6,695.19 -6,825.98 7.00 70.13 5,941,484.87 491,616.20 11 11,700.00 91.17 125.89 5,986.65 2,916.93 -6,632.66 -6,752.58 7.00 110.00 5,941,443.58 491,678.72 11,725.00 90.57 127.54 5,986.27 2,901.99 -6,612.63 -6,727.85 7.00 110.18 5,941,428.64 491,698.75 12 11,800.00 90.57 122.29 5,985.53 2,859.08 -6,551.14 -6,654.03 7.00 -90.00 5,941,385.72 491,760.21 11,900.00 90.56 115.28 5,984.55 2,810.96 -6,463.56 -6,558.07 7.00 -90.05 5,941,337.59 491,847.78 11,925.00 90.55 113.54 5,984.30 2,800.63 -6,440.80 -6,534.68 7.00 -90.12 5,941,327.25 491,870.53 13 12,000.00 87.54 109.23 5,985.55 2,773.29 -6,370.99 -6,465.99 7.00 -125.00 5,941,299.91 491,940.33 12,025.00 86.54 107.60 5,986.84 2,765.37 -6,347.32 -6,443.65 7.00 -124.93 5,941,291.97 491,963.99 14 12,100.00 66.55 113.06 5,991.36 2,739.25 -6,277.19 -6,375.58 7.00 90.00 5,941,265.84 492,034.12 12,200.00 86.62 120.07 5,997.32 2,694.64 -6,187.96 -6,280.95 7.00 89.68 5,941,221.22 492,123.33 12,250.00 86.67 123.57 6,000.25 2,668.33 -6,145.55 -6,232.36 7.00 89.27 5,941,194.90 492,165.72 16 12,300.00 86.98 127.06 6,003.02 2,639.47 -6,104.82 -6,183.15 7.00 85.00 5,941,166.04 492,206.44 12,400.00 87.64 134.04 6,007.72 2,574.57 -6,028.97 -6,083.62 7.00 84.81 5,941,101.12 492,282.27 12,450.00 87.98 137.53 6,009.64 2,538.77 -5,994.14 -6,033.67 7.00 84.48 5,941,065.32 492,317.09 7242017 12:56:25PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips BAER ConocoPhillips Planning Report UGI�ES a6Ecompery Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 2K-04 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-04 @ 154.00usft (2K-04) Site: Kuparuk 2K Pad North Reference: True Well: 2K-04 Survey Calculation Method: Minimum Curvature Wellbore: 2K-041-1 Depth Inclination Design: 2K -04L1 wp02 +Nl-S +El -W Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +Nl-S +El -W Section Rate Azimuth Northing Easting (usft) (I Wall) (usft) (usft) (usft) (-1100ft) (1) (usft) (usft) 12,500.00 87.07 140.91 6,011.79 2,500.94 -5,961.51 -5,983.86 7.00 105.00 5,941,027.49 492,349.70 12,600.00 85.30 147.70 6,018.45 2,419.96 -5,903.33 -5,885.46 7.00 104.85 5,940,946.50 492,407.86 12,700.00 83.60 154.52 6,028.12 2,332.88 -5,855.27 -5,789.90 7.00 104.40 5,940,859.42 492,455.90 17 12,800.00 89.67 158.02 6,033.99 2,241.55 -5,815.13 -5,696.93 7.00 30.00 5,940,768.09 492,496.02 18 12,900.00 90.89 164.91 6,033.50 2,146.79 -5,783.35 -5,607.46 7.00 80.00 5,940,673.33 492,527.77 12,950.00 91.49 168.36 6,032.47 2,098.17 -5,771.60 -5,564.91 7.00 80.03 5,940,624.71 492,539.31 19 13,000.00 92.09 171.81 6,030.90 2,048.94 -5,763.19 -5,524.01 7.00 80.00 5,940,575.49 492,547.91 13,100.00 93.28 178.71 6,026.21 1,949.46 -5,754.94 -5,447.83 7.00 80.11 5,940,476.02 492,556.13 20 13,200.00 90.87 185.29 6,022.59 1,849.65 -5,758.43 -5,379.72 7.00 110.00 5,940,376.21 492,552.62 13,250.00 89.66 188.57 6,022.36 1,800.02 -5,764.47 -5,348.90 7.00 110.24 5,940,326.60 492,546.58 21 13,300.00 88.46 191.86 6,023.18 1,750.83 -5,773.33 -5,320.39 7.00 110.00 5,940,277.41 492,537.70 13,350.00 87.27 195.16 6,025.04 1,702.26 -5,785.00 -5,294.29 7.00 109.95 5,940,228.84 492,526.02 22 13,400.00 87.28 191.65 6,027.42 1,653.68 -5,796.58 -5,268.13 7.00 -90.00 5,940,180.27 492,514.43 13,500.00 87.32 184.65 6,032.14 1,554.86 -5,810.73 -5,208.26 7.00 -89.83 5,940,081.47 492,500.26 13,600.00 67.40 177.64 6,036.76 1,455.05 -5,812.72 -5,139.09 7.00 -89,50 5,939,981.67 492,498.25 23 13,700.00 87.42 184.65 6,041.29 1,355.23 -5,814.71 -5,069.92 7.00 90.00 5,939,881.86 492,496.24 13,800.00 87.47 191.65 6,045.75 1,256.40 -5,628.86 -5,010.04 7.00 89.68 5,939,783.04 492,482.06 13,850.00 87.52 195.16 6,047.94 1,207.82 -5,640.44 -4,983.87 7.00 89.37 5,939,734.47 492470.48 Planned TD at 13860.00 7242017 12:56.25PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips BAT ConocoPhillips Planning Report '1lIGHES a GEcompany Database: EDTAlaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kuparuk 2K Pad Well: 2K-04 Wellbore: 2K-041.1 Design: 2K -04L1 wp02 Targets Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2K-04 Mean Sea Level 2K-04 @ 154.00usft (2K-04) True Minimum Curvature Target Name -hitimiss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting -Shape (1 (1) (usft) (usft) (usft) (usft) (usft) 2K-041_1_708 0.00 0.00 6,023.00 1,805.031,134,400.00 5,940,076.00 1,632,597.00 -plan misses target center by 1140154.95usft at 13100.00usft MD (6026.21 TVD, 1949.46 N. -5754.94 E) 5,944,045.00 - Point MD (6026.21 2K-041_7_702 0.00 0.00 5,980.00 3,282.871,133,023.53 5,941,554.00 1,631,221.00 - plan misses target center by 1138779.25usft at 13100.00usft MD (6026.21 TVD, 1949.46 N, -5754.94 E) - Point 2K-04L1_Faultl 2K-04L1_TOS 0.00 0.00 6,010.00 2,547.061,134,223.82 5,940,818.00 1,632,421.00 - plan misses target center by 1139978.91 usft at 13100.00usft MD (6026.21 TVD, 1949.46 N, -5754.94 E) 0.00 - Point Point 2 21K -041_1_T04 0.00 0.00 5,984.00 2,796.971,133,724.71 5,941,068.00 1,631,922.00 - plan misses target center by 1139479.96usft at 13100.00usft MD (6026.21 TVD, 1949.46 N, -5754.94 E) 5,943,795.02 - Point 0.00 2K-04L1_T03 0.00 0.00 5,993.00 3,013.921,133,365.63 5,941,285.00 1,631,563.00 - plan misses target center by 1139121.06usft at 13100.00usft MD (6026.21 TVD, 1949.46 N, -5754.94 E) Point - Point -969.08 2K-04L1_T07 0.00 0.00 6,033.00 2,2911,09 1,134,461.90 5,940,569.00 1,632,659.00 - plan misses target center by 1140216.89usft at 13100.00usft MD (6026.21 TVD, 1949.46 N, -5754.94 E) 0.00 - Point -2.65 2K-04L7_Faultl_M 0.00 0.00 0.00 2,778.981,133,775.72 5,941,050.00 1,631,973.00 - plan misses target center by 1139546.89usft at 13100+00usft MD (6026.21 TVD, 1949.46 N, -5754.94 E) -1,531.18 - Rectangle (sides W1.00 H1,000.00 D0.00) 5,942,513.99 2K-04 CTD Polygon Nor 0.00 0.00 0.00 5,774.311,133,871.06 5,944,045.00 - plan misses target center by 1139648.35usft at 13100.00usft MD (6026.21 TVD, 1949.46 N, -5754.94 E) - Polygon 2K-04L1_Faultl Point 1 0.00 0.00 0.00 5,944,045.00 Point 2 0.00 -249.94 299.10 5,943,795.02 Point 3 0.00 -447.99 191.14 5,943,597.01 Point 0.00 -969.08 49.27 5,943,076.01 Points 0.00 -1,285.13 -2.65 5,942,760.00 Point 0.00 -1,531.18 -93.59 5,942,513.99 Point 0.00 -1,774.25 -256.54 5,942,270.96 Point 0.00 -1,952.32 -443.51 5,942,092.97 Point 0.00 -2,028.39 -666.51 5,942,016.96 Point 10 0.00 -2,160.44 -798.49 5,941,884.96 Point 11 0.00 -2,215.50 -999.49 5,941,829.95 Point 12 0.00 -1,993.49 -1,061.56 5,942,051.95 Point 13 0.00 -1,754.43 -923.61 5,942,290.95 Point 14 0.00 -1,511.31 -561.64 5,942,533.97 Point 15 0.00 -1,375.26 -454.67 5,942,669.98 Point 16 0.00 -1,212.23 -395.71 5,942,832.98 Point 17 0.00 -823.17 -315.81 5,943,221.98 Point 18 0.00 -413.10 -214.91 5,943,631.99 Point 19 0.00 0.00 0.00 5,944,045.00 1,632,069.00 1,632,069.00 1,632,368.01 1,632,260.02 1,632,118.05 1,632,066.06 1,631,975.08 1,631,812.09 1,631,625.10 1,631,402.10 1,631,270.11 1,631,069.11 1,631,007.10 1,631,145,09 1,631,507.08 1,631,614.07 1,631,673.06 1,631,753.04 1,631,854.02 1,632,069.00 2K-04L1_T05 0.00 0.00 6,000.00 2,661.021,133,986.77 5,940,932.00 1,632,184.00 - plan misses target center by 1139741.93usft at 13100.00usft MD (6026.21 TVD, 1949.46 N, -5754.94 E) - Point 2K-04L1_Faultl 0.00 0.00 5,984.00 2,778.981,133,775.72 5,941,050.00 1,631,973.00 - plan misses target center by 1139530.96usft at 13100.00usft MD (6026.21 TVD, 1949.46 N, -5754.94 E) - Polygon Point 5,964.00 0.00 0.00 5,941,050.00 1,631,973.00 Point 5,984.00 1.00 1.00 5,941,051.00 1,631,974.00 2K -041-7_T01 0.00 0.00 5,997.00 3,631.921,133,102.46 5,941,903.00 1,631,300.00 La0tude Longitude 70° 0'59.567 N 140° 55'22A90 W 70° V 15.929 N 140" 55'55.272 W 70" T7.031 N 140° 55' 70° 1'10.187 N 140" 55'37.432 W 70" 1' 12.818 N 140° 55'4&704 W 70° V4,265 N 140' 55'18.627 W 70° V9.938 N 140° 55'36.060 W 70" 1'38.889 N 140° 55'20.559 W 70° V8.484 N 140' 55'30.570 W 70' V9.938 N 140° 55'36.060 W 70° 1' 19.204 N 140° 55'51.541 W 724/2017 12:56:25PM Page 6 COMPASS 5000.14 Build 85 2K-04 CTD Polygon SOL 0.00 0.00 0.00 ConocoPhillips ConocoPhillips Planning Report Database: EDT Alaska Sandbox Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Project: Kupamk River Unit MD Reference: Site: Kuparuk 2K Pad North Reference: Well: 2K-04 Survey Calculation Method: Wellbore: 2K-041_1 Point 3 Design: 2K-04L1_wp02 -365.09 2K-04 CTD Polygon SOL 0.00 0.00 0.00 3,587.941,133,197.48 5,941,859.00 - plan misses target center by 1138969.54usft at 13100.00usft MD (6026.21 TVD, 1949.46 N, -5754.94 E) - Polygon - plan misses target center by 1139976.89usft at 13100.00usft MD (6026.21 TVD, 1949.46 N, -5754.94 E) Depth - Polygon Diameter Point 1 0.00 0.00 0.00 5,941,859.00 Point 0.00 233.02 -21.07 5,942,092.00 Point 3 0.00 190.92 -365.09 5,942,049.98 Point 0.00 -31.14 -480.04 5,941,827.97 Points 0.00 -365.14 -378.94 5,941,493.98 Point 0.00 -587.11 -187.86 5,941,271.99 Point 0.00 -954.98 420.30 5,940,904.02 Point 0.00 -1,114.91 732.38 5,940,744.04 Point 0.00 -1,287.86 961.45 5,940,571.05 Point 10 0.00 -1,357.85 1,041.48 5,940,501.05 Point 11 0.00 -1,478.85 1,066.51 5,940,380.06 Point 12 0.00 -1,874.91 1,007.62 5,939,984.05 Point 13 0.00 -2,325.98 930.73 5,939,533.04 Point 14 0.00 -2,457.99 916.77 5,939,401.05 Point 15 0.00 -2,562.91 1,267.83 5,939,296.06 Point 16 0.00 -1,815.80 1,382.64 5,940,043.07 Point 17 0.00 -1,437.76 1,395.54 5,940,421.07 Point 18 0.00 -1,162.74 1,350.45 5,940,696.07 Point 19 0.00 -857.79 1,066.34 5,941,001.06 Point 20 0.00 -499.93 430.18 5,941,359.02 Point 21 0.00 -278.01 69.08 5,941,581.00 Point 22 0.00 0.00 0.00 5,941,859.00 Well 2K-04 Mean Sea Level 2K-04 @ 154.00usft(2K-04) True Minimum Curvature 1,631,395.00 1,631,395.00 1,631,373.98 1,631,029.99 1,630,915.00 1,631,016.02 1,631,207.03 1,631,815.04 1,632,127.06 1,632,356.07 1,632,436.07 1,632,461.07 1,632,402.10 1,632,325.12 1,632,311.13 1,632,662.13 1,632,777.09 1,632,790.08 1,632,745.05 1,632,461.04 1,631,825.02 1,631,464.01 1,631,395.00 2K-04Li_T09 0.00 0.00 6,047.00 1,222.941,134,281.12 5,939,494.00 1,632,478.00 - plan misses target center by 1140036.29usft at 13100.00usft MD (6026.21 TVD, 1949.46 N, -5754.94 E) - Point 2K-04L1_Fault2_M 0.00 0.00 0.00 2,459.051,134,221.84 5,940,730.00 1,632,419.00 -plan misses target center by 1139992.82usft at 13100.00usft MD (6026.21 TVD, 1949.46 N, -5754.94 E) - Rectangle (sides W1.00 H1,000.00 D0.00) Vertical 2K-04L1_Fault2 0.00 0.00 6,010.00 2,459.051,134,221.84 5,940,730.00 1,632,419.00 - plan misses target center by 1139976.89usft at 13100.00usft MD (6026.21 TVD, 1949.46 N, -5754.94 E) Depth - Polygon Diameter Point 1 6,010.00 0.00 0.00 5,940,730.00 1,632,419.00 Point 6,010.00 1.00 1.00 5,940,731.00 1,632,420.00 BAr:R ES a GE company 70° V 18.636 N 140° 55'49.030 N 70° 0'54,088 N 140° 55'28.351. W 70° 1'6.179 N 140' 55'24.757 W 70° 1'6.179 N 140° 55'24.757 W Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 13,850.00 6,047.94 23/8' 2.375 3.000 724201712:56:25PM Page 7 COMPASS 5000.14 Build 65 Plan Annotations Measured ConocoPhillips Local Coordinates BA_ ICER ConocoPhillips Planning Report +Nl-S UGHES (usft) (usft) a GE company Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 2K-04 5,940.16 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level 10,482.00 Project: Kupawk River Unit MD Reference: 2K-04 @ 154.00usft (2K-04) KOP Site: Kuparuk 2K Pad North Reference: True -6,993.65 Well: 2K-04 Survey Calculation Method: Minimum Curvature 3,630.42 Wellbore: 2K-041-1 4 10,675.00 5,984.85 Design: 2K-04L1_wp02 -7,145.52 5 10,775.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +Nl-S +El -W (usft) (usft) (usft) (usR) Comment 10,400.00 5,940.16 3,538.80 -6,911.51 TIP 10,482.00 5,975.36 3,581.57 -6,971.97 KOP 10,511.00 5,986.73 3,597.11 -6,993.65 End 12 dis, Start 45 dis 10,585.07 5,995.30 3,630.42 -7,058.08 4 10,675.00 5,984.85 3,629.14 -7,145.52 5 10,775.00 5,980.57 3,562.11 -7,216.12 6 10,875.00 5,980.79 3,464.70 -7,218.92 End 45 dis, Start 7 dis 11,075.00 5,981.13 3,288.32 -7,125.69 8 11,325.00 5,988.11 3,107.69 -6,954.40 9 11,525.00 5,992.48 3,004.58 -6,783.66 10 11,625.00 5,989.36 2,958.20 -6,695.19 11 11,725.00 5,986.27 2,901.99 -6,612.63 12 11,925.00 5,984.30 2,800.63 -6,440.80 13 12,025.00 5,986.84 2,765.37 -6,347.32 14 12,250.00 6,000.25 2,668.33 -6,145.55 15 12,450.00 6,009.64 2,538.77 -5,994.14 16 12,700.00 6,028.12 2,332.88 -5,855.27 17 12,800.00 6,033.99 2,241.55 -5,815.13 18 12,950.00 6,032.47 2,098.17 -5,771.80 19 13,100.00 6,026.21 1,949.46 -5,754.94 20 13,250.00 6,022.36 1,800.02 -5,764.47 21 13,350.00 6,025.04 1,702.26 -5,785.00 22 13,600.00 6,036.76 1,455.05 -5,812.72 23 13,850.00 6,047.94 1,207.82 -5,840.44 Planned TD at 13850.00 7241201712:56:25PM Page 8 COMPASS 5000.14 Build 85 ConocoPhillips ProlacF. Kuparuk Rlver Unit Site: Kupamk 2K Pad Well: 2K-04 nna.�wroni. RqM u.R•.e�umn:n tha ra_ sowm: ST<]]Wn WELLBORE DETAILS: 2K.04Li REFERENCE INFORWTION BA�(ER Parent Wellbore: 2K-04 Te MD: 10400.00 c irmm IRAQ Reaena: ww x1(4)4, T. nom vaaul Mai Ream. M rUat Wellbore: 2K -14L1 aRrwk: eos4 on S4) (vs)RO.: SIN 10.MN.O.WEI UGHES Plan: 2Kd L1_wp02 (21K -0412K4 1.1) Latitude nl ww Npo RalxeMa'. 21(434@15e(OaArY 4) -{�1 ce comuany 5938525.46 498310.06 CtladSan Wftd w4)' 14' 35.784 N 150° Mean f 5951 5601 25( 490( ass( C42n( in 385[ 0 735 0( �z80( Z245( cnvo( 175C 1400 1056 WELL DETAILS: 2K-04 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 5938525.46 498310.06 70' 14' 35.784 N 150° 0'49.136 W Sec MD Inc Ali TVDSS +N/ -S +E/ -W Dleg TFace VSect 1 10400.00 63.97 304.90 5940.16 3538.80 -6911.51 0.00 0.00 -7389.49 Annotation 2 10482,00 65.18 305.64 5975.36 3581.57 -6971.97 1.69 29.07 -7462.48 TIP 3 10511.00 68.66 305.64 5986.73 3597.11 -6993.65 12.00 0.00 -7488.80 TDP 4 10585.07 98.00 289.53 5995.30 3630.42 -7058.08 45.00 330.00 -7557.90 End 12 dls, Start 45 cls 5 10675.00 94.79 248.92 5984.85 3629.14 -7145.52 45.00 268.00 -7618.83 4 6 10775,00 89.86 204.14 5980.57 3562.11 -7216.12 45.00 265.00 -7621.36 5 7 10875,00 89.90 159.14 5980.79 3464.70 -7218.92 45.00 270.00 -7554.46 5 8 11075,00 89.91 145.14 5981,13 3288.32 -7125.69 7.00 270.00 -7363.82 End 45 dls, Start 7 cls 9 11325.00 86.92 127.89 5988.11 3107.69 -5954.40 7.00 260.00 -7114.97 5 10 11525.00 90.59 114.37 5992.48 3004.58 -6783.66 7.00 285.00 -6921.33 9 11 11625.00 92.98 120.96 5989.36 2958.20 -6695.19 7.00 70.00 -6825.98 10 12 11725.00 90.57 127.54 5986.27 2901.99 5612.63 7.00 110.00 -6727.85 11 13 11925.00 90.55 113.54 5984.30 2800.63 -6440.80 7.00 270.00 -6534.68 12 14 12025.00 86.54 107.80 5986.84 2765.37 -6347.32 7.00 235.00 -6443.65 13 15 12250.00 86.67 123.57 6000.25 2668.33 -6145.55 7.00 90.00 -6232.36 14 16 12450.00 87.98 137.53 6009.64 2538.77 -5994.14 7.00 85.00 -6033.67 15 17 12700.00 83.60 154.52 6028.12 2332.88 -5855.27 7.00 105.00 -5789.90 16 18 12800.00 89.67 158.02 6033.99 2241.55 -5815.13 7.00 30.00 -5696.93 17 19 12950.00 91.49 168.36 6032.47 2098.17 -5771.80 7.00 80.00 -5564.91 18 20 13100.00 93.28 178.71 6026.21 1949.46 -5754.94 7.00 80.00 -5447.83 19 21 13250.00 89.66 188.57 6022.36 1800.02 5764.47 7.00 110.00 -5348.90 20 22 13350.00 87.27 195.16 6025.04 1702.26 5785.00 7.00 110.00 .5294.29 21 23 13600.00 87.40 177.64 6036.76 1455.05 -5812.72 7.00 270.00 -5139.09 22 24 13850.00 87.52 195.16 6047.94 1207.82 5840.44 7.00 90.00 -0983.87 23 planned TD at 13650.00 Mean f 5951 5601 25( 490( ass( C42n( in 385[ 0 735 0( �z80( Z245( cnvo( 175C 1400 1056 West( -)/East(+) (350 usR/in) 5550 5625 _ f■■■■�■�a�p 4: ■■■ 5700 r g 8 5775 8 3 r o N $ 85p w y West( -)/East(+) (350 usR/in) 5550 5625 _ 5700 r g 8 5775 8 3 r o N $ 85p w y 2K 2K LI 1' , 2K 2K LI M1 TIP 5925 -lief - 6 Plannwl To qt 1395'.0 6000 2' bol 04LI 6075 8 9 14 1. 0 2K Y2K- i 18 1 20 2 22 23 721-041 6225 1 Fault 630 K-041 _Faul2 ea L Venical rection ai i.S3.UU- (/_� ust1/In) 1 Baker Hughes INTEQ BAd<ER ConocclPhiilips Travelling Cylinder Report �jUGHES a GE company Company: ConocoPhillips(Alaska) Inc.-Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2K Pad Site Error. 0.00 usft Reference Well: 2K-04 Well Error: 0.00 usft Reference Wellbore 2K-041_1 Reference Design: 2K-04L1_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 2K-04 2K-04 @ 154.00usft (2K-04) 2K-04 @ 154.00usft (2K-04) True Minimum Curvature 1 DO sigma OAKEDMP2 Offset Datum Reference 2K-04L7wp02 Centre to Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Data 7/20/2017 interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 10,400.00 to 13,850.00us11 Scan Method: Tmv. Cylinder North Results Limited by: Maximum center -center distance of 1,581.45 usft Error Surface: Pedal Curve Summary Site Name Offset Well - Wellbore - Design Kuparuk 2K Pad 2K-01 - 2K-01 - 2K-01 2K-02 - 2K-02 - 2K-02 2K-03 - 2K-03 - 2K-03 2K-04 - 2K-04 - 2K-04 2K-04 - 2K-0411-01 - 2K-041_1-01_wp04 2K-04 - 2K-0411-02 - 21K-041_1-02_wp02 2K-05 - 2K-05 - 2K-05 2K-06 - 2K-06 - 2K-06 2K-07 - 2K-07 - 2K-07 2K-08 - 2K-08 - 2K-08 2K-08 - 2K -08A - 2K -08A 2K-08 - 2K-OBAP61 - 2K-08APB1 2K-08 - 2K-08APB2 - 2K-08APB2 2K-08 - 2K-08APB3 - 2K-08AP03 2K-08 - 2K-08BPB1 - 2K-08BPB1 2K-08 - 2K-08BPB2 - 2K-08BPB2 2K-08 - 2K-08BPB3 - 2K-08BPB3 2K-09 - 2K-09 - 2K-09 2K-09 - 2K -09L1 - 2K -09L1 2K-09 - 2K-091-7-01 - 2K-091.1-01 2K-10 - 2K-10 - 2K-10 2K-11 -2K-11 -2K-11 2K-11 -2K-11A-2K-11A 2K-11 - 2K-11AL1 - 2K-11 AL1 2K-11 - 2K-11APB1 - 2K-11APB1 2K-12 - 2K-12 - 2K-12 2K-26 - 2K-26 - 2K-26 2K-28 - 2K-28 - 2K-28 Reference Offset Centre to No -Go Survey Tool Program Data 7/20/2017 Measured Centre From To Depth Depth (usft) (usft) Survey (Wellbore) Tool Name Description 200.00 10,400.00 2K-04 (2K-04) BOSS -GYRO Sperry -Sun BOSS gyro multishot 10,400.00 13,850.00 2K-04L1_wp02(2K-041-1) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 13,850.00 6,201.94 2 3/8" 2-318 3 Summary Site Name Offset Well - Wellbore - Design Kuparuk 2K Pad 2K-01 - 2K-01 - 2K-01 2K-02 - 2K-02 - 2K-02 2K-03 - 2K-03 - 2K-03 2K-04 - 2K-04 - 2K-04 2K-04 - 2K-0411-01 - 2K-041_1-01_wp04 2K-04 - 2K-0411-02 - 21K-041_1-02_wp02 2K-05 - 2K-05 - 2K-05 2K-06 - 2K-06 - 2K-06 2K-07 - 2K-07 - 2K-07 2K-08 - 2K-08 - 2K-08 2K-08 - 2K -08A - 2K -08A 2K-08 - 2K-OBAP61 - 2K-08APB1 2K-08 - 2K-08APB2 - 2K-08APB2 2K-08 - 2K-08APB3 - 2K-08AP03 2K-08 - 2K-08BPB1 - 2K-08BPB1 2K-08 - 2K-08BPB2 - 2K-08BPB2 2K-08 - 2K-08BPB3 - 2K-08BPB3 2K-09 - 2K-09 - 2K-09 2K-09 - 2K -09L1 - 2K -09L1 2K-09 - 2K-091-7-01 - 2K-091.1-01 2K-10 - 2K-10 - 2K-10 2K-11 -2K-11 -2K-11 2K-11 -2K-11A-2K-11A 2K-11 - 2K-11AL1 - 2K-11 AL1 2K-11 - 2K-11APB1 - 2K-11APB1 2K-12 - 2K-12 - 2K-12 2K-26 - 2K-26 - 2K-26 2K-28 - 2K-28 - 2K-28 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (usft) from Plan (usft) (usft) (usft) (usft) 11,619.40 9,875.00 517.68 11,619.40 9,875.00 517.68 11,619.40 9,875.00 517.68 Out of range Out of range Out of range 21.10 502.32 Pass - Major Risk 6.64 516.64 Pass - Minor 1/10 6.66 516.62 Pass - Minor 1110 Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 7/202017 3:33:32PM Page 2 COMPASS 5000.14 Build 85 Baker Hughes INTEQ BA�(ER COnoccl illip5 Travelling Cylinder Report UIGHES aGEmmpany Company: ConocoPhillips(Alaska) Inc.-Kup2 Project: Kupamk River Unit Reference Site: Kuparuk 2K Ped Site Error: 0.00 usft Reference Well: 2K-04 Well Error: 0.00 usft Reference Wellbore 2K -04L1 Reference Design: 2K-041_1_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well 2K-04 2K-04 Lai 154.00usft (2K-04) 2K-04 @ 154.00usft (2K-04) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Summary Kuparuk 2K Pad- 2K -04 -2K -04-2K-04 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usfd (usft) (usft) (usft) Kuparuk 2K Pad Vertical Measuretl Vertical Reference Offset 2K-28 - 2K-28AL1 - 2K-28AL1 oases Wellbore Ce. Casing- Genres. No Go Out of range 2K-28 - 2K-28AL1 PB1 - 2K-28,41_7 PB1 Doi Glen Depth Out of range 2K-28 - 2K-28AL1 PB2 - 2K-28AL1 PB2 WS + `VN Hole slat Cease Out of range 2K-28 - 2K-28AP01 - 2K-28APB1 (usft) (raft) (usft) (usft( Out of range 2K-29 - 2K-29 - 2K-29 (1 (usft) (usft, 1.1 Out of range 2K-34 - 2K-34 - 2K-34 loan) 10,425.00 6,105.06 10,425.00 Out of range 2K-34 - 2K -34L1 - 2K-341_1 0.47 -6102 3,551]1 -6,92994 Out of range 2K-34 - 2K-34PB1 - 2K-34PB7 2.36 -067 FAIL - Major Risk 10,45000 6.115.81 Out of range Offset Design Kuparuk 2K Pad- 2K -04 -2K -04-2K-04 (affaeselte Error. 000usft survey Program: 206803SGVRG Rule An,,.4 Major Risk Offset well Error, 0.00 usft Reference Greet Semi Major Axis Mani Vertical Measuretl Vertical Reference Offset Toolfacea oases Wellbore Ce. Casing- Genres. No Go Aftaxonb Waraing Galatia Doi Glen Depth Aderom WS + `VN Hole slat Cease Olso n. O.Nation (usft) (raft) (usft) (usft( (asftl Pram (1 (usft) (usft, 1.1 (saft) (urn) loan) 10,425.00 6,105.06 10,425.00 6.10505 023 0.47 -6102 3,551]1 -6,92994 3 000 2.36 -067 FAIL - Major Risk 10,45000 6.115.81 10.450.00 6,11581 046 0.94 -60.89 3,564.74 -694037 3 0.00 448 -146 FAIL -Major Risk 10,475.00 6,126.42 10,475.00 6,12642 0.69 1.41 -60.76 3.57187 5,986.81 3 0.00 662 -2.06 FAIL -Major Risk 10499.99 6,138.61 10,500.00 613686 0.75 1.00 12125 3,591.12 $,98525 3 029 0.38 -2.55 FAIL - Major Risk 10,524.75 6,145.13 10,525.00 6,147.20 0.75 2.39 111.79 3,804.42 -7,003.73 3 2.19 9.74 -2.75 FAIL - Major Risk 10,548.13 6,149.72 10,5$0.00 6.157.30 016 289 90.34 3,617.73 -7,02229 3 6.16 1206 0.16 Pass - Major Risk 10,560.98 6.15064 10,57500 6,167.43 036 3.39 90.94 3.63104 4040.91 3 18.11 14.10 802 Pass - Major Risk 10,507.03 6.149.02 10,800.00 6.177.34 0,77 3.89 84.71 3,84435 -7,05961 3 31.29 15.84 19.73 Pass -Major Risk 10604.86 614861 10.825.00 6,187.15 0.77 441 7281 3,657.64 -7,078.37 3 4622 17.40 33.41 Pass -Major Risk 10,620.73 6,144.57 10.650.00 8,19689 0,70 4.94 61.19 3.670.91 4,097.19 3 62.30 14764 48.19 Pass - Major Risk 10,83451 6,142.91 10,875.00 6208.59 0.78 540 50.82 3,884.16 -7,116.04 3 7856 1954 6129 Pass - Major Risk 10,64632 6.141.60 10,700.00 6.216.29 079 5.99 41.89 3.69141 -0,13489 3 9198 20.15 61.73 Pass - Major Ruk 10,656.39 6,14055 10.725.00 47225.99 079 6.51 34.31 3.71065 -7,15375 3 11134 20.55 100.M Pass -Major Risk 10,664.97 6.13973 10.750.00 6,23569 0.79 7.04 2190 3,723.90 -7,17260 3 137.56 20.81 120.00 Paas -Major Risk 10,67231 6,139.08 10,]]500 6,24539 0.79 757 2245 3,737.15 -7,191.45 3 150.48 sear 140.48 Pass - Major Risk 10,678.56 6138.58 10,800.00 6,255.09 080 8.09 17.84 3,750.40 -7,210.30 3 1]9.9] 2105 161.64 Pass - Major Risk 10.683.93 6,130.13 10.825.00 6,284.79 080 8.62 13.09 3,763.65 -7,229.15 3 20194 21.09 183.38 Pass - Major Risk 10,69000 6,13168 10050.00 6,274.49 0.80 9.14 9.81 3,1`7890 -7.248.00 3 224.32 2089 20545 Pass - Major Risk 11,61940 6,143.65 9,875.00 5.849.80 1A5 em 65.22 3,335.16 6,495.80 3 517.60 21.10 502.32 Pass- Major Ran. CC. Es, SF 11,633.63 6,142.93 9.050.00 5,83695 147 0.00 61 3,327.90 -647560 3 52194 21.51 51241 Pau - Major Risk 11,550.00 6,142.20 9,82500 5,824.09 1.50 Gee 68.87 3,320.01 -6,455.40 3 538.67 2200 522.92 Pass -Major Risk 11.659.89 6,141,01 9,80000 5,81121 1.52 0.00 7025 3.313.66 -643520 3 54939 22.29 53391 Pass - Major Risk 11.672.76 6,141.36 9,775.00 5,798.33 154 0.00 71.80 3,30047 8,41501 3 58131 2268 545.26 Pass -Major Risk 11.685A7 6,140.99 9,750.00 5.785.47 1.5fi 0.00 73.29 3,29923 5.394.84 3 573.16 2305 558.95 Pass - Major Risk 11,70000 6,140.65 9,725.00 5]]2.63 1.56 0.00 74.87 3,29195 5,37486 3 585.36 23.48 568.95 Pass - Maj, Risk 11.71041 6,140.46 9.700.00 5.759.82 1.60 0.00 78.13 3.284.62 5,35448 3 597.86 23.79 581.31 Paas -Major Risk 11.725.00 6.140.27 9,675.00 5,74103 1.63 0.00 7153 327126 5,33430 3 61068 2421 59395 Pass - Major Risk 11,764.37 6139.88 9,650.00 5]34.28 1.71 000 75.37 3,269.85 -6,314.12 3 62340 2481 606.17 Pass - Major Risk 11,014.72 6139.30 9,625.00 5,721.50 1.81 000 72.39 3.262.41 5,29395 3 635.20 25.10 617.36 Pass - Major Risk 11,86833 6,138.87 960000 5,]00.]6 1.92 0.00 89,38 3,254.93 5,273.78 3 846.04 25.57 627.59 Pass - Major Risk 11,91677 6.130.36 9,575.00 5,698.02 2.03 000 66.38 3,247,42 5,253.63 3 655.93 26.02 638.86 Paas -Major Risk 11,947.85 6,138.27 9550.00 5188326 2.09 000 65.38 3,23967 -6,233.50 3 66524 2637 645.81 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 720/2017 3:33:32PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Project: Kuparuk River Unit Avm�u.amexem, M.anaa xamv rrm• WELLBORE DETAILS: 2K-041_1 REFERENCE INFORMATION Site: Kuparuk 2K Pad Mea�em neM Perenl Wellbore: 2K-04 Do Mb (Nk) Reaemwe: M12N�04,TmaN Well: 2K-04 ae.oph si4fa.ani Pe MD:10400.00 W. 2KL4011541MApa (2N04) Vm Jl Wellbore: 2K-041_1 ap A,oM: eau• on (VS)Nfaa.: S—(vS) Releml�cv sld-IOa0N, 0.00E) Plan: 2K-04L1_wp02 (2K-04/2K-04Lt) _ 1 rh Rea: lmll3al t Haemal DWaI Woe= 2K-04 @ IS4a0wa (2KL4) { MwN: eaa6IIol 41 Caledew. Wm, MMhamm cu m A1.14/LI-14ALI 2H-IfN2H-161_1-0I v 3300 O 3000 1 v p2700 tA 2400 1 1 BA (ER HUGHES aGEwmpany Li-IMfIJ 1800 _ \ I500 �1i10 3MJNV2M{Ig t4 1 A 111 2 -JI .�EL'900 4 Al IIt� -2.�-096KL9 - � p K_h l4lpfl�M ftlL1AI i � � o� � 1 0 'll%AI' � e \ -IIIOONIOBpaI-0WOD-10200-9900 -9600 9n DO -9000 -8700 8900 -8I D0 -7900 -7500 -7200 6900 6600 -6300 -6000 -5]00 -5400 -51110 4800 -0500 4200 - � 3900 3600 -,300 -3000 -2]00 -2400 2100 1800 .1500 -1200 West( -)/East(+) (300 usft/in) =-M4 K-34PRI 2K-04 Q 154.DOusR (2K-04) 1 r�]i1i+ �- 3 _ 1 rh i' 1 t .-I tI { l 41 �i0 I t .'.1I�1•1 5900 IylOn 1 �5ou0 � I J-00. G . 9^DO I lo. /2'. n .:IJO I 3- 900 i k 1 X3600 v 3300 O 3000 1 v p2700 tA 2400 1 1 BA (ER HUGHES aGEwmpany Li-IMfIJ 1800 _ \ I500 �1i10 3MJNV2M{Ig t4 1 A 111 2 -JI .�EL'900 4 Al IIt� -2.�-096KL9 - � p K_h l4lpfl�M ftlL1AI i � � o� � 1 0 'll%AI' � e \ -IIIOONIOBpaI-0WOD-10200-9900 -9600 9n DO -9000 -8700 8900 -8I D0 -7900 -7500 -7200 6900 6600 -6300 -6000 -5]00 -5400 -51110 4800 -0500 4200 - � 3900 3600 -,300 -3000 -2]00 -2400 2100 1800 .1500 -1200 West( -)/East(+) (300 usft/in) =-M4 K-34PRI 2K-04 Q 154.DOusR (2K-04) 1 2K-04 Proposed CTD Schematic SIIIIL Camco DS -nipple at 10344' MD (2.813" min 10) /8" 36#J-55 shoe Northern Solution Wedge Assembly 10454' MD 4026' MD 3-1/2" X -nipple at 10469' MD (2.813" min ID) Northem Solution Wedge Assembly 10495' MD 3-1/2" X -nipple at 10509' MD (2.813" min ID) C4 -sand perfs 10,402'-10,424' MD ` •\�•,. 2K-0411-02 wp02 TD 13,000' MD Top of Liner Q 10,475' MD A4 -sand perfs 10,482'-1,0522'MD _'----- -- ----""=-- 2K -04L7-01 wpO4 --7 --- � -=- "- - TO 13,600' MD '------'^"_"�-----TOP of Billet (aj 10,590' MD ------------------- 26#J-55 shoeQ 10,836' 2K -04u wp02 TD 13,850' MD - Top .3 B.H t@ 10,a75' MD II 3-1/2'9.3# L-80 EUE 8rd Tubing to surface 6" 62# H-40 hoe 115' MD 3-1/2" Camco MMG gas lift mandrels @ 3175', 5502', III 7196' 85141, 94851,101451 MD 7" 26# L-80 Tieback 2345' MD III Baker FHL Packer w/ PBR @ 10229' MD SIIIIL Camco DS -nipple at 10344' MD (2.813" min 10) /8" 36#J-55 shoe Northern Solution Wedge Assembly 10454' MD 4026' MD 3-1/2" X -nipple at 10469' MD (2.813" min ID) Northem Solution Wedge Assembly 10495' MD 3-1/2" X -nipple at 10509' MD (2.813" min ID) C4 -sand perfs 10,402'-10,424' MD ` •\�•,. 2K-0411-02 wp02 TD 13,000' MD Top of Liner Q 10,475' MD A4 -sand perfs 10,482'-1,0522'MD _'----- -- ----""=-- 2K -04L7-01 wpO4 --7 --- � -=- "- - TO 13,600' MD '------'^"_"�-----TOP of Billet (aj 10,590' MD ------------------- 26#J-55 shoeQ 10,836' 2K -04u wp02 TD 13,850' MD - Top .3 B.H t@ 10,a75' MD ` KUP P --7D Conoa;Phillips Well AttribuG fJ2Skd. 1170. WellNoreApYUVfi Fila' 2K-04 NONE 1 301 12/512016 /Last WO: I ]51201) 1 40.191 7112/1989 em lnnofalwn CepM (nKB) Entl Oafe gnlwlalion LaatMW By EntlDM Last Tag: Doyant 10.542.0 ]Ifil20D Rev HEason GLV COD&PULL WEE ppro--n 41)2017 HANGER', a1?- asmg Surrogs eaeine 0eaceprion Go (IN mpn) Top INNER BH Depth set Depth lrv0l... Watch (I Gmme Top TnreaE CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H40 WELDED Gaming Descrlplion OOpi) 196171 Too�Me) a. omen MO) SN Di(NEk... WVIsn IL.. Gr to Top Threat SURFACE 95`8 8.921 35.0 4,026.4 2,913.3 3600.F55 BTC Casing Deseriplion oo 1{17) 191117) Top(MB) Sv[OapM (Me) SM pe01h RVO1... WN.en I1... GrWe Top heat PRODUCTION TIEBACK ) 62]6 33.0 2,951 2,057.1 2600 L-80 Hyddl563 capas Oepeopeon OD(nl 191117) Tap MKB) Bet DepM(IIkB) Sal Depth RVD1... Va I1... Getle Top brtat ORIGINAL ) 6.2]6 2342.5 10035.9 6,269.0 2800 J-55 BTC PRODUCTION Tubing Strings f Dennis 0asaip4on Sbing Ma... ID (n) Top MKNj set OepM (R. SN CepM jNDj L.. WIgWh) Grade Tap Conrlectcn TUBING -RWO 2017 31/2 2.992 31.1 10,515.3 6,1432 9.30L410 EUE I Mott Completion Details cONOVci0R; 3801150 ..St., lD Top MKBI Top DVO)mKBI Topi I Sam Des Com (in) 311 31.1 0.21 HANGER Tubing Hanger, FMC, TC -MA N, 31/2' EUE bid lop x 2.992 bottom, 8' ISA BPVG 10,2014 6.007.0 63.62 LOCATOR Locate, sub, Baker, GBH -22 (botlmn of locaWr spaced 2.992 IxALT) PRODUCTION TIEBACK SO 0-_ 10,21#46.007-4 63.62 SEAL Seal Assembly, Baker, W40(seal length =21]1') 2990 23+6.2 ASSEMBLY 10.2(15 .5 60088 63.64 PBR PBR, Baker 20'80-40 4000 GAS NET; s, 1747 10,2286 6,019.0 63.76 FHLPACKER Packer, Baker 4)62 FHL 2940 10344.1 6,069.6 64.05 NIPPLE Nipple, Camillo 2.813"CIS Profile 2,813 10,4533 6,1174 fid.)) WEDGE Wedge AsaemDly, Nonbem Solutions 2.992 ASSEMBLY 1046&6 6.123.7 64.99 NIPPLE Nipple, Halliburton 2.8131 X Profile 2.813 SURFACE 35.Oa.a.64- 10494.6 6,134.6 65.3] WEDGE Wetlge Assembry, NaMem Solutions 2.992 ASSEMBLY 10,5094 6,140.8 65.58 NIPPLE Nipple, Halliburton 2.813"X Profile 2.813 GAS uFT, 55ozo Other In Hole (wireline retrievable plugs, valves, pumps, fish, etc.) (TV01 Tamama) TopImd ISMS.)MSB) 1°p Des cam Bun Dale Io 0171 10,5420 6,1541 6602 FISH Coiletl Tubing 22'19178; cOemically wtin cal (wile 4/1]/1990 OWO 6PS LIFT; ],1955 Perforations &Slots Shot Dens Top BM IahnW c -As UFT. eslay T.PMS) B1mmKB1 KS) 1M01 e) Go. Dale 11) Type Cam 10402.0 10,424.0 6,0 6,095.0 6,104.6 K4 C-0, 2K4M 12/1012003 6.0 APERF 2.5"HSD PJ 10,482.0 10,522.0 6,129.4 6,146.0 A4,2K-04 42911996 4.0 #PERF 2.5"HC. 180 Mg. Phasing, no orient GASUFT;a4e4.s 10,4820 10,522.0 6,129.4 6,146.0 A1, 2K-04 11/4/1989 20 (PERF 4- Super Omnikone Ca, 180 deg. Phasing Mandrel Inserts sl WaUFT:m,wB m an Top(I Valw Litt(( PonSas TRO Run N Tap me) Me) MSM Motel EDGE) Sm Type Type (In) IW9 Run Dao Com It 3,1)4.] 2.500.4 Camco MMG 112 GAS LIFT GLV RK 0.188 1200,. ]1141201) 2 6502.0 3.643.3 Camto MMG 112 GAS LIFT GLV RK 0.188 1,2]4.0 )114/201) LOCATOR, lGaine 3 7,1955 4,504.6 Camco MMG 112 GAS LIFT OV RK 0.188 0.0 )1141201) SEA-aNGEeR1;I0.SEi 4 8,5137 5,156.8 Camco MMG 112 GAS LIFT DMY RK 0.000 ]181201] Pea; to..a 5 9.4845 66497 Camco MMG 112 GAS LIFT DMY RK 0.000 702017 FHLPADNEp IoM6 6 10,1446 6981.3 Canino MMG 112 GAS LIFT DMY RK 0.000 7181209 Notes: General & Safety EM DSM AnnoMbn 101292010 NOTE'.View Schemafit w/ Alaska SCbemanc90 NIPPLE; 10,3M.1 APERF;ID10201G4ba- 1 WEDGE ASSEMI 10.0.637 NIPPLE; IO.a899 T f WEDGE ASSEMBLY; 10. IBIE IFERF; IO,Nx610,420 R £RF; f0,Nx010,5II.0 NIPPLE: 1D.5034 FIGH', IGER0 OEIfiINALPROpIC ON: 2SIR .510,45.6 Haggerty -Sherrod, Ann (Northland Staffing Services) From: Peirce, John W Sent: Wednesday, September 06, 2017 1:08 PM To: Haggerty -Sherrod, Ann (Northland Staffing Services) Subject: 10-404 Requested for 1J-136 MARCIT MBE Job Categories: Red Category Ann, Please prepare 10-404's for 11-136 for the MARCIT Job of 8/15/17 to close out approval #317-222. The Pre -job and Post -job injection rate data reported should be 'Shut In'. Thanks, John Peirce Sr Wells Engr CPAI Drilling & Wells (907)265-6471 office TRANSMITTAL LETTER CHECKLIST WELL NAME: i{t` u- A PTD: 417-1 z- /evelopment _ Service _ Exploratory Stratigraphic Test _ Non -Conventional FIELD: POOL:G/UFiI'/[� ©� / 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. / Rs _ r 17 , API No. 50-_L1Db - 000 q7 -na - 'p (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(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - _-� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company) 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 PTD#:2171260 Administration Appr Date PKB 9/11/2017 Engineering Appr Date VTL 9/25/2017 Geology Appr Date PKB 9/11/2017 CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 2K-041_1 Program DEV Well bore seg d❑ .mmnanv CONOCOPHILLIPS ALASKA. INC. Initial Class/Tvpe DEVI PEND_ _GeoArea 890 Unit 11180 _ _ . On/OffShore On Annular Disposal n 17 Nonconven. gas conforms to AS31,05.0300A.A),0.2.A-D) NA 1 Permit fee attached. _ NA. 2 Lease. number appropriate Yes 3 Unique well. name and number. Yes 4 Well located in a defined pool Yes 5 Well located proper distance from drilling unit. boundary Yes 6 Well located proper distance from other wells _ Yes 7 Sufficient acreage available in. drilling unit _ Yes 8 If deviated, is wellbore plat. included Yes 9 Operator only affected party Yes 10 Operator has. appropriate bond in force Yes 11 Permit can be issued without conservation order.. Yes 12 Permit can be issued without administrative approval Yes 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: duration of pre -production less than 3 months (For service well only) NA 18 Conductor string. provided NA 19 Surface casing protects all known. USDWs NA 20 CMT vol adequate to circulate on conductor & surf csg NA 21 CMT vol adequate. to tie-in long string to surf csg NA 22 CMT will cover all known productive horizons No. 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit _ Yes 25 If a re -drill, has a 10403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes 27 If diverter required, does it meet regulations. NA. 28 Drilling fluid program schematic .& equip list adequate Yes 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogensulfide measures No 36 Data presented on potential overpressure zones Yes 37 Seismic analysis of shallow gas zones NA 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date Date Commissioner: ommissioner: QTS �1z6� r7 ADL0025588, Surf Loc; ADL0025589, Top Prod Intery and TD. KRU 2K -04L1 KUPARUK RIVER, KUPARUK RIV OIL - 490100,. governed. by Conservation. Order No. 432D. CO 432D contains no spacing restrictions with. respect to drilling unit boundaries. CO 432D hs. no intenvell spacing restrictions. Wellbore will be more than 500' from an external property line where ownership of landownership changes. Conductor set for KRU 2K-04 Surface casing set in KRU 2K-04 Surface casing set and fully cemented Productive_ interval will be completed with. slotted liner Rig has steel tanks; all waste to approved disposal wells Anti -collision analysis complete; no major risk failures Max formation pressure is 4405 psig(13.8 ppg EMW); will drill w/ 8.7 ppg EMW and. maintain overbal w/ MPD MPSP is 3803 psig; will test BOPS. to 4500 psig 1-12S measures required Wells on 2K -Pad are H2S-bearing. 1-12S measures required. Max. potential reservoir pressure is 13.8 ppg EMW; will be drilled using 8,7 ppg mud and MPD. Onshore development lateral to be drilled.
