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Home My WebLink About217-127DATA SUBMITTAL COMPLIANCE REPORT 1/26/2018 Permit to Drill 2171270 Well Name/No. KUPARUK RIV UNIT 2K -04L1-01 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20099.61.00 MD 12946 TVD 6101 Completion Date 10/26/2017 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log No Samples No J Directional Survey Yes J DATA INFORMATION List of Logs Obtained: GR/Res (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH I Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 28772 Digital Data 11/7/2017 Electronic File: 2K-041-1-01 EOW - NAD27.pdf' ED C 28772 Digital Data 11/7/2017 Electronic File: 2K-041_1-01 EOW - NAD27.txt - Log C 28777 Log Header Scans 0 0 2171270 KUPARUK RIV UNIT 21K-041-1-01 LOG HEADERS ED C 28777 Digital Data 10209 12946 11/9/2017 Electronic Data Set, Filename: 2K -04L1-01 GAMMA RES.Ias ED C 28777 Digital Data 11/9/2017 Electronic File: 2K -04L1-01 21VID Final Logs.cgm , ED C 28777 Digital Data 11/9/2017 Electronic File: 2K-041-1-01 51VID Final Logs.cgm - ED C 28777 Digital Data 11/9/2017 Electronic File: 2K-041-1-01 5TVDSS Final Logs.cgm ED C 28777 Digital Data ?11/9/2017 Electronic File: 2K-041-1-01 21VID Final Logs.pdf ED C 28777 Digital Data p 11/9/2017 Electronic File: 2K-041_1-01 51VID Final Logs.pdf . ED C 28777 Digital Data 11/9/2017 Electronic File: 2K-041_1-01 5TVDSS Final Logs.pdf ED C 28777 Digital Data 11/9/2017 Electronic File: 2K -04L1-01 EOW - NAD27.pdf ED C 28777 Digital Data 11/9/2017 Electronic File: 2K-041-1-01 EOW - NAD27.txt . ED C 28777 Digital Data 11/912017 Electronic File: 2K -D41-1-01 Survey Listing.txt ' ED C 28777 Digital Data 11/9/2017 Electronic File: 2K-041-1-01 Surveys.txt. ED C 28777 Digital Data 11/9/2017 Electronic File: 2K-04L1-01_Final TD 12946.csv . ED C 28777 Digital Data 11/9/2017 Electronic File: 2K-041-1-01—Final TD 12946.xlsx . ED C 28777 Digital Data 11/9/2017 Electronic File: 2K-04L1- 01_25_tapescan_BHI_CTK.txt - AOGCC Page 1 of 2 Friday. January 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/26/2018 Permit to Drill 2171270 Well Name/No. KUPARUK RIV UNIT 2K-041-1-01 Operator CONOCOPHILLIPS ALASKA, INC. MD 12946 TVD 6101 Completion Date 10/26/2017 Completion Status 1 -OIL Current Status 1 -OIL API No. 50-103-20099-61-00 UIC No ED C 28777 Digital Data 11/9/2017 Electronic File: 2K-041-1- - 01_5_tapescan_B H I_CTK.txt ED C 28777 Digital Data 11/9/2017 Electronic File: 2K-04L1-01_output.tap ' ED C 28777 Digital Data 11/9/2017 Electronic File: 2K -04L1-01 21VID Final Logs.tif ED C 28777 Digital Data 11/9/2017 Electronic File: 2K-041.1-01 51VID Final Logs.tif , ED C 28777 Digital Data 11/9/2017 Electronic File: 2K-041.1-01 5TVDSS Final Logs.tif Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report,`f(`7�/� Directional / Inclination Data O Mud Logs, Image Files, Digital Data Y le) Core Chips Y /CA Production Test Information MYNA Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files 0 Core Photographs Y & Geologic Markers/Tops V Daily Operations Summary V Cuttings Samples Y /® Laboratory Analyses Y 1 NA COMPLIANCE HISTORY Completion Date: 10/26/2017 Release Date: 9/26/2017 Description Date Comments Comments: { /� Compliance RevieWLW� V AOGCC Page 2 of Date: _ Friday, January 26, 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil [Z' Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 2canc 25.105 20MC 25.110 GINJ ❑ WINJ ❑ WAG[] WDSPL ❑ No. of Completions: 1b. Well Class: Development R] • Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. ' 6. Date Comp., Susp., or Abend.: 10/26/2017 14. Permit to Drill Number/ Sundry: 217-127 3. Address: P.O. Box 100360 Anchorage, AK 99510.0360 7. Date Spudded: 10/17/2017 15. API Number: 50-103-20099-61-00 4a. Location of Well (Governmental Section): Surface: 5058' FNL, 94' FEL, Sec 2, T1 ON, R8E, UM Top of Productive Interval: 1457' FNL, 1823' FEL, Sec 3, T1 ON, RBE, UM Total Depth: 4724' FNL, 1018' FEL, Sec 34, Ti t N, R8E, UM 8. Date TO Reached: 10/19/2017 16. Well Name and Number: KRU 2K-041-1-01 9. Ref Elevations: KB: 154 GL: 118.5 - BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25589, ADL 25588, ADL 25586 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498310 y- 5938525 Zone- 4 TPI: x- 491301 y- 5942131 Zone- 4 Total Depth: x- 492104 y- 5944143 Zone- 4 11. Total Depth MD/TVD: 12946/6101 • 19. DNR Approval Number: LONS 85-096 12. SSSV Depth MD1 VD: N/A 20. Thickness of Permafrost MD1 VD: 1550/1496 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 1 N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 10530/6145 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 I necessary RECEIVED GR/Res NOV Z 1 2017 AOGCC 23, CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 36 115 36 115 - 179 sx AS 1 95/8 36 J-55 35 4026 35 2913 121/4 1069 sx AS III, 297 sx Class G 7 26 L-80 33 2345 33 2057 81/2 834 sx ASI 7 26 J-55 2342 10836 2055 6269 81/2 73 sx Class G 23/8 4.6 L-80 10629 12946 6140 6101 3 Liner 24. Open to production or injection? Yes ❑e No ❑ If Yes, list each interval open (MD(rVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER @ 10652 - 12946 MD and 6137 -6101 .: i. 11VIP I:! 01% rn; TE I/ q, ( t) Zla} V'I �FRIFIELr (�v 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) AMOUNT 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 hrs Production for Test Period Oil -Bbl: 412 Gas -MCF: 282 Water -Bbl: 1578 Choke Size: 176 Gas -Oil Ratio: 848 Flow Tubing Press. 287 Casinq Press: 1 1336 Calculated 24 -Hour Rate Oil -Bbl: 430 1 Gas -MCF: 372 Water -Bbl: 1 Oil Gravity- API (corr): 22.1 -407R 5/201y�Forrm1j-7-1 ;7-12-q //.),CONTINUED ON PAGE ��it ORIGINAL o PA �e_�`I�n 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� 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 10530 6145 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk A TD 12946 6101 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, paleontoloaicalr o r n orwell test results. 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.Lonwftop.conn Authorized Contact Phone: 263-4372 Signature: Date: A % INSTRUCTIONS General: This fOK 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 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 2K-04 As-DrilleA CTD Schematic 51115' MD I ]' 28tl L-80 Tieback 2345' MD U -sand perts 10,402'-10,424'MD ,I Top of Wedge ®10,1]9' MD 10,482'-1,0522' MD 3-12" 9.3R L-80 EUE BM Tubing W su tace 312' Camco MMG gas lift mandrel.Q 3175', 5502', 7198', 851W. 9485',10145' MD Baker FHL packer V PER Q 10229' MD Camco DS ple at 10344' MD (2.813 -min ID) Norhem Solution Wedge Assembly 10454' MD 3-12' X -nipple at 10489' MD (2.813" min ID) NOMem Solution Wedge Assembly 10495' MD 3 -112 -X -nipple at 10509' MD (2.013" min ID) 3K4I11-02 TO'. 13,01PMD 2 W Slopi Unor 10,330-12801' MO BII mnl Sleeve onT dWx 2K411."I TD: 12.We'MD 2. 'Skeet Uner Mmomd Mlet®10.&tl MD (NOT Onenlen) Md,ored &Iltl 10828'MD K-0CL1 TD: 13T PMD 39'$IOaed Lnel10.,8553-la.MD Sold Pipe 12, WO' -12,X1' Mil Mored BAMt 10530'MO operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Tme our (hr) Phase Op code Adviri'Code Tme P -T -X Operation stat Depth WE) End Depth WS) 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 & hallway house over to 2K -pad, pull subs off of well, install jeeps 10/7/2017 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 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 cep, •' 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 1018/2017 1.00 MIRU WHDBOP BOPE P Test 1 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 C6, 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 13:00 17:18 10/812017 10/8/2017 2.70 MIRU WHDBOP BOPE P Crew change, PJSM, continue on 0.0 0.0 17:18 20:00 testing BOPE. test 13 -18, draw down, down w/ BOP testing •** BOP Test time 8.0 hrs 10/8/2017 1018/2017 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 dear 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 cenrlol of rig personnel during false alarm. 1002017 10/8/2017 1.00 MIRU WHDBOP CTOP P PJSM, test inner reel iron, pac-off, 0.0 0.0 2030 21:30 driller side PDL, and tiger tank line. 10/8/2017 10/9/2017 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 PROD1 WHPST PULD P Prep for Pressure Deploy, valve 0.0 0.0 00:00 00:30 checklist, PJSM pressure deploy Page 1118 ReportPrinted: 111112017 uperations Summary (with Timelog uepths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Mr(hr) Phase Op Code Activity Cade Time P -TX Operation Sart OepM (flKB) End Depth (aKB) 10/9/2017 10/9/2017 1.00 PROD1 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 1019/2017 2.00 PROW 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 1019/2017 1.70 PROD1 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 PRODt 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 08:00 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 mudcing 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 PROD1 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/g/2017 10/9/2017 0.70 PROM 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. 10/9/2017 10/9/2017 0.20 PROD1 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 lbs, set rale 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, 10/912017 10/9/2017 7.00 PROD1 WHPST WPST P Start stacking 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 PROD1 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 Report Printed: 111112017 operations Summary (with Timelog uepths) 2K-04 Qg: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth SlaRTime EM Time Dur (hd Phase OP Code Activity Code Time P-T-X Opvation (ftKa) End Depth WS) 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, WHP 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 WOO 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, WHIP 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- 10/912017 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 10110/2017 10/1012017 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 10/10/2017 10/10/2017 1.25 PROD1 DRILL PULD P PJSM, PD build section BHA# 2 0.0 72.0 03:00 04:15 10110/2017 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 Kt marker correction of minus 10,230.0 10,306.3 06:15 06:30 4.0' 10/10/2017 10/10/2017 0.25 PROD1 DRILL TRIP P Continue IH 10,306.3 10,504.0 06:30 06:45 10110/2017 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 10/102017 0.75 PROD1 DRILL DRLG P PUH to tie-in to K1 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'. 10/102017 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' 10/102017 10/10/2017 0.50 PROD1 DRILL WPRT P Pump 5/5 sweep, pull 1 00'short viper 10,826.0 10,826.0 11:45 12:15 to 10726'. RBIH. 10/102017 10/10/2017 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, OA=1, PUMP=4849 PSI@1.8 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. 10/102017 10/102017 1.35 PROD1 DRILL PULD P At surface. PUD build BHA#2 64.8 0.0 15:45 17:06 10/10/2017 1011012017 1.74 PROD1 DRILL PULD P Crew change, PJSM, PU/MU/PD AL1 0.0 78.3 17:06 18:50 lateral BHA# 3 10/10/2017 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 Report Printed: 11/1/2017 . operations Summary (with Timelog uepths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Dept, Start Time End Time Dur(hr) Phase Op code Actbily code Time P -T -X Operator M(B) End Depth(1KB) 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' 10/1012017 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 it, 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, WHP 146, IA 255, OA 2, CTSW=6 k, DHWOB=0.5 k, ROP 130 fph 10/1112017 10/11/2017 0.25 PROM DRILL WPRT P Wiper up hole PUW 36 k 11,300.0 10,900.0 01:15 _ 01:30 10/11/2017 10/1112017 0.25 PROM 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 PROM 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 PROM 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 PROM DRILL WPRT P Wiper back in hole. RIW=9k 10,890.0 11,690.0 07:48 06:06 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 --1 358 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 PROD1 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 PROD1 DRILL DRLG P BOBD. 1.80 bpm at 5813 psi, Diff 12,090.0 12,302.0 15:18 19:16 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 clearf survey, PUH 12,302.0 12,302.6- 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 PROM 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 PROD1 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 PROD1 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 PROM 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: 1111/2017 Uperations Summary (with Timelog uepths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sme oepm Somme End Time om(Iv1 Phase Op Code AmenyCode nmeP-T-x Opemm„ (Intal End Depmpscet 10/12/2017 10/1212017 7.20 PRODt DRILL DRLG P Drilling break, increase AP to form 12,655.0 12,748.0 0448 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, WHP 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 PROM DRILL DRLG P Hard drilling continuing @12748', 12,748.0 12,764.0 12:00 15:00 have tubed system w/ 1 % LoTorq. ROP=2.5'lhr. 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 10/1212017 2.00 PROD1 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 PROD? 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, WHP 383, IA 259, OA 7, Discussed with town plan forward, slow ROP, crossing fault with no ROP change, w/excessive weight on bit, 10/1212017 10112/2017 2.25 PROD1 DRILL TRIP P Pump 10x10 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 PROD1 DRILL PULD P PUD, drilling BHA# 3 78.3 0.0 22:45 00:00 "" Note: Bit Grade 6-4... 10/13/2017 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 10/13/2017 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 10/13/2017 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' 10113/2017 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' 10/13/2017 10/13/2017 1.25 PROM 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 PROD1 DRILL WPRT P Wgt check to 12847'. PUW=34k 12,920.0 12,920.0 08:15 08:30 I Page 5118 ReportPrinted: 111112017 Operations Summary (with Timelog Uepths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SW Depth Sted Time End Time our(hr) Phase Op Code ArJ ity Code Time P-T.X operation MO) End Depth (WH) 10/13/2017 10/13/2017 4.90 PROD1 DRILL DRLG P BOBD. 1.79 bpm @ 5823 psi, 12,920.0 13,200.0 08:30 13:24 BHP=4268, DIf=1429, WHTP=367, IA=261, OA=3, CTSW=-1.8, W08=1.04, ROP=97'. Note: MWD having difficulties getting accurate surveys (inclination still accurate); send info to Sperry to process. 10/132017 10/13/2017 0.30 PRODi DRILL WPRT P Wiper up hole. PUW=35k. 13,200.0 12,350.0 13:24 13:42 10/13/2017 10/132017 0.40 PROD1 DRILL WPRT P wiper back in hole.RIW=4K 12,350.0 13,200.0 13:42 14:06 10/132017 10/13/2017 4.00 PROD1 DRILL DRLG P BOBD.1.77 bpm @ 5759 psi, 13,200.0 13,330.0 14:06 18:06 BHP=4264, DIf=-1358, WHTP=352, IA=262, OA=3, CTSW=-3.6, WOB=1.0, ROP=31'. 10/132017 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, WHIP 422, IA 263, OA 5, CTSW= minus 1.75 k, DHWOB= 1.3 k, ROP 30 fph 10/132017 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 10/132017 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, WHIP 410, IA 263, OA 5 10/13/2017 10/14/2017 0.55 PRODi 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 PRODi DRILL DRUG P OBD, 1.56 bpm at 5,060 psi, Diff 970, 13,494.0 13,782.0 00:00 09:24 BHP 4,279, WHIP 432, IA 263, OA 5, CTSW= minus 5.0 k, DHWOB= 1.0 k, ROP 60 fph 10/14/2017 10/142017 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). 515 sweep in pipe, PUH slowly and wait for sweep to exit. 10/142017 10/14/2017 1.30 PROD1 DRILL WPRT P Wiper to window. 13,782.0 10,521.0 09:42 11:00 10/142017 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 PROD1 DRILL TRIP P TD well at 13852' (corrected). Pump 13,852.0 78.3 15:06 18:36 10110 low/high sweep. Chase out of hole to swab. 10/14/2017 10/14/2017 0.15 PROD1 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 PRODt DRILL DLOG P Log the K1 Marker correction of minus 10,245.0 10,290.0 20:27 20:39 1 1 8.0' 10/14/2017 10/14/2017 0.15 PROD1 DRILL TRIP P Continue Rill 10,290.0 10,465.0 20:39 20:48 10/142017 10/14/2017 0.50 PRODt 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, shutdown again and montior well. annular pressure 4,077 psi 112.885 ppg. discuss plan forward with TE, Page 6118 ReportPrinted: 111112017 . - Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time Endnne Dur(hr) Phase Op Cade A Mtycode Time P -T -X Operation (MB) End Depth (50) 10/14/2017 10/1412017 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 clear, 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 PROD1 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 PROD1 DRILL TRIP T Continue weighting up completion fluid 10,465.0 10,465.0 00:00 00:46 12.9 ppg -13.1 ppg 10/15/2017 10/15/2017 2.15 PRODi DRILL TRIP P RIH, no correction at RA marker. 10,465.0 13,852.0 00:45 02:54 10/15/2017 10/15/2017 0.60 PROD1 DRILL TRIP P Confirm 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 10/152017 3.00 PROD1 DRILL DISP P POOH, laying in 13.1 ppg beaded liner 13,852.0 71.5 03:30 06:30 running pill. 10/15/2017 10/152017 0.40 PROD1 DRILL PULD P Al surface. Open up @ riser and 71.5 0.0 06:30 06:54 perform flow check. No Flow. Perform PJSM. Fill hole; look 1.5 bbls to fill after 13 mins static. 10/152017 10/152017 0.80 PROD1 DRILL PULD P Undeploy drilling BHA #4. Prep to 0.0 0.0 06:54 07:42 function test 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 10/152017 1.10 PROD1 DRILL PULD P Function lest BOPE. Service blocks. 0.0 0.0 07:42 08:48 10/15/2017 10/152017 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. bbis since flow check). Losses -3.5 bb /hr. 10/15/2017 10/15/2017 0.30 COMPZ1 CASING SFTY P Perform Kick While Running Liner 0.0 0.0 09:48 10:06 Drill. 10/152017 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/ GSandi-1 2,681.7 2,726.7 12:30 13:24 liner assembly. 10/152017 10/15/2017 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 COMPZ1 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. 10/152017 10/15/2017 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 COMPZI 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 -00' per run 10/162017 10/16/2017 3.50 COMPZ1 CASING RUNL P Continue working liner to bottom, 12,580.0 12,784.0 00:00 03:30 10/16/2017 10/162017 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 10/162017 1.50 COMPZ1 CASING RUNL P I Continue to work liner to bottom. 13,038.0 13,061.0 08:30 10:00 gaining T-10' at a time; slow going. E::::: Page 7/16 ReportPrinted: 11/1/2017 Am. ft Operations Summary (with Timelog Uepths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sacoMm srnru,re EDW rise ow(mt Phase Op cotle nmvsrcme rsee P -r -x oP�o„ (nka) tstl wpm (tial 10!16/2017 10/16/2017 0.60 COMPZI CASING RUNL P Begin tubing 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. 10/16/2017 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 10116/2017 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.Continue to work liner to bottom. 10116/2017 10/1612017 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 COMPZ1 CASING TRIP P Set depths, PUH to log tie in. 10,660.4 10,440.0 21:24 21:33 10/16/2017 10116/2017 0.25 COMPZ1 CASING CLOG P Log the RA marker corretion of Plus 10,440.0 10,455.0 21:33 21:46 41.5' 10/16/2017 10/16/2017 0.15 COMPZ1 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 10/16/2017 1.75 COMPZ1 CASING TRIP P POOH, pumping pipe displacement 10,701.5 44.2 21:57 23:42 1 10/16/2017 10117/2017 0.30 COMPZI CASING OWFF P At surface check well for flow, PJSM 44.2 44.2 23:42 00:00 10/17/2017 10/17/2017 0.15 COMPZI CASING OWFF P At surface, check well for flow, PJSM 44.2 44.2 00:00 00:09 10/17/2017 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. 10/17/2017 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. 10117/2017 10/17/2017 0.50 COMPZ1 CASING PULD P MU, Ll upper Liner segment with 0.0 232.1 01:39 02:09 1 1 OHA Billet. 10/17/2017 10117/2017 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 jts of 2-3/8" slotted liner, and ported bullnose. 10/17/2017 10/17/2017 0.25 COMPZ1 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 10/17/2017 0.30 COMPZI CASING RUNL P Continue RIH, tag TOL at 10,701' 10,454.0 10,701.5 04:54 05:12 10/17/2017 10/17/2017 0.25 COMPZI 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 10/17/2017 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 COMPL1 CASING PULD P At surface; perform flow check. Begin 69.8 0.0 07:27 08:27 1 I undeploying upper liner assembly running BHA#6 Page 8118 ReportPrinted: 11/1/2017 Operations Summary (with Timelog uepths) AN77 1h 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth I Start Time Ertl Tkm Dur(hr) Phase op cod. Activity Cade TimePTX opm bw WS) End DePta(WBI 10/17/2017 10/17/2017 1.00 PROD2 DRILL KOST P Makeup 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, 10,556.0 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', pregob 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 10/17/2017 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 RS 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 10/18/2017 10/18/2017 1.70 PROD2 DRILL TRIP P Continue RIH with BHA#8, swapping 296.0 10,240.0 00:00 01:42 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 10/18/2017 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 = 850 psi, annular = 4196 psi Page 9118 Report Printed: 11/1/2017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Slaty Time Fid Time Dw(hr) Phase Op Code Adh*Code Time PJA Operation (#Ka) PSE Depth 0") 10/18/2017 10/1812017 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, dip = 1315 psi, circ pressure = 5548 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 1 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 1 FS, BHP=4300, RIW=1K, DHWOB=2.4K, R0P=-100FPH 10/18/2017 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 10/1812017 10/18/2017 5.40 PROM DRILL DRLG P 11702', D611, 119 BPM @ 5313 PSI 11,702.0 12,111.0 12:54 18:18 FS, BHP=4290, RIW=-1.iK, DHWOB=2.4K, ROP= -105 FPH 10/18/2017 10/18/2017 0.70 PROD2 DRILL WPRT P WT up -hole, PUW = 31K 12,111.0 10,490.0 18:18 19:00 10/1812017 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 10/1812017 10/18/2017 0.60 PROD2 DRILL WPRT P WT in-hole, RIW = 5K 10,510.0 12,111.0 -19:06 19:42 - 10/1812017 10/1912017 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 10/1912017 10/19/2017 1.90 PROM 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 (PUW's -41 K) 10/19/2017 10/19/2017 0.30 PROM DRILL WPRT P WT up -hole, PUW = 40K 12,513.0 11,564.0 01:54 02:12 10/19/2017 10/19/2017 0.30 PROD2 DRILL WPRT P WT in-hole, RIW = 5K 11,564.0 12,513.0 02:12 02:30 10/19/2017 10/19/2017 2.00 PROM 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 PROM DRILL DRLG P OBD, continue to pump Lo Vis sweeps 12,592.0 12,690.0 04:30 06:18 followed by beaded pills, CWT = - 8.7K, WOB = 1.2K, annular = 4354 psi, WHIP = 586 psi 10/19/2017 10/19/2017 0.10 PROD2 DRILL WPRT P 12690, BHA wiper, PUW=36K 12,690.0 12,690.0 06:18 06:24 10/19/2017 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 j FS, BHP=4340, RIW=-7K, DHWOB=I.6K Page 10/18 ReportPrinted: 11/1/2017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth I Slat Too End rine D. M phase op Code Activity Code Time P -T -x operation (MB) End Depth (Po(e) 10/19/2017 10/19/2017 0.50 PROD2 DRILL WPRT - P 12766', 1000'wiper trip, 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 PROD2 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 10/19/2017 10/19/2017 0.20 PROD2 DRILL DLOG P Log RA for+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 10/19/2017 10/19/2017 0.20 PROD2 DRILL OTHR P 10469', Stop and obtain static 10,469.0 10,469.0 14:46 15:00 pressure, Pressure sender@ 6103TVD, BHP stable @ 4065PSI, EMW=12.85 10/19/2017 10/1912017 1.70 PROD2 DRILL WPRT P Continue wiper trip to swab 10,469.0 78.0 15:00 16:42 10/19/2017 10/1912017 1.90 PROD2 DRILL WPRT P RBIH 78.0 12,238.0 16:42 18:36 10/19/2017 10/19/2017 0.60 PROM DRILL DLOG P Log Kt for +8' correction, check & 12,238.0 12,470.0 18:36 19:12 dean injector counter, obtain SBHP, bit depth = 12,470', sensor TVD = 6103', EMW =12.81 ppg 10/19/2017 10119/2017 1.00 PROM DRILL WPRT P Continue RIH, dean run to bottom, 12,470.0 12,946.0 19:12 20:12 confirm TO 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 10/20/2017 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 dean up of gripper blocks out of critical path (due to pipe coating) 10/20/2017 10/20/2017 0.80 COMM CASING PUTS P PJSM, Lt -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 - 10I20/2017 10/20/2017 0.50 COMPZ2 CASING RGRP T Change out elevators 440.0 440.0 02:00 02:30 10/20/2017 10/20/2017 0.80 COMM CASING PUTS 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 COMM 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 10/20/2017 10/20/2017 1.60 COMM CASING RUNL P RIH with liner Run #1 1,200.0 10,400.0 04:30 06:06 10/20/2017 10/20/2017 0.10 COMPZ2 CASING DLOG P Correctto flag for -17.9' 10,400.0 10,382.1 06:06 06:12 1 Page 11118 ReportPrinted: 111112017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Tme EM TM our (hr) Phase Op Code AdAty Code Time P-T-X Opamtion M8) Ere Depth (fl B) 10/20/2017 10/20/2017 2.10 COMPZ2 CASING RUNL P Continue in well, Unable to slow down 10,382.1 12,946.0 06:12 08:18 and tie in without slacking out @ 11630', P/U and continue in hole, first seldown @ 12,450'. Work pipe down to 12946 10/20/2017 10/20/2017 2.40 COMPZ2 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 COMPZ2 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, LI-01 upper liner 0.0 1,149.4 11:24 13:30 segment with ported bullnose, 28 As slotted liner, 2 pups, OH anchor billet. Perform BOP drill. 10/20/2017 10/20/2017 1.00 COMM CASING PULD P PJSM, PIU OH Anchor billet, P/U coil 1,149.4 . 1,211.1 13:30 14:30 track, M/U to liner, M/U to coil and surface test 10/20/2017 10120/2017 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 COMM 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 COMM CASING RUNL T Continue in well, stop at 10457 close 10,436.0 11,790.0 16:24 19:42 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 COMPZ2 CASING TRIP P POOH 11,790.0 78.0 19:42 21:36 10/2012017 10/20/2017 0.90 COMM 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 1021/2017 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: e-line anchor pulled out of anchor carrier, last coil cut was on 1017 a1-12:00 hrs, no slack managemnt was documented as less than 30' of coil was rut. 10/21/2017 1021/2017 1.50 COMPZ2 WHDBOP RURD P Prepping for BOPE test, test inner reel 0.0 0.0 00:00 01:30 valve & stripper, grease tree, fluid pack 10/21/2017 10212017 2.50 COMPZ2 WHDBOP BOPE P Test BOPE (start time 1:30 hrs), 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 10121/2017 1.80 COMPZ2 WHDBOP BOPE P Continue testing from Test #9 to test 0.0 0.0 04:12 06:00 1 I I I 13 Page 12118 Report Printed: 11/1/2017 Operations Summary (with Timelog Liepths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan oeplh Stan Time End Time Dow (hr) Phase Op Code Adivdy Code Time P -T -X Operation 0") End DqM V") 10121/2017 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 10/2112017 10/21/2017 1.00 COMPZ2 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 e -line back into CT, 2.5 BPM @ 0.0 0.0 11:00 11:30 4700 PSI - Hear wire move. Unstab injector 10/21/2017 10/21/2017 1.50 COMPZ2 CASING CTOP T PJSM, R1U hydraulic tubing cutter, Cut 0.0 0.0 11:30 13:00 208' CT to find E -line. RID cutter then hand cut 4' (total CT cut 212) 10/21/2017 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 10/2112017 10/21/2017 1.00 COMM CASING CTOP T PJSM test a -line, rehead UCC and 0.0 0.0 14:00 15:00 1 1 test all good, PT to 4500 PSI 10/2112017 10121/2017 1.30 COMM CASING CIRC T Install nozzle, stab injector on well. 0.0 0.0 15:00 16:18 Circulate forward displacing CT back Ito 13.1 PPG KFonnate 10/21/2017 10/21/2017 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 10121/2017 1.80 COMM CASING RUNL T RIH with BHA#11 72.9 10,245.0 17:36 19:24 10/21/2017 10121/2017 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 COMM CASING TRIP T POOH, tag up, flow check well 10,643.0 73.0 20:00 21:48 10/21/2017 1021/2017 0.60 COMPZ2 CASING PULD T PJSM, LD BHA#11, reconfigure tools 73.0 0.0 21:48 22:24 10/212017 10/21/2017 0.60 PRODS STK PULD P PU BHA#12 Ll -02 KO/Build 0.0 72.0 22:24 23:00 Assembly (2.0° AKO motor, RR Hughes, 1-1 bit from L1 let) 10/21/2017 10/2212017 1.00 COMM STK TRIP P Open EDC, RIH with BHA #12 72.0 4,200.0 23:00 00:00 10/22/2017 10/222017 1.10 PRODS STK TRIP P Continue RIH 4,200.0 10,240.0 00:00 01:06 10/22/2017 10/2212017 0.30 PRODS STK DLOG P Log K1 for -10' correction 10,240.0 10,288.0 01:06 01:24 10/22/2017 10/22/2017 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 PROD3 STK DISP P Displace well to 8.8 ppg PowerPro, 10,430.0 10,430.0 01:30 02:48 1 close EDC 10/22/2017 10/22/2017 0.30 PROD3 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 10/22/2017 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 ReportPrimed: 11/12017 Operations Summary (with Timelog Depths) 2K-04 Raw Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Sbrt Time End Time Our thn Phase Op Code Activity Code Time PJA Operation MB) End Depth MO) 10/22/2017 10/22/2017 3.80 PRODS DRILL DRLG P Drilling in formation on Lt -02 build 10,635.0 10,930.0 04:24 08:12 section, CWT =BK, 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 PROD3 DRILL TRIP P Call EOB, Trip out for lateral drilling 10,930.0 96-3- 08:12 10:30 BHA # 13, AVG DLS=33.9', Open EDC @ 10,433'. 10122/2017 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. M/U to coil and surface test 10/2212017 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 QD 300'- Good j 10/22/2017 10/22/2017 0.10 PROD3 DRILL DLOG P Log K-1 for -9', PUW=32K 10,250.0 10,283.0 15:42 15:48 10/22/2017 10122/2017 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 10/2212017 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 5400PSI 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 10/22/2017 0.30 PRODS DRILL WPRT P WT up -hole, PUW = 34K 11,330.0 10,650.0 20:00 20:18 10/22/2017 10/22/2017 0.20 PRODS DRILL WPRT P WT down -hole, RIW = 7K 10,650.0 11,330.0 20:18 20:30 10/22/2017 10/2312017 3.50 PROD3 DRILL DRLG P BOBO, pumping 1.8 bpm, FS = 1095 11,330.0 11,710.0 20:30 00:00 psi, CWT = 4K, WOB = 2K, annular = 4170 psi, WHIP = 504 psi, circ pressure = 5348 psi, rip = 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 j 4K, WOB 1.6K, annular = 4298 psi, pump sweeps 10/23/2017 10123/2017 0.30 PRODS DRILL WPRT P WT up -hole, PUW = 34K 11,730.0 10,892.0 00:18 00:36 1023/2017 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 = 1.41K, WOB = 1.8K, annular = 4184 psi, WHP = 416 psi, Circ pressure = 5385 psi, begin to pump 5x5 sweeps at 11,957', 74 fph average ROP over interval 1023/2017 10/2312017 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 = 1.2K, annular = 4246 psi 10232017 10/23/2017 1.90 PRODS DRILL WPRT P 12134', Wiper trip #3 to window with 12,134.0 12,134.0 05:42 - 07:36 tie in for+8', PUW=36K, Clean trip up and down 10232017 10/23/2017 2.80 PRODS DRILL DRLG P 12138', Drill, 1.52 BPM Q 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: 111112017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth star Tma End Tme Dur(hr) Phase Op Code AcWy Code Tme P -T -X operation (Nta) End DapflnOEM) 10/23/2017 10/23/2017 0.20 PRODS 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 10123/2017 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 1 1 1 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 10/23/2017 10123/2017 0.20 PRODS DRILL WPRT P 12,606, BHA wiper, stacking, 12,606.0 12,606.0 15:36 15:48 PUW=42K 10/2312017 10/23/2017 2.60 PRODS DRILL DRLG P 12,606', drill, 1.67 BPM @ 5150PSI 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 PRODS 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 PRODS 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=1.1 K 10/23/2017 10/23/2017 0.50 PRODS DRILL WPRT P BHA wiper, slacking, PUW=43K, recip 12,798.0 12,798.0 20:54 21:24 for second BHA wiper 10/23/2017 10/23/2017 0.30 PROD3 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 10/23/2017 10/23/2017 1.00 PROD3 DRILL DRLG P 12,809 Drill, 1.79 BPM @ 5515 PSI 12,609.0 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 10124/2017 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, WHP = 462 psi, reached TO 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 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 10/2412017 10/24/2017 0.30 PRODS DRILL CLOG P Log Kt 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 10/24/2017 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 10/24/2017 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 15118 ReportPrinted: 11/112017 Operations Summary (with Timelog (Depths) A ims� 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth start Time I End Time Dur (no Phase Op Code ActiNty Code Time P -T -X Operation (1d(6) End Depth (00) 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 10/24/2017 10/24/2017 4.10 COMPZ3 CASING PUTB 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 10/24/2017 10/24/2017 1.00 COMM 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 Dosed. 10/24/2017 10/24/2017 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 10/24/2017 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 10/24/2017 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 10/25/2017 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, Plck up, PU Wt 49 k LBS, WOB - 22k Ibs. Work pipe I liner toward bottom with multiple pick ups, 50 plus 10/25/2017 10/25/2017 1.50 COMPZ3 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 ft/min. Work pipe, 13 PU's and a a ' good run from 12,115'-12,459', Work pipe, multiple PU's lost ground to 12,197'then RBIH to 12,458' 10/25/2017 10/25/2017 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 10/25/2017 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 ft/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 10/25/2017 0.50 COMPZ3 CASING RUNL P Struggle to get back down to depth of 12,592.0 12,666.0 04:30 05:00 112,656 for - 35 min. Worked liner 10/25/2017 10/25/2017 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 ReportPrinted: 11/1/2017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stott Tune End Time Dw(hr) Phase DoCode Activity Code Time P -T -X Operation (W) Ehd Depth Me) 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', get by, difficutly working past 12,785', get by, difficutly working past 12,800' 10/25/2017 10/2512017 2.00 COMM 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 10/25/2017 1.70 COMM 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' 10/25/2017 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 10/25/2017 2.70 COMPZ3 CASING WAIT T PUH to tie in, 8e 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, waft on used mud from 1 B -Pad. 10/25/2017 10/25/2017 2.80 COMPZ3 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 10/25/2017 0.40 COMPZ3 CASING DISP T 10,100.0 10,325.0 19:00 19:24 10/25/2017 10/25/2017 0.60 COMM CASING TRIP T Line up pumps to the coil, RIH, pump 12,856.0 12,856.0 19:24 20:00 - 5 bbis 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. 10/2512017 102512017 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. 10125/2017 10/252017 0.10 COMPZ3 CASING RUNL T Line up down the coil, stack 4 k WOB, 12,856.0 10,314.4 2012 20:18 PU, 26 k lbs, released and left liner (2531.2l') on bottom. Best corrected depth putting BOL at 12,861'. TOL at 10,329, 10252017 10252017 2.90 COMPZ3 CASING DISP P Displace well to seawater while 10,314.0 48.0 20:18 23:12 POOH. Pump 30 bbis to the coil for FP, lay in from 2500' and to surface. 10/25/2017 10/262017 0.80 COMPZ3 CASING PULD P Bump up, PUD BHA# 14 10,314.0 48.0 23:12 00:00 Page 17118 Report Printed: 111112017 Uperations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start oeplh Stall Tune Ertl Tim our (hr) MO. op Code A W¢y Cade Tim P -T -X Operation We) End Dep (ftl(B) 10/2612017 10/26/2017 0.70 COMPZ3 CASING PULD P Continue to PUD and UD BHA #14. 48.0 0.0 00:00 00:42 10/2612017 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. 10/262017 10/26/2017 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. 10262017 10/26/2017 1.00 DEMOB WHDBOP RURD P Complete blow down of lines, pull 0.0 0.0 03:00 04:00 night rap, vac down stack, add MetOH to stack above BPV. Called DTH to remove TT hard line. reinstall night cap and attach slings for BOP storage/travel. 10/26/2017 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 10262017 10/26/2017 3.50 DEMOB WHDBOP RURD P RDMO, PUTZ, etc, continue to work 0.0 0.0 05:00 08:30 1RD checklist 10/26/2017 10/262017 2.50 DEMOB WHDBOP MOB P NES trucks arrive at 2K -Pad, PJSM, 0.0 0.0 08:30 11:00 - rig up sows to pits & sub, load up shop & 1/2 way house, move off 2K -Pad Page 18118 ReportPrinted: 11/1/2017 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K -04L1-01 50-103-20099-61 Baker Hughes INTEQ Definitive Survey Report 25 October, 2017 BAER UGHES �f J,., ConocoPhillips &iRFs m ConocoPhillips Definitive Survey Report Company: ConowPhilllps(Alaska) Inc. -Kup2 Loal Coordinate Referenme: We112K-04 Project: Komarek River Unit TVD Reference: 2K-04@15400usn(21K-04) Sla: Kupamk 2K Pad MD Reference: 2K-04@154.00osft (2K-04) Well: 2K-04 North Reference: True Wellbore: 2K -04L1 Survey Calculation Methoo. Minimum Cutvalure Deign: 2K -04L1 Dolega : EDT Alaska Sandbox Project Kupamk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point . Map Zane: Alaska Zone 04 Using geodetic scale factor Well 2K-04 Well PosNion aNi 0.00 usft Nonhing: 5,938,525.46usg Latitude: 70° 14' 35784 N aE1-W 000 usn Battle, 498 310 Laughed.: 150°0'49,136W Position Uncenamm, 0 00 esti Wellhead Elevation: usg Ground Level: 11850 rush Wellbore 2K-04LL01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength V) V) (nn BGGM2017 10/112017 17.30 8084 57,474 Design 2K -04L1-01 AudltNmes: Version: 10 Phase: ACTUAL To On Depth: 10510.72 Vertical Selden: Depth From (TVD) ahpi aEf-W Direction hei bi haft) (1) 3550 0.00 0.00 1000 survey Progam Dace 101252017 From To Survey Survey (ustt) (usi Survey g4elibure) Toot Name Description San Dafe End baa 200.00 10,400.00 2K-04 (2K-04) BOSS -GYRO Spem7-Sun BOSS gym mulhshot 11412001 1047900 10,510.72 2K -04L1 fit (2K-0411) MWD MWD -Standard 101101209 1011012017 1053000 10,560.36 2K-041.101 MWD-IND(2K-0411-01) MWD-INC_ONLY MWD -INC ONLYFILLER 10117209 101172017 10,589.85 12,906.02 2K -04L101 MWD(2K-041.1-01) Mi MWD -Standard 101171209 101202017 1025201712:35 22PM Page 2 COMPASS 500014 Bm1085 1&2&01712.36,22W Paps 3 COMPASS 5000.14 Suits 9 ConocoPhillips arW11 & ConocoPhilli s P Definitive Survey Repos Co.,.,: ConocoPbillips(Alaska) Inc .-Kup2 Local Coordinate Reference: Welt 2K-04 i Project: Kupamk River Unit NO Reference: 2K-N@154.OWusB(2K-W) 1 site: Kupamk 2K Pad MD Reference: 2K-04 C15400usfi(2K-04) Well: 20704 North Reference: True Widths.: 2KMLIsurvey Calculadon Method Minimum Curvature Doohn: 2K -04L1 _ ��___..... Nuihese: EDTAIaska Sandbox ..r..._. Survey Map Map WRdcal MO Inc Au ND MOSS 43413 4FJAV DLS Naming sending Siphon survey Tool Name Ann018sOn Waft) (') f) Ivm) IMa1N (aM9 (Matt) (N (m fnW) ,) 10510.72 7155 259.50 6,13901 598581 3595.110 zinks80 5,942,122.47 491,31696 27.01 2326.57 MWD (2) Interyolated Aunnuut - TIP 10,530.[0 77.44 29592 6, wall 5,9:0.91 3.80443 4.011.% 5,942131,10 491,300.51 33.85 2332.21 MWDINC ONLY(3) KOP 10%0% Was 304.80 6,140.01 5,99441 3,61949 -],03].14 5,942148.1] 491,27444 49.53 234252 MW41NC_ONLY(3) Intelp01ate0AbrINl11 105¢905 98.39 318,62 6145 72 5991.72 3838.82 -7,05916 5,942.1149 491,252.43 55.17 235]]2 MWD(4) 10,02014 97.0 33232 514139 5.907.39 3.893.46 -7,076.11 5,942.190.13 491,235.40 44.79 231`9.05 MiMi 10,650% 96 4] 3,13 70 6.13246 5.934.46 3,68149 -7 W743 6942,21817 49122017 3].16 2404,69 MJrD(4) , 10,07007 015 35264 6f 34.14 590714 3,720.94 -],073% 5,942,24].62 01,218.01 Mu 2,432.62 Mkilli 10,71091 &5.01 355 6.f 3133 5,91733 3,]%.07 -],074.58 591 W 01,21203 W37 2,46174 MWD(4) 10.741.. 9107 14.52 0,1N.73 5,97573 3,]80.36 -706.85 5,942,307.0 491,221]0 W61 2,491.79 NOW (4) 10,170.34 90.34 25.01 6,134.38 5,975.36 3,80]91 -],0]9.95 5,942,3%.% 491,3418] 8.8 2,520.04 MM(4) 10,80071 90.x6 36.11 5134.15 5,97515 3,834.0 -7.064.% 5,9423%65 491,24)0] 36.60 2,64089 MAO(4) 10,626.33 N45 4569 A=17 5,975.17 3,063.31 -0,04.82 5.9423496 491.26381 Vail 2,57092 MWD(4) 100741 0932 56w 6,129.51 5.97551 3,8nN -7,02360 5,942369% 491,20795 34.11 259437 MM (4) 10,88799 0.61 %W 6,134.53 5.97553 3,880.30 4,90].0 5.84.415 94 491,31373 871 2615M MM (4) 10,918M %.92 59,45 Q1N1 5,9751 3.901.]] 6,9nA2 5,942431 40 491,33951 825 263415 MWD (4) 10,94807 N.46 61,W 5133.34 5,9]8.34 3.919.% fl946.01 5942.445.18 491.075.62 ].W 265185 MM (4) 10,9864 W31 64,05 6,131.17 5,917.17 3,933.00 $919]3 5,942,45969 491,391.90 &64 2071.8 61079 (4) 11,080] Was 091 6,13187 5.9887 3945.94 4,892.17 5.942.412.% 49141947 650 2834.10 MD (4) 11,03]]5 89.1] 04.84 6.132.33 5,97833 395831 4,865.19 5.942.484.91 491446.44 363 2706.04 MWD (4) 11,06].]5 81 82.64 5132.0 5,9780 397150 4.830.34 5,942498.17 49147334 281 272.78 MD (4) 11,07&N 0].54 07.94 6,133.96 5,979.% 3,934.90 8,81141 5,942,512.59 491,500.23 649 274265 AM (4) 11,12289 W.77 3497 6,134.92 59%.172 44007.59 8.781 5,942.52].1] 491,52507 529 2751.50 MM (4) 11,15740 0.54 58.11 6,135.35 5,98135 4,015]] 4,7W.W 5,941 M 491,55120 682 2780.84 MiND(4) 11,187,46 90.34 %43 6,184 5,98147 4W1.96 4,73503 5.942.5%.52 491,57661 487 280110 MM (4) 11,220.49 5025 1.2] 8,13538 5,071.39 405043 4,70265 5,912,5]6.98 49113.% 447 2824.12 Wei 11,2%.48 W43 %.]0 6125.21 5 a 21 4W]84 6,0325 5942%4.39 491,628.39 527 2845.50 Mini 11.207.1 91.32 62.1 6.134.75 5,9175 4,08588 8,659.1 5942.61243 491,6%.1 4.05 2.1240 MJUD(4) 11,31050 91.14 5151 6,1011 5807.11 410.18 4,61540 5,942613 .]2 491 SINS t6 4% 28059 M (4) 11,3401 9132 834 6,133.45 5,87945 4,12334 861194 5,84,619.87 41,834.71 434 2,91254 MND(4) 11.3701 9114 40.09 6,132.82 5,970.82 4442.75 8.50.49 5.942,851 491.]34.16 7.20 2.935.% MWD(4) 1&2&01712.36,22W Paps 3 COMPASS 5000.14 Suits 9 ConocoPhillips TZK6 a COnocoPhillips Definitive Survey Report Company: CenocnPhillips(Ales") Inc.-Kup2 Project: Kupamk River Unit site: Kupamk 2K Pad Well: 21(-04 Walnut. 2)(4I11 Design: 21<4411 Survey Local Coardmate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Curacao.: Mil 2K-04 2K -04(Q 154. Musa(2K-0Q 2K44 a 154.OWusa (2K-04) True Minimum CurvaWre EDT Nasky Sandbox IOR52017123522PM Page 4 Annotation COMPASS 5000.14 BWJd 85 Map Map MD Inc Azi ND ND55 .NIS +V -W venting Eart)np USWrote?Weft) 9eP (°) (1) (--ft) (..ft) Oull Npt) Ch04l Survey Tool No. it) I 167 0U 11,400.59 91.66 46.19 6,132.08 597808 4,153 is L,56]A] 5.942,689 .89 491,]44.18 8.55 2959.50 MMD l41 11,43060 9138 .M 6.13129 S9P.29 4.18428 -54616 5.942.710.79 491.]65.50 610 2.983.99 INI 11,48tist 9104 4304 8,130.85 5,976.65 4.20502 852.38 6942]32.52 491.786.a 459 3.009.00 . (4) 11,a9050 90.61 4123 6,133.22 5.976.22 4,22820 -50531 594Z754 70 491806.35 622 3,034.33 ul(4) 11,52042 W71 2.02 6,129.88 5,97599 4.25100 -48.99 5.942.77749 491,025.57 742 3.060.12 VNVD(4) 11,55081 9].89 3722 6,12.45 5,97545 427491 -,467.33 5,942801 .39 491,044.33 595 3,085.22 MWD (4) 11,5803] 99.92 35.2 6,120.99 5,97499 4,298.]5 -,449.07 5,94282523 491,861.80 8.77 3,113.44 scan) (4) 114610.61 91.32 30.99 6,70.39 5,9]4.39 4,023]] -,4MN 5,942aW24 491,878.]] ].2 3,141@ MM (4) 11,640.82 9183 3188 8,12782 5,9]383 4,349.11 8.41584 5,942,875.57 491994.94 4.74 3,16816 MAR) (4) 11,6662 92.36 243 612.66 5.9n to 4,372.92 4.402.70 5.9t289830 491908.90 8.54 3.194.65 MM (4) 11,70074 037 27.37 6,1404 5,97104 440143 8,30]3] 5,94292788 491,92432 ].W 322.41 MWO(4) 11,73074 004 24.99 6,122.04 5,968.84 4,42826 -,37417 5,942,954.n 491,93752 9.70 3254.14 MIND (4) 11,781.14 93.61 M50 8,11975 5,995.]5 4,455.93 e'wt00 5,912982.40 491,94970 962 3,283.51 MWO(41 11,790.90 9549 245 8,11535 5,992.35 4,400 8,351.14 5,943,02.98 491,99055 6 a 3,312.56 FAM (4) 11,82.8) 9.M 1741 8.11278 5,958.]8 4,51138 8,341.58 5,913.0781 49197011 1059 3.34154 MWD(4) 11,850.2 99.2 1541 6,109.02 5,95502 4,539.61 -,333.28 ti'm.o"8.01 491,87843 669 3,370.00 MWD(4) 11,899.53 6877 1325 6,10547 5,95147 4,550.70 -,335.85 5,M.095 12 491,995.87 7]] 340081 MWD(4) 11,910.35 M24 13.61 fti=74 594814 4,597.58 8,31095 5943.12.99 491,99217 B.91 3430.45 Mini 11.94039 91.93 13.74 6,101.12 5,947.12 4.6MM 8,311.85 5.943,153.13 491.911 7.70 3480.39 MWD(4) 11,9]0.83 W97 142 0.10062 S.9W.62 4,658.2 -.30452 5.948,182.66 49200722 661 3.400.75 MA11)(4) 12,9902 Is 37 1424 6,10104 5.94704 4,684.]5 -,29730 5943,211.15 49201444 544 3.52006 MWD(4) 12030.27 0761 1299 6,10210 5948.10 4,71393 ZM24 5,943,240.33 49202151 495 3,55003 MhD(4) 12063.M 9721 11.12 6,103.61 5,94981 4148.]3 8,283.24 5943,271-2 492,028.51 5.6D 3.50354 MND (4) 12,99187 WIN 1042 5,10417 5,950.7] 417424 8.27801 5.943,399.83 492,033.75 395 3.61154 MND(4) 12,116.19 88.93 860 6,105.41 695141 4.7W21 -SW399 5,943,324.50 49203].]7 82 3,63585 MWD(4) 12,14801 58.59 720 8,10511 5,95211 48272 -,m so 5,943,356.10 49204217 4M 3,50761 NAND (4) 12,180.91 a713 555 6,199.16 5,953.16 4,962.40 $.552 5.943388.78 492099.95 5.87 3100.46 MND(4) 12.210M 7W 357 6.108.37 6951.3) 4.89181 426358 5.943.418.10 492.048.21 671 3.M9.83 MM (4) 12.241.97 aT.M 299 6199.84 usetom 4.923. 4,262.99 5.943,.964 49{049.76 599 3,]8108 MWD(4) 12.2]083 86 039 6,111.39 5.95739 4,952.0] -,26141 5,943,478M I ,05038 504 3199.56 PAVE) (4) 12,330.80 WA? 35945 6,113.15 5,959.15 4.98199 -,26146 5,94350085 41M,OW35 332 3,81901 MINI IOR52017123522PM Page 4 Annotation COMPASS 5000.14 BWJd 85 ConocoPhlllips1Es 0 ConocoPhillips Definitive Survey Report Company: CORocoPh80pa(Maske) Inc. Kup2 Lo®I CoaMIIMte Reference: W01121<A Pro)ecc Kupamk Ever Unit ND Reference: 2K-D4®154.00us0(2K-04) St. Kupamk 2K Pad MD Poperenw: 21(-04@154.Wus0(2K-04) Weft. 21<-04 North Reference: Tme Weflbore'. 2K-0411 Survey Calculation Method Minimumcurtature Doeign'. 2K-0411 Database: EDTAIasks Sandbox 1026201112:36:227704 Page 5 COMPASS 5000.14 6uiM05 Map Map Vonkid MD Inc Azi ND ND56 ANIS +EI.W NO Elating OL9 Section (UM) (1) (1) (use) (uaR) (-aft) (-an) (.11.) Survey Tool Name Annotation (ft) (rt) (ft) 32,330.30 86.29 357 80 6.31501 5,961.01 5,O11'42 4,26216 5,943.53]]9 49204965 562 3,8288 MWp(4) 12,330.51 WIG 356.01 51162 5.96347 4041.55 4.26.4.99 5,943.56].91 492040.02 056 107726 MW➢(4) 12,350.39 09.5] 355.26 6.31106 5,993.06 5071.34 4,283.07 594159]]0 492876.]6 534 190520 MWD(4) 12.4211.Y 89.91 354.W 511120 5.93320 5,10104 5,26084 eoo,62]..4 49;04299 421 1034.97 MWD (4) 12452.50 9129 35359 8.11683 5.66286 atoll 527232 5,943,659.48 49'{D3952 451 3,96597 MWD (4) 12.478 78 0.95 35489 6,11635 5,58235 5,159.27 6,27496 5,943,685.62 492039.89 5.11 3.99135 MWD (4) 12,51150 9160 He 75 6,11562 e9olW 5, 191 52]]34 5,843,710.24 492,034.51 802 4,021.97 MWD (4) 12,54007 92.10 35755 6,114.65 5,dow 5221.01 4,2]0.]9 5,943,]4).36 492.033.07 339 4.05139 "D (4) 12,.4023 93.74 359.49 6,113.13 5.959.13 52`.4.52 4.79.55 5943.]]6.08 492.032.31 641 4.080.32 MAID (4) 12,87053 93.29 1.16 611127 5,95].7 5.283.]6 -.2]9.38 5.943,807 10 492,032.49 570 4it013 MWD (4) 12,63049 92.80 363 5109.0.4 SMas 5,31005 6,7813 5,943,836.99 422,033.75 8.39 4.139.70 MWD (4) 12,%052 MISS 551 6,10.02 5,954.02 5,340.54 -6,275 74 5,943,866.07 492,033]4 6,74 4,16963 MWD(4) 126929.65 004 321 8,108.24 5,95234 537044 4,2T2.41 5943.we" 492039.48 576 4.19965 MAK) (4) 12720.54 91.87 512 5104.92 5.950.92 5.460.M 4,266.43 5.943.926.35 4 ,04347 539 4,229.46 MWD(4) 12]5.436 87.95 964 510418 5950.18 5.429.40 -.287.82 5,943,95581 492,048.08 595 4,259.31 MAD(4) 1278049 80.49 1114 8,low 5,949.80 5.459.11 4,258.39 5,941985.2 491,0.9.52 5.21 4,209.41 MWD(4) 12814.37 90.92 16.87 6,1039 5,949.39 5.493.02 4,250.43 5944016.34 Mosel 40 tIS 4,323.7 MWD(4) 12,840.33 90.40 16.34 8.16409 5.94909 5.51695 5,243.19 5,9H,043.26 48206fl73 228 4349.02 MWD(4) 128)0.30 W.BE 16.55 410276 5.848.76 RUE 62 -234.19 5,80403192 49297.]4 751 437001 MWD(4) 32.887.02 9184 N.]0 6,10192 5,94].92 55]9.1] b27.20 5,944.105.46 492M.74 683 4,41393 MWO(4) 12.946.W 91.84 20.78 8.100.83 5.948.63 561fi.53 6,208.02 5904,14282 492,10092 OW 4453.19 PROJECTED 10 TD 1026201112:36:227704 Page 5 COMPASS 5000.14 6uiM05 BAN( R PRINT DISTRIBUTION LIST I'1 UGHES a GE company COMPANY ConocoPhillipsAlaskBECEIVED WELL NAME 2K -04L1-01 NeY 0-9 2017 FIELD Greater Kuparuk Area AOG. COUNTY North Slope Borough CC BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Ridercbbakerhughes.com 21 71 27 28 77 7 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) DATA LOGGED 700 G Street. It iq /201-1 Anchorage, Alaska 99510 M. K. BENDER to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE October 24, 2017 TODAYS DATE November 7, 2017 Revision STATUS Final Replacement: No Details: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V I BP North Slope. EOA, PROC, PRB-20 (Office 109) D&G WO Wells Admin Brenda Glassmakcr & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Ann: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 CD in 217-126 Rev. Requested by: FIELD/ FINAL CD/DVD FINAL PRELIM (las, dlis, PDF, META, SURVEY REPORT LOGS LOGS CGM, Final Suryeys) (Compass) # OF PRINTS # OF COPIES I# OF COPIES I# OF COPIES zr 4 lu lu lu 4 01 01 0 1 70:� 3 ExxonMobil,Aleska 0 0 0 0 1 0 Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska -AOGCC 0 i 1 0 Attn: Makona Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division ofOil & Gas **e Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 -*- Stamp "confidential" on all material deliver to DNR_I 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, IR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 0 1 1 1 0 TOTALS FOR THIS PAGE: 0 2 3 3 0 .-' ConocoPhillips DECEIVE[` NOV 0 9 2017 AOGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K -04L1-01 50-103-20099-61 Baker Hughes INTEQ Definitive Survey Report 25 October, 2017 21 71 27 28 77 7 BA, ICER UGHES a GEcompany e g Project Kuparuk River Unit, North Slope Alaska, United States Map System: ConocoPhillips Conoco'Phillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc.-Kup2 Local Coordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2K Pad MD Reference: Well: 2K-04 North Reference: Wellbore: 2K -04L7 Survey Calculation Method: Des] n: 2K-04Li Database: e g Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 2K-04 +E/ -W Well Position +N/ -S 0.00 usft Northing: .E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 2K-0411-01 35.50 Magnetics Model Name Sample Date BGGM2017 10/1/2017 Design 2K-04Li-01 Audit Notes Well 2K-04 2K-04 @ 154.00usft(2K-04) 2K-04 @ 154.00usft (2K-04) True Minimum Curvature EDT Alaska Sandbox Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,938,525.46usft 498,310.06 usft usft Declination C) 17 3D Latitude: Longitude: Ground Level: Dip Angle C) 80.84 11 WMEIS 70" 14'35.784 N 150° 0'49.136 W 118.50 usft Field Strength (nT) 57.474 Version: 1.0 Phase: ACTUAL Tie On Depth: 10.510.72 Vertical Section: Depth From (TVD) +N/S +E/ -W Direction (usft) (usft) (usft) (°) 35.50 0.00 0.00 10.00 Survey Program Date 10/25/2017 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date ? f 200.00 10,400.00 2K-04 (2K-04) BOSS -GYRO Sperry -Sun BOSS gyro multishot 1/12/2001 10,479.00 10,510.72 2K -04L1 MWD-INC(2K-04L1) MWD MWD -Standard 10/10/2017 10/10/2017 10,530.00 10,560.36 2K-041-1-01 MWD -INC (2K -04L1-01) MWD -INC ONLY MWD-INC_ONLY_FILLER 10/17/2017 10/17/2017 10,589.85 12,906.02 2K -04L1-01 MWD(2K-04L1-01) MWD MWD -Standard 10/17/2017 10/20/2017 Page 2 COMPASS 5000.14 Build 85 10252017 12:36:22PM ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Project Kuparuk River Unit Site: Kuparuk 2K Pad Well: 2K-04 Wellbore: 2K-041-1 Design: 2K-041-1 Survey ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2K-04 2K-04 @ 154.00usft (2K-04) 2K-04 @ 154.00usft (2K-04) True Minimum Curvature EDT Alaska Sandbox 10/25/2017 1296:22PM Page 3 'gUGHES a Annotation Interpolated Azimuth - TIP KOP Interpolated Azimuth COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi ND ND55 +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (°I (usft) (usft) (usft) (usft) (°1100') Survey Tool Naim 00 (ft) (ft) 10,510.72 71.55 299.50 6,139.81 5,985.81 3,595.80 6,994.60 5,942,122.47 491,316.96 27.01 2,326.57 MWD (2) 10.530.00 77.77 295.92 6,144.91 5,990.91 3,604.43 -7,011.06 5,942,131.10 491,300.51 36.85 2,332.21 MWD -INC -ONLY (3) 10,560.36 90.49 304.00 6,148.01 5.994.01 3,619.49 -7,037.14 5,942,146.17 491,274.44 49.53 2,342.52 MWD-INC_ONLY(3) 10,589.85 98.38 318.62 6,145.72 5,991.72 3,638.62 -7,059.16 5,942,165.49 491,252.43 56.17 2,357.72 MWD (4) 10,620.14 97.98 332.32 6,141.39 5,987.39 3,663.46 -7,076.11 5,942,190.13 49123548 44.79 2,379.05 MWD (4) 10,650.68 96.77 343.70 6,137.46 5,983.46 3,691.49 -7,087.43 5.942218.17 491.224.17 37.16 2.404.69 MWD(4) 10,680.98 95.75 352.64 6,134.14 5,980.14 3,720.94 -7,093.59 5,942,247.62 491,218.01 29.52 2,432.62 MWD(4) 10,710.91 95.01 3.55 6.131.33 5,977.33 3,750.68 -7,094.58 5,942,277.35 491,217.03 36.37 2,461.74 MWD (4) 10,741.06 91.07 14.52 6.129.73 5,975.73 3,780.36 -7,089.85 5,942,307.03 491,221.76 38.61 2,491.79 MWD (4) 10,770.36 90.34 25.01 6,129.36 5,975.36 3,807.91 -7,079.95 5,942,334.58 491,231.67 35.86 2,520.64 MWD (4) 10,800.71 90.46 36.11 6,129.15 5,975.15 3,833.99 -7,064.56 5,942,360.65 491,247.07 36.60 2,548.99 MWD (4) 10,826.30 89.45 45.69 6,129.17 5,975.17 3,853.31 -7,047.82 5,942,379.96 491,263.81 37.64 2,570.92 MWD (4) 10,857.41 89.32 55.30 6,129.51 5,975.51 3,872.86 -7,023.68 5,942,399.50 491,287.95 34.11 2,594.37 MWD (4) 10,887.99 90.61 58.63 6,129.53 5,975.53 3,889.30 6,997.90 5,942,415.94 491,313.73 8.71 2,615.04 MWD (4) 10,918.06 88.92 59.45 6,129.65 5,975.65 3,904.77 6,972.12 5,942,431.40 491,339.51 6.25 2,634.75 MWD (4) 10,948.07 88.46 61.50 6,130.34 5,976.34 3.919.55 6,946.01 5,942.446.18 491,365.62 7.00 2,653.85 MWD (4) 10,977.64 88.31 64.05 6,131.17 5,977.17 3,933.08 6,919.73 5,942,459.69 491,391.90 8.64 2,671.72 MWD (4) 11,008.07 89.05 65.91 6,131.87 5,977.87 3,945.94 -6,892.17 5,942,472.55 491,419.47 6.58 2,689.18 MWD (4) 11,03275 89.17 64.84 6,132.33 5,978.33 3,958.31 .6,865.19 5,942,484.91 491,446.44 3.63 2.706.04 MWD (4) 11,067.75 88.58 62.64 6,132.93 5,978.93 3,971.58 6,838.29 5,942,498.17 491,473.34 7.61 2,723.78 MWD (4) 11,098.28 87.54 60.94 6,133,96 5,979.96 3,986.00 6,811.41 5,942,512.59 491,500.23 6.49 2,742.65 MWD (4) 11,127.89 88.77 59.97 6,134.92 5,980.92 4,000.59 6,785.66 5,942,527.17 491,525.98 5.29 2,761.50 MWD (4) 11,157.40 89.54 58.11 6,135.35 5,981.35 4,015.77 .6,760.36 5,942,542.35 491,551.28 6.82 2,780.84 MWD (4) 11,187.46 90.03 56.73 6,135.47 5.981.47 4,031.96 6,735.03 5,902,558.52 491,576.61 4.87 2,601.18 MM (4) 11,220.49 90.25 55.27 6,135.38 5,981.39 4,050.43 6,707.65 5,942,576.99 491,603.99 4.47 2,824.12 MWD (4) 11,250.46 90.43 53.70 6,135.21 5,981.21 4,067.84 6,683.25 5,942,594.39 491,628.39 5.27 2.845.50 MWD (4) 11,280.65 91.32 52.86 6,134.75 5,980.75 4,085.88 -6,659.06 5,942,612.43 491,652.58 4.05 2,867,48 MWD (4) 11,310.50 91.14 51.51 6,134.11 5,980.11 4,104.18 6,635.48 5,942,630.72 491,676.16 4.56 2,889.59 MWD (4) 11,340.86 91.32 50.22 6,133.45 5,979.45 4,123.34 6,611.94 5,942,649.87 491,699.71 4.29 2.912.54 MWD (4) 11.370.55 91.14 48.09 6,132.82 5,978.82 4,142.75 -6,589.49 5,942,669.27 491,722.16 TM 2,935.56 MWD (4) 10/25/2017 1296:22PM Page 3 'gUGHES a Annotation Interpolated Azimuth - TIP KOP Interpolated Azimuth COMPASS 5000.14 Build 85 Survey ConocoPhillips w 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 (2K-04) Site: Kuparuk 2K Pad MD Reference: 2K-04 @ 154.00usft (2K-04) Well: 2K-04 North Reference: True Wellbore: 2K-0417 Survey Calculation Method: Minimum Curvature Design: 2K -04L1 Database: EDT Alaska Sandbox Survey 10252017 12:36:22PM Page 4 'UGHES 0 Annotation COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS -NIS +EI -W Northing Easting DLS Section Survey Tool Name usft ( ) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°71000 (ft) 11.400.59 91.66 46.19 6,132.08 5,978.08 4,163.18 -6,567.47 5,942,689.69 491,744.18 6.56 2,959.50 MWD (4) 11,430.60 91.38 44.38 6,131.29 5,977.29 4,184.28 6,546.16 5,942.710.79 491765.50 6.10 2,983.99 MM (4) 11,460.68 91.04 43.04 6,130.65 5,976.65 4,206.02 -6,525.38 5,942,732.52 491,785.28 4.59 3,009.00 MVVD(4) 11,490.60 90.61 41.23 6,130.22 5,976.22 4,228.20 -6,505.31 5,942,754.70 491,807.35 6.22 3,034.33 MWD(4) 11,520.42 90.71 39.02 6,129.88 5,975.88 4,251.00 -6,486.09 51942,777.49 491,825.57 7.42 3,060.12 MM (4) 11,550.81 90.89 37.22 6,129.45 5,975.45 4,274.91 6,467.33 5,942,801.39 491,844.33 5.95 3,086.92 MM (4) 11,580.37 90.92 35.22 6,128.99 5,974.99 4,298.75 -6,449.87 5,942,825.23 491.861.80 6.77 3,113.44 MWD (4) 11,610.61 91.32 33.07 6,128.39 5,974.39 4,323.77 6,432.90 5,992,850.24 491,878.77 7.23 3,141.02 MWD (4) 11,640.62 91.63 31.68 6,127.62 5,973.62 4,349.11 -6,416.84 5,942,875.57 491,894.84 4.74 3,168.76 MM (4) 11,668.29 92.35 29.43 6,126.66 5,972.66 4,372.92 -6,402.78 5.942,899.38 491,908.90 8.54 3,194.65 MWD (4) 11,700.74 93.37 27.37 6,125.04 5,971.04 4,401.43 -6,387.37 5,992927.88 491,924.32 TM 3,225.41 MWD(4) 11,730.74 95.04 24.98 6,122.84 5,96884 4,428.28 6,374.17 5,942,954.72 491,937.52 9.70 3,254.14 MWD(4) 11,761.14 96.61 22.50 6.119.75 5,965.75 4,455.96 6,362.00 5,942,982.40 491,949.70 9.62 3,283.51 MWD (4) 11,790.98 96.49 20.45 6,116.35 5,962.35 4,483.54 6,351.14 5,943,009.98 491,960.56 6.84 3,312.56 MWD (4) 11,820.63 97.32 17.41 6,112.78 5,958.78 4,511.38 -6,34159 5,943,03281 491,970.11 10.56 3,341.64 MWD (4) 11,850.30 97.23 15.41 6,109.02 5,955.02 4,539.61 6,333.28 5,943,066.04 491,978.43 6.69 3,370.88 MM (4) 11,880.53 96.27 13.25 6,105.47 5,951.47 4,558.70 -6,325.85 5,943,095.12 491.965.87 7.77 3,400.81 MWD (4) 11,910.35 94.24 13.61 6,102.74 5,948.74 4,597.58 6,318.96 5,943,123.99 491,992.77 6.91 3,430.45 MWD (4) 11,940.39 91.93 13.74 6,101.12 5,947.12 4,626.72 -6,311.86 5,943,153.13 491,999.87 7.70 3,460.39 MWD (4) 11,970.83 89.97 14.20 6,100.62 5,946.62 4,656.26 -6,304.52 5,943,182.66 492,007.22 6.61 3,490.75 MWD (4) 12,000.23 88.37 14.24 6,101.09 5.947.4 4,684.75 6,297.30 5,993,211.15 492,014.44 5.44 3,520.06 MWD (4) 12,030.27 87.61 12.96 6,102.10 5,948.10 4,713.93 6,290.24 5,943,240.33 492,021.51 4.95 3.550.03 MM (4) 12,063.84 87.21 11.12 6,103.61 5,949.61 4,746.73 6,283.24 5,943.273.12 492,028.51 5.60 3,583.54 MWD (4) 12,091.87 88.07 10.42 6,104.77 5,950]7 4,774.24 -6,278.01 5,943,300.63 492,033.75 3.95 3,611.54 MWD (4) 12,116.19 88.90 8.60 6,105.41 5,951A1 4,798.21 6,273.99 5,993,324.60 492,037.77 8.22 3,635.85 MM (4) 12,148.01 88.59 7.28 6,106.11 5,952.11 4,829.72 -6,269.60 5,943,356.10 492.042.17 4.26 3,667.64 MWD (4) 12,180.91 87.73 5.55 6,107.16 5,953.16 4,862.40 6,265.92 5,943,388.78 492,045.85 5.87 3,700.46 MWD(4) 12,210.44 87.60 3.57 6,108.37 5,954.37 4,891.81 6,263.58 5,943,418.18 492.48.21 6.71 3,729.83 MWD(4) 12,241.97 87.05 2.06 6,109.84 5,955.84 4,923.26 6,262.03 5,943,449.64 492.049.76 5.09 3,761.08 MWD (4) 12270.83 86.80 0.39 6,111.39 5,957.39 4,952.07 6.26191 5,943,478.44 492.5038 5.84 3.789.56 lv D(4) 12,300.80 85.47 35945 6,113.15 5,959.15 4,981.99 6,26146 5,943,508.36 492,05035 332 3.819.01 MWD (4) 10252017 12:36:22PM Page 4 'UGHES 0 Annotation COMPASS 5000.14 Build 85 1012512017 1236 22P Page 5 COMPASS 5000.14 Build 85 ConocoPhillips SA0 ConocoPhillips p Definitive Survey Report DGHE$ER 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-0417 Survey Calculation Method: Minimum Curvature Design: 21K-0411 Database: EDT Alaska Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS -NIS -El-W Northing Easting DLS Section (usft) (1) V) (usft) (usft) (usft) (usft) (°1100') Survey Tool Name Annotation (ft) (ft) (ft) 12.330.30 86.29 357.80 6,115.01 5,961.01 5,011.42 -6,262.16 5,943,537.79 492.049.65 5.62 3,847.88 MVUD(4) 12,360.51 88.16 356.01 6,116.47 5.962.47 5,041.55 6,263.79 5,943,567.91 492,048.02 8.56 3,877.26 MWD (4) - 12,3W.39 89.57 355.26 6,117.06 5,963.06 5,071.34 6,266.07 5,943,597.70 492,045.76 5.34 3,906.20 MWD (4) 12.420.22 89.91 354.05 6,117.20 5,963.20 5,101.04 -6,268.84 5,943,627.39 492,042.99 4.21 3,934.97 MWD (4) 12,452.50 91.29 353.59 6,116.86 5,962.86 5,133.13 6.272.32 5,943,659.48 492.039.52 4.51 3,965.97 MWD(4) 12,478.7B 90.95 354.89 6,116.35 5,962.35 5,159.27 6,274.96 5,943,685.62 492,035.89 5.11 3,991.25 MWD 14) 12,51150 91.60 356.75 6,115.62 5,961.62 5,191.89 4i,277.34 5,943,71B.24 492,034.51 6.02 4,022.97 MWD(4) 12,540.67 92.18 357.55 6,114.66 5,960.66 5,221.01 6,278]9 5,943,747.36 492,033.07 3.39 4,051.39 MWD(4) 12,570.23 93.74 359.49 6,113.13 5,959.13 5,250.52 6,279.55 5,943,776.86 492.032.31 8.41 4,080.32 MWD (4) 12,600.53 93.29 1.16 6,111.27 5,957.27 5,280.76 6,279.38 5,943,807.10 492,032.49 5.70 4,110.13 MWD (4) 12,630.49 92.80 3.63 6,109.68 5,955.68 5,310.65 6,278.13 5,943,836.99 492.033.75 8.39 4,139.78 MWD(4) 12,660.52 93,56 5.51 6,108.02 5,954.02 5,340.54 6,275.74 5,943,866.87 492,036.14 6.74 4,169.63 MWD (4) 12890.66 93.20 7.21 6,106.24 5,952.24 5,370.44 6,272.41 5,943,896.77 492.039.48 5.76 4,199.66 MWD(4) 12,720.54 91.87 8.12 6,104.92 5,950.92 5,400.02 6,268.43 5,943,926.35 492,043.47 5.39 4,229.48 MWO (4) 12,750.38 90.95 9.64 6,104.18 5,950.18 5,429.49 6,263.82 5,943,955.81 492,048.08 5.95 4,259.31 MWD (4) 12,780.49 90.49 11.14 6,103.80 5,949.80 5,459.11 6,258.39 5,943,985.42 492,053.52 5.21 4,289.41 MWD(4) 12.814.37 90.92 16.05 6,103.39 5,949.39 5,492.02 6,250.43 5,944,01B.34 492,061.48 14.55 4,323.21 MWO(4) -_ 12,840.33 90.40 16.34 6,103.09 5,949.09 5,516.95 6,243.19 5,944,043.26 492,06833 2.29 4,349.02 MWD (4) 12,870.38 90.86 18.55 6,102.76 5,948.76 5,545.62 6,234.19 5,944,071.92 492,077.74 7.51 4.378.81 MWD(4) 12,906.02 91.84 20.78 6,101.92 5,947.92 5,579.17 6,222.20 5,944,105.46 492.089.74 6.83 4,413.93 MWD (4) 12,946.00 91.84 20.78 6,100.63 5,946.63 5,616.53 6,208.02 5.944.142.82 492,103.92 0.00 4,453.19 PROJECTED to TD 1012512017 1236 22P Page 5 COMPASS 5000.14 Build 85 RER W 1 1 a GE company To: Letter of Transmittal Date: DATA LOGGED November 6, 2017 A /'t 1201 M. K. BENDER Makana Bender AOGCC 333 West 711 Ave, Suite 100 Anchorage, Alaska 99501 From: Yosha Ragbirsingh / Michael Soper Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2K -04L1 21 7 1 2 6 2 8 7 7 1 2K -04L1-01 2 1 7 1 2 7 28 77 2 2K -04L1-02 217 1 2 8 28 7 7 3 RECEIVED NOV 07 2017 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 A®GCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K -04L1-01 50-103-20099-61 Baker Hughes INTEQ Definitive Survey Report 25 October, 2017 217127 28 77 2 BAER UGHES a GE company ConocoPhillips SA ER ttDHE�s ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2K-04 Project: Kupamk River Unit TVD Reference: 2K-04 @ 154.00usft (2K-04) Site: Kupamk 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: 2K -04L7 Database: EDT Alaska Sandbox Project Kuparuk River Unit, North Slope Alaska, United States _ Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2K-04 1 Well Position +N/ -S 0.00 usft Northing: 5,938,52546usft Latitude: 70° 14' 35.784 N +E/ -W 0.00 usft Easting: 498,310.06usft Longitude: 150° D'49 136 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 118.50 usft Wellbore 2K -04L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2017 10/1/2017 17.30 80.84 57.474 Design 2K -04L1-01 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,510.72 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction i (usft) (usft) (usft) 35.50 0.00 0.00 10.00 ...................... S '. Survey Program Date 10/25/2017 From TO Survey 7 (usft (usft) SurveySurvey (Wellbore) Tool Name Description Start Date End Date 200.00 10,400.00 2K-04 (2K-04) BOSS -GYRO Sperry -Sun BOSS gyro multishot 1/12/2001 10,479.00 10,510.72 2K -04L7 MWD-INC(21K-041-1)MWD MWD - Standartl 10/10/2017 10/10/2017 i i 10,530.00 10,560.36 2K -04L7-01 MWD -INC (2K -04L1-01) MWD-INC_ONLY MWD-INC—ONLY—FILLER 10/17/2017 10/17/2017 10,589.85 12,906.02 2K-041-1-01 MWD (21<44t_1-01) MWD MWD - Standartl 10/17/2017 10/20/2017 10/252017 12.36:22PM Page 2 COMPASS 5000.14 Build 85 Survey 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 Q 154.00usft (2K-04) Well: 2K-04 North Reference: True Wellbore: 2K-0411 Survey Calculation Method: Minimum Curvature Design: 2K -04L1 Database: EDT Alaska Sandbox Survey Annotation Interpolated Azimuth - TIP KOP Interpolated Azimuth 10/252017 12:38:22PM Page 3 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DI Northing Easting -S Section Survey Tool NamE (usft) (1) V) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (R) 10,510.72 71.56 299.50 6,13981 5,985.81 3,595.80 6,994.60 5,942,122.47 491,316.96 27.01 2,326.57 MWD (2) 10,530.00 77.77 295.92 6,144.91 5,990.91 3,604.43 -7,011.06 5,942,13110 491,300.51 36.85 2,332.21 MWD-INC_ONLY(3) 10,550.36 90.49 304.00 6,148.01 5,994.01 3,619.49 -7,037.14 5,942,146.17 491,27444 49.53 2,342.52 MWD -INC _ONLY (3) 10,589.85 98.38 318.62 6,145.72 5,991.72 3,638.82 -7,059.16 5,942,165.49 491,252.43 56.17 2,357.72 MM (4) 10,620.14 97.98 332.32 6,141.39 5,987.39 3,663.46 -7,076.11 5,942,190.13 491,23548 44.79 2,379.05 MWD (4) 10,65068 96.77 343.70 6,137.46 5,983.46 3,691.49 -7,087.43 5,942,218.17 491,224.17 37.16 2,409.69 MWO(4) 10,680.98 9575 352.64 6,134.14 5,980.14 3,720.94 -7,093.59 5,942,24762 491,218.01 29.52 2,432.62 MWD (4) 10,710.91 95.01 3.55 6,131.33 5,97783 3,750.68 -7,094.58 5,942,277.35 491,217.03 36.37 2,461.74 MAD (4) 10,741A6 91.07 14.52 6,129.73 5,975.73 3,780.36 -7,089.85 5,942,307.03 491,221.76 38.61 2,491.79 MWD (4) 10,770.38 90.34 25.01 6,129.36 5,975.36 3,807.91 -7,079.95 5,942,334.58 491,231.67 35.66 2,520.64 MWO(4) 10,80071 90.46 36.11 6,129.15 5,975.15 3,833.99 -7,064.56 5,942,360.65 491,247.07 36.60 2,54899 MWD(4) 10,826.30 89.45 45.69 6,129.17 5,975.17 3,853.31 -7,047.82 5,942,37996 491,263.81 37.64 2,570.92 MWD (4) 10,857.41 89.32 55.30 6,129.51 5,975.51 3,872.86 -7,023.68 5,942,399.50 491,287.95 34.11 2,594.37 MWD (4) 10,887.99 90.61 58.63 6,129.53 5,975.53 3,889.30 8,997.90 5,942,415.94 491,313.73 8.71 2,615.04 MWD (4) 10,918.06 88.92 59.45 6,129.65 5,975.65 3,904.77 8,972.12 5,942,431.40 491,339.51 6.25 2,634.75 MWO(4) 10,998.07 88.46 61.50 6,130.34 5,976.34 3,919.55 8,946.01 5.942,446.18 491,365.62 7.00 2,653.85 MVV (4) 10,97]64 88.31 64.05 6,131.17 5,977.17 3,93308 4919.73 5,942,459.69 491,391.90 8.64 2,671.72 MWD (4) 11,008.07 89.05 65.91 6,131.87 5,977.87 3,945.94 6,892.17 5,942,47255 491,419.47 6.58 2,689.18 MWD (4) 11,037.75 89.17 64.84 6,132.33 5,978.33 3,958.31 8,655.19 5,942,484.91 491,44644 3.63 2,706,04 MWD(4) 11,06775 88.56 62.64 6,132.93 5,978.93 3,971.58 8,838.29 5,942,49817 491,473.34 7.61 2,723.78 MWD(4) 11,098.28 87.54 60.94 6,133.96 5,979.96 3,986.00 6,811.41 5,942,512.59 491,500.23 6.49 2,742.65 MWD(4) 11,12789 88.77 59.97 6,134.92 5,980.92 4,00.59 8,785.66 5,942,527.17 491,525.98 5.29 2,761.50 MWO(4) 11,157.40 89.54 58.11 6,13535 5,981.35 4,015.77 6,760.36 5,942,542.35 491,551.28 6.82 2,780.84 MWD (4) 11,187.46 90.03 56.73 6,135.47 5,981.47 4,03196 8,735.03 5,942,558.52 491,576.61 4.87 2,801.18 MWO(4) 11,220.49 0.25 5527 6,135.38 5,981.39 4,050.43 8,707.65 5,942,576.99 491,603.99 4.47 2,824.12 MWO(4) 11,25046 0.43 53.70 6,135.21 5,981.21 4,067.64 8,683.25 5,942,594.39 491,628.39 5.27 2,845.50 VIM (4) 11,280.65 91.32 5286 6,134.75 5,980.75 4,085.68 6,659.06 5,942,612.43 491,652.58 4.05 2,867.48 MWD(4) 11,310.50 91.14 51.51 6,139.11 5,90.11 4,104.18 6,635.48 5,942,630.72 491,676.16 4.56 2,889.59 MWD(4) 11,340.86 91.32 50.22 6,133.45 5,979.45 4,123.34 8,611.94 5,942,649.87 491,699.71 4.29 2,912.54 MWD (4) 11,370.55 91.14 48.09 6,132.82 5,97082 4,142.75 8,589.49 5,942,669.27 491,722.15 7.20 2,935.56 MWD(4) Annotation Interpolated Azimuth - TIP KOP Interpolated Azimuth 10/252017 12:38:22PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips RA ER ConocoPhillips Definitive Survey Report ucHEs Company: ConocoPhillips (Alaska) Inc -Kup2 Local Co-ordinate Reference: Well 2K-04 Project: Kuparuk River Unit ND Reference: 2K-04 @ 154.00usft (2K-04) Site: KupanA 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: 21 Database: EDT Alaska Sandbox Survey.. Map Map Vertical MD Inc Azi ND NDSS +N/S +EI -W DLS (usft) 1 (1) (usft) (usft) (usft) (usft) Northing East) r/100') Section Survey Tool Name Annotation 11,400.59 91.66 46.19 6,13208 5,978.08 4,163.18 43,567.47 5,942,68969 491,744.18 6.56 2,959.50 MWD (4) 11,430.60 91.38 44.38 6,131.29 5,977.29 4,184.28 8,546.16 5,942,710,79 491,765.50 6.10 2,983.99 MWD (4) 11,460.68 91.04 43.04 6,130.65 5,976.65 4,206.02 -6,525.38 5,942,732.52 491,786.28 4.59 3,009.00 MWD (4) 11,490.60 90.61 41.23 6,130.22 5,976.22 4,228.20 -6,505.31 5,942,754.70 491,806.35 6.22 3,034.33 MWD(4) 11,520.42 90.71 39.02 6,129.88 5,975.88 4,251.09 8,486.09 5,942,777.49 491,825.57 7.42 3,060.12 MWD(4) 11,550.81 90.89 37.22 6,129.45 5,975.45 4,274.91 6,467.33 5,942,801.39 491,844.33 5.95 3,086.92 MWD (4) 11,580.37 90.92 35.22 6,128.99 5,974.99 4,298.75 8,449.87 5,942,825.23 491,861.80 6.77 3,113.44 MWD(4) 11,610.61 91.32 33.07 6,128.39 5,974.39 4,323.77 -6,432.90 5,942,850.24 491,878.77 7.23 3,141.02 MWD(4) 11,640.62 91.63 3168 6,127.62 5,97362 4,349.11 8,416.84 5,942,875.57 491,894.84 4.74 3,16876 MWD (4) 11,668.29 92.36 29.43 6,126.66 5,972.66 4,372.92 8,402.78 5,942,899.38 491,908.90 8.64 3,19465 MVVD(4) j 11,700.74 93.37 27.37 6,125.04 5,971.04 4,401.43 8,387.37 5,942,927.88 491,924.32 7.06 3,225.41 MWD(4) I 11,730.74 95.04 2498 6,122.84 5,968.84 4,428.28 8,374.17 5,942,954.72 491,937.52 9.70 3,254.14 MWD(4) 11,761.14 96.61 22.50 6,11975 5,965.75 4,455.96 8,362.00 5,942,982.40 491,949.70 9.62 3,283.51 MWD(4) 11,790.98 96.49 2045 6,116.35 5,962.35 4,483.54 8,351.14 5,943,009.98 491,960.56 6.84 3,312.56 MVID(4) 11,820.63 97.32 1]41 6,112.78 5,958.78 4,511.38 8,341.59 5,943,037.81 491,970.11 10.56 3,34164 MWD(4) 11,850.30 97.23 1541 6,109.02 5,955.02 4,539.61 8,333.28 5,943,066.04 491,978.43 6.69 3,370.88 MWD(4) _ 11,880.53 96.27 13.25 6,105.47 5,951.47 4,568,70 8,325.85 5,943,095.12 491,985.87 7.77 3,400.81 MM (4) '. 11,910.35 94.24 13.61 6,102.74 5,948]4 4,597.58 8,318.96 5,943,123.99 491,99237 6.91 3,430.45 MWD(4)', 11,940.39 91.93 1334 6,101.12 5,947.12 4,626.72 8,311.86 5,943,153.13 491,999.87 7.70 3,460.39 NIM (4) 11,970.83 89.97 14.20 6,100.62 5,946.62 4,656.26 8,304.52 5,943,182.66 492,007.22 6.61 3,49075 Mi (4) 12,000.23 88.37 1424 6,101.04 5,947.04 4,68435 -6,297.30 5,943,211.15 492,014.44 5.44 3,520.06 MM (4) 12,030.27 87.61 12.96 6,102.10 5,948.10 4,713.93 -6,290.24 5,943,240.33 492,021.51 4.95 3,550.03 MWD (4) 12,063.84 87.21 11.12 6,10361 5,949.61 4,74633 8,283.24 5,943,273.12 492,028.51 5.60 3,583.54 MM (4) ` 12,091.87 88.07 10.42 6,10437 5,95037 4,77424 8,278.01 5,943,30063 492,033.75 3.95 3,611.54 MWD(4) 12,116.19 88.90 860 6,10541 5,951.41 4,798.21 8273.99 5,943,324.60 492,037.77 8.22 3,635.85 MM (4) 12,148.01 88.59 7.28 6,106.11 5,952.11 4,829.72 8,269.60 5,943,356.10 492,042.17 4.26 3,657,64 MM (4) 12,180.91 87.73 5.55 6,107.16 5,953.16 4,862.40 8,265.92 5,993,388.78 492,045.85 5.87 3,700.46 MWD(4) 12,210.44 87,60 3,57 6,108.37 5,954.37 4,891.81 8,263.58 5,943,418.18 492,048.21 6.71 3,729.83 MWD (4) 12,241.97 87.05 2.06 6,109.84 5,955.84 4,923.26 8,262.03 5,943,449.64 492,049.76 5.09 3,761.08 MVVD(4) I 12,270.83 86.80 0.39 6,111.39 5,957.39 4, 952A7 -6,261.41 5,943,478.44 492,050.38 5.84 3,789.56 MWD(4) 12,300.8D 8647 359.45 6,113.15 5,959.15 4981.99 -6,261.46 5,943,50836 492,050.35 3.32 3,819.01 MWD (4) 10252017 12'36:22PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Company: ConocoPhillips (Alaska) Inc -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: 2K-04 Wellbore: 2K-041-1 Design: 21K-0411 ConocoPhillipsER Definitive Survey ReportDDPs Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: - - Well 2K-04 2K-04 @ 154.00usft (2K-04) 2K-04 @ 154.00usft (2K-04) True Minimum Curvature EDT Alaska Sandbox Survey.. _-.-.��-® ..e..� .....,�_.�,......-.-......m.,,..,.®...e.-,..r._.....e...........__�._�®_®_�-.... _.�....�..., ., Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +El -W Northing Easting DLS Section (usft) (°) (°I (usft) (usft) (usft) (usft) (°1100') Survey Tool Name Annotation (ft) (ft) (ft) 12,330.30 86.29 357.80 6,115.01 5,961.01 5,011.42 $262.16 5,943,537.79 492,049.65 5.62 3,84788 MWD (4) 12,360.51 88.16 356.01 6,11647 5,962.47 5,041.55 -6,263.79 5,943,567.91 492,048.02 8.56 3,877.26 MWD (4) 12,390.39 89.57 355.25 6,117.06 5,96396 5,071.34 41,266.07 5,943,597.70 492,045.76 5.34 3,906.20 MWD (4) 12,420.22 89.91 354.05 6,117.20 5,963.20 5,101.04 -6,268.84 5,943,627 39 492,042.99 4.21 3,934.97 MWD (4) 12,452.50 91.29 353.59 6,116.86 5,962.86 5,133.13 -6,272.32 5,943,659.48 492,039.52 4.51 3,965.97 MM (4) 12,478.78 90.95 35489 6,116.35 5,962.35 5,159.27 -6,274.96 5,993,685.62 492,036.89 5.11 3,991.25 MWD (4) 12,511.50 91.60 356.75 6,115.62 5,961.62 5,191.89 -6,277.34 5,943,718.24 492,034.51 6.02 4,022.97 MWD (4) 12,540.67 92.18 357.55 6,114.66 5,960.68 5,221.01 -6,278.79 5,943,747.36 492,033.07 3.39 4,051.39 MWO(4) 12,570.23 9374 359.49 6,113.13 5,959.13 5,250.52 -6,279.55 5,943,776.86 492,032.31 8.41 4,080.32 MWD (4) 12,600.53 9329 1.16 6,111.27 5,957.27 5,280.76 -6,279.38 5,943,807.10 492,032.49 570 4,110.13 MWD (4) i 12,630.49 92.80 3.63 6,109.68 5,955.68 5,310.65 -6,278.13 5,943,836.99 492,033.75 8.39 4,139.78 MWD (4) 12,660.52 93.56 5.51 6,108.02 5,954.02 5,340.54 -6,275.74 5,943,866.87 492,036.14 6.74 4,169.63 MWD (4) 12,690.66 9320 7.21 6,106.24 5,952.24 5,370.44 -6,272.41 5,943,896.77 492,039.48 5.76 4,199.66 MWD (4) 12,720.54 91.87 8.12 6,104.92 5,950.92 5,400.02 -6,268.43 5,943,926.35 492,043.47 5.39 4,229.48 MWD (4) 12,750.38 90.95 9.69 6,104.18 5,950.18 5,429.49 -6.263.82 5,943,955.81 492,04898 5.95 4,259.31 MWO(4) 12,780.49 90.49 11.14 6,103.60 5,949.60 5,459.11 -6,258.39 5,943,985.42 492,053.52 5.21 4,289.41 MWD (4) 12,814.37 90.92 16.05 6,103.39 5,949.39 5,492.02 -6,250.43 5,944,01834 492,06148 14.55 4,323.21 MM (4) 12,840.33 90.40 16.34 6,103.09 5,949.09 5,516.95 -6,243.19 5,944,04326 49296873 2.29 4,349.02 MWD(4) j 12,870.38 90.86 18.55 6,102.76 5,948.76 5,545.62 -6,234.19 5,94407192 492,077.74 7.51 4,378.81 MWD (4) 3 12,906.02 91.84 20.78 6,101.92 5,947.92 5,579.17 -6,222.20 5,944,10546 492,089.74 6.83 4,413.93 MWD(4) 1 12,946.00 91.84 20.78 6,100.63 5,946.63 5,616.53 -6,208.02 5,944,142.82 492,103.92 0.00 4,453.19 PROJECTED IO TO 10/2&1017 12:36:22PM Page 5 COMPASS 5000.14 Build 85 THE STATE 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 -04L1-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-127 Surface Location: 5058' FNL, 94' FEL, SEC. 2, TI ON, R8E, UM Bottomhole Location: 4723' FNL, 965' FEL, SEC. 34, TI IN, R8E, UM Dear Mr. Starck: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276 7542 www.aogcc.alaskc.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, Hollis S. French �l Chair DATED this Z6 day of September, 2017. STATE OF ALASKA ALAanA OIL AND GAS CONSERVATION COMMIS_.JN PERMIT TO DRILL 20 AAC 25.005 RECEIVED SEP 07 2017 AOGCC 1a. Type of Work: 11b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG Service - Disp ❑ 11c. Specify if well is proposed for: Drill ❑ Lateral . ❑� Stratigraphic Test ❑ Development -Oil 2Service - 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 -04L1-01 ' 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 13600' ' T`/D' 5942' Kuparuk River Pool / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 5058' FNL, 94' FEL, Sec 2, TI ON, RBE, UM ADL 25589 S • Tap of Productive Horizon: 8. DNR Approval Number: 113. Approximate Spud Date: 1597' FNL, 2031' FEL, Sec 3, T10N, R8E, UM LONS 85-096 9/19/2017 Total Depth: 9. Acres in Property: 77 t 14. Distance to Nearest Property: 4723' FNL, 965' FEL, Sec 34, T11 N, R8E, UM 286 7PV 11970' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 154' - 15. Distance to Nearest Well Open Surface: x- 498310 Y- 5938525 Zone- 41 GL / BF Elevation above MSL (ft): 114' to Same Pool: 920'(2M-22) 16. Deviated wells: Kickoff depth: 10875 feet - 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hale Angle: 102 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 3020' 10580' 5996' 13600' 5942' 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 Cement Volume 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 AS1 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 ❑✓ 20. Attachments: Property Plat ❑ BOP Sketch lling Program v. Depth lot Shallow Hazard Analysis e DSleabed 8 eFluid e e✓ Divertter Sketch Report Drilling 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 i deviated from without prior written approval. Contact Name: William Long Authorized Name: Kai Starck Contact Email: William. R. Lon COP.DOm Authorized Title: CTD Director Contact Phone: 263-4372 Authorized Signature: Date: -/ - Commission Use Only Permit to Drill API Number: Permit Approv I See cover letter for other �tt,� Number: ?' r 50- ro3- -0o O� — I — Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce co lb duretha_nr@, gas hydrates, or gas contained in shales: ,--,( J-p p r Samples req'd: Yes E]Nou Mud log req'd: Yes ❑ Nou Other: BOP /.r� /.,. 5--"Cl fit✓ - fio Z JAG P5L 4 S measures: Yes M NOE] Directional svy req'd: Yes VNo❑ J fin ✓ v q r X71 t t lh /—/ R h Gy 56b*cing exception req'd: Yes ❑ Nog Inclination -only svy req'd: Yes ❑ NOVl Vl , VR C G f o '2 o A,4 CZu /s�rR�/fcd 7<a a!/a�✓ 7 -he /C/bkc,FF Pari t ¢o he Post initial injection MIT req'd:Yes❑ No,LJ✓ Cfy po/n71 ar/ont, tht per✓'„tt la�trz / ✓ APPROVED BY q I 1 Approved by: - COMMISSIONER THE COMMISSION Date: Submit Form and Form JDAP1 Revi a 5/201 sb/Firif�i>�ra�id dor L4 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 0 7 2017 A`lOGCC 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- 0411-01, and 2K -04L1-02 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 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: 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-041-1, 2K- 041-1-01, and 2K-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-0411-01, and 2K-041-1-02 - Detailed Summary of Operations - Directional Plans for 2K -04L1, 2K -04L1-01, and 2K-041-1-02 - 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 W Kuparuk CTD Laterals ". 2K-041-1, 2K-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(0 and 20 AAC 25.005(b))...................................................................................................................2 2. Location Summary .......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005 (c)(3)) ................................ .................. ............................. ........ ..................... .-.- ...... ........... .... - ... ..... 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4))..................................................................................................................................................2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................2 6. Casing and Cementing Program.................................................................................................... 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 -04L1-01, & 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-0411-01, & 2K-041-1-02 laterals...........................................6 Page 1 of 6 August 31, 2017 PTD Application: tK-04L1. 21K-041-1-01. & 2K-041-1-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 2K -04L1, 2K-041-1-01, and 21K-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 -04L1, 2K-041-1-01, and 2K-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 7/15/2017. 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 2K -04L1 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 2K -04L1-02 10,475' 13,000' 5,972' 5,943' 2W, 4.7#1 L-80, ST -L slotted liner; deployment sleeve on to Page 2 of 6 August 31, 2017 PTD Application: 2K -04L1, 2K-041-1-01, & 2K-041-1-02 Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top ND 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). 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' TVD) Usina 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 3824psi' Choke Pressure Required to Maintain Target BHP 214 psi 1052 psi Page 3 of 6 August 31, 2017 PTD Application: 2K-041-1, 21K-041-1-01, & 2K-041-1-02 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 -04L1-01 lateral. The 2K-04Ll-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 -04L1-02 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. RUE -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 -04L1, 2K -04L1-01, & 2K -04L1-02 Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2K -04L1 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. Kick off 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: tK-04L1. 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 DS4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plans — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire open hole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 2K -04L1 11,930' 21K-041-1-01 11,970' 21K-041-1-02 11,970' Distance to Nearest Well within Pool Lateral Name Distance Well 21K-041-1 400' 2K-04 2K -04L1-01 920' 2M-22 2K -04L7-02 920' 2M-22 16. Attachments Attachment 1: Directional Plans for 2K -04L1, 2K -04L1-01, & 2K-04L1-02laterals. Attachment 2: Current Well Schematic for 2K-04 Attachment 3: Proposed Well Schematic for 2K -04L1, 2K -04L1-01, & 2K -04L 1-02 laterals. Page 6 of 6 August 31, 2017 11 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-04 2K-041-1-01 Plan: 2K-041-1-01_wp04 Standard Planning Report 24 July, 2017 BER GHES TGE company ConocoPhillips BAER ConocoPhillips Planning Report UGI ES BAT Gf!wmpany Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: 2K-04 Wellbore: 2K-0411-01 Design: 2K -04L1-01 _wpD4 Local Co-ordinate 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 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2K Pad 2K-04 Site Position: Northing: 5,938,600.18usft 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 Well Position +N/ -S 0.00 usft Northing: 5,938,525.46 usft Latitude: 70" 14'35.784 N Sample +E1 -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 -04L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) 1°I InTI BGGM2017 10/1/2017 17.30 80.84 57474.37 Design 2K-0411-01_wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 10,875 00 Vertical Section: Depth From (TVD) +N/ -S +EI -W Direction (usft) (usft) (usft) (°) -118.50 0.00 0.00 10.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (°) (°I (usft) (usft) (usft) (°1100ft) (°I100ft) (°1100ft) (°) Target 10,875.00 89.90 159.14 5,980.79 3,464.70 -7,218.91 0,00 0.00 0.00 0.00 10,945.00 63.00 142.09 5,997.15 3,405.90 -7,186.47 45.00 -38.43 -24.36 210.00 11,015.00 84.96 118.40 6,016.61 3,363.64 -7,135.34 45.00 31.37 -33.84 310.00 11,085.00 88.31 87.02 6,020.82 3,348.49 -7,068.03 45.00 4.78 -44.83 275.00 11,165.00 88.63 51.01 6,023.03 3,376.67 -6,994.59 45.00 0.40 -45.01 270.00 11,280.00 88.65 42.95 6,025.76 3,455.04 -6,910.61 7.00 0.01 -7.00 270.00 11,530.00 90.21 25.52 6,028.28 3,66D.91 -6,770.51 7.00 0.63 -6.97 275.00 11,755.00 91.56 9.83 6,024.78 3,874.58 -6,702.41 7.00 0.60 -6.98 275.00 12,025.00 91.80 28.73 6,016.81 4,128.17 -6,613.70 7.00 0.09 7.00 89.00 12,325.00 102.03 10.23 5,980.43 4,407.14 -6,514.44 7.00 3.41 -6.17 300.00 12,550.00 89.84 20.26 5,957.16 4,622.30 -6,455.53 7.00 -5.42 4.47 140.00 12,800.00 90.75 2.81 5,955.87 4,866.29 -6,405.69 7.00 0.36 -6.99 273.00 13,100.00 90.70 23.81 5,952.04 5,156.58 -6,337.04 7.00 -0.02 7.00 90.00 13,225.00 90.69 32.56 5,950.52 5,266.65 -6,278.06 7.00 -0.01 7.00 90.00 13,600.00 91.95 6.33 5,941.74 5,617.07 -6,154.34 7.00 0.33 -6.99 273.00 724/2017 12'58:06PM Page 2 COMPASS 5000 14 Build 85 ConocoPhillips BA_ TR ConocoPhillips Planning Report UGHES a GEcompaq Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 2K-04 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kupamk River Unit MD Reference: 2K-04 @ 154.00usft (2K-04) Site: Kupamk 2K Pad North Reference: True Well: 2K-04 Survey Calculation Method: Minimum Curvature Wellbore: 2K-041-1-01 Depth Inclination Design: 2K-0411-01_wp04 +N1-3 -81-W Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N1-3 -81-W Section Rate Azimuth Northing Easting (usft) (1) (1 (usft) (usft) (usft) (usft) ellooft) (') (usft) (usft) 10,875.00 89.90 159.14 5,980.79 3,464.70 -7,216.91 2,158.51 0.00 0.00 5,941,991.43 491,092.65 TIPIKOP 10,900.00 80.18 153.46 5,982.95 3,441.92 -7,208.93 2,137.82 45.00 -150.00 5,941,968.66 491,102.63 10,945.00 63.00 142.09 5,997.15 3,405.90 -7,186.47 2,106.24 45.00 -149.51 5,941,932.63 491,125.07 Start 46 cils 11,000.00 80.07 123.09 6,014.65 3,371.24 -7,148.12 2,078.76 45.00 -50.00 5,941,897.96 491,163.41 11,015.00 84.96 118.40 6,016.61 3,363.64 -7,135.34 2,073.50 45.00 -43.86 5,941,890.36 491,176.18 3 11,085.00 88.31 87.02 6,020.82 3,348.49 -7,066.03 2,070.27 45.00 -85.00 5,941,875.20 491,243.48 4 11,100.00 88.32 80.27 6,021.26 3,350.15 -7,053.14 2,074.49 45.00 -90.00 5,941,876.86 491,258.38 11,165.00 88.63 51.01 6,023.03 3,376.67 -6,994.59 2,110.77 45.00 -89.80 5,941,903.36 491,316.92 End 45 dls, Start 7 dls 11,200.00 88.63 48.56 6,023.86 3,399.26 -6,967.88 2,137.66 7.00 -90.00 5,941,925.94 491,343.64 11,280.00 88.65 42.95 6,025.76 3,455.04 -6,910.61 2,202.54 7.00 -89.94 5,941,981.70 491,400.92 6 11,300.00 86.77 41.56 6,026.21 3,469.84 -6,897.16 2,219.45 7.00 -85.00 5,941,996.50 491,414.36 11,400.00 89.39 34.59 6,027.82 3,548.50 -6,835.54 2,307.61 7.00 -84.97 5,942,075.14 491,475.99 11,500.00 90.02 27.61 6,028.34 3,634.08 -6,783.92 2,400.85 7.00 -84.86 5,942,160.69 491,527.63 11,530.00 90.21 25.52 6,026.28 3,660.91 -6,770.51 2,429.60 7.00 -84.82 5,942,187.52 491,541.05 7 11,600.00 90.64 20.64 6,027.76 3,725.28 -6,743.07 2,497.76 7.00 -85.00 5,942,251.88 491,568.50 11,700.00 91.24 13.67 6,026.12 3,820.76 -6,713.60 2,596.91 7.00 -85.04 5,942,347.34 491,597.99 11,755.00 91.56 9.83 6,024.78 3,874.58 -6,702.41 2,651.86 7.00 -85.15 5,942,401.16 491,609.19 8 11,600.00 91.61 12.98 6,023.54 3,918.67 -6,693.52 2,696.82 7.00 89.00 5,942,445.24 491,618.09 11,900.00 91.71 19.96 6,020.64 4,014.47 -6,665.18 2,796.08 7.00 89.09 5,942,541.02 491,646.45 12,000.00 91.78 26.98 6,017.59 4,106.08 -6,625.38 2,893.22 7.00 89.29 5,942,632.62 491,686.27 12,025.00 91.80 28.73 6,016.81 4,128.17 -6,613.70 2,917.00 7.00 89.50 5,942,654.70 491,697.95 9 12,100.00 94.41 24.18 6,012.74 4,195.20 -6,580.34 2,988.80 7.00 -60.00 5,942,721.71 491,731.31 12,200.00 97.86 18.04 6,002.04 4,287.89 -6,544.54 3,086.30 7.00 -60.25 5,942,814.38 491,767.14 12,300.00 101.21 11.81 5,985.47 4,383.11 -6,519.13 3,184.48 7.00 -60.90 5,942,909.59 491,792.57 12,325.00 102.03 10.23 5,980.43 4,407.14 -6,514.44 3,208.97 7.00 -61.94 5,942,933.62 491,797.26 10 12,400.00 97.99 13.64 5,967.40 4,479.37 -6,499.16 3,262.75 7.00 140.00 5,943,005.64 491,812.55 12,500.00 92.56 18.08 5,958.21 4,575.10 -6,47195 3,381.75 7.00 140.59 5,943,101.55 491,839.78 12,550.00 89.84 20.28 5,957.16 4,622.30 -6,455.53 3,431.09 7.00 141.00 5,943,148.75 491,856.22 11 12,600.00 90.02 16.79 5,957.22 4,669.70 -6,439.64 3,480.53 7.00 -87.00 5,943,196.14 491,872.12 12,700.00 90.39 9.80 5,956.86 4,766.96 -6,416.66 3,580.30 7.00 -87.00 5,943,293.38 491,895.11 12,800.00 90.75 2.81 5,955.87 4,866.29 -6,405.69 3,680.02 7.00 -87.02 5,943,392.70 491,906.10 12 12,900.00 90.74 9.81 5,954.57 4,965.62 -6,394.72 3,779.75 7.00 90.00 5,943,492.01 491,917.10 13,000.00 90.73 16.81 5,953.28 5,062.86 -6,371.72 3,879.51 7.00 90.09 5,943,589.24 491,940.12 13,100.00 90.70 23.81 5,952.04 5,156.58 -6,337.04 3,977.83 7.00 90.18 5,943,682.95 491,974.81 13 13,200.00 90.69 30.81 5,950.82 5,245.38 -6,291.19 4,073.23 7.00 90.00 5,943,771.72 492,020.67 13,225.00 90.69 32.56 5,950.52 5,266.65 -6,278.06 4,096.46 7.00 90.09 5,943,792.99 492,033.81 14 13,300.00 90.96 27.31 5,949.44 5,331.61 -6,240.65 4,166.93 7.00 -87.00 5,943,857.94 492,071.23 13,400.00 91.31 20.32 5,947.45 5,423.02 -6,200.30 4,263.96 7.00 -87.08 5,943,949.33 492,111.59 7242017 12:58:06PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips BA_ ICER ConocoPhillips Planning Report 11GIF1ES aGEcompany Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 2K-04 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kupamk River Unit MD Reference: 2K-04 @ 154.00usft (2K-04) Site: Kupamk 2K Pad North Reference: True Well: 2K-04 Survey Calculation Method: Minimum Curvature Wellbore: 2K-041-1-01 Map Map Rate Azimuth Design: 2K -04L7-01 wPO4 (°1100ft) (°) (usft) (usft) Planned Survey -87.21 5,944,044.94 492,140.53 7.00 -87.39 Measured 492,157.60 TVD Below Vertical Depth Inclination Azimuth System +N/ -S +E/ -W Section (usft) (I (.) (usft) (usft) (usft) Wait) 13,500.00 91.64 13.33 5,944.88 5,518.65 -6,171.39 4,363.16 13,600.00 91.95 6.33 5,941.74 5,617.07 -6,154.34 4,463.05 Planned TO at 13600.00 Dogleg Toolface Map Map Rate Azimuth Northing Easting (°1100ft) (°) (usft) (usft) 7.00 -87.21 5,944,044.94 492,140.53 7.00 -87.39 5,944,143.35 492,157.60 7242017 12.:58:06PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips BA ER ConocoPhillips Planning Report F IGHES BAT GE company Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: 2K-04 Wellbore: 21K-041-1-01 Design: 2K -04L1-01 _Wp04 Targets Local Co-ordinate 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 -hit/miss target Dip Angle Dip Dir. TVD -N/-S +E/ -W Northing Easting -Shape (1) (1) (usft) (usft) (usft) (usft) (usft) 2K -04L1 -01_T01 0.00 0.00 6,029.00 3,647.981,133,375.48 5,941,919.00 1,631,573.00 -plan misses target center by 1139531.52usft at 13600.00usft MD (5941.74 TVD, 5617.07 N, -6154.34 E) 5,944,045.00 - Point MD (5941.74 2K -0411-01_T03 0.00 0.00 5,958.00 4,635.151,133,681.29 5,942,906.00 1,631,879.00 - plan misses target center by 1139836.05usft at 13600,00usft MD (5941.74 TVD, 5617.07 N, -6154.34 E) - Point 2K-0411-01_705 0.00 0.00 5,942.00 5,628.321,133,986.10 5,943,899.00 1,632,184.00 - plan misses target center by 1140140.44usft at 13600.00usft MD (5941.74 TVD, 5617.07 N, -6154.34 E) 0.00 - Point Point 2K -04L1 Fault? 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 1139949.07usft at 13600.00usft MD (5941.74 TVD, 5617.07 N, -6154.34 E) 5,943,795.02 - Rectangle (sides W1.00 H1,000.00 DO. 00) 0.00 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 1140040.89usft at 13600.00usft MD (5941.74 TVD, 5617.07 N, -6154.34 E) - Polygon - Polygon Point 0.00 0.00 0.00 5,944,045.00 Point 0.00 -249.94 299.10 5,943,795.02 Point 0.00 -447.99 191.14 5,943,597.01 Point 0.00 -969.08 49.27 5,943,076.01 Point 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 5,942,270.98 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 2K-041-1_Faultl 0.00 0.00 5,984.00 2,778.961,133,775.72 5,941,050.00 - plan misses target center by 1139933.59usft at 13600.00usft MD (5941.74 TVD, 5617.07 N, -6154.34 E) - Polygon Point 1 5,984.00 0.00 0.00 5,941,050.00 Point 5,984.00 1.00 1.00 5,941,051.00 2K-04 CTD Polygon Sot 0.00 0.00 0.00 3,587.941,133,197.48 5,941,859.00 - plan misses target center by 1139369.12usft at 13600.00usft MD (5941.74 TVD, 5617.07 N, -6154.34 E) - Polygon Point 1 0.00 0.00 0.00 5,941,859.00 Point 0.00 233.02 -21.07 5,942,092.00 Point 0.00 190.92 -365.09 5,942,049.98 Point 0.00 -31.14 480.04 5,941,827.97 Point 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 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 1,631,973.00 1,631,973.00 1,631,974.00 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 Latitude Longitude 70° V 18.962 N 140` 55'43 718 W 70° 1'28.102 N 140° 55' 30.816 W 70" V37.303 N 140° 55' 17.915 W 70° V9.938 N 140° 55'36.060 W 70" V 38.889 N 140° 55'20.559 W 70° V9.938 N 140° 55' 36.060 W 70° 1'1&638 N 140° 55'49,030 W 7242017 12:58'06PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: 2K-04 Wellbore: 2K-041-1-01 Design: 2K-0411-01 wp04 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: 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 2K-041-1_Fault2_M 0.00 0.00 0.00 2,459.051,134,221.84 5,940,730.00 - plan misses target center by 1140396.02usft at 13600.O0usft MD (5941.74 TVD, 5617.07 N, -6154.34 E) - Rectangle (sides W1.00 H1,000.00 D0.00) 2K -0411-01_T02 0.00 0.00 6,017.00 4,148.071,133,528.39 5,942,419.00 - plan misses target center by 1139683.67usft at 13600.00usft MD (5941.74 TVD, 5617.07 N, -6154.34 E) - Paint BAF�UGHES a GEmmpany Well 2K-04 Mean Sea Level 2K-04 @ 154.00usft (2K-04) True Minimum Curvature 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 1,632,419.00 70° 1'6.179 N 140"55' 24.757 W 1,631,726.00 70° V23.595 N 140'55'37,240 W 2K -041-1-01_T04 0.00 0.00 5,953.00 5,155.231,133,827.19 5,943,426.00 1,632,025.00 70" 1'32.940 N 140" 55'24.450 W - plan misses target center by 1139981.62usft at 13600.00usft MD (5941.74 TVD, 5617.07 N, -6154.34 E) Depth - Point Diameter 2K-041-1_Fault2 0.00 0.00 6,010.00 2,459.051,134,221.84 5,940,730.00 1,632,419.00 70° V6.179 N 140° 55'24,757 W - plan misses target center by 1140380.55usft at 13600.00usft MD (5941.74 TVD, 5617.07 N, -6154.34 E) 13,600.00 Polygon 2.375 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 Casing Points Measured Vertical Casing Depth Depth Diameter (usft) (usft) Name (in) 13,600.00 5,941.74 23/8" 2.375 Plan Annotations Measured Vertical Local Coordinates Depth Depth -NI-S +EI -W (usft) (usft) (usft) (usft) Comment 10,875.00 5,980.79 3,464.70 -7,218.91 TIP/KOP 10,945.00 5,997.15 3,405.90 -7,186.47 Start 45 dls 11,015.00 6,016.61 3,363.64 -7,135.34 3 11,085.00 6,020.82 3,348.49 -7,068.03 4 11,165.00 6,023.03 3,376.67 -6,994.59 End 45 dls, Start 7 dls 11,280.00 6,025.76 3,455.04 -6,910.61 6 11,530.00 6,028.28 3,660.91 -6,770.51 7 11,755.00 6,024.78 3,874.58 -6,702.41 8 12,025.00 6,016.81 4,128.17 -6,613.70 9 12,325.00 5,980.43 4,407.14 -6,514.44 10 12,550.00 5,957.16 4,622.30 -6,455.53 11 12,800.00 5,955.87 4,866.29 -6,405.69 12 13,100.00 5,952.04 5,156.58 -6,337.04 13 13,225.00 5,950.52 5,266.65 -6,278.06 14 13,600.00 5,941.74 5,617.07 -6,154.34 Planned TD at 13600.00 Hole Diameter (in) 3.000 7242017 12:58r06PM Page 6 COMPASS 500014 Build 85 (ui/3jsn OSE) (+)9uoN/(-)gmoS mm b 0 a r r2 m ^ O 0 v r 3O'a v d 0 ¢�ulMv w`mrmm.-^^^moo. @ orr Q O mOrmNMm�n hNNNr h4 N�i . 6m@O tG C)OO fV e�rm�r(OM �OO D Z >,ryOrr�ONm�OMmrOf lO N N N N N N N N N M M M M Q Q -3500 48]5 r m o 0000 0000000000 O O O O O O O O O O I=! 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Cylinder North Results Limited by: Maximum center -center distance of 1,556.45 usft Error Surface: Pedal Curve Survey Tool Program Date 7/20/2017 From To (usft) (usft) Survey (Wellbore) 200.00 10,400.00 2K-04 (2K-04) 10,400.00 10,875.00 2K-041_1_WP02 (2K-041-1) 10,875.00 13,600.00 2K-04L1-01_wp04 (2K-0411-01) Tool Name Description BOSS -GYRO Sperry -Sun BOSS gyro multishot MWD MWD -Standard MWD MWD -Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name l"1 1'9 13,600.00 6,095.74 23/8" 2-318 3 Summary CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation Warning Out of range Out of range Out of range Pass- Major Risk Pass- Minor 1/10 Pass- Minor 1/10 Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 720/2017 3:46:21PM Page 2 COMPASS 5000.14 Build 85 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) 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 11,343.59 10,400.00 103.02 18.14 92.35 2K-04-2K-04L1-2K-04L1_wp02 11,343.59 10,400.00 103.02 7.80 102.55 2K-04-2K-04L7-02-2K-041-1-02_wp02 12,659.16 12,025.00 0.30 1.56 0.08 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-OBA 2K-08 - 2K-08APBl - 2K-08APB1 2K-08 - 2K-0BAPB2 - 2K-08APB2 2K-08 - 2K-08APB3 - 2K-08APB3 2K-08 - 2K-08BPB1 - 2K-08BPB1 2K-08 - 2K-08BPB2 - 2K-08BPB2 2K-08 - 2K-08BP63 - 2K-08BPB3 2K-09 - 2K-09 - 2K-09 2K-09 - 2K-0911 - 2K-091-1 2K-09 - 2K -09L7-01 - 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-11APB7 - 2K-11 APBt 2K-12 - 2K-12 - 2K-12 2K-26 - 2K-26 - 2K-26 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation Warning Out of range Out of range Out of range Pass- Major Risk Pass- Minor 1/10 Pass- Minor 1/10 Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 720/2017 3:46:21PM Page 2 COMPASS 5000.14 Build 85 Baker Hughes lNTEQBpl(ER ConoeoPhillips Travelling Cylinder Report UGHES a GEmmpany Company: Conocoldhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2K Pad Site Error: 0.00 haft Reference Well: 2K-04 Well Error: 0.00 usft Reference Wellbore 2K-041.1-01 Reference Design: 2K-0411-01_wp04 Local Co -Ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well 2K-04 2K-041@ 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 200 -BOSS -GYRO Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 2K Pad Measured Vertical Measured Vertical Reference Mae 2K-28 - 2K -28A- 2K -28A Onstt Wash.. Coal. cosm,- canlreto No Go Out of range 2K-28 - 2K-28AL7 - 2K-28AL1 Depth Depth Depth Depth Out of range 2K-28 - 2K-28AL1 PB1 - 2K-28AL1 PB1 w16 .!V -w Hole S. Centre Diane" Out of range 2K-28 - 2K-28AL1 PB2 - 2K-28AL1 PB2 (earl Nae) (haft) (win humin Out of range 2K-28 - 2K-28APB1 - 2K-28APB1 laser( (sar) 1"1 hi Nano Out of range 2K-29 - 2K-29 - 2K-29 1133199 6,13085 10,60000 6,17734 0.85 Out of range 2K-34 - 2K-34 - 2K-34 3644.35 -7,05961 3 236.90 1911. Out of range 2K-34 - 2K-3411 - 2K-3411 11.333.85 6,160.88 10,575.00 6,167.43 0.85 Out of range 2K-34 - 2K-34PB1 - 2K-34PB7 3,631.04 -7,04091 3 21440 1900 Out of range Offset Design Kuparuk 2K Pad- 2K -04 -2K -04-2K-04 onatt silo error: omusn Sorvey Poem.: 200 -BOSS -GYRO Rule Awaked: Mayor Risk Onset Well Erre, 000 use Reference DRset Semi Mal9rAxls Measured Vertical Measured Vertical Reference Mae Tissues.. Onstt Wash.. Coal. cosm,- canlreto No Go Alessi assuming Depth Depth Depth Depth Azimuth w16 .!V -w Hole S. Centre Diane" D.spian (earl Nae) (haft) (win humin lose) (1) laser( (sar) 1"1 hi Nano (oan) 1133199 6,13085 10,60000 6,17734 0.85 3.89 49.83 3644.35 -7,05961 3 236.90 1911. 218.99 Pass - Major Risk 11.333.85 6,160.88 10,575.00 6,167.43 0.85 3.39 -47.21 3,631.04 -7,04091 3 21440 1900 19683 Pass - Major Risk 11,33552 8,180.91 10,550.00 6,157.38 085 2.89 4390 3,61773 -7,02228 3 192.57 18.57 17543 Pass - Major Rask 11,33702 6.180.93 10.52500 6,14720 0.85 2.39 -39.69 3.604.42 -7,003]3 3 171.60 18.75 155.09 Pass - Major Risk 11.338.35 6.180.96 10.500.00 6,136.98 0.85 1.99 -34.27 3,591.12 -6,985.25 3 152.12 1861 138.34 Pass - Major Risk 11,33965 6,180.98 10475.00 6,12642 085 141 -27.27 3,5n 87 -6,96681 3 134.49 1850 119.31 Pass - Major Risk 11,310.95 6,18100 10,450.00 6,115.81 085 0.94 .1828 3,564.74 -6,94837 3 11965 1838 105.51 Pass - Major Risk 11,34226 6,19102 10.425.00 6.10506 0.85 0.47 -706 3,55111 -6,92994 3 10874 18.28 88.13 Pass -Major Risk 11,343.59 5,18105 10,40000 6,094.18 085 000 603 3,53880 6,911.51 3 103.02 18.14 92.35 Pass- Major Risk, CC, ES, SF 11,345.10 6,181.07 10.375.00 6.003.19 0.85 0.00 19.83 3.526.11 1.,092.98 3 103.28 18.16 92.86 Pass - Major Risk 11,346.92 6,181.10 10,35000 6.072.24 0.85 0.00 32.76 3,513.74 6,074.22 3 109.39 18.18 9902 Pass -Major Risk 11,319.05 6,181.14 10,32500 6,061.30 0.85 0.00 4378 3,501.70 6,855.24 3 12044 1820 110.04 Pass - Major Risk 11,3$144 6,181.18 10,300.00 6,050.38 0.65 000 52.62 3,489.98 6,836.04 3 135.21 10.23 124.74 Pass - Major Risk 11,354.05 6,181.22 10,275.00 6.03944 0.85 000 59.51 3,470.57 4,916.67 3 15263 1026 142.07 Pass - Major Risk 11.356.83 6,18126 10,250.00 6.028.45 0.85 000 6485 3,467,48 6,797.18 3 17191 1829 161,27 Pass - Major Risk 11,359.77 6,181.30 10225.00 8,017,41 0.85 000 69.01 3.456.64 6,777.51 3 192.49 18.32 181.77 Pass - Major Risk 1136285 6.181.35 10200.00 8006.32 0.85 000 7228 3.446.12 4.757.73 3 21396 18.36 203.17 Pass - Major Risk 11,366.05 6,181.40 10,175.00 5,995.12 0.85 0.00 74,86 3,435.89 -5737.86 3 236.41 1839 22526 Pass - Major Risk 1136933 6,181.44 10,150.00 5,983.75 085 0.00 76.91 3.425% -6,717,93 3 258.79 19.43 247.88 Pass - Major Risk 1137270 6.10149 10,12500 5.97221 085 am 78.54 3.41633 -6,697.95 3 28185 1847 270.99 Pass - Major Risk 11,376.15 6.101.54 10,100.00 5.960.50 0.85 0.00 79.84 3.47.00 -6,67793 3 30520 1851 294.19 Pass - Major Risk 11.379.68 6,18158 10,075.00 5,948.66 0.85 0.00 80.88 3,39798 -6,857 85 3 32876 1555 317,70 Pass -Major Risk 1138330 6.18163 10,050.00 5.938.72 0.85 0.00 8173 3.389.25 4,637.69 3 35245 18.59 34134 Pass - Major Risk 11.387.00 6,101.67 10.025.00 5.92431 0.95 0.00 92.41 3,39082 4,61)45 3 37826 1563 jsMiA0 Pan - Major Risk 11,39078 6,181.72 10,000.00 5,91260 0.85 000 82.98 3.37270 6,597.14 3 400.14 1867 38893 Pass -Major Risk 11,394.58 6.181.76 9,97500 5,900.37 085 0.00 W39 3.364.82 6.576.81 3 424.10 10.71 412.85 Pa. - Major Fi 11,400.00 6.181.82 9,925.00 5.875.39 085 000 84.12 3.34965 4.536.25 3 47228 18.77 460.94 Pan - Major Risk 11.400.00 6,18162 9,950.00 5.8117.96 0.85 000 83.61 3,357.14 4,556.51 3 44814 16.77 436.83 Pass - Major Risk 11.405.79 6,18165 9,900.00 5,862.64 085 000 84.18 3,342.35 8.518.01 3 496.41 18M 485.03 Pass - Major Risk 11409.42 6.181.92 9,875.67 5,849.80 0.85 0.00 84.29 3.335.16 6.495.80 3 520.62 18.55 50920 Pass - Major Risk 11,41294 6,151.95 9.85000 5.836.95 0.05 0.00 8440 3,327.98 -6,475.80 3 544.97 18.92 53340 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 7/20/2017 3:46:21PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips lli-1112H-IOf.l-01 41-I,W:II-IOL 311-IJ/3161{p 311-ILQH-IJAI,1 9AI�j r l I - it r- I I _I. I I t li 'l E ,'. �1't tl��.+�:+#*f 6(r-� I l�nh'� •.4:1 ".,ll_Ir �� -_ll` It'd• 1 �I� +i_�( r��- Ij I� er r- I�4' it I `1. nlnnr n l x 1 yy} S"/Ox rM1 'Tt 1 ,1'.' , A s4001�1. ,i -iT i+' � i � Ill e } } J 1 II f l '�r 4A00� � Ir I ' • / -- loll 1Li I 4500 I G CD 'goo 3600 v ni I _LI -I 3300 93000 05 2]00ISuon 0 � 2400 2100- 1500 100 1500 1200 ]M-U9RMLB 900. M4 Xl'M4 xl ILI !. ITi � r� 1 1 ) 11 A Ik w1B\�� LOB2KH ;" 1'iAll 300 0u,. .-:.I 4 i' -11 1001110111MO-10200-9900 -9600 A300 -9000 -9700 -8400 -8100 -7800 -7500 -7200 -6900 -6600 -6300 -6000 -5]00 -5400 -5100 -4800 4500 -9200 -3900 -3600 -3300 -3000 -2700 -2400 -2100 =1800 -1500 1200 West( -)/East(+) (300 usfl 2K-34PK.l{Ppl 2K-04 @ 154.00usR (2K-04) wmwaorna wen WELLBORE DETAILS: 2K -04L1 REFERENCE wFORMnT10x Project: Kuparuk RNer Unit MepiWb xwu: n.w• Site: Kuparuk 2K Pad T/ Coardnam INIE) Rearm: MI x84{, Trva No Well: 2KA4 {\{I{✓L/} su.no�°:u ¢rmFAn Parent W811bore: 2K-04 VerAsl (IWIRMeterce: 2Nd1�151[Ousfl RK -041 Wellbore: 2K -04L1 pp NMl.: ma4• Tie on MD: ll BA ER I IGHES E,o,,,, semen Nsl Relererce: sml-romN, o.mD Plan: 2KA4Lt_Mry02 (2K-0N2K•D4Li) ecoBwlx IArsalve]Ozyl, Relcenca: 184a�159.Wurn R84JI IJoeeu CahMeYm MelM1at Mnvxm CUMun ConocoPhillips lli-1112H-IOf.l-01 41-I,W:II-IOL 311-IJ/3161{p 311-ILQH-IJAI,1 9AI�j r l I - it r- I I _I. I I t li 'l E ,'. �1't tl��.+�:+#*f 6(r-� I l�nh'� •.4:1 ".,ll_Ir �� -_ll` It'd• 1 �I� +i_�( r��- Ij I� er r- I�4' it I `1. nlnnr n l x 1 yy} S"/Ox rM1 'Tt 1 ,1'.' , A s4001�1. ,i -iT i+' � i � Ill e } } J 1 II f l '�r 4A00� � Ir I ' • / -- loll 1Li I 4500 I G CD 'goo 3600 v ni I _LI -I 3300 93000 05 2]00ISuon 0 � 2400 2100- 1500 100 1500 1200 ]M-U9RMLB 900. M4 Xl'M4 xl ILI !. ITi � r� 1 1 ) 11 A Ik w1B\�� LOB2KH ;" 1'iAll 300 0u,. .-:.I 4 i' -11 1001110111MO-10200-9900 -9600 A300 -9000 -9700 -8400 -8100 -7800 -7500 -7200 -6900 -6600 -6300 -6000 -5]00 -5400 -5100 -4800 4500 -9200 -3900 -3600 -3300 -3000 -2700 -2400 -2100 =1800 -1500 1200 West( -)/East(+) (300 usfl 2K-34PK.l{Ppl 2K-04 @ 154.00usR (2K-04) wmwaorna wen WELLBORE DETAILS: 2K -04L1 REFERENCE wFORMnT10x Project: Kuparuk RNer Unit MepiWb xwu: n.w• Site: Kuparuk 2K Pad T/ Coardnam INIE) Rearm: MI x84{, Trva No Well: 2KA4 {\{I{✓L/} su.no�°:u ¢rmFAn Parent W811bore: 2K-04 VerAsl (IWIRMeterce: 2Nd1�151[Ousfl RK -041 Wellbore: 2K -04L1 pp NMl.: ma4• Tie on MD: ll BA ER I IGHES E,o,,,, 2K-04 Proposed CTD Schematic 115' MD 7" 26# L-80 Tieback @ 2345' MD 9-5/8" 36# J-55 shoe (a14026' MD C4 - sand per's 10,402'-10,424' MD A4 -sand perfs 10,482'-1,0522' MD 3-1/7' 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camoo MMG gas lift mandrels Q 3175', 5502', 7196', 8514', 9485',10145- MD Baker FHL Packerw/ PBR (v)c„ 10229' MD Camco DS -nipple at 10344' MD (2.813" min ID) Northern Solution Wedge Assembly 10454' MD 3-1/2" X -nipple at 10469' MD (2.813" min ID) Northern Solution Wedge Assembly 10495' MD 3-1/2" X -nipple at 10509' MD (2.813" min ID) 2K -04L7-02 Wp02 TD 13,000' MD Top of Liner @ 10,475' MD 2K-0411-01 wp04 TD 13,600' MD Top of Billet Q 10,580' MD 2K--0417 wp02 TD 13,850' MD op of BiAet ®10,876' MD KUP POOD Cono4hillipsWell Attribul Alaska. irtc. )wMvG vupn F'nk 2K-04 .ONE I 301 1&5201R LaRIWO I ]5801] 1 40.191 711WN9 ew Annete Oaptx 11MB1 E OaM Annodtlen Last MW By End Dare ..._...... -.. .. _... Last Tag' DOFdn1 105420 862017 Rev Reason: GLV C/O & PULL WRP pproven 7/1)201] XPNGER: al asmg nngs CuingO¢:nlpuon oD(.ro ID (nl Top gNLBI sH Dep+x lnNel sH Oepm INDl... wuLen p... Grale Top TxM] CONDUCTOR 16 15062 36.0 115.0 115.0 6250 H40 WELDED LxInB OnacnMlonOD pnl ID (ml iop11M(B) 6M Oeptx 6tN01 SN DMx(IVGL.. sed. a.. Gude TOPR a`'IY2J1 SURFACE 9518 6921 35.0 4,026.4 2,913.3 36W J-55 BTC 1 L. too Deaorlp5on OO llnl ID lint Top,-.,-LiNplxrytllBl Sat Mplx(rv01... Wllten IL. Grate Tap Txmd PRODUCTION TIEBACK 7 1276 33.0 2,3452 2,057.1 26001-80 Hydril 563 ILL Call OetcnPan- ON,, ID gn Top Otl(BI Set Depm 6tl(BI SM De"IiVD1... Vllllen g.., Go. op TMeG ORIGINAL 7 62]6 2,3425 148359 6,269.0 26.00 J-55 BTC PRODUCTION Tubing Strings ruWn00BKdppon Shln9 Ma... Nlgn) Top (M(BI Set Ozgx lR. Set OepM(IV014.. WI(IpTp GrMe Top Connectlm TUBING-RW020n 312 2.992 31.1 10515.3 6,1432 9.30 L-80 EUE Bid MW CONDUCTOR;]40.+150 Completion Details Nam to Top(M(B) raplrvDl lraplrel rm a) l Me De. Co.Lpm p2. 31.1 31.1 0.27 HANGER Tubing Hedger, FMC, TC -IA - EN, 112" BLUE Brd top r 2.992 al.1 bosom, 3" ISA EPVG 10,201 74 6,OD7.0 63.62 LOCATOR Localer sub. Baker, GBH-22(botlom of locator spaced 2.992 out Zr) PRooucrwN N.I.F. 3a.0- 10,2024 6,DD7.4 6362 SEAL Seal ASlartly, Baker, 8D-40(seal longer 21.711 2.990 2ats.s ASSEMBLY 10,205.5 00D8.8 63.64 PER PER, Baker 20' INI 4.000 CAS LIFT: 3,1/47 10,228.6 6.0190 63.76 FHLPACKER Packer, Baker 4782 FHL 2940 10,344.1 6'696 64.05 NIPPLE Nipple, Camco 2.813" DS Pmfile 2.813 10,4533 6,1174 6477 WEDGE Went Assembly, Northern Solufionr 2.992 ASSEMBLY 10,468.6 0123.7 64.99 NIPPLE Nipple, Halliburton 2.813'X Profile 2.813 SURFACE; sS.o Qal.4-� 10,494.6 6,tPISI 65.37 WEDGE Wgige AssemDly,NOMem Solue Tls 2992 ASSEMBLY 10,5094 6,140.8 65.56 NIPPLE Nipple, Halliburton 2.813"X Profile 2813 GOS UFT: 5,5GU0 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Topf"ot ToRin rov lMLal IMNBI VL1 DeeCom Run m+e mop 10.542.0 6,154.1 66.02 FISH Culled Tubing 22' long', chemically cut in at hale 4IDI1990 0000 GPS UFT:7.+855 Perforations & Slots Shot Dena Tep(ND) a. DVD) I.I. GP5un:Bs+a7 Top(ME) B.IM(BI Me) IBNBI Lone Dab al TYPO Co. 10,4020 10,424.0 6,095.0 6,104.6 C4,2K-04 12/102003 6.0 APERF 2,5' Al PJ 10,4820 10,5220 6,1294 6,1460 A4,2K-04 429`1998 4.0 RPERF 2.5'FIG. 180 deg. Phasing, n0 board GAS LIFT, mels 10,4820 10,5220 6,1294 6,1460 A4,2K-04 11/4/1989 2.0 IPERF a- Super Omnikone Ca, 180 tleg. Phasing Mandrel Inserts sl Gas uFr; +0+4a.e au N Tap (TV01 VaRe Lath Pon3W TRO Run Top Rush food" Maka MWeI ODIMI Sery TYR, Tyq Ed (I Run MM Com 3,1]4.] 2,500.4 Council MMG 112 GAS LIFT GLV RK 0188 1290.0 7/14I20t] 2 5,502.0 3,643.3 Cannot, MMG 112 GAS LIFT GLV RK 0,188 1 274.0 7/102'1.7 ..TCR 10.201,4- 3 7,1955 4,504.5 Camco MMG 112 GAS LIFT JOV RK 0,188 0.0 7It41201] SEPLACEMaLT', m.4- 4 8,5137 5,156.8 Carrico MMG 112 GAS LIFT jDMY RK 0,000 7/612'1] PER: 10a735 5 9,484.5 5,649) Camco MMG 112 GAS LIFT DMY RK 6000 FHLPACNERI IU.4As 6 10,144.6 5,9813 U.M. MMG 1112 GAS LIFT DMY RK 0000 >/6/2p17 Notes: General & Safety End Dah Ann ourk n 1029/2010 NOTEView School wl Alaska Scheirrum0 NIPPLE: 103!4+ PPERF,104CGGNrTN0- f WEDRE ASSEMBLY; TA,Gd7 NIPPLE: 101086 WEDGEASSEMBLY; 10.484.5 IPERF', 104626100E.0 RPERF', 10.48201054.0 NIPPLE: 10,4 FISH;10520 ORIGINAL PRODUCTION; 23x2510635.8 TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: C2 ? ' �a Development _ Service _ Exploratory Stratiggaphic Test Non -Conventional FIELD: �Cy / 1�/ POOL: kW4 l�(Ed' ILI�CIGiJ �� fJ & 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. API No. 50- /-03 Q 00. aoo � -cL-_ 1/ (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_- _� from records, data and logs acquired for well name on permio. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be nm. 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 -- - letion, sus ension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 PTD#. 2171270 Company CONOCOPHILLIPS ALASKA, -INC. _ __ Initial Class/Type Well Name: KUPARUK RIV UNIT 2K-041-1-01 Program DEV Well bore seg d❑ DEV/PEND GeoArea 890 Unit 11160_ On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.030Q.1.A),(j.2.A-D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes ADL0025588, Surf Loc; ADLOO25589, Top Prod; ADL0025586,.TD. 3 Unique well name and number Yes KRU 2K-041-1-01 4 Well located in a defined pool. _ Yes KUPARUK RIVER, KUPARUK RIV OIL - 490100,. governed by Conservation Order No. 432D.. 5 Well located proper distance from drilling unit boundary Yes CO 432D contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells.. _ Yes CO 432D has no interwell spacing restrictions, 7 Sufficient acreage. available in drilling unit Yes 8 If deviated, is wellbore plat. included Yes 9 Operator only affected party Yes Wellbore. will be more than 500' from an external property line where ownership or landownership changes. 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative. approval Yes PKB 9/11/2017 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 Conductor set in KRU 2K-04 Engineering 19 Surface casing. protects all. known USDWs NA 20 CMT. vol adequate to circulate on conductor & surf csg NA Surface casing set and fully cemented 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will cover all known productive horizons.... No Productive interval will be completed with. slotted liner 23 Casing designs adequate for C, T, B &. permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all waste to approved disposal wells 25 If a. re -drill, has a 10-403 for abandonment been approved NA _ 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; no major risk failures 27 If diverier required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is 4405 psig(13.8 ppg EMW); will drill w/ 8.7 ppg EMW and. maintain overbal w/ MPD VTL 9/25/2017 29 BOPEs,. do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 3803 psig; will test BOPS to 4500 psig 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown. Yes 33 Is presence of 1-12S gas probable Yes H2S measures required 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Wells on 2K -Pad are H2S-beadng. 1-12S measures required. Geology 36 Data presented on potential overpressure zones Yes Maximum potential reservoir pressure is 13.8 ppg EMW; will be drilled using 8.7 ppg mud and MPD technique. Appr Date 37 Seismic. analysis of shallow gas. zones NA PKB 9/11/2017 38 Seabed condition survey (if off -shore) NA. _ 39 Contact name/phone for weekly progress reports [exploratory only] NA Onshore development lateral to be drilled. Geologic Engineering Public Commissioner: Date: Commissioner: Dale om ssio o Date 2-r.