The URL can be used to link to this page

Home My WebLink About217-128DATA SUBMITTAL COMPLIANCE REPORT 1/26/2018 Permit to Drill 2171280 Well Name/No. KUPARUK RIV UNIT 2K-041-1-02 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20099-62-00 MD 13010 TVD 6103 Completion Date 10/26/2017 Completion Status 1-0I1- Current Status 1-0I1- UIC No REQUIRED INFORMATION Mud Log No ✓ Samples No ✓ Directional Survey Yes v 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 28773 Digital Data 11/7/2017 Electronic File: 2K-041-1-02 EOW - NAD27.pdf , ED C 28773 Digital Data 11/7/2017 Electronic File: 2K-041-1-02 EOW - NAD27.txt Log C 28773 Log Header Scans 0 0 2171280 KUPARUK RIV UNIT 2K-041-1-02 LOG HEADERS ED C 28778 Digital Data 10209 13010 11/9/2017 Electronic Data Set, Filename: 2K -04L1-02 `GAMMA RES.Ias ED C 28778 Digital Data 11/9/2017 Electronic File: 2K-041-1-02 2MD Final Logs.cgm ED C 28778 Digital Data 11/9/2017 Electronic File: 2K-041-1-02 51VID Final Logs.cgm - ED C 28778 Digital Data 11/9/2017 Electronic File: 2K-041-1-02 5TVDSS Final' Logs.cgm ED C 28778 Digital Data ,Q 11/9/2017 Electronic File: 2K-041-1-02 21VID Final Logs.pdf ' ED C 28778 Digital Data <7 11/9/2017 Electronic File: 2K-041-1-02 51VID Final Logs.pdf - ED C 28778 Digital Data .111/9/2017 Electronic File: 2K-041-1-02 5TVDSS Final, Logs.pdf ED C 28778 Digital Data 11/9/2017 Electronic File: 2K-041-1-02 EOW - NAD27.pdf . ED C 28778 Digital Data 11/9/2017 Electronic File: 2K-041-1-02 EOW - NAD27.txt ' ED C 28778 Digital Data 11/9/2017 Electronic File: 2K-041-1-02 Survey Listing.txt ED C 28778 Digital Data 11/9/2017 Electronic File: 2K -04L1-02 Surveys.txt - ED C 28778 Digital Data 11/9/2017 Electronic File: 2K-041-1-02_Final TO 13010 . ConBrmed.csv ED C 28778 Digital Data 11/9/2017 Electronic File: 2K-04L1-02_Final TD 13010' Confirmed.xlsx ED C 28778 Digital Data 11/9/2017 Electronic File: 2K-041-1- 02_25_tapescan_BH I_CTK.txt AOGCC Page I of$ Friday, January 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/26/2018 Permit to Drill 2171260 Well Name/No. KUPARUK RIV UNIT 2K-041-1-02 MD 13010 TVD 6103 Completion Date 10/26/2017 ED C 28778 Digital Data ED C 28778 Digital Data ED C 28778 Digital Data ED C 28778 Digital Data ED C 28778 Digital Data Log C 28778 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report OY Production Test Informatior�YY NA Geologic Markers/Tops (Y / COMPLIANCE HISTORY Completion Date: 10/26/2017 Release Date: 9/26/2017 Description Comments: Interval Start Stop Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20099-62-00 Completion Status 1 -OIL Current Status 1 -OIL UIC No Core Chips Y 1( ) 11/9/2017 Electronic File: 21K-041-1- A Core Photographs Y (A Daily Operations Summary 02_5_tapesca n_B H I_CT K.txt Laboratory Analyses Y / 11/9/2017 Electronic File: 2K-0411-02_output.tap 11/9/2017 Electronic File: 2K-0411-02 2MD Final Logs.tif ' 11/9/2017 Electronic File: 2K-0411-02 5MD Final Logs.tif 11/9/2017 Electronic File: 2K-041-1-02 5TVDSS Final Logs.tif 0 0 2171280 KUPARUK RIV UNIT 21K-0411-02 LOG HEADERS Sample Set Sent Received Number Comments Directional / Inclination Data f Y 1 Mud Logs, Image Files, Digital Data Y /AJAR Core Chips Y 1( ) Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files l./ A Core Photographs Y (A Daily Operations Summary Cuttings Samples Yli rvFy Laboratory Analyses Y / Date Comments Compliance Reviewed By: A0G('CPage 2of$. I l I ( 3 Date: Friday. January 26. 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ia. Well Status: OilEI� Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 21 A C 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 1b. Well Class: Development ❑+ ' 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: 217-128 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 10/22/2017 15. API Number: 50-103-20099-62-00 4a. Location of Well (Governmental Section): Surface: 5058' FNL, 94' FEL, Sec 2, T1 ON, R8E, UM Top of Productive Interval: 1390' FNL, 1892' FEL, Sec 3, T1 ON, R8E, UM Total Depth: 4653' FNL, 1036' FEL, Sec 34, T11 N, RBE, UM 8. Date TD Reached: 10/24/2017 16. Well Name and Number: KRU 2K-041_1-02 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- 491232 y- 5942198 Zone- 4 Total Depth: x- 492086 y- 5944214 Zone- 4 11. Total Depth MD/TVD: 13010/6103 1 1 19. DNR Approval Number: LONS 85-096 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MDrrVD: 1550/1496 5. Directional or Inclination Survey: Yes 2 (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: . 10629/6140 - 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res RECEIVED NOV Z 1 2017 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD 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 AS 1 7 26 J-55 2342 10836 2055 6269 81/2 73 sx Class G 23/8 4.6 L-80 10330 12861 6063 6203 3 Slotted Liner 24. Open to production or injection? Yes E] No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER @ 10331 -12861 MD and 6064 -6203 TVD ' Lv 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDIrvD) 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) 1AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 10126/2017 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 Casing Press: 1336 Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: 372 Water -Bbl: 15 Oil Gravity - API (torr): Form 10-407 Revised 5f2017�(�� `/7i/21//'7-CONTINUIDf PAGE2�v✓--, �� 'G'iPubmit ORIGINIALor 28. CORE DATA Conventional Core(s): Yes ❑ No 2 Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, From[To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1550 1496 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 10629 6140 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk A TD 13010 6103 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, paleontoloaical report, production or well test results. per 20 AAC 27. 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.LonqAcop.com Authorized Contact Phone: 2634372 Signature: Date: INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 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 11b: 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 MO 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 forth: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 2K-04 As -Drilled CTD Schematic 1112' 9.3P L40 EUE BN Tubing to surface a H-10 Q 115' MO 3-112' Camra MMG gas lift mandrels @ 31]5', 5502', 1198', 8514', 9485',10145' MD 7 -ML -BO Tieback II11 @ 2345' MD II Baker FHL Packer W PBR @ 10229' MD 9-5/8' 389 JS5 shoe @ 4026' MD sand parte 10,402'-10,424' MO 6 sand pad 10,402'-1,0522' M0 Camra DS -nipple at 18344' MD (2.813' mm ID) Northam Solution Wadga Aesemby 10454'141) 3-12" X -nipple at 10469' MD (2.81T min ID) Northam 6nlu8on Wedge Assembly 10495' MO 1112' X -nipple at 10509' MO (2.813' min ID) 2SGn: 31BM'- 13,3M' MD"IL'T0s326 18WW PI, 12,14P-12,341'Mm 0oe,d B M M 0 10530 MD Operations Summary (with Timelog Depths) 2K-04 r. Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our (hr) Phase Op God. Activity Code Time P -T -X Operehon (ftK61 End Depth (WEI) 10/7/2017 10/7/2017 5.00 MIRU MOVE MOB P Trucks on location (2A -pad), 0.0 0.0 18:00 23:00 move/spot shop & halfway house over to 2K -pad, pull subs off of well, install jeeps 10/7/2017 10/8/2017 1.00 MIRU MOVE MOB P Move dg down road 0.0 0.0 23:00 00:00 10/8/2017 10/8/2017 1.00 MIRU MOVE MOB P Continue Moving Rig to next 0.0 0.0 00:00 01:00 1 1 destination 2K -pad 10/8/2017 10/8/2017 4.00 MIRU MOVE MOB P Remove jeeps, spot subs over well 0.0 0.0 01:00 05:00 10/8/2017 1018/2017 1.00 MIRU WHDBOP NUND P RU surface equipment (nipple up), 0.0 0.0 05:00 06:00 install tiger tank line, install fuseable cap, " Rig accept 06:00 10/8/2017 10/8/2017 3.00 MIRU WHDBOP RURD P C/O stack riser, collect RKB's, remove 0.0 0.0 06:00 09:00 & replace R1 (leaking on previous well). Unchain Injector cart and storage reel. 10/8/2017 10/812017 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 1018/2017 10/8/2017 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 C8, observe leek at the stack. Cylcle R1, no fluid at the stack, atempt high to 4500 psi, leaking off, bleed down cycle swab 1 reatempt high test, looks good, bleed down. Start test. Had to run out but got a pass. - moving on 10/8/2017 10/8/2017 4.30 MIRU WHDBOP BOPE P Continue on testing BOPE. tests 2- 12 0.0 0.0 13:00 17:18 10/8/2017 10/8/2017 2.70 MIRU WHDBOP 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 10/8/2017 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 clear of 1-12S, upon investigation found a steam leak that was spraying onto H2S sensor in cellar. Called AAR in doghouse, discussed station bill and the great command and conrtol of dg personnel during false alarm. 10/8/2017 10/8/2017 1.00 MIRU WHDBOP CTOP P PJSM, test inner reel iron, pac-off, 0.0 0.0 20:30 21:30 driller side PDL, and tiger tank line. 10/8/2017 10/9/2017 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 WHIP, 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: 11/1/2017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stec( Time End Time Dw (hr) Phase Op Cade Activity Code Time P -T -X Operabon (ttKB) End Depth (flKB) 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 10/912017 1.50 PROD1 WHPST PULD P Pressure deploy window milling BHA# 0.0 74.3 01:30 03:00 1, MU UO to CoilTrak tools, surface test (good test), inspect pac-off 10/9/2017 10/9/2017 2.00 PROD1 WHPST TRIP P RIH, w/ window milling BHA# 1, 2.80 74.3 9,950.0 03:00 05:00 OD whipstock mill, string reamer, x- treme motor, 9' pup joint 10/9/2017 10/9/2017 1.70 PRODt WHPST DLOG P Log the HRZ down to the pinch point. 9,950.0 10,480.0 05:00 06:42 tag Q 10,480 corrected. Bring sea water returns from the TT back inside to the pits 10/9/2017 10/9/2017 1.30 PROM WHPST CIRC P Increase rate to drilling, 1.80 bpm, 9,950.0 10,480.6- 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 slailized 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 reudcing the rate at 23 bbls out. Building WH / BHP. 43 bbls away built WH to 1366 psi, and 0.4 bpm, 12.96 ppg at the window 10/9/2017 10/9/2017 0.20 PROD? WHPST CIRC P Open choke targeting 12.0 ppg at the 10,394.0 10,382.0 09:30 09:42 window stage pums rate up to 1.8 bpm in, 1.7 bpm out holding 12.0 ppg at the window. 10/9/2017 10/9/2017 0.70 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 rate at 1.81 bpm, holding 12.0 ppg RBIH, CT 4699 psi, WH 433 psi, 1.80 bpm in , 1.46 bpm out, CT RIH Wt 10- 12 k lbs off bottom FS 436 psi, oriented 330 " ROHS, 10/9/2017 10/9/2017 7.00 PROD? 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 Q 10479.2 Swap to auto drill @ 14:00 1019/2017 10/9/2017 0.70 PROM WHPST WPST P Power failure due to High -line crew, 10,484.5 10,484.5 17:36 18:18 bring rig back online. PUW 31 k, bring pump back online Page 2118 ReportPrinted: 111112017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start time End Time Our (hr) phase Op Code Activity Code Time RT.X Operation ^8) End Depth(We) 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 Mill/drill formation at 5-36 fph, 1.78 10,486.0 10,504.0 20:27 22:42 bpm at 4,661 psi OB, BHP 3,796, 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' 10/9/2017 10/10/2017 0.15 PROD1 WHPST TRIP P PUH, 10,458' Open EDC, POOH 10,504.0 9,279.0 23:51 00:00 10/10/2017 10/10/2017 1.50 PROD1 WHPST TRIP P Continue POOH, PJSM @ 1,500' 9,279.0 79.3 00:00 01:30 while POOH 10110/2017 10/10/2017 1.50 PROD1 WHPST PULD P PUD and LD window milling BHA# 1, 79.3 0.0 01:30 03:00 Mills gauged 2.79 no-go 10/10/2017 10/10/2017 1.25 PRODt DRILL PULD P PJSM, PD build section BHA# 2 0.0 72.0 03:00 04:15 10/10/2017 10/10/2017 2.00 PROD1 DRILL TRIP P Stab INJH, surface test CoilTrak tools 72.0 10,230.0 04:15 06:15 (good-test), tag up reset counters, RIH 10/10/2017 10/10/2017 0.25 PROD1 DRILL DLOG P Log the K1 marker correction of minus 10,230.0 10,306.3 06:15 06:30 4.0' 10/10/2017 10/10/2017 0.25 PROW 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 10/10/2017 0.75 PRODt 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 lhm window. TOWS=10,479', BOWS=10486'. 10/10/2017 10/10/2017 3.25 PROD1 DRILL DRLG P Resume drilling build section. 10,593.0 10,826.0 08:30 11:45 WHP=96 PSI, ANN=3873 psi, IA=250, 0A=1, PUMP=4900psiQo 1.8 bpm, WOB=2.5, ROP=95' 10/10/2017 10/10/2017 0.50 PROD1 DRILL WPRT P Pump 5/5 sweep, pull 100' short wiper 10,826.0 10,826.0 11:45 12:15 to 10726'. RBIH. 10/10/2017 10/10/2017 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, 0A=1, PUMP=4849 PSI@1.8 BPM, ANN=3884 PSI, W013=1.47, ROP=114'. 10/10/2017 10/102017 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 10/10/2017 1.35 PROD1 DRILL PULD P At surface. PUD build BHA#2 64.8 0.0 15:45 17:06 10/102017 10/102017 1.74 PROD1 DRILL PULD P Crew change, PJSM, PU/MU/PD AL1 0.0 78.3 17:06 18:50 lateral BHA# 3 10/102017 10/1012017 0.25 PRODi DRILL PULD P Stab INJH onto CoilTrak tools, surface 78.3 78.3 18:50 19:05 test (good-test), tag up/reset counters. Page 3118 ReportPrinted: 111112017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depen Sten Time End Time 0. (hr) Phase Op Code ACW4 Corte Time P4A Operation (ftK0) F1W Depth (ftKB) 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 10110/2017 10/10/2017 0.25 PROD1 DRILL DLOG P Log the K1 marker correction of minus 10,237.0 10,344.0 2105 21:20 7.0' 10/10/2017 10/10/2017 0.42 PROD1 DRILL TRIP P Continue RIH 10,344.0 10,885.0 21:20 21:45 10/10/2017 10/11/2017 2.25 PROD1 DRILL DRLG P OBD, 1.75 bpm at 5,083 psi FS, Diff 10,885.0 11,125.0 21:45 00:00 864 psi, BHP 3,886, WHP 145, IA 254, OA 2, CTSW=2 k, DHWOB=1.9 k, ROP 135-215 fph 10/11/2017 10/11/2017 1.25 PROD1 DRILL DRLG P OBD, 1.80 bpm at 5,274 psi, Diff 11,125.0 11,300.0 00:00 01:15 1,010 psi, BHP 3,928, WHP 146, IA 255, OA 2, CTSW=6 k, DHWOB=0.5 k, ROP 130 fph 10/11/2017 10/11/2017 0.25 PROD1 DRILL WPRT P Wiper up hole PUW 36 k 11,300.0 10,900.0 01:15 01:30 10/11/2017 1011112017 0.25 PROD1 DRILL WPRT P Wiper back in hole RIW 7 k 10,900.0 11,300.0 01:30 01:45 10/11/2017 10/1112017 5.75 PROD1 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 10111/2017 0.30 PROD1 DRILL WPRT P Wiper back in hole. RIW=9k 10,890.0 11,690.0 07:48 08:06 10/11/2017 10/11/2017 6.00 PROD1 DRILL DRLG P BOBD. 1.80 bpm at 5675 psi, 11,690.0 12,090.0 08:06 14:06 Diff -1358 psi, BHP=3957, WHP=166, IA=257, OA=2, CTSW=2.2, DHWOB=1.5k, ROP=80 fph 10/11/2017 10/11/2017 0.60 PROD? 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 19:18 1372 psi, BHP 3979, WHP 130, IA 257, OA 2, CTSW=-0.6, DHWOB=1.62k, ROP=65 fph 10/11/2017 10/11/2017 0.20 PRODi DRILL WPRT P Unable to obtain clean survey, PUH 12,302.0 12,302.0 19:18 19:30 PUW 34 k 10/11/2017 10/1212017 4.50 PROD? DRILL DRLG P BOBD, 1.77 bpm at 5,000 psi FS, 12,302.0 12,485.0 19:30 00:00 BHP 3,974, WHP 273, IA 259, OA 2, CTSW=minus 5 k, DHWOB=1.1 k, ROP 40 fph 10/12/2017 10/12/2017 0.25 PROD1 DRILL DRLG P OBD, 1.78 bpm at 5,341 psi, Diff BHP 12,485.0 12,490.0 00:00 00:15 4,008, WHP 271, CTSW=minus 5 k, DHWOB=1.0 k, ROP=26 fph 10/12/2017 10/12/2017 0.50 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 ReportPrinted: 11 /112 01 7 o Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SW Depth Start Tune EM Tuna Our (hr) Phew Op Code Atl Ity Code Tune P -T -X Operation (fto) End Depth MKB) 10/12/2017 10/12/2017 7.20 PROD? DRILL DRLG P Drilling break, increase AP to form 12,655.0 12,748.0 04:48 12:00 4,062 psi to 4,145 psi to keep one for one. PUW 32 k, RBIH, continue drilling ahead, 1.77 bpm at 5,402 FS, BHP 4,140, WHP 338, IA 258, OA 2, CTSW= 5.0 k, DHWOB=1.0 k, ROP 30-90 fph 10/12/2017 10/1212017 3.00 PROD1 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'/hr. Pumping 1.76 Bpm @5341 psi, CTSW=-5.21K, W013=3.13k, BHP=4132, DIF=1054, WHP=329, IA=261, OA=4. Pumping 5/5 sweeps as needed. Last PUW=34K. 10/12/2017 10/12/2017 2.00 PROD1 DRILL DRLG P Hard drilling continuing. ROP=6- 12,764.0 12,771.0 15:00 17:00 15'/hr. Pumping 1.77 Bpm @5427 psi, CTSW=-3.21 K, WOB=2.94k, BHP=4142, DIF=1060, WHP=313, IA=264, OA=8. Pumping 5/5 sweeps as needed. 10/1212017 10/12/2017 3.50 PROD1 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, 10/12/2017 10/12/2017 2.25 PROD? 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 white 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 10/1312017 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' 10/1312017 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 PRODt 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 bbis 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 0815 0830 Page 5118 ReportPrinted: 1111/2017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Time End Time Our (hr) Phase Op code Achor Code ry Time P -T -X O tion para (rtKe) End Oe Depth (W) 10/13/2017 10/13/2017 4.90 PROD1 DRILL DRLG P BOBO. 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, WOB=1.04, ROP=97'. Note: MWD having difficulties getting accurate surveys (inclination still accurate); send info to Sperry to process. 10/13/2017 10/13/2017 0.30 PROD1 DRILL WPRT P Wiper up hole. PUW=35k. 13,200.0 12,350.0 13:24 13:42 10/13/2017 10/13/2017 0.40 PROD1 DRILL WPRT P Wiper back in hole.RIW=4K 12,350.0 13,200.0 13:42 14:06 10/13/2017 10/13/2017 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'. 10/13/2017 10/13/2017 1.80 PROD1 DRILL DRLG P OBD, 1.75 bpm at 5,517 psi, BHP 13,330.0 13,425.0 18:06 19:54 4,257, WHP 422, IA 263, OA 5, CTSW= minus 1.75 k, DHWOB= 1.3 k, ROP 30 fph 10/13/2017 10/13/2017 0.40 PRODt DRILL WPRT P 400' wiper up hole, PUW 39 k 13,425.0 13,425.0 19:54 20:18 10/13/2017 10/13/2017 3.15 PROD1 DRILL DRLG P OBD, 1.6 bpm at 5,579 psi, BHP 13,425.0 13,494.0 20:18 23:27 4,288, WHP 410, IA 263, OA 5 10/13/2017 10/14/2017 0.55 PROD1 DRILL WPRT P 600' wiper up hole PUW 39 k 13,494.0 13,494.0 23:27 00:00 10/14/2017 10/14/2017 9.40 PROD1 DRILL DRLG P OBD, 1.56 bpm at 5,060 psi, Diff 970, 13,494.0 13,782.0 00:00 09:24 BHP 4,279, WHP 432, IA 263, OA 5, CTSW= minus 5.0 it, DHWOB= 1.0 k, ROP 60 fph 10/14/2017 10/14/2017 0.30 PROD1 DRILL DRLG P Temporarily stuck pipe @ 13,782'; 13,782.0 13,782.0 09:24 09:42 pop'd free at 701k (last PUW=42k). 5/5 sweep in pipe, PUH slowly and wait for sweep to exit. 10/14/2017 1011412017 1.30 PROD1 DRILL WPRT P Wiper to window. 13,782.0 10,521.0 09:42 11:00 10/14/2017 10114/2017 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 TO well at 13852' (corrected). Pump 13,852.0 78.3 15:06 18:36 10/10 low/high sweep. Chase out of hole to swab. 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 PROD1 DRILL DLOG P Log the K1 Marker correction of minus 10,245.0 10,290.0 20:27 20:39 8.0' 10/14/2017 10/14/2017 0.15 PROD1 DRILL TRIP P Continue RIH 10,290.0 10,465.0 20:39 20:48 10/14/2017 10/14/2017 0.50 PROD1 DRILL TRIP P Perform Static Pressure Survey, shut 10,465.0 10,465.0 20:48 21:18 down pump holding 12.7 ppg ECD at the window, annnular pressure increased to 4073 psi, bring pump on circulate bottoms up to confirm back side is clear, shut down again and montior well. annular pressure 4,077 psi / 12.885 ppg. discuss plan forward with TE, Page 6118 ReportPrinted: 11/1/2017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depm Stan T re End Time Our (hr) Phase On Code Aa,ty Code Time P -TA Operation (fl(B) End Depth (fIKB) 10/14/2017 10/14/2017 0.75 PROD1 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 / 12.885 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 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 00:45 12.9 ppg - 13.1 ppg 10/15/2017 10/15/2017 2.15 PROD1 DRILL TRIP P RIH, no correction at RA marker. 10,465.0 13,852.0 0045 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 10/15/2017 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 10/15/2017 0.40 PRODt DRILL PULD P At surface. Open up @ riser and 71.5 0.0 06:30 06:54 perform flow check. No Flow. Perform PJSM. Fill hole; took 1.5 bbls to fill after 13 mins static. 10/15/2017 10/15/2017 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 10/15/2017 1.10 PROD1 DRILL PULD P Function test BOPE. Service blocks. 0.0 0.0 07:42 08:48 10/15/2017 10/15/2017 1.00 COMPZI CASING PULD P PJSM for running liner. Begin making 0.0 0.0 08:48 09:48 up liner. Filling hole every 5Its; -1 bbl to fill (10. bbls since flow check). Losses -3.5 bbl/hr. 10/15/2017 10/15/2017 0.30 COMPZI CASING SFTY P Perform Kick While Running Liner 0.0 0.0 09:48 10:06 Drill. 10/15/2017 10/15/2017 2.40 COMPZI CASING PULD P 2 0.0 2,681.7 10:06 12:30 10/15/2017 10/15/2017 0.90 COMPZI CASING PULD P PU Baker ColiTrak BHA w/ GS and Lt 2,681.7 2,726.7 12:30 13:24 liner assembly. 10/15/2017 10/15/2017 1.10 COMPZI CASING RUNL P Run in hole with liner. RIW=8k. 2,726.7 10,426.7 13:24 14:30 10/15/2017 10/15/2017 0.25 COMPZI CASING RUNL P Tie in to window flag and correct 10,426.7 11,146.0 14:30 14:45 minus 20.6', 7700' EOP and 10,426.72 end of liner. PUW 40k, RIW=12k. 10/15/2017 10/15/2017 5.00 COMPZI CASING RUNL P Friction out @ 11146'; PUW=43k. 11,146.0 11,850.0 14:45 19:45 Work liner to bottom. 10/15/2017 10/16/2017 4.25 COMPZ1 CASING RUNL P Line up down the backside, pumping 11,850.0 12,580.0 19:45 00:00 min rate, continue to work liner to bottom, pulling up 100-150' gaining 10 -40' per run 10/16/2017 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 10/16/2017 5.00 COMPZI 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 10/16/2017 1.50 COMPZI CASING RUNL P Continue to work liner to bottom. 13,038.0 13,061.0 08:30 j 10:00 gaining T-10' at a time; slow going. Page 7/18 ReportPrinted: 111112017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Starr Depth Start Time Ed Time Our (hr) Phase Op Code Ad0y Code Time P"T"X Operadon (fll@) Ertl Depth (WB) 10/16/2017 10/16/2017 0.60 COMPZ1 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 born to verity we can surface fluids; losses -30%. Confer with town, begin mixing up beaded liner pill. 10/16/2017 10/16/2017 1.75 COMPZt CASING RUNL P Online bull -heading 13.1 beaded -pill 13,075.0 13,145.0 10:36 12:21 down CTxtbg annuli 0.18 bpm, 0.18 bpm, 500 psi WHP max. Resume working liner to bottom. 10/16/2017 10/16/2017 3.00 COMPZ1 CASING RUNL P Shut down to add lubes to beaded pill. 13,145.0 13,145.0 12:21 15:21 (note: Lead 20 bbis of 50 bbl bead pill not lubed). 10/16/2017 10/16/2017 5.90 COMPZ1 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. 10/16/2017 10/16/2017 0.15 COMPZ1 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 10/16/2017 0.25 COMPZ1 CASING CLOG P Log the RA marker corretion of Plus 10,440.0 10,455.0 21:33 21:48 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 10/16/2017 10/17/2017 0.30 COMPZ1 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 COMPZ1 CASING OWFF P At surface, check well for flow, PJSM 44.2 442 00:00 00:09 10/17/2017 10/17/2017 0.75 COMPZ1 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 10/172017 0.75 COMPZ1 CASING SVRG P Service reel, INJH, DOMS inspection, 0.0 0.0 00:54 01:39 and check pac-off. 10/17/2017 10/172017 0.50 COMPZ1 CASING PULD P MU, L1 upper Liner segment with 0.0 232.1 01:39 02:09 OHA Billet. 10/17/2017 10/17/2017 2.50 COMPZ1 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. 10/172017 10/172017 0.25 COMPZ1 CASING RUNL P Log the K1 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 10/172017 0.30 COMPZ1 CASING RUNL P Continue RIH, tag TOL at 10,701' 10,454.0 10,701.5 04:54 05:12 10/172017 10/17/2017 0.25 COMPZ1 CASING RUNL P PUH, orient TO 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 COMPZ1 CASING TRIP P POOH, pumping pipe displacement 10,530.0 69.8 05:27 07:27 10/17/2017 10/1712017 1.00 COMPZI CASING PULD P At surface; perform flow check. Begin 69.8 0.0 07:27 08:27 undeptoying upper liner assembly running BHA#6 Page 8118 Report Printed: 11/112017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log $tart Depth Smd`t a EW Tim Dur (hr) Phase Op Cafe AcWq CWe D.P-T-X Operation (WS) EW DOM(WEn 10/17/2017 10/17/2017 1.00 PROD2 DRILL KOST P Make up Lt -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 K1 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 (a3 10526 10/17/2017 10/17/2017 1.00 PROD2 DRILL KOST P PUH, PUW=28K, Pumps on @ 1.8 10,526.0 10,536.0 14:15 15:15 BPM @ 4992 PSI FS, BHP=4113, Light tag @ 10526 then looks like puching down hole. TOB is supposed to be at 10530. Continue working in with low - no DHWOB very little motor work. Some aluminum on shaker 10/17/2017 10/17/2017 0.60 PROD2 DRILL DRLG P 10536', Drill Ahead, Low differential, 10,536.0 10,558.0 15:15 15:51 High WOB 10/17/2017 10/17/2017 0.15 PROD2 DRILL WPRT P PUH to drift billet area to 10,515. 10,558.0 10,558.0 15:51 16:00 Drifted clean up and down 10/17/2017 10/17/2017 2.50 PROD2 DRILL DRLG P OBD, CWT =9K, WOB =1.5K, 10,558.0 10,855.0 16:00 18:30 annular = 4851 psi, call TD of build at 10,855' 10/17/2017 10/17/2017 1.90 PROD2 DRILL TRIP P POOH, open EDC at 10,459', pre -job 10,855.0 72.0 18:30 20:24 while POOH, tag up, space out, WHP = 1350 psi 10/17/2017 10/17/2017 1.90 PROD2 DRILL PULD P PUD BHA #7, checks not holding, 72.0 0.0 2024 2218 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 RB Hughes bit), slide in cart, MU coil 10/17/2017 10/18/2017 0.40 PROD2 DRILL TRIP P Begin RIH with BHA #8, surface test 78.0 296.0 23:36 00:00 agitator, vibrating, though not overly aggressive, continue RIH 10/18/2017 10/18/2017 1.70 PROD2 DRILL TRIP P Continue RIH with BHA #8, swapping 296.0 10,240.0 00:00 01:42 1 1 to mud System #3 10/18/2017 10/18/2017 0.50 PROD2 DRILL DLOG P Log K1 for -5.5' correction 10,240.0 10,289.0 01:42 02:12 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, dose 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. Pi = 31K, RBIH, free spin = 850 psi, annular = 4196 psi Page 9/18 ReportPrinted: 1 11112 01 7 Operations Summary (with Timelog Depths) c 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth ftd Tena Ertl Time DW hr ( ) phase Op Code Adrviry Gatle Tema P -T -X Operation (rt Ka) End Depth (WS) 10/18/2017 10/18/2017 3.40 PROM 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, rip = 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 1 PUW=33K, Clean up and down 10/18/2017 10/1812017 4.10 PROM DRILL DRLG P 11,317', Drill. 1.79 BPM @ 5302PSI 11,317.0 11,702.0 08:12 12:18 FS, BHP=4300, RIW=1K, DHWOB=2.4K, ROP=-100FPH 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 10/18/2017 10/18/2017 5.40 PROD2 DRILL DRLG P 11702', Drill, 1.79 BPM @ 5313 PSI 11,702.0 12,111.0 12:54 18:18 FS, BHP=4290, RIW=-1.1K, DHWOB=2.4K, ROP= -105 FPH 10/18/2017 10/18/2017 0.70 PROD2 DRILL WPRT P WT up -hole, PUW = 31K 12,111.0 10,490.0 18:18 19:00 10/18/2017 10/18/2017 0.10 PROM DRILL DLOG P Log R4 tag for+7.5' correction 10,490.0 10,510.0 19:00 19:06 10/18/2017 10/18/2017 0.60 PROD2 DRILL WPRT P WT in-hole, RIW=5K 10,510.0 12,111.0 19:06 19:42 10/18/2017 10/19/2017 4.30 PROD2 DRILL DRLG P BOBD, FS = 950 psi, pumping 1.78 12,111.0 12,422.0 19:42 00:00 bpm, CWT= -5.5K, WOB =2K, annular = 4264', circ pressure = 5673 psi, WHIP = 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 PROD2 DRILL DRLG P Continue drilling from 12,422', beaded 12,422.0 12,513.0 00:00 01:54 pill had moderate effect (effect short lived in OH), CWT = -51K, WOB = 1.9K though quickly falls off, annular = 4262 psi, WHIP = 491 psi Continue sending pills (1% 776, 1% LoTorq, & Alpine beads), PU's as required to continue drilling (PUW's -41 K) 10119/2017 10/19/2017 0.30 PROD2 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 10119/2017 2.00 PROD2 DRILL DRLG P BOBD, pumping 1.8 bpm, CWT= EK, 12,513.0 12,592.0 02:30 04:30 WOB = 1.4K, annular = 4269 psi, arc pressure = 4778 psi, WHIP = 480 psi 10/19/2017 10/19/2017 1.80 PROD2 DRILL DRLG P OBD, continue to pump LoVis sweeps 12,592.0 12,690.0 04:30 06:18 followed by beaded pills, CWT = - 8.7K, WOB = 1.2K, annular = 4354 psi, WHIP = 588 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 10/192017 10/19/2017 1.00 PROD2 DRILL DRLG P 12690', Drill, 1.81 BPM @ 5248 PSI 12,690.0 12,766.0 06:24 07:24 FS, BHP=4340, RIW=-7K, DHWOB=I.6K Page 10118 ReportPrinted: 11/1/2017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Slat/ Depth Start Tme EM Time Dw (hr) Phase Op Code Aaivity coda Tang PT-X Operation (flKa) Ertl Depth (WS) 10/19/2017 10/19/2017 0.50 PROD2 DRILL WPRT P 12766', 1000'wiper trip, PUW=36K, 12,766.0 12,766.0 0724 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 top, 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 PROW 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 14:48 15:00 pressure, Pressure sender 6103TVD, BHP stable @ 4065PSI, EMW=12.85 10/19/2017 10/19/2017 1.70 PROD2 DRILL WPRT P Continue wiper trip to swab 10,469.0 78.0 15:00 16:42 10/19/2017 10/19/2017 1.90 PROD2 DRILL WPRT P RBIH 78.0 12,238.0 16:42 18:36 10/19/2017 10/19/2017 0.60 PROD2 DRILL CLOG P Log K1 for+8' correction, check & 12,238.0 12,470.0 18:36 19:12 clean injector counter, obtain SBHP, bit depth = 12,470', sensor TVD = 6103', EMW = 12.81 ppg 10/19/2017 10/19/2017 1.00 PROD2 DRILL WPRT P Continue RIH, clean run to bottom, 12,470.0 12,946.0 19:12 20:12 confirm TD at 12,946' 10/19/2017 1020/2017 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 0.6- 00:00 01:12 good, PJSM, LD BHA #8 over a dead well, 2 bbllhr losses, RB Hughes bit came out a 1-1 Slide back cart, begin clean up of gripper blocks out of critical path (due to pipe coating) 10/20/2017 10/20/2017 0.80 COMPZ2 CASING PUTB P PJSM, L1-01 Liner Run #1 (non- 0.0 440.0 01:12 02:00 ported bull nose, 29 jnts slotted liner, shorty deployment sleeve) Gripper blocks look good, minimal cleaning required, work was out of critical path 10/20/2017 10/20/2017 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 COMPZ2 CASING PUTB P Continue PU Liner, Drill: kick while 440.0 1,156.0 02:30 03:18 running liner (good) 10/20/2017 10/20/2017 1.20 COMPZ2 CASING PULD P PJSM, PU BHA#9, liner running tools, 1,156.0 1,200.0 03:18 04:30 slide in cart, MU coil, EDC dosed, tag up, reset counters 10/20/2017 10/202017 1.60 COMPZ2 CASING RUNL P RIH with liner Run #1 1,200.0 10,400.0 04:30 06:06 10/20/2017 10/202017 0.10 COMPZ2 CASING DLOG P Correct to flag for-17.9' 10,400.0 10,382.1 0606 0612 Page 11118 ReportPrinted: 111112017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth StartTme Ertl Time Oiu hr ( ) Phase Op Cotle Adivlty Cotle Time P -T -X operator (WB) End Depth (tKB) 10/20/2017 10/20/2017 2.10 COMPZ2 CASING RUNL P Continue in well, Unable to slowdown 10,382.1 12,946.0 06:12 08:18 and tie in without stacking out @ 11630', P/U and continue in hole, first setdown @ 12,450'. Work pipe down to 12946 10/20/2017 10/20/2017 2.40 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, L1-01 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, P/U 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 10/20/2017 1.80 COMPZ2 CASING RUNL P Trip in hole, EDC open 1,211.1 10,424.0 14:30 16:18 10/20/2017 10/20/2017 0.10 COMM CASING DLOG P Tie into 10411 EOP 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 COMM CASING TRIP P POOH 11,790.0 78.0 19:42 21:36 10/20/2017 10/20/2017 0.90 COMPZ2 CASING PULD P PJSM, flow check well, good, check 78.0 0.0 21:36 22:30 coil, good, LD BHA #10 (using new LD over dead well checklist) 10/20/2017 10/21/2017 1.50 COMM CASING CIRC P MU nozzle, roll coil to fresh water, jet 0.0 0.0 22:30 00:00 the stack, LD nozzle, slide back cart Note: a -line anchor pulled out of anchor carrier, last coil cut was on 10/7 at -12:00 hrs, no slack managemnt was documented as less than 30' of coil was cut. 10/21/2017 10/21/2017 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 10/2112017 10/21/2017 2.50 COMM 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 1021/2017 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 1021/2017 1.80 COMM WHDBOP BOPE P Continue testing from Test #9 to test 0.0 0.0 0412 06:00 13 Page 12118 ReportPrinted: 11/1/2017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Siad'n'm End Time Dur thr) Phase Op Coda Activity Code Time P -T -X Opembw ^8) EM Depth (WS) 10/21/2017 10/21/2017 3.00 COMPZ2 WHDBOP BOPE P Continue testing from step 13 to 15, 0.0 0.0 06:00 09:00 Perform draw down test. Check N2 levels, Test gas alarms 10/2112017 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, Cul 0.0 0.0 10:00 11:00 CTC off. Boot wire, Stab on well. Line up to reverse circulate 10/21/2017 10/21/2017 0.50 COMPZ2 CASING CTOP T Pump a -line back into CT, 2.5 BPM @ 0.0 0.0 11:00 11:30 4700 PSI - Hear wire move. Unstab injector 10/21/2017 10/21/2017 1.50 COMPZ2 CASING CTOP T PJSM, R/U hydraulic tubing cutter, Cut 0.0 0.0 11:30 13:00 208' CT to find E -line. R/D culler then hand cut 4' (total CT cut 212) 10/21/2017 10121/2017 1.00 COMPZ2 CASING CTOP T PJSM, Prep coil for CT connector and 0.0 0.0 13:00 14:00 instalt. Pull test to 35K 10/21/2017 10/21/2017 1.00 COMPZ2 CASING CTOP T PJSM test a -line, rehead UQC and 0.0 0.0 14:00 15:00 1 1 test all good, PT to 4500 PSI 10/21/2017 10/21/2017 1.30 COMPZ2 CASING CIRC T Install nozzle, stab injector on well. 0.0 0.0 15:00 16:18 Circulate forward displacing CT back to 13.1 PPG KFormate 10/21/2017 10/21/2017 1.30 COMPZ2 CASING PULD T PJSM, M/U BHA#11, OH anchor& 0.0 72.9 16:18 17:36 billet 10/21/2017 10/21/2017 1.80 COMPZ2 CASING RUNL T RIH with BHA#11 72.9 10,245.0 17:36 19:24 10/212017 10/21/2017 0.20 COMPZ2 CASING DLOG T Tie in for a -8' correction 10,245.0 10,298.0 19:24 19:36 1021/2017 10/21/2017 0.40 COMPZ2 CASING RUNL T Continue RIH, oriented 150° ROHS as 10,298.0 10,643.0 19:36 20:00 per plan, tag TOL at 10,643', bring up pump, shear off anchor, putting TOB at -10,631' 10/21/2017 10/21/2017 1:80 COMPZ2 CASING TRIP T POOH, tag up, flow check well 10,643.0 73.0 20:00 21:48 10/21/2017 10/21/2017 0.60 COMM CASING PULD T PJSM, LD BHA #11, reconfigure tools 73.0 0.0 21:48 22:24 10/21/2017 10/21/2017 0.60 PRODS STK PULD P PU BHA #12 Lt -02 KO/Build 0.0 72.0 22:24 23:00 Assembly (2.0° AKO motor, RR Hughes, 1-1 bit from Ll let) 10/21/2017 10/22/2017 1.00 COMM STK TRIP P Open EDC, RIH with BHA #12 72.0 4,200.0 23:00 00:00 10/22/2017 10/22/2017 1.10 PRODS STK TRIP P Continue RIH 4,200.0 10,240.0 00:00 01:06 10/22/2017 1022/2017 0.30 PRODS STK DLOG P Log K1 for -10' correction 10,240.0 10,288.0 01:06 01:24 10/222017 10222017 0.10 PRODS STK TRIP P Continue RIH 10,288.0 10,430.0 01:24 01:30 1022/2017 101222017 1.30 PRODS STK DISP P Displace well to 8.8 ppg PowerPro, 10,430.0 10,430.0 01:30 02:48 1 1 close EDC 1022/2017 10/22/2017 0.30 PRODS STK TRIP P RIH, zero WOB, dry tag TOB at 10,430.0 10,629.3 02:48 03:06 10,631, PUW = 31K, bring up pumps, RBIH 1022/2017 10222017 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 13118 Report Printed: 11/1/2017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log startD Pp S1 d T. End Time Dis (hr) Phase Op code Aavity Code Time P -T -X Operation (ftKB) End Depth MKS) 10/22/2017 10/22/2017 3.80 PRODS DRILL DRLG P Drilling in formation on L1-02 build 10,635.0 10,930.0 04:24 08:12 section, CWT = 8K, WOB= 1.1 K, annular = 4158 psi, WHP = 486 psi, dry drifted billet area up & down, clean 10/22/2017 10/22/2017 2.30 PRODS DRILL TRIP P Call EOB, Trip out for lateral drilling 10,930.0 56.3 08:12 10:30 BHA # 13, AVG DLS=33.9', Open EDC @ 10,433'. 10/22/2017 10/22/2017 1.00 PROD3 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. L7-02 Lateral 0.0 78.3 11:30 13:12 BHA with .5" motor, Agitator, and RR Hughs Bi Center. WU to coil and surface test 10/22/2017 10/22/2017 2.50 PRODS DRILL TRIP P Trip in hole, EDC open, Pump .4 BPM. 78.3 10,250.0 13:12 15:42 Test agitator @ 300' - Good 10/22/2017 10/22/2017 0.10 PRODS DRILL DLOG P Log K-1 for -9', PUW=32K 10,250.0 10,283.0 15:42 15:48 10/22/2017 10/22/2017 0.20 PRODS DRILL TRIP P Continue in well, clean through 10,283.0 10,930.0 15:48 16:00 1 window and past billets 10/22/2017 10/22/2017 4.00 PRODS DRILL DRLG P 10930', Drill ahead, 1.75 BPM @ 10,930.0 11,330.0 16:00 20:00 540OPSI FS, BHP=4221, RIW=6.8K, DHWOB=I.6K, ROP=-120FPH Begin swapping to mud system #4 at -11,075', add 1% LoTorq to system, additional lube hit the bit at 11,295' (Squatting heavy on bit to get pointed down for geo's) 10/22/2017 10/22/2017 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 10/23/2017 3.50 PRODS DRILL DRLG P BOBD, pumping 1.8 bpm, FS = 1095 11,330.0 11,710.0 20:30 00:00 psi, CWT = 4K, WOB = 2K, annular = 4170 psi, WHP = 504 psi, circ pressure = 5348 psi, rip = 1328 psi, 109 fph average over interval 10/23/2017 10/23/2017 0.30 PROD3 DRILL DRLG P Continue drilling from 11,710, CWT = - 11,710.0 11,730.0 00:00 00:18 4K, WOB 1.6K, annular = 4298 psi, pump sweeps 10/23/2017 10/23/2017 0.30 PROD3 DRILL WPRT P WT up -hole, PUW = 34K 11,730.0 10,892.0 00:18 00:36 10/23/2017 10/23/2017 0.30 PRODS DRILL WPRT P WT in-hole, RIW = 7K 10,892.0 11,730.0 00:36 0054 10/23/2017 10/23/2017 3.10 PRODS DRILL DRLG P BOBO, pumping 1.8 bpm, FS = 1020 11,730.0 11,958.0 00:54 04:00 psi, CWT = 1.4K, 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 10/23/2017 10/23/2017 1.70 PRODS DRILL DRLG P Continue drilling ahead, pumping 1.8 11,958.0 12,134.0 04:00 05:42 bpm, CWT = -6K, WOB = 1.21K, annular = 4246 psi 10/23/2017 10/23/2017 1.90 PRODS DRILL WPRT P 12134', Wiper trip #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 10/23/2017 10/23/2017 2.80 PRODS DRILL DRLG P 12138', Drill, 1.52 BPM @ 4577 PSI 12,138.0 12,368.0 07:36 10:24 FS, BHP=4271, RIW=-6.2, DHWOB=2.9K. Pumping reduced rate to arrest build Page 14118 ReportPrinted: 111112017 -, Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our (hr) Phase Op Curtis Ac"i Code Time P -T -X Operation (ftKB) End Depth (WB) 10/23/2017 10/23/2017 0.20 PROD3 DRILL WPRT P BHA Wiper, PUW=42K 12,368.0 12,368.0 10:24 10:36 10/23/2017 10/23/2017 1.70 PROD3 DRILL DRLG P 12368', Drill, 1.79 BPM @ 5311 PSI 12,368.0 12,461.0 10:36 12:18 FS, BHP=4254. RIW=-5.5K, DHWOB=IK, Multiple BHA Wipers, Hard to maintain steady state drilling 10/23/2017 10/23/2017 0.70 PROD3 DRILL WPRT P 12461, 1 000'wiper, PUW=42K, Clean 12,461.0 12,461.0 12:18 13:00 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 1300 15:36 FS, BHP=4316 10/23/2017 10/23/2017 0.20 PROD3 DRILL WPRT P 12,606, BHA wiper, stacking, 12,606.0 12,606.0 15:36 15:48 PUW=42K 10/23/2017 10/23/2017 2.60 PROD3 DRILL DRLG P 12,606', drill, 1.67 BPM @ 515OPSI 12,606.0 12,736.0 15:48 18:24 FS, BHP=4310RIW=-3.5', DHWOB=I.4K 10123/2017 10123/2017 1.30 PROD3 DRILL WPRT P Pull BHA Wiper, PUW=39K, Unable to 12,736.0 12,736.0 18:24 19:42 get back in hole. Convert wiper trip to 1000'er 10/23/2017 10/23/2017 1.20 PROD3 DRILL DRLG P 12736', Drill, 1.77 BPM @ 5580 PSI 12,736.0 12,798.0 19:42 20:54 FS, BHP=4290, RIW=6K, DHWOB=I.1K 10/23/2017 10/23/2017 0.50 PROD3 DRILL WPRT P BHA wiper, stacking, 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 127981, 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 12,809.0 12,838.0 22:06 23:06 FS, BHP=4260, Multiple small pick UPS 10/23/2017 10/23/2017 0.20 PROD3 DRILL WPRT P Pull BHA wiper, PUW=42K, 10 BBI 12,838.0 12,8Y8-0- 23:06 23:18 beaded pill down coil 10/23/2017 10/24/2017 0.70 PROD3 DRILL DRLG P 12,838', Drill, 1.8 BPM @ 5515 PSI 12,838.0 12,864.0 23:18 00:00 FS, BHP=4332 10/24/2017 10/24/2017 3.20 PROD3 DRILL DRLG P Continue drilling from 12,864', CWT = 12,864.0 13,000.0 00:00 03:12 4K, WOB = 1.5K, annular = 4289 psi, WHIP = 462 psi, reached 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 78.6- 04:18 06:00 10/24/2017 10/24/2017 2.00 PROD3 DRILL WPRT P RBIH 78.0 10,238.0 06:00 08:00 10/24/2017 10/24/2017 0.30 PROD3 DRILL DLOG P Log K1 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 TO 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 TO 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: 111112017 Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten cepm Stat Time End Time Dur (hr) Mea, op Code AMvity Cade Time P -T -X openibm (flKB) End Depth (ttK8) 10/2412017 10/24/2017 2.00 PRODS 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 EDP 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 1 f 2 10/24/2017 10/24/2017 4.10 COMPZ3 CASING PUTB P Prep to run liner, PJSM, PU Lt -02 0.0 2,508.0 15:30 19:36 liner (Non -ported bullnose, 3 pups, 63 jnts slotted liner, R shorty deployment sleeve), "Installed safety joint for crew change - Safely joint drill 10/24/2017 10/24/2017 1.00 COMPZ3 CASING PULD P PU BHA #14, Liner Running BHA, 2,508.0 2,576.0 19:36 20:36 swap out upper checks, inspect pack offs- good, stab on bump up, set counters, tool test good, EDC is 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 10124/2017 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 10124/2017 0.40 COMPZ3 CASING RUNL P PU 42 k lbs, -11k WOB, continue to 10,355.0 11,598.0 22:12 22:36 RIH. 10/24/2017 10125/2017 1.40 COMM CASING RUNL P SD@ 11,598', CT -6 k lbs, WOB 4 k 11,598.0 11,751.0 22:36 00:00 Itis, Pick up, PU Wt 49 k LBS, WOB - 22k lbs. Work pipe / 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' a160 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' 10125/2017 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 fl/hr 3 am to 4 am averaged 6 ft/hr then made 43 feet in 2 m 10/25/2017 10/2512017 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 12,656 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 Depm Surf Tim End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (flKB) EW Depili(MB) 10/25/2017 10/25/2017 2.20 COMP23 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, diffcully working past 12,785', get by, difficutly working past 12,800' 10125/2017 10/25/2017 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 10125/2017 1.70 COMPZ3 CASING RUNL P Continue to work liner from 12,812', 12,812.0 12,833.0 1142 13:24 difficulty working past 12,833' 10/25/2017 10/25/2017 0.10 COMPZ3 CASING RUNL P Confer with town, decison made to 12,656.0 10,325.0 1324 13:30 pump off liner, lie in, await used mud arrival to dg, 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 be in, tie in for+28' correction, 10,325.0 10,100.0 13:30 16:12 putting BOL at 12,861', TOL at 10,329, " ** Obtain SBHP, pressure = 4128 psi, ND at sensor = 6201 psi, EM W = 13 ppg• wait on used mud from 1 &Pad. 10/25/2017 10/25/2017 2.80 COMM CASING DISP T Begin pumping 50 bbl PowerPro down 10,100.0 10,100.0 16:12 19:00 coil, follow with 50 bbl of seawater, displacing KWF to surface 10/25/2017 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 COMPZ3 CASING TRIP T Line up pumps to the coil, RIH, pump 12,856.0 12,856.0 19:24 20:00 - 5 bbls seawater out the coil while RIH and latch up. Down on pumps, PU 65 k lbs, no movement - 20 k WOB. Line up down the back side, RBIH, set down -3 k lbs Ct Wt. 10/25/2017 10/25/2017 0.20 COMPZ3 CASING RUNL T Work pipe, Ct Wt -11 to 60 k lbs , 12,856.0 12,856.0 20:00 20:12 WOB from 8 k lbs to -20 k lbs while pumping min rate down the back side against a dosed choke. RIH / PUH rate 25 to 75 ft/ min. Consult w town. Pumped - 20 bbls total seawater down back side out of planned 30 bls. 10/25/2017 10/25/2017 0.10 COMPZ3 CASING RUNL T Line up down the coil, stack 4 k WOB, 12,856.0 10,314.4 20:12 20:18 PU, 26 k lbs, released and left liner ( 2531.21) on bottom. Best corrected depth putting BOL at 12,861', TOL at 10,329, 10/25/2017 10/2512017 2.90 COMPZ3 CASING DISP P Displace well to seawater while 10,314.0 48.0 20:18 23:12 POOH. Pump 30 bbls to the coil for FP, lay in from 2500' and to surface. 10/25/2017 10/26/2017 0.80 COMPZ3 CASING PULD P Bump up, PUD BHA# 14 10,314.0 48.0 23:12 00:00 Page 17118 ReportPrinted: 1111/2017 ® Operations Summary (with Timelog Depths) 2K-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Shan Dept, Start Time End Time Da (hr) phase Op Code Aa,ty Code Time P -T -X Opereton W13) EM Depth (tKB) 10/26/2017 10/26/2017 0.70 COMPZ3 CASING PULD P Continue to PUD and UD BHA #14. 48.0 0.0 00:00 00:42 10/26/2017 10/26/2017 1.30 DEMOB WHDBOP MPSP P Pull QTS, up valve crew lubricator, Set 0.0 0.6- 00:42 02:00 BPV, UD lubricator '""' Well head 1,420 psi under the BPV. 10/26/2017 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. 10/26/2017 10/26/2017 1.00 DEMOB WHDBOP RURD P Complete blow down of lines, pull 0.0 0.0 03:00 04:00 night cap, vac down slack, add MetOH to slack 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 WHOBOP NUND P Nipple down BOP slack, check tree 0.0 0.0 04:00 05:00 flange bolts. ""'Rig Release @ 6:00 AM 10/26/2017 10/26/2017 3.50 DEMOB WHDBOP RURD P ROMO, PUTZ, etc, continue to work 0.0 0.0 05:00 08:30 RD checklist 10/262017 10/26/2017 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 18/18 ReportPrinted: 11/1/2017 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K -04L1-02 50-103-20099-62 Baker Hughes INTEQ Definitive Survey Report 25 October, 2017 BAER F�UGHES Gfa p� Conocolphillips 8Ar cFKEs - ConocoPhillips Definifive Survey Report Co.,.,: Ccn..Phllllps(Alaska) In. . -Kup2 Local Ceordinale Reference: We1121 Projil Kuparvk River Unit WO thermal 2K-04®154.00osh 0K-04) Site: Kuparvk 2K Pad MD Refiendm : 2K-04@15401(2K-04) Well: 2K-04 NOM Referedce'. True Wellbore: 2K-04L1 Survey C.1a.1 nMethod Minimum Curvature Deal 2K-OAL1 DUbase: EDT Alaska Sandbox Prepaid 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 Zone: Alaska Zeno 04 Using g..data scale factor Well 2K-04 Well Position aN1S 000 usfl Northing: 5938,52566osfl Unlade: 70'14'35.784N .V-W 000 usfl Eason, 498,31001 Longitude: 150.0'49.136W Position Uncertainty 0.00 usfl Wellhead Elevation. usg Ground Level: 11850 usft Wellbore 2K-NL1-02 Magnetics Model Name Semple Data Declination Dip Angle Field Strength r) PI (nn BGGM2017 10/112017 17.30 80.84 57,474 Design 2K-04L1-02 Audit Notes: Version: 10 Phase: ACTUAL Te On Depth: 10620.14 Vertical Section: Depth From(TVDI +N145 aSAN Direction (van) (ural (ialp 0 35.50 000 0.00 10.00 10R520171237 23PM Page 2 COMPASS Who 14 Dmld 85 ConocoPhillips ConoccPhillips Definitive Survey Report Oompst, ConoLOPlvlllpa(Alaska) Inc. -Kup2 Local Co-ordinate Reference: Wall 2K-04 Proium Kupamk River Unit Map ND ReMrence: 2K -04@154,011(2K-04) MD Sita: Kupamk 2K Pad NO MD Reference: 2K -04®154.001(2K -eq &M i Welt: 2K-04 Seotlon Survey Tool Nelle North Reference: True P) W6110on: 2K -04L1 (treft) Survey Calculation Mal Minimum CurvaWre (ft) 1.000'1 Oesi9n: 2K44L1 10.62014 Database: EDT Alaska Sandbox 6,141.39 5,987.39 Survey Program 4.076.11 Dab 104252917 491,235.40 44.]9 2,37905 MWO(4) SII From To 335.63 0140.16 5.985.10 Sarvain Sandi (ueRl Nan) SurvaY(We iandi Toel Nelle DascOpmn Stan Etld Dote 2W.00 10,40000 2K -04(2K-04) BOSS -GYRO SIarry-Sun BOSS gyre mulESNat 1/1212001 491,21953 10,479.00 10,510,72 2K-ML1 MW0.1NC(2K-0411) MWD MWD-Slandarol 10110/2017 101 10,530.00 10,560.36 21K-0411-01 MWD-INC(21K-041-1-01) Mriti ONLY MW41NC_ONLY _FILLER IW17QO17 10Ifl2017 10,589.85 10,620.14 21K4 1.1-01 MM(21<4411-01)MWD 354.60 MWD -Standard 1011209 1MM017 ' 10,629.00 10,66o90 21K -1M11-02 MM -INC (21K-0411-02) knurl ONLY MWD -INC ONLY FILLER 10812017 102112017 j i 10.695.50 12966.06 21K-0411-02 MM (21<-(141-1-02)MI 8,00.25 MWD -Standard 101212017 102412017 Survey Map Map Vertical MD Inc ea Azi NO DS NDSS Ni♦♦EIiV &M MMIn9 Leader, OLS Seotlon Survey Tool Nelle AnnotegOn (BAD P) IWID (treft) Ift) (ft) 1.000'1 IRI 10.62014 07.0 332.32 6,141.39 5,987.39 3,663.46 4.076.11 5942, Ise 13 491,235.40 44.]9 2,37905 MWO(4) TIP 10,629.03 97.W 335.63 0140.16 5.985.10 367134 -7,079% 5,942,198.02 491,231.83 37.19 2,385.14 RINI ONLY (5) KOP 10890.90 84.03 339.60 6133.71 5,90571 3700 76 -7,092.07 5,942,22744 491,21953 44.49 2,41301 MND4NL CNLY(5) Inter,daled AvmuN 10,69550 74.0 314-01 6146.17 5.9417 3,733.0 -7,102.89 5942,25968 491,20 .92 W43 2. YUso MND(6) 10/25.07 TIN 354.60 6153.47 5,99947 3,761.55 -T.IWW 5,942,200.33 491,20353 35.72 2,47020 heard (6) 10.754.60 79.44 30 6,159.25 8,00.25 3,70.04 -710067 5,942,31671 491,202.95 29.0 2,49005 Mean (6) 10.]840 W71 12.0 6,181.44 5,01045 3,81934 -7,10.50 5,94234802 491,207.04 32.56 2,52762 MAD (6) 10,81461 U27 22.26 6,10.0 6.0140 3,84753 4,09568 5,941 M 491,21597 3149 9,55693 MNO(6) ' 16614.05 84.0 32.67 8.172.48 6.01048 3,07413 -7,081.0 5,942.40.79 4915619.81 34.70 250.53 MNO(6) 10.87470 85.17 420 617528 5,021.29 3,07.64 4.0371 5.942,424.29 491,24793 Win 2,611.83 MNO(6) 10.50223 W31 51.72 8.177.33 8,023.33 3,916.29 7.07381 594244294 491,20.04 3344 2633.69 MNO(6) 10,93358 9372 56.0 6.177.33 5,023.33 3934.75 -7.01830 5.942141.39 491,29334 27.37 26stm MWO(6) 10,9'6505 92.0 59.47 6,175.57 6,02157 3,95151 -,99173 5,942,478.15 491,319.91 11.34 2,67738 MM (6) 11 91.97 59.09 6.174.39 S.Mall 3,90.20 $90.62 5,942,492.83 491,345.0 20 2,60.21 even (6) 11.027.10 an Be 6116 6173.86 6,0190 3982.40 6,93795 5.942,50.02 491,373.69 750 2,717.14 MM (6) 11143.56 090 0.44 6,174.18 0020.18 3.994.0 Be -,914 5,91 491.31 1 6.28 2.733.0 MWD(6) 11,063 At 0.1B 84.15 617497 6,020.97 40038 4,88804 5.942,504.0 49142361 616 275128 MWD (6) 11.11397 8729 62.92 6,176.10 fi022.10 4021.0 6.86064 5.942548.51 491,45101 4& 276940 MWD(6) 10252017123723PM Page 3 COMPASS 5000.14 Burd 85 �: ConocoPhillips �� 4 Conoc( Phillips Definitive Survey Report Canada., CoadcaP1915p3(Alaska) Inc-Kup2 Local Coaddmate Reference: Wall 2K-04 Project: Kupamk River Unit WD Reference: 2K -N Q 154DOusfl(2K-04) Site: Kuparuk 2K Pad MD Reference: 2K-04 @ 154 00ue6 (2K44) Well: 2K-04 Norm Referenda: Tao Wellbore: 21(-04L1 Survey Calculation Metlatl: Minimum Curvatura Design: 21<441-1 Database: EDT Alaska Santlsk, SUNey Mew, Map MD Inc Asi TVD TVD59 4078 ♦Ea4N Nodi Eadiing 01.5 Setl� al stoney Tool ram. Annotation (usn) (1) (1) 14tary (L -M (USM (uenl 1M 1% VAID01 (e) 11144.92 01.67 60.76 61754 60n54 4,03551 4833.39 5.942.563. to 4914Mn 211 2180.58 MWD(6) 11,17SN edge 59.10 617843 6,02443 4,051.70 4807.18 5942,5)8.28 491,504.49 697 2eW.07 MWD(a) 11.20536 9169 58.38 6,17825 60I 4,07 .32 418142 5,942593&1 49153023 9.20 2017.95 MWD(a) 1123503 93.01 57.37 6,11703 5023.03 4,08301 47MM 5,942,60884 491,555.31 5.61 284)02 MWD(6) 11,'29509 92N W17 6,115.48 6,02146 4,099M 6.13125 5,942,626.32 491,58031 230 286.59 ki(6) 11 93.55 52.65 6114.50 6021.51 411803 4,10622 5,942,644.59 491,606 an 1152 2090.¢3 MWD(6) 11.M729 0.7 50.0 8,11415 6.021.15 413253 4681.98 5,942.604.07 491,8"88 801 2914.36 MVA)on 11390.46 910 48.5] 6173.61 6,01961 4,159.15 48`.4.87 5,942.68589 491,654.81. 459 2940D2 MM (6) 11,39o.46 91.54 48.54 fkin 2 6.01892 4,179.38 Z,634.70 5,942,70593 '91.6m INS 894 2963.19 MWD(6) 11,42082 91N H40 6,1025 8,01825 4,200.53 4613.21 5.942.7220 491,629.46 220 2980.36 MWD(6) 11.44974 W18 4238 8,12994 5017.94 4.22169 4593.21 5,942,748 21 491,110.46 1.54 3,01266 MAD(6) 11.400 910 4101 6,11128 501226 4,24851 45le'n 5.94211502 49114235 6.25 3,07321 MWDl6) 1151284 91.04 39.18 61700 6.01655 4,209.37 4655tM 5,942.195.81 491,159.92 7.51 3,06601 MWD(6) 11541.88 W.14 0.79 611050 6.01650 4292.18 4,533.95 5,912,81861 491,117.13 10.55 3.0"1 MWD(6) 11,51155 93.25 35W 6,17066 6,01586 4,31608 451838 5.942.8,1257 4911030 495 3,11896 MWD(61 11,58978 089 35.12 6,170.38 8,018.30 433907 4500.07 59/288556 491,011.60 339 314444 11JrD(61 1163058 93.47 078 6,160.21 6,01521 4.364.30 6482.37 5,94289011 491029.32 545 31M.M MWD(6) 11,855.82 W61 33.10 6167.45 6.01345 4,30502 4,486.42 5,942,911.49 491,84327 809 3,1011 MWD(6) 11,88540 920 33.92 8,164.41 601041 441020 4,45260 5,942939.81 491,659.02 1093 3,22271 MWD(6) 11,11566 90.18 30.15 6160.15 6,006.15 4,435.91 443250 5.942.962.39 491.81420 250 3,2 068 MWD(8) 1175078 98M 21.10 8,751.07 6.00.00 4,4040 64211.07 5,9@,072.85 4m W.83 0.90 3.263.57 MWD(61 11,18090 07.0 2882 8,150.79 Aide 79 449299 640731 5;913019." 491,90.39 460 3.31212 IJI 1181042 98.59 2A,x 614231 5,9031 4,51912 4.394.83 5,943.04539 49191206 870 3,Mo.M MWD(8) 11,840.39 961 23.0 6,11385 5,989.85 4549.61 4,382.55 5,913.07304 491,829.16 289 3,36922 MJVD(81 11.8740 99.19 2011 6,139.41 5.985.41 4571.53 6339.95 5,91310395 491,941.75 Ino 3,401 Be MVUD(6) 119060 98.19 1879 6,1N.68 5,907.80 4,61 6.359.54 5,913133.04 01,952.19 6M 3.432.31 MVUD(81 1193516 9263 14.00 6130.57 5976.50 4.6M96 4,351211 51913116128 491,MM 16.01 3,46167 MJrI 11961 9267 12.95 6120.54 590.54 4,664.18 63"20 5,913107.60 01,07.55 3.43 3.49167 MWD(6) 11070.52 98.07 13." 6.123.11 5,988.11 4,688.33 4,330.53 5.943.21476 491.91321 256 3,51843 MJUD(6) 12,02432 98.48 911 6,11823 5,96423 472113 6.332.0 594324253 491,819.76 12.13 3.54986 MJUDon 12,055.50 lai 6 890 621450 5960.50 475170 b,39.15 5943.278.10 49188461 1035 3.580.01 MWD(5) 10254017 12 37 23W Page4 COMPASS5000.148 SS ConocoPhillips SIAL, i ConocoPhillips Definitive Survey Report Company: ConacoP116Lps(Masks) Inc.-Kup2 Local Co-ardbade Refsrence: Win 2K-04 P,.j.0 Kupa(uk River Unit NO Reference: 2K-5@ 154.00uafl(21<44) Site: Kupamk 2K Pad MD Reference: 2K-04@154.00usfl(2K-04) Well: 21c64 North Reference: hue Wettable: 2K -04L1 Survey Calculation Method: Minimum Curvature Design: 2K -0L1 Datnaase: EDT Alaska Sandbox Survey 1025201] 17:3]7317. Pape 5 COMPASS 500014 Build 86 Map Map Will MD Inc Av TVD TVDSS +WS iV-W NO Endingrmw) DLS auction Survey Tool Name /331notdllan (1) (1) (wait) (usR) I..R) (uaRl (I m( m( w 12,080 99.6] 828 611169 5,95769 4]83]3 -6.322.31 5,943.310.13 481,989.45 263 3.61330 MWD(6) 12,116.72 94.11 939 6,109.49 5555549 4,01201 -6.31792 5,943,339.40 491,91005 4,32 3.64181 MWD(6) 12,145.50 92.51 939 6,107]] 5,953]] 484134 -6,31307 5,943.36].]3 491,998.]1 5.37 30)51 Smol 12,17636 9.'161 008 6,19 .0 5,952.98 4,8MM 6,309.53 5,943,397.23 49ZWG 25 773 S701 37 all 12,27663 8963 654 SIM 90 5,95290 4,902.. 6,304.38 5,943,42 .22 49200741 525 3.733.61 MWD(6) 12,24028 890 5.73 6,10.12 5,953.12 4,934.30 6,30.95 5,943.40.9 492010.85 313 3,76519 MPoD(6) 12,26720 88.62 295 6,10.M 5953.. 4961.14 6,3m.91 5,943.48751 492012.89 102 3.79197 MWD(6) 12,2611 88.83 0.64 8.100.10 5.954.10 4,9000 -S,2m.0 5,943.51640 492013.81 60 382.50 MWD(5) 12,331.2 92.02 357.0 6,10.92 5,9092 5025.10 -6.29.57 5943,55107 49201324 lax 3,85502 9102(6) 12,35745 92.76 35544 6,10.83 5,95283 5,05128 -6.30.19 5943,57)64 49291.54 833 360052 .Wold) 12,38702 9123 30.28 6,10.00 5,951.00 5.00059 6,333.07 5,943,69.95 49200.9 1626 3908 75 WMD(6) 12,41524 92.15 main 6,1..0 5950.97 51937 -6,308 74 5,m.lod.73 49200.10 39 3,935.26 Ill (6) 12,44582 92.70 3512 6,1067 5..967 5,130.51 8,313]6 5,9436..8] 49199.00 501 3,904.0 ill 12,48233 93.9 35.0 6,10.51 5,940.51 5,17468 46,31625 5943,70104 491,9061 10.33 3,99.92 MMD(6) 12,508.63 03.6" 35.85 6,10.17 5,940.1] 51968 -6.320.48 5943,725.24 491,991.30 1. cm as MrYD(6) 1253540 919 358.16 6.101.50 5.].50 5,220.61 6,322.2 5,943.].97 49198957 1150 4,051.33 ill (6) 12,56318 ON 3%05 6,1042 5.94042 5,250.36 6,32.01 5,943]..71 491980.86 310 4,000 WIND (6) 12,594.59 09.72 016 6.099.93 5,94594 5,286.77 46,323.21 5,WS13.11 491,90.67 9.69 4,10843 Mi (6) 12,626M 8791 258 6,1cow 5,940.83 532049 6,32.40 5,931,540.81 491.989.49 695 414179 VIND(6) 126.0 68.62 475 6,1943 5,94743 534689 -6,32.]1 5943,873.2 491,991.18 663 419.08 all (6) 12,0394 IS 48 ].1] 6,19.92 5.94792 5,335.9 6,31764 5,94390.2 491.99421 681 4197.14 MMU (6) 12,71516 89.23 633 6,102.27 5940.27 54979 6,313.47 5,943,933.13 491.9943 300 422633 MND (6) 12,7402 W.7 1040 6,102.71 5,.0.]1 5,43149 F,30.30 5943.85782 4920253 878 4,253.36 MAID (6) 12,77163 90.58 132 6.10.88 5,.080 5,452.24 -S,02.91 594399.57 49200.0 low 4.284.77 MAU(6) 12,79645 9163 1485 8,102.41 5.940.41 549.32 46,256 87 5944,92.9 49201505 7.67 Slide 53 MMD(6) U.S. 20 91.n 1694 6,1942 5,94742 5,51075 6.28763 5,944,95.07 49204.30 6.11 4,3430 MJrl 12.85512 9043 17.14 5,10.]6 Suds 76 5552.13 6,27740 5,844.0645 492031.51 374 4377M MWD(5) 12.895 14 9.03 1998 5.1064 5,946.64 5,563.59 -e,26765 S.W.10.m 4920440 949 4,407.41 MWD(5) 13,925.. 017 M49 5.10.85 5,946.95 5,60.65 6,25751 5.914.134.95 492651.43 338 4485.0 MNA(9 12.950 28 0.99 W47 6,10126 5,94726 5,63229 -6,24688 5,941,15969 492 DwV 072 4,01.65 Moll 1296.9 08.34 .76 610163 594763 5.846.95 5,24267 5,944,173.25 49200.9 150 447).10 MWO(6) 1025201] 17:3]7317. Pape 5 COMPASS 500014 Build 86 �- ConocoPhillips SIAM� Cofloo 11111p5 Definitive Survey Report COmpury: ConocoPsillips(Alaska) Inc. -Kup2 1V0 Reierenee: 2K-04 ® 154.00usR (2K-04) Project, Kupamk River Unit NorM Reference: True Survey Calculation Maltese: $be: Kupsmk 2K Pad EDTAlaska Sandbox lal 2K -(M y4e11Usn: 2K -04L1 OeatpM 21 Survey MD Int Ad ND ND$S ♦NIS team (1) (1) Nall (meal II 18,o10on 8034 22.76 6,10290 5,94898 5,68746 Local Co,niinale Referents: Mil 2K -U 1V0 Reierenee: 2K-04 ® 154.00usR (2K-04) NO Snrerenca: 2K-04 @ 154.00usS (2K-04) NorM Reference: True Survey Calculation Maltese: Ml0imum0m.g.. Oambase: EDTAlaska Sandbox Map Map Vertical 'V'W Nortbin8 Easting OLS Sal Survey Tool Name MOOtdUOn (dal IRI (R) Moo) tRl 1,21560 51944218.74 492.089.08 000 451594 'PO JECT'cD IO TD 102520171237:23PM Page S COMPASS 5000.14 &OM 65 21 71 28 BAPRINT DISTRIBUTION LIST UKER 28 778 %' GHES a GE company COMPANY ConocoPhillips Alaska, RE i Y �. WELL NAME 2K -04L1-02 NOV t 9 2017 FIELD Greater Kuparuk Area COUNTY North Slope Borough • `0GCC BHI DISTRICT Alaska ee sign and return one copy of this transmittal form to: xoPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technicii*A LOGGED G Street. U /q /201-1 ioraee. Alaska 99510 ,1 K. BENDER LOG TYPE GR - RES LOG DATE October 24, 2017 AUTHORIZED BY Patrick Rider EMAIL Patrick. Rldef(a)bakerhughes.COm TODAYS DATE November 7, 2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY ADDRESS (Fli WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V BP North Slope. EOA. PBOC, PRBdO (Office 109) D&G WO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 CD in 217-126 FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY I REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES 1# OF COPIES 1# OF COPIES VV 0 0 0--T 0 0 2 ConocoPhillips Alaska Inc. 0 0 0 0 0 Attn: Ricky Elgarica ATO 708 700 G Street Anchorage, AK 99510 3 ExxonMobil, Alaska 0 0 0 0 0 Atm: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4State of Alaska -AOGCC 0 1 1 1 0 Attn: Makers Bender 333 W. 7th Ave, Suite 100 .Anchorage, Alaska 99501 5 DNR - Division ofOil & Gas *** 0 0 T 1 0 AM: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 ** Stamp "confidential" on all material deliver to DNR 6' BP Exploration (Alaska) Inc. Petrotechnical Data Center, IR2-1 900 E. Reason Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 ConocoPhillips RECE9VL' —s. NOV 0 9 2017 AOGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K -04L1-02 50-103-20099-62 Baker Hughes INTEQ Definitive Survey Report 25 October, 2017 BA ER F UGHES a GE company 21 71 28 28 77 8 r ConocoPhillips eAf ER,Es ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kuparuk 2K Pad Well: 2K-04 Wellbors: 2K -04L1 Design: 2K-041-1 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 2K-04 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Position -N/-S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position uncertainty 0.00 usft Wellhead Elevation: Wellbore 2K-0411-02 Magnetics Model Name Sample Date BGGM2017 10/1/2017 Design 2K-0411-02 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 35.50 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 Latitude: 498,310 06usft Longitude: usft Ground Level: Declination Dip Angle (1) (1 17.30 80.84 Tie On Depth: 10,620.14 +N/ -S +E/ -W Direction (usft) (usft) (1) 0,00 0.00 10.00 70° 14' 35.784 N 150° 0'49.136 W 118.50 usft Field Strength (nT) 57,474 10/252017 12:37:23PM page 2 COMPASS 5000.14 Build 85 ConocoPhillips ea�1EN ConocoPhilli s DGN p LS Definitive Survey Report Company: ConocoPhillips (Alaska) Inc -Kup2 Local Coordinate Reference: Well 2K-04 Project: Kuparuk River Unit TVD Reference: 2K-04 @ 154.00usft (2K-04) Site: Kupamk 2K Pad MD Reference: 2K-04 @ 154.00usft (2K -D4) Well: 2K-04 North Reference: True Wellbore: 2K -04L1 Survey Calculation. Method: .Minimum Curvature Design: 2K -04L1 Database: EDT Alaska Sandbox Survey Program Date 1 012 5/2 01 7 From TO Survey Survey (usft) (judo Survey (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 (2K-04111) MWD MWD -Standard 10/10/2017 10/10/2017 10,530.00 10,560.36 2K-041-7-01 MWD-INC(21K-041-1-011)MWD4NC_ONLY MWD -INC -ONLY -FILLER 10/17/2017 10/17/2017 10,589.85 10,620.14 2K-04Li-01 MWD (2](4411-011) MWD MWD -Standard 10/17/2017 10/20/2017 10,629.00 10,660.90 2K -04L7-02 MWD-INC(2K-041.1-02) MWD-INC_ONLY MWD -INC -ONLY -FILLER 10/21/2017 10/21/2017 10,695.50 12,966.06 2K-04Li-02 MWD (21<4411-02) MWD ----- MWD - Standard 10/21/2017 10/24/2017 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLS Northing Easting Section Survey Tool Name Annotation (usft) 0 (1 (usft) (usft) lush) (usft) (ft) (ft) (°/100') (ft) 10,620.14 97.98 332.32 6.141.39 5,987.39 3,663.45 -7,076.11 5,942,190.13 491,235.48 44.79 2,379.05 MWD (4) TIP C 10,629.00 97.66 335.63 6,140,18 5,986.18 3,671.34 -7,079.96 5,942,198.02 491,231.63 37.19 2,386.14 MWD -INC -ONLY (5) KOP I 10,660.90 84.03 339.60 6.139.71 5,985.71 3,700.76 -7,092.07 5,942,227.44 491,219.53 44.49 2.413.01 MWD -INC ONLY(5) Interpolated Azimuth 10,695.50 74.43 344.01 6,146.17 5,992.17 3,733.00 -7,102.69 5,942,259.68 491,208.92 30.43 2.442.92 MWD (6) 10,725.60 77.60 354.60 6,153.47 5,999.47 3,761.65 -7,108.08 5,942,288.33 491,203.53 35.72 2,470.20 MWD (6) 10,754.60 79.44 3.00 6,159.25 6,005.25 3,790.04 -7,108.67 5,942,316.71 491,202.95 29.08 2,498.05 MWD (6) 10]84.68 80.71 12.86 6,164.44 6,010.45 3,819.34 -7,104.58 5,942,346.02 491,207.04 32.56 2.527.62 MWD (6) i 10,814.61 82.27 22.26 6,168.88 6,014.68 3,847.53 -7,095.66 5,942,374.20 491,215.97 31.49 2,556.93 MWD (6) I 10,844.85 84.09 32.67 6,172.48 6,018.48 3,874.13 -7,081.83 5,942,400.79 491,229.81 34.70 2,685.53 MWD (6) f 10,874.70 85.17 42.56 6,175.28 6,021.29 3,897.64 -7,063.71 5,942,424.29 491,24793 33.18 2611.83 MWD (6) j 10,902.23 86.31 51.72 6,177.33 6,023.33 3,916.29 -7,043.61 5,942,442.94 491,268.04 33.44 2,633.69 MWD (6) 10,933.58 93.72 56.05 6,177.33 6,023.33 3,934.75 -7,018.30 5,942,461.39 491,293.34 27.37 2,656.26 MWD (6) { 10,965.05 92.68 59.47 6,175.57 6,021.57 3,951.51 -6991.73 5,942,478,15 491,319.91 11.34 2,677.38 MAD J6) 10,994.17 91.97 59.89 6,174.39 6.020.39 3,966.20 0,966.62 5,942,492.83 491,345.03 2.83 2,696.21 MWD J6) t 11,027.10 89.85 61.16 6,173.86 6,019.86 3,982.40 si,93].95 5,942,509.02 491373.69 7.50 2,717.14 MWD (6) 11,053.56 88.80 62.44 6,174.18 6,020.18 3,994.90 -5,914.64 5,942,521.51 491,397.01 6.26 2,733.50 MWD (6) 11,083,34 88.16 64.16 6,174.97 6,020.97 4,008.28 b,888.04 5,942,534.88 491,423.61 6.16 2,751.29 MWD (6) 11,113.97 87.29 52.92 6,176.18 6.022.18 4,021.92 -.860.64 5,942,546.51 491451.01 4.94 2,76948 MVVD(6) 10125/2017 12'37: 23PM Page 3 COMPASS 5000. 14 B,dd 85 ConocoPhillips �<ER BA Q UGHES ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc.-Kup2 Local Coordinate Reference: Well 2K-04 Project: Kupamk River Unit ND 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-041_1 Survey Calculation Method: Minimum Curvature Design: 2K -04L1 Database: EDT Alaska Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +El -W Northing Easing DLS Section Survey Tool Name Annotation (usft) (') (") (usft) (usft) (usft) (usft) (ft) (ft) (-/100') (ft) 11,144.92 87.67 60.]5 6,177.54 6.023.54 4,036.51 8.833.39 5,942,563.10 491,478.26 7.11 2,788.56 MWD(6) 11,175.24 88.99 59.10 6,178.43 6,024.43 4,051.70 8,807.16 5,942,578.28 491504.49 6.97 2,808.09 MM (6) 11,205.36 91.69 58.38 6,178.25 6,024.25 4,067.32 8,781.42 5,942,593.90 491.530.23 9.28 2,827.95 MWD (6) 11,235.00 93.01 57.37 6,177.03 6,023.03 4,083.07 8,756.34 5,942,609.64 491,555.31 5.61 2.847.82 MWD 16) 11 265.09 92.98 55.17 6,175.46 6,021.46 4,099.76 8,731.35 5,942,626.32 491,580.31 730 2,868.59 MWD (6) 11,296.10 90.55 52.55 6,174.50 6,020.51 4,118.03 8,706.32 5,942,644.59 491,605.33 11.52 2,890.93 MWD (6) 11327.29 90.T SOA6 6,174.15 6,020.15 4,137.53 8,68198 5,942,664.07 491,629.68 8.01 2,914.36 MWD (6) 11,360.46 91.08 48.57 6,173.61 6,019.61 4,159.15 !,656.83 5,942,685.69 491,654.83 4.59 2,940.02 MWD(6) 11,390.46 91.54 46.54 6,172.92 6,018.92 4,179.39 8,634]0 5,942.705.92 491,676.96 6.94 2,963]9 MVVV (6) . 11,420.62 91.04 44.40 6,172.25 6,018.25 4,200.53 8,613.21 5,942,727.06 491,698.46 7.28 2,988.35 MWD (6) 11,449.74 90.18 42.38 6,171.94 6,017.94 4,221.69 8,593.21 5,942,748.21 491,718.46 7.54 3,012.66 MWD (6) 11,485.66 91,96 41.01 6,171.26 6,017.26 4,248.51 8,569.32 5,942,775.02 491742.35 6.25 3,043.21 MWD (6) 11,512.94 91.04 39.18 6,170.55 6,016.55 4,269.37 8,551.76 5,942,795.87 491,759.92 7.51 3,066.81 MWD(6) 11,541.88 89.14 36.79 6,170.50 6,016.50 4,292.18 8,533.95 5,942,818.67 491,777.73 10.55 3,092.36 MM (6) 11,571.55 90.25 35.83 6,170.66 6,016.66 4,316.08 8,516.38 5.942.842.57 491,795.30 4.95 3,118.96 MWD(6) 11,599.78 90.89 35.12 6,170.38 6,016.38 4,339.07 8500.00 5,942,865.56 491,811.69 3.39 3,144.44 MWD (6) ; 11630.58 93.47 34.78 6,169.21 6,015.21 4,364.30 8,482.37 5,942,890.77 491,829.32 8.45 3,172.34 MM (6) 11,655.62 94.61 33.10 6,167.45 6613.45 4,385.02 8,468.42 5,942,911.49 491,843.27 8.03 3,195.17 MVVD(6) 11,685.48 97.05 30.92 6,164.41 6,010.41 4,410.20 8,452.68 5,942,936.67 491,859.02 10.93 3,222.71 MM (6) i 11,715.66 99.18 30.15 6,160.15 6,006.15 4,435.94 8,437.50 5,942,962.39 491,874.20 7.50 3,250.68 MM (6) 11,750.78 98.35 27.10 6,154.80 6,000.80 4,466.40 8,420.87 5,942.992.85 491,890.83 8.90 3,283.57 MWD(6) 11,780.90 - 96.95 26.92 6,150.79 5,996.79 4,492.99 8,407.31 5,943,019.44 491,904.39 4.69 3,312.12 MWD(6) ! 11810.42 96.59 24.36 6,147.31 5,993.31 4,519.42 8,394.63 5,943,045.86 491,917.08 8.70 3,340.34 MM (6) 11,840.36 96.30 23.54 6,143.95 5,989.95 4,546.61 8,382.55 5,943,073.04 491,929.16 2.89 3,369.22 MWD (6) 11,874.06 99.19 20.71 6,139.41 5,985.41 4,577.53 8,369.98 5,943,103.96 491,941.75 11.95 3,401.86 MWD(() 11,905.32 98.19 18.79 6,134.68 5,980.68 4,606.62 8,359.54 5,943,133.04 491952.19 6.86 3,432.31 MM (6) 11,935.16 97.63 14.00 6,130.57 5,976.58 4,634.96 8,351.20 5.943.161.38 491,960.54 16.01 3.461.67 MAD 16) 11,965.48 97.67 12.95 6,126.54 5,972.54 4,664.18 8,344.20 5,943,190.60 491,967.55 3.43 3,491.67 MWD (6) 11990.52 98.09 13.44 6,123.11 5,969.11 4,688.33 8,338.53 5,943,214.75 491,973.21 2.56 3,516.43 MM (6) 12,024.32 98.48 9.11 6.118.23 5,96423 4,721.13 8,332.00 5,943,247.53 491,979.76 12.73 3,549,86 MWD (6) 12.055.50 95.26 8.90 6,114.50 6,960.50 4,75170 -6,327.15 5,943,278.10 491984.61 10.35 3,580.81 MVID(6) Page 4 COMPASS 5000.14 Build 85 10/25/2017 12.3T23PM ConocoPhillips6Ad<DeRGH69 Definitive Survey Report p ConocoPhilli I� s Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2K-04 Project: Kuparuk River Unit ND Reference: 2K-04 @ 154.00usft (2K-04) Site: Kuparuk 2K Pad MD Reference: 2K-04 @ 154.00usft (2K-04) Well: 2K-04 North Reference: True Wellbore: 2K -04L7 Survey Calculation Method: Minimum Curvature Design: 2K -04L7 Database: EDT Alaska Sandbox Survey 10/25/2017 12r3723PM Annotation COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVID NDSS +WS tEl-W Northing Eaating DLS Section (usft) (°) (°) (usk) (usk) (usft) (usR) Survey Tool Name (ft) (R) (R) 12088.02 94.67 8.28 6,11169 5,957,69 4,783.73 8,322.31 5,943,310.13 491,989.45 2.63 3,613.20 MWD(6) 12,116.72 94.11 9.39 6,109.49 5,955.49 4,812.01 8,317.92 5,943,338.40 491,993.85 4.32 3,641.81 MWD (6) 12,146.50 92,51 9.39 6.107.77 5,953.77 4,841.34 8,313.07 5,943,367.73 491,998.71 5.37 3,671.54 MWD (6) 12,176.36 90.61 8.08 6,106.96 5,952.96 4,870.84 8,308.53 5,943,397.23 492,003.25 7.73 3,701.37 MM (6) 12,208.63 89.60 6.72 6.106.90 5,952.90 4.902.84 8.304.38 5,943,429.22 492,007.41 5.25 3,733.61 MWD (6) 12,240.28 89.60 5.73 6,107.12 5,953.12 4,934.30 8,300.95 5,943,460.68 492,010.85 3.13 3,765.19 MWD (6) 12,267.20 68.62 2.95 6,107.54 5,953.54 4,961.14 8,298.91 5,943,487.51 492,012.89 10.95 3,791.97 MWD (6) 12,296,11 88.83 0.64 6,108.16 5,954.18 4,990.02 8,298.00 5,943,516.40 492.013.81 8.02 3,820.58 NIM (6) 12,331.20 92.02 357.50 6,107.92 5,953.92 5,025.10 8,298.57 5,943,551.47 492,013.24 12.76 3,855.02 MM (6) 12,357.45 92.76 355.49 6,106.83 5,952.83 5,051.28 8,300.19 5,943,577.64 492,011.64 8.33 3,880.52 MWD (6) 12,387.02 91.23 350.26 6,105.80 5,951.80 5,080.59 8,303.87 5,943,606.95 492,007.96 18.26 3,908.75 MM (6) 12,415.24 92.15 349.83 6,104.97 5,950.97 5,108.37 8,308.74 5,943,634.73 492,003.10 3.60 3,935.26 MM (6) 12,445.82 92.70 351.26 6,103.67 5,949.67 5,138.51 -6,313,76 5,943,664.87 491998.08 5.01 3,964.07 MWD (6) 12,482.30 90.95 354.60 6,102.51 5,948.51 5,174.68 8.318.25 5,943,701.04 491,993.61 10.33 3,998.92 MM (6) 12,506.60 90.64 354.85 6,102.17 5,948.17 5,198.88 8,320.48 5.943,725.24 491,991.38 1.64 4,022.36 MWD(6) 12,536.40 91.93 358.18 6,101.50 5,947.50 5,228.61 8,322.29 5,943,754.97 491,989.57 11.98 4,051.32 MWD (6) 12.566.18 92.24 359.05 6,100.42 5,946.42 5,258.36 0,323.01 5,993,784.71 491,988.86 3.10 4,080.50 MWD (6) 12,594.59 89.72 0.16 6,099.93 5,945.94 5,286.77 0,323.21 5,943,813.11 491,988.67 9.69 4,108.43 MWD (6) 12,628.39 87.91 2.58 6,100.63 5,946.63 5,320.49 0,322.40 5,943,846.84 491,989.49 8.95 4,141.79 MWD (6) 12,654.80 88.62 4.75 6,101.43 5,947.43 5,346.89 0,320.71 5,943,873.23 491,991.18 8.63 4,168.08 MWD (6) 12,683.94 89.48 7.17 6,101.92 5,947.92 5,375.86 0,317.68 5,943,902.20 491,994.21 8.81 4,197.14 MWD (6) 12,715.16 89.23 8.33 6,102.27 5,948.27 5,406.79 0,313.47 5,943,933.13 491,998.43 3.80 4,228.33 MWD (6) 12,740.20 88.77 10.48 6,102.71 5,948.71 5,431.49 0,309.38 5,943,957.82 492,002.53 8.78 4.253.36 MWD (6) 12,771.63 90,58 13.29 6,102.86 5,948.88 5,462.24 0,302.91 5,943,988.57 492,009.00 10.63 4,284.77 MWD (6) 12,796.46 91.63 14.88 6,102.41 5,948.41 5,486.32 0,296.87 5,944,012.65 492,015.05 7.67 4,309.53 MWD (6) 12,830.20 91.72 16.94 6,101.42 5,997,42 5,518.75 0,287.63 5,944,045.07 492,024.30 6.11 4,343.08 MWD(6) 12,865.12 90.43 17.14 6,100.76 5,946.76 5,552.13 0,277.40 5,944,078.45 492,034.54 3.74 4,377.73 MM (6) 12,895.14 90.03 19.96 6,100.64 5,946.64 5,580.59 8,267.85 5,944,106.90 492,044.09 9.49 4,407.41 MWD(6) 12,925.04 89.17 20.49 6,100.85 5,946.85 5,608.65 8,257.51 5,944,134.95 492,054.43 3.38 4,436.83 MWD (6) 12,950.28 88.99 2047 6,101.26 5,947.26 5,632.29 0.248.68 5.944,158.59 492,063.27 0.72 4,461.65 MWD (6) 12,966.06 88.34 2276 6.101.63 5,947.63 5,646.95 8,242.87 5,944.17325 492,06908 15.08 4,477.10 MWD(6) 10/25/2017 12r3723PM Annotation COMPASS 5000.14 Build 85 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kupatuk 2K Pad Well: 2K-04 Wellbore: 2K-0411 Design: 2K -04L1 Survey MD Inc (usft) P) 1301000 88.34 Azi TVD TVDSS (°I (usft) (usft) 2276 6,102.90 5,948.90 ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map +N/ -S +EuW Northing (usft) (usft) (ft) 5e87,46 -6225.88 5.944.213.74 Well 2K-04 2K-04 @ 154.00usft (2K-04) 2K-04 @ 154.00usft (2K-04) True Minimum Curvature EDT Alaska Sandbox Map Vertical Easting DLS Section Survey Tool Name Annotation (ft) (°1100') (ft) 492,08608 0.00 4519.94 PROJECTEDeTD aA ER L? UGRES 10/2512017 12:37.23PM Page 6 COMPASS 5000.14 Build 85 174 "1IER WES , a GE company Letter of Transmittal Date: DATA LOGGED November 6, 2017 IN -t i201n 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 9411 Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data forth e following we] I(s): 2K-0411-1 21 7 1 2 6 2 8 7 7 1 4- cc, 2K-04LI -01 21 7 1 2 7 28 77 2 �/ 2K -04L1-02 21 7 1 2 8 28 7 7 3 RECEIVED NOV 07 2011 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.RMbirsingh@BHGE.com ConocoPhillips RECEIVED NOV 0 7 2017 AOGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K -04L1-02 50-103-20099-62 Baker Hughes INTEQ Definitive Survey Report 25 October, 2017 BA ER F�UGHES aGEcompany 21 71 28 28 773 Wellbore 2K-0411-02 Magnetics Model Name Sample Date Declination (I BGGM2017 10/l/2017 1730 Latitude: Longitude: Ground Level: Dip Angle (I 80.84 B,T i 70° 14' 35.784 N i 150° 0'49.136 W ' 118.50 usft Field Strength (nT) 57,474 Design 2K-0411-02 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2K-04 Project: Kuparuk River Unit TVD Reference: 2K-04 @ 154.00usft (2K-04) Site: Kuparuk 2K Pad MD Reference: 2K-04 @ 154.00usft (2K-04) Well: 2K-04 North Reference: True Wellbore: 2K-0417 Survey Calculation Method: Minimum Curvature Design: 2K -04L7 Database: EDT Alaska Sandbox Project Kuparuk River Unit, North Slope Alaska. UnitedStates 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 Well Position +N/ -S 0.00 usft Northing: 5,938,525.46usft +EI -W 0.00 usft Easting: 498,310.06usft Position Uncertainty 0.00 usft Wellhead Elevation: usft Wellbore 2K-0411-02 Magnetics Model Name Sample Date Declination (I BGGM2017 10/l/2017 1730 Latitude: Longitude: Ground Level: Dip Angle (I 80.84 B,T i 70° 14' 35.784 N i 150° 0'49.136 W ' 118.50 usft Field Strength (nT) 57,474 Design 2K-0411-02 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,620.14 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (1) 35.50 0.00 0.00 10.00 10/25/2017 12:37:23PM Page 2 COMPASS 5000.14 Build 85 Survey ConocoPhillips 6A ER m "ES ConocoPhilli p s Map Definitive Survey Report Vertical Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2K-04 TVD TVDSS 2 Project: Kuparuk River Unit TVD Reference: 2K-04 @ 154.00usft (2K-04) Site: Kuparuk 2K Pad (9 MD Reference: 2K-04 @ 154.00usft (2K-04) (waft) (usft) Well: 2K-04 Easting North Reference: True Survey Tool Name Annotation # Wellbore: 2K-041_1 Survey Calculation Method: Minimum Curvature Design: 21K-041_1 Database: EDT Alaska Sandbox 1 10,620.14 Survey Program 332.32 Date 10/25/2017 5,987.39 3,663.46 -7,076.11 5,942,190.13 From To 2,379.05 MWD (4) TIP ? Survey Survey (usft) (usft) Survey (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 339.60 I 10,479.00 I 10,510.72 2K-041_1 MWD -INC (21<441-1) MWD MWD -Standard 10/10/2017 10/10/2017 10,530.00 10,560.36 2K-041-7-01 MWD -INC (2K-041-1-01) MWD-INC_ONLY MWD -INC -ONLY -FILLER 10/17/2017 10/17/2017 10,589.85 10,620.14 2K-0411-01 MWD (2K-041.1-01) MWD MWD -Standard 10/17/2017 10/20/2017 10,629.00 10,660.90 2K-041.1-02 MWD -INC (2K-0411-02) MW0.1NC_ONLY MWD -INC -ONLY -FILLER 10/21/2017 10/21/2017 10,695.50 12,966.06 2K-041.1-02 MWD (2K-0411-02) MWD MWD -Standard 10/21/2017 10/24/2017 Survey 10/252017 12:37:23PM Page 3 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DILS (usft) (9 V) (usft) (waft) (usft) (usft) Northing Easting (°1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 1 10,620.14 WAS 332.32 6,141.39 5,987.39 3,663.46 -7,076.11 5,942,190.13 491,23548 4479 2,379.05 MWD (4) TIP ? 10,629.00 97.66 335.63 6,140.18 5,986.18 3,671.34 -7,079.96 5,942,198.02 491,231.63 37.19 2,386.14 MWD-INC_ONLY (5) KOP 10,660.90 84.03 339.60 6,139.71 5,985.71 3,700.76 -7,092.07 5,942,22244 491,219.53 44.49 2,413.01 MWD -INC _ONLY (5) Interpolated Azimuth 10,695.50 74.43 344.01 6,146.17 5,992.17 3,733.00 -7,102.69 5,942,259.68 491,208.92 30.43 2,442.92 MWD (6) - 10,72560 7260 354.60 6,153.47 5,999.47 3,761.65. -7,108.08 5,942,288.33 491,203.53 35.72 2,470.20 MWD(6) 10,75460 7944 3.00 6,159.25 6,005.25 3,790.04 -7,10867 5,942,316.71 491,202.95 29.08 2,498.05 MWD(6) 10,78468 80.71 12.86 6,164.44 6,010.45 3,819.34 -7,104.58 5,942,346.02 491,207.04 32.56 2,527.62 MWD (6) 1Q814.61 8227 22.26 6,168.88 6,014.88 3,847,53 -7,09565 5,942,374.20 491,215.97 31.49 2,556.93 MWD (6) 10,844.85 84.09 32.67 6,172.48 6,018.48 3,874.13 -7,081.83 5,942,400]9 491,229.81 34.70 2,585.53 MWD(6) 10,87410 85.17 42.56 6,175.28 6,021.29 3,89764 -7,063.71 5,942,424.29 491,247.93 33.18 2,611.83 MWD (6) 10,902.23 86.31 51.72 6,177.33 6,023.33 3,916.29 -7043.61 5,942,442.94 491,268.04 33.44 2,633.69 MWD(6) 10,933.58 93.72 5605 6,177.33 6,023.33 3,934.75 -7,018.30 5,942,461.39 491,293.34 27.37 2,656.26 MWD(6) 10,965.05 92.68 59.47 6,175.57 6,021.57 3,951.51 $,99173 5,942,478.15 491,319.91 11.34 2,677.38 MM (6) 10,994.17 91.97 59.89 6,174.39 6,020.39 3,966.20 -6,966.62 5,942,492.83 491,345.03 2.83 2,696.21 MWD (6) 11,027.10 89.85 61.16 6,17386 6,019.86 3,982.40 -6,93795 5,942,509.02 491,373.69 7.50 2,717.14 MWD(6) 11,053.56 88.80 62.44 6,174.18 6,020.18 3,994.90 6,91464 5,942,521.51 491,397.01 6.26 2,733.50 MM (6) 11,083.34 88.16 64.16 6,174.97 6,020.97 4,008.28 6,888.04 5,942,534.88 491423.61 6.16 2,751.29 MM (6) 11,113.97 87.29 62.92 6.176.18 6,022.18 4,021.92 5,860.64 5,942,548.61 491, 451 01 4.94 2,76948 AVID (6) 10/252017 12:37:23PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips RA ER ConocoPhillips Definitive Survey Report u�HEs Company: Project: Site: Well: Wellbore: Design: Survey ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-04 2K-0411 2K-0411 Local Coordinate Reference: TVD Reference: MD Reference: Norm 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 Annotation 10/252017 12:37:23PM Page 4 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +NlS +EAW DLS (usft) (I (I (usft) (usft) (usft) (usft) Northing Ea( ting (0)100') Section Survey Tool Name (ft) (ft) (ft) 11,144.92 87.67 60.75 6,177.54 6,023.54 4,036.51 -6,833.39 5,942,563.10 491478.26 7.11 2,788.58 MWD (6) 11,175.24 88.99 59.10 6,17843 6,024.43 4,051.70 -6,807.16 5,942,57828 491,504.49 6.97 2,808.09 MVD (6) 11,205.36 9169 58.38 6,178.25 6,024.25 4,067.32 6,781.42 5,942,593.90 491,530.23 9.28 2,827.95 MWD (6) 11,235.00 93.01 57.37 6,177.03 6,023.03 4,083.07 -6,756.34 5,942,609.64 491,555.31 5.61 2,847.82 MWD (6) 11,265.09 92.98 55.17 6,175.46 6,021.46 4,099.76 -6,731.35 5,942,626.32 491,580.31 730 2,868.59 MWD(6) 11,296.10 90.55 52.55 6,174.50 6,020.51 4,118.03 -6,706.32 5,942,644.59 491,605.33 11.52 2,890.93 MWD (6) 11,327.29 90.77 50.06 6,174.15 6,020.15 4,137.53 -6,68198 5,942,66407 491.629.68 8.01 2,914.35 MWD(6) 11,360.46 91.08 48.57 6.173.61 6,019.61 4,159.15 -6,656.83 5,942,68569 491,654.83 4.59 2,940.02 MWD (6) 11,39046 91.54 46.54 6,172.92 6,018.92 4,179.39 -6,634.70 5,942,70592 491,676.96 6.94 2,963.79 MWD(6) 11,420.62 91.04 44.40 6.172.25 6,018.25 4,200.53 -6,613.21 5,942,72766 491,698.46 728 2,988.35 MWD(6) 11,449.74 90.18 42.38 6,171.94 6,017.94 4,221.69 -6,59321 5,942,74821 491718.46 7.54 3,012.66 MM (6) 11,485.66 91.96 41.01 6,171.26 6,017.26 4,248.51 -6569.32 5,942,775.02 491,742.35 6.25 3,043.21 MWD(6) 11,512.94 91.04 39.18 6,170.55 6,016.55 4,269.37 6,551.76 5,942,795.87 491,759.92 7.51 3.066.81 MWD(6) 11,541.88 89.14 36.79 6,170.50 6,016.50 4,292.18 6,533.95 5,942,818.67 491,777.73 10.55 3,092.36 MWD (6) 11,571.55 9025 35.83 6,170.66 6,016.66 4,316.08 6,516.38 5,942,842.57 491,795.30 4.95 3,118.96 MWD (6) 11,599.78 90.89 35.12 6,170.38 6,016.38 4,339.07 -6,500.00 5,942,865.56 491,81169 3.39 3,144.44 MWD(6) 11,630.58 93.47 34.78 6,169.21 6,015.21 4,364.30 -6,482.37 5,942,890.77 491,829.32 8.45 3,172.34 MWD (6) 11,655.62 94.61 33.10 6,167.45 6,013.45 4,385.02 -6,468.42 5,942,911.49 491,843.27 8.09 3,195.17 MWD (6) 11,685.48 97.05 3092 6,164.41 6,010.41 4,410.20 -6,452.68 5,942,936.67 491,859.02 10.93 3,222.71 MM (6) 11,715.66 99.18 30.15 6,160.15 6,006.15 4,435.94 -6,437.50 5,942,962.39 491,874.20 7.50 3,250.68 MM (6) 11,75078 98.35 27.10 6,154.80 6,000.80 4,466.40 6,420.87 5,942,992.85 491,890.83 8.90 3,283.57 MWD (6) 11,780.90 96.95 26.92 6,150.79 5,996.79 4,492.99 -6,407.31 5,943,019.44 491,904.39 4.69 3,312.12 MWD(6) 11,810.42 96.59 24.36 6,147.31 5,993.31 4,519.42 -6,394.63 5,943,045.86 491,917.08 8.70 3,340.34 MWD (6) 11,840.36 96.30 23.54 6,143.95 5,989.95 4,546.61 -6,382.55 5,943,073.04 491,929.16 2.89 3,369.22 MWD (6) 11,874.06 99.19 20.71 6,139.41 5,98541 4,577.53 s'Wa% 5,943,103.96 491,941.75 1195 3,401.86 MWD (6) 11,905.32 98.19 18.79 613468 5,98068 4,6W.62 -6,359.54 5,943,133.04 491,952.19 6.86 3,432.31 MWD (6) 11,935.16 9763 14.00 6,130.57 5,976.58 4,634.96 6,351.20 5,943,161.38 491,960.54 16.01 3,46167 MM (6) 11,96548 97.67 12.95 6,126.54 5,972.54 4,664.18 -6,344.20 5,943,190.60 491,967.55 3.43 3,491.67 MWD (6) 11,990.52 98.09 13.44 6,123.11 5,969.11 4,688.33 -6,338.53 5,943,214.75 491,973.21 2.56 3,51643 MWD (6) 12,024.32 98.48 9.11 6,118.23 5,96423 4,721.13 6,332.00 5,943,247.53 491,979.76 1273 3,549.86 MWD (6) 12.055.50 9526 8.90 6,114.50 5,960.50 4,751.70 -6327.15 5,943,278.10 491984.61 1035 3,580.81 MWD (6) Annotation 10/252017 12:37:23PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips BA ER ConocoPhilli S UGNES p Definitive Survey Report .�E,a Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: 2K-04 P: Walloons: 2K-0411 Design: 2K-0411 Survey 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 Annotation 1025/2017 12:37:23PM Page 5 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLS (usft) (') (1) (usft) Wait) Wei (usft) Northing Easting (./100•) Section Survey Tool Name (R) (ft) (R) 12,088.02 9467 8.28 6,111.69 5,957.69 4,783.73 6,322.31 5,943,310.13 49198945 263 3,613.20 MWD (6) 12,116.72 94.11 939 6,109.49 5,955.49 4,812.01 -6,31792 5,943,33840 491,993.85 4.32 3,641.81 MM (6) 12,146.50 92.51 9.39 6,107.77 5,953.77 4,841.34 -6,313.07 5,943,367.73 491,99811 5.37 3,671.54 MWD (6) 12,176.36 90.61 8.08 6,105.96 5,952.96 4,870.84 -6,308.53 5,943,397.23 492,003.25 773 3,701.37 MWD (6) 12,20863 89.60 6.72 6,106.90 5,952.90 4,902.84 -6,304.38 5,943,42922 492,00241 525 3,733.61 MWD (6) 12,240.28 8960 5.73 6,107.12 5,953.12 4,934.30 -6,300.95 5,943,460.68 492,010.85 3.13 3,765.19 MWD (6) 12,267.20 8862 2.95 6,107.54 5,953.54 4,961.14 6,298.91 5,943,487.51 492,012.89 10.95 3,791.97 MAD (6) 12,296.11 88.83 0.64 6,108.18 5,954.18 4,990.02 -6,298.00 5,943,516.40 492,01381 802 3,820.58 MWD (6) 12,331.20 9202 357.50 6,107.92 5,953.92 5,025.10 6,298.57 5,943,551.47 492,013.24 1276 3,855.02 MM (6) 12,357.45 92.76 355.44 6,106.83 5,952.83 5,051.28 6,300.19 5,943,577.64 492,01164 8.33 3,880.52 MAD (6) 12,387.02 91.23 35026 6,105.80 5,951.80 5,080.59 -6,303.87 5,943,606.95 492,007.96 18.26 3,908.75 MWD (6) 12,415.24 92.15 349.83 6,104.97 5,950.97 5,108.37 -6,308.74 5,943,634.73 492,003.10 3.60 3,935.26 MM (6) 12,445.82 92.70 351.26 6,103.67 5,949.67 5,138.51 -6,313.76. 5,943,664.87 491,998.08 5.01 3,964.07 MWD (6) 12,482.30 90.95 35460 6,102.51 5,948.51 5,174.68 6,318.25 5,943;701.04 491,993.61 10.33 3,998.92 MWD(6) 12,506.60 90.69 354.85 6,102.17 5,948.17 5,198.88 -6,320.48 5,943,725.24 491,991.38 1.64 4,022.36 MWD(6) 12,536.40 91.93 358.18 6,101.50 5,947.50 5,228.61 -6,322.29 5,943,754.97 491,989.57 11.98 4,051.32 MWD (6) 12,566.18 92.24 359.05 6,100.42 5,946.42 5,258.36 6,323.01 5,943,784.71 491,988.86 3.10 4,080.50 MM (6) 12,594.59 89.72 0.16 6,099.93 5,945.94 5,286.77 -6,323.21 5,943,813.11 491,988.67 9.69 4,108.43 MWD(6) 12,628.34 87.91 2.58 6,100.63 5,945.63 5,320.49 6,322.40 5,993,846.84 491,989.49 8.95 4,141.79 MM (6) 12,654.80 88.62 4.75 6,101.43 5,94743 5,346.89 -6,320.71 5,943,873.23 491,991.18 8.63 4,168.08 MWD (6) 12,683.94 89.48 7.17 6,101.92 5,947.92 5,375.86 -6,317.68 5,943,902.20 491,994.21 8.81 4,197.14 MWD (6) 12.715.16 89.23 833 6,102.27 5,94827 5,403.79 -6,313.47 5,943,933.13 491,998.43 3.80 4,228.33 MAD (6) 12,740.20 88.77 10.48 6,102.71 5,948.71 5,431.49 -6,309.38 5,943,957.82 492,002.53 8.78 4,253.36 MWD (6) 12,771.63 90.58 1329 6,102.88 5,948.88 5,462.24 -6,302.91 5,943,988.57 492,009.00 10.63 4,284.77 MM (6) 12,79646 91.63 14.88 6,10241 5,94841 5,486.32 -6,296.87 5,944012.65 492,015.05 7.67 4,309.53 MVD (6) 12,830.20 91.72 16.94 6,10142 5,947.42 5,518.75 6,287.63 5,944,045.07 492,024.30 6.11 4,343.08 MWD (6) 12,865.12 90.43 17.14 6,100]6 5,94676 5,552.13 -6,277.40 5,94407845 492,034.54 3.74 4,37773 MWD(6) 12,895.14 90.03 19.96 6,10064 5,946.64 5,580.59 -6,267.85 5,944,106.90 492,044.09 9.49 4,40241 MWD(6) 12,925.04 89.17 20.49 6,100.85 5,946.85 5,608.65 -6,257.51 5,944,134.95 492,054.43 3.38 4,436.83 MWD (6) 12,950.28 88.99 2047. 6,101.26 5,947.26 5,632.29 -6,248.68 5,944158.59 492063.27 0.72 4,461.65 MVM (6) 12,966.06 8834 22.76 6,101.63 5,94763 5,646.95 6,242.87 5944.173.25 49206908 1508 4,477.10 MV (6) Annotation 1025/2017 12:37:23PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: 2K-04 Wellbore: 2K-0411 Design: 2K-0411 Survey MD Inc Azi TVD TVDSS (usft) (I V) (usft) (usft) 1301000 88.34 22.76 6.102.90 5,948.90 ConocoPhillips Definitive Survey Report 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 Q 154.00usft (2K-04) True Minimum Curvature EDT Alaska Sandbox +N/S +E7 -W Map Map Vertical Northing Easting DLS Section Survey Tool Name (usft) lust[) (ft) (ft) (°2100') (ft) 568746 -6,225.88 5944.213.74 492.08608 000 4,519.94 PROJECTEDIo TD Annotation BA, �(ER UDRES 1012512017 12: 3723PM Page 6 COMPASS 5000.14 Build 85 THE STATE 01ALASKA GOVERNOR BILL WALKER Kai Starck CTD Director ConocoPhillips Alaska, Inc, P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Evil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K -04L1-02 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-128 Surface Location: 5058' FNL, 94' FEL, SEC. 2, TION, R8E, UM Bottomhole Location: 4703' FNL, 932' 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.00gcc.olaska.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 Chair DATED this day of September, 2017. STATE OF ALASKA AL, -KA OIL AND GAS CONSERVATION COMM(.. ,ON PERMIT TO DRILL 20 AAC 25.005 (RECEIVED SEP 07 2017 1a. Type of Work: I 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ tc. Sp ci we w ro osed for: Drill ❑ Lateral -Ell Stratigraphic Test ❑ Development - Oil 0 ' Service - Winj ❑ Single Zone 0 ' Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ ReentryEll 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 -04L1-02 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 13000' - ` TVD: 5943' Kuparuk River Pool / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 5058' FNL, 94' FEL, Sec 2, T1 ON, R8E, UM o2, SS $6 ADL 25589 SS Top of Productive Horizon: 8. DNR Approv Number: 1 13. Approximate Spud Date: 1433' FNL, 1865' FEL, Sec 3, T10N, R8E, UM LONS 85-096 9/19/2017 Total Depth: 9. Acres in Property: !/� 14. Distance to Nearest Property: 4703' FNL, 932' FEL, Sec 34, T11 N, R8E, UM 2 68� 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- 4 GL / BF Elevation above MSL (ft): 114' to Same Pool: 920' (2M-22) 16. Deviated wells: Kickoff depth: 10580 feet , 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 96 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 2525' 10475' 5972' 13000' 5943' 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 ❑1 20. Attachments: Property Plat ❑ BOP Sketch Drillingv. o h Plot eFlu Shallow Hazard Analysis Divertter Sketch B Report B Drilling d Prgrram B 20 AAC 25.050 requirements B✓ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: William LongAflc Authorized Name: Kai Starck Contact Email: William. R. Lon COP.com Authorized Title: CTD Director Contact Phone: 263-4372 Authorized Signature: Date: . 6-12 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: �'' 50- W-1002CJ - —00 Date: Vr (p ' requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed urethan , gas hydrates, or gas contained in shales: ,--/ Other: �-r,57 to Q. SD D p 5 r Samples req'd: Yes ❑ NoRT Mud log req'd: Yes ❑r� No Lw .8C9p �q�Yl vl et✓Pre✓ek, 2gV0P,5T measures: Yes No EJDirectional svy req'd: Yes tYJ No E] A ✓a /-in hC G td a o .9-A-c,2s o iSlb,pacing ezcr(ption req'd: Yes ❑ NoR Inclination -only svy req'd: Yes ❑ Nov p", )'O al l0 /-✓ �-At'C re 1 e.- GF j o i it t is b -c' Post initial injection MIT req'd: Yes ❑ No J"5 q ru n te-d t%c luttrrtl. locivrtnfi Gkl5/7a trt u)0"'y APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 7ouomn rorm ano �/ Form 10-401 sed 2b nTJiJrti1ys{✓a�l f�r 24 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 ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill three laterals out of the newly worked over KRU 2K-04 (PTD# 188-119) well using the coiled tubing drilling rig, Nabors CDR3-AC. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. The work is scheduled to begin September 2017. The objective will be to drill three laterals KRU 2K -04L1, 2K 04L1-01, and 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 -04L1-01, and 2K -04L1-02 - Detailed Summary of Operations - Directional Plans for 2K -04L1. 21K-041-1-01. and 21K-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 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 -04L1, 2K- 041-1-01, 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-041-1-02 - Detailed Summary of Operations - Directional Plans for 2K -04L1, 2K-041-1-01, 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 Kuparuk CTD Laterals 2K-041-1, 2K -04L7-01, & 2K-041-1-02 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(t) 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)(8)).................................................................................................................................................. 3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(0)).................................................................................................................................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4 11. Seabed Condition Analysis............................................................................................................4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14)) ............................. ...... -........................................................................................................... 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 2K-041-1, 2K-041-1-01, & 2K-041-1-02 laterals.........................................................6 Attachment 2: Current Well Schematic for 2K-04............................................................................................................6 Attachment 3: Proposed Well Schematic for 21K-041-1, 2K-041-1-01, & 2K-041-1-02 laterals...........................................6 Page 1 of 6 August 31, 2017 PTD Application: 2K -04L1, 2K-041_1-01, & 2K -04L1-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b)) The proposed laterals described in this document are 2K-041_1, 2K-041_1-01, and 2K-041_1-02. All laterals will be classified as "Development -Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 forms for surface and subsurface coordinates of the 2K -04L1. 2K -04L1-01, 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. S. 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 -04L1-01 10,580' 13,600' 5,996' 5,942' 2W, 4.7#, L-80, ST -L slotted liner; aluminum billet on to 2K -04L7-02 10,475' 13,000' 5,972' 5,943' 2W, 4.7#, L-80, ST -L slotted liner; de to ment sleeve on to Page 2 of 6 August 31, 2017 PTD Application. [1K-041-1, 2K-041-1-01, & 21K-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 Tubing3-1/2" 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' ND) Using MPD Page 3 of 6 August 31, 2017 Pumps On 1.5 bpm) Pumps Off A -sand Formation Pressure 11.9 3784 psi 3784 psi Mud Hydrostatic 8.7 2772 psi 2772 psi Annular friction i.e. ECD, 0.080psi/ft) 838 psi 0 psi Mud + ECD Combined no chokepressure) 3610 psi underbalanced -174psi) 2772 psi underbalanced -1012psi) Target BHP at Window 12.0 3824 psi 3824 psi Choke Pressure Required to Maintain Target BHP 214 psi 1052 psi Page 3 of 6 August 31, 2017 PTD Application. 2K -04L1, 2K-041-1-01, & 2K -04L1-02 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 2K-04 is a Kuparuk A -sand and C -sand producer equipped with 3-1/2" tubing and 7" production casing. A recent rig workover installed a 7" production tieback, new 3-1/2" tubing, and a tandem wedge design to facilitate three CTD laterals. The laterals will target the A -sands to the north and southeast of the 2K-04 parent wellbore. The project will improve the ultimate recovery in the parent pattern as well as provide offtake from a premised sheltered resource on the eastern side of a large 90 ft. sealing fault. Prior to CTD operations, slickline will conduct a dummy whipstock drift and E -line will obtain a jewelry log and set 3-1/2" Northern Solutions Whipstock at 10482' MD. The 2K -04L1 lateral will exit the 3-1/2" tubing and 7" casing at 10482' MD and TD at 13850' MD, targeting the A3 and A4 sands. It will be completed with 2-3/8" slotted liner from TD up to 10875' MD with an openhole anchored aluminum billet for kicking off the 2K -04L1-01 lateral. The 2K -04L1-01 lateral will drill north to a TD of 13600' MD targeting the A3 and A4 sands. It will be completed with 2-3/8" slotted liner from TD up to 10580' MD with an aluminum billet for kicking off the 2K -04L 1-02 lateral. The 2K -04L1-02 lateral will drill southeast to a TD of 13000' MD targeting the A4 sand. It will be completed with 2-3/8" slotted liner from TD up to 10475' MD with a deployment sleeve back into the 3- 1/2" tubing. Pre -CTD Work 1. Perform RWO to install new 3-1/2" tubing and tandem wedge design. 2. RU Slickline: Perform a dummy whipstock drift. 3. 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-041_1, 2K-041-1-01, & 2K-041-1-02 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 SB14P, 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 2W rams will provide secondary well control while running 2%" liner. Page 5 of 6 August 31, 2017 PTD ADDllcatlon: tK-04L1. 2K-041-1-01. & 2K-041-1-02 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 2K -04L1 11,930' 2K -04L1-01 11,970' 2K -04L1-02 11,970' - Distance to Nearest Well within Pool Lateral Name Distance Well 2K -04L1 400' 2K-04 21K-041-1-01 920' 21V-22 21K-041-1-02 920' 2M-22 16. Attachments Attachment 1: Directional Plans for2K-04L1, 2K -04L1-01, & 2K -04L1-02 laterals. Attachment 2: Current Well Schematic for 2K-04 Attachment 3: Proposed Well Schematic for 2K-04L1,2K-04L1-01,&2K-04L1-02laterals. Page 6 of 6 August 31, 2017 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-04 2K -04L1-02 Plan: 2K-04L1-02_wp02 Standard Planning Report 24 July, 2017 BT�a GHES GE company ConocoPhillips Database: EDTAlaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: 2K-04 Wellbore: 2K-0411-02 Design; 2K-04L1-02_wp02 ConocoPhillips Planning Report 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 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 Zone: Alaska Zone 04 Using geodetic scale factor BA ER BAT a GE company site Kuparuk 2K Pad Site Position: Northing: 5,938,600.18 usft Latitude: 70° 14'36.519 N From: Map Easting: 498,310.17 usft Longitude: 150'0'49A33W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: -0.01 ° Well 2K-04 Audit Notes: Well Position +N/ -S 0.00 usft Northing: 5,938,525.46 usft Latitude: 70° 14'35.784 N +N/ -S +E/ -W 0.00 usft Easting: 498,310.06 usft Longitude: 150° 0'49.136 W Position Uncertainty 0.00 0.00 usft Wellhead Elevation: usft Ground Level: 118.50 usft Wellbore 2K -04L1-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (°) inn BGGM2017 10/1/2017 17.30 80.84 57,474.37 Design 2K-04L1-02_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 10,580.00 Vertical Section: Depth From (TVD) +N/ -S +EAW Direction Dogleg (usft) (usft) (usft) (°) Depth -118.50 0.00 0.00 10.00 Plan Sections Measured TVD Below Dogleg Build Tum Depth Inclination Azimuth System +N/.S +E/ -W Rate Rate Rate TFO (usft) (1 11 (usft) (usft) (usft) (°1100ft) ('1100ft) (°1100ft) (°) Target 10,58000 95.99 290.61 5,995.91 3,628.69 -7,053.35 0.00 0.00 0.00 0.00 10,650.00 95.10 322.25 5,988.98 3,669.54 -7,108.88 45.00 -1.26 45.20 90.00 10,850.00 90.00 52.25 5,977.65 3,847.77 -7,085.64 45.00 -2.55 45.00 90.00 11,050.00 90.00 66.25 5,977.65 3,949.77 -6,914.19 7.00 0.00 7.00 90.00 11,250.00 91.45 52.32 5,975.11 4,051.65 5,742.68 7.00 0.72 -6.96 276.00 11,550.00 91.35 31.32 5,967.69 4,273.90 -6,543.81 7.00 -0.03 -7.00 270.00 11,900.00 91.23 6.81 5,959.68 4,602.10 5,430.39 7.00 -0.03 -7.00 270.00 12,000.00 91.22 359.81 5,957.54 4,701.85 -6,424.62 7.00 -0.01 -7.00 270.00 12,300.00 90.07 20.78 5,954.13 4,995.35 -6,371.29 7.00 -0.39 6.99 93.00 12,500.00 90.06 6.78 5,953.90 5,189.11 -6,323.77 7.00 0.00 -7.00 270.00 13,000.00 92.35 41.72 5,943.05 5,637.86 -6,121.71 7.00 0.46 6.99 86.00 712412017 12.59: 10PM Page 2 COMPASS 5000.14 Build 85 i ConocoPhillips BA�CER ConocoPhillips Planning Report TjUGHES a GEcomparry 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 @ 154.00usit (2K-04) Site: Kupamk 2K Pad North Reference: True Well: 2K-04 Survey Calculation Method: Minimum Curvature Wellborn: 21K-041-1-02 Map Map Design: 2 K -041-1-02_W pO2 System +N/ -S Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) N (I (usft) (usft) (usft) (usft) (-1100ft) (1) (usft) (usft) 10,580.00 95.99 290.61 5,995.91 3,628.69 -7,053.35 2,348.76 000 0.00 5,942,155.37 491,258.2311 TIPIKOP 10,600.00 95.91 299.66 5,993.84 3,637.13 -7,071.34 2,353.95 45.00 90.00 5,942,163.81 491,240.24 10,650.00 95.10 322.25 5,988.98 3,669.54 -7,108.68 2,379.39 45.00 90.94 5,942,196.23 491,202.92 Start 46 dls 10,700.00 94.71 344.83 5,984.64 3,713.85 -7,130.72 2,419.19 45.00 90.00 5,942,240.54 491,180.88 10,800.00 91.95 29.83 5,978.51 3,810.30 -7,118.26 2,516.34 45.00 91.96 5,942,336.98 491,193.37 10,850.00 90.00 52.25 5,977.65 3,847.77 -7,085.64 2,558.90 45.00 94.72 5,942,374.43 491,225.99 End 45 dls, Start 7 dls 10,900.00 90.00 55.75 5,977.65 3,877.15 -7,045.20 2,594.86 7.00 90.00 5,942,403.80 491,266.44 11,000.00 90.00 62.75 5,977.65 3,928.25 -6,959.31 2,660.10 7.00 90.00 5,942,454.87 491,352.33 11,050.00 90.00 66.25 5,977.65 3,949.77 -6,914.19 2,689.13 7.00 90.00 5,942,476.38 491,397.45 4 11,100.00 90.37 62.77 5,977.49 3,971.28 -6,869.06 2,718.15 7.00 -84.00 5,942,497.89 491,442.58 11,200.00 91.09 55.81 5,976.22 4,022.32 -6,783.14 2,783.33 7.00 -84.01 5,942,548.90 491,528.50 11,250.00 91.45 52.32 5,975.11 4,051.65 -6,742.68 2,819.24 7.00 -84.10 5,942,578.22 491,568.97 6 11,300.00 91.45 48.82 5,973.85 4,083.39 -6,704.07 2,857.20 7.00 -90.00 5,942,609.94 491,607.57 11,400.00 91.42 41.82 5,971.34 4,153.63 -6,633.03 2,938.72 7.00 -90.09 5,942,680.17 491,678.62 11,500.00 91.38 34.82 5,968,89 4,232.02 -6,571.08 3,026.67 7.00 -90.26 5,942,758.53 491,740.58 11,550.00 91.35 31.32 5,967.69 4,273.90 -6,543.81 3,072.65 7.00 -90.44 5,942,800.40 491,767.86 6 11,600,00 91.35 27.82 5,966.51 4,317.37 -6,519.15 3,119.74 7.00 -90.00 5,942,843.86 491,792.53 11,700.00 91.33 20.82 5,964.17 4,408.42 -6,478.01 3,216.55 7.00 -90.08 5,942,934.89 491,833.69 11,800.00 91.29 13.81 5,961.88 4,503.80 -6,448.28 3,315.65 7.00 -90.25 5,943,030.26 491,863.44 11,900.00 91.23 6.81 5,959.68 4,602.10 -6,430.39 3,415.56 7.00 -90.41 5,943,128.54 491,881.35 7 12,000.00 91.22 359.81 5,957.54 4,701.85 -6,424.62 3,514.79 7.00 -90.00 5,943,228.28 491,887.14 8 12,100.00 90.85 6.80 5,955.73 4,801.60 -6,418.85 3,614.03 7.00 93.00 5,943,328.02 491,892.93 12,200.00 90.46 13.79 5,954.59 4,899.92 -6,400.99 3,713.96 7.00 93.13 5,943,426.33 491,910.81 12,300.00 90.07 20.78 5,954.13 4,995.35 -6,371.29 3,813.09 7.00 93.21 5,943,521.74 491,940.52 9 12,400.00 90.07 13.78 5,954.01 5,090.77 -6,341.61 3,912.23 7.00 -90.00 5,943,617.15 491,970.23 12,500.00 90.06 6.78 5,953.90 5,189.11 -6,323.77 4,012.16 7.00 -90.01 5,943,715.47 491,988.08 10 12,600.00 90.55 13.76 5,953.36 5,287.44 -6,305.95 4,112.10 7.00 86.00 5,943,813.79 492,005.93 12,700.00 91.03 20.75 5,951.98 5,382.87 -6,276.31 4,211.23 7.00 86.04 5,943,909.20 492,035.59 12,800.00 91.49 27.73 5,949.78 5,473.98 -6,235.29 4,308.07 7.00 86.13 5,944,000.29 492,076.62 12,900.00 91.93 34.72 5,946.78 5,559.40 -6,183.50 4,401.18 7.00 86.29 5,944,085.69 492,128.43 13,000.00 92.35 41.72 5,943.05 5,637.86 -6,121.71 4,489.18 7.00 86.50 5,944,164.12 492,190.23 Planned TD at 13000.00 7242017 12:59.IOPM Page 3 COMPASS 5000.14 Build 85 Targets ConocoPhillips Planning Report 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 +N4S +El -W Northing Easting -Shape (1) C) (usft) (usft) (usft) (usft) (usft) 2K-04L1-02_TO4 0.00 0.00 5,954.00 5,155.231,133,827.19 5,943,426.00 1,632,025.00 - plan misses target center by 1139949.00usft at 13000.00usft MD (5943.05 TVD, 5637.86 N. -6121.71 E) Point 2K -041-1-02_T02 0.00 0.00 5,969.00 4,148.071,133,528.39 5,942,419.00 1,631,726.00 - plan misses target center by 1139651.07usft at 13000.00usft MD (5943.05 TVD, 5637.86 N, -6121.71 E) - Point 2K-0411 Faulti 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 1139916.51 usft at 13000.00usft MD (5943.05 TVD, 5637.86 N, -6121.71 E) - Rectangle (sides W1.00 1-11,000.00 DO.00) 2K-04 CTD Polygon Nor 0.00 0.00 0.00 ConocoPhillips Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kupamk 2K Pad Well: 2K-04 Wellbore: 2K-041-1-02 Design: 2K-04111-02 WpO2 Targets ConocoPhillips Planning Report 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 +N4S +El -W Northing Easting -Shape (1) C) (usft) (usft) (usft) (usft) (usft) 2K-04L1-02_TO4 0.00 0.00 5,954.00 5,155.231,133,827.19 5,943,426.00 1,632,025.00 - plan misses target center by 1139949.00usft at 13000.00usft MD (5943.05 TVD, 5637.86 N. -6121.71 E) Point 2K -041-1-02_T02 0.00 0.00 5,969.00 4,148.071,133,528.39 5,942,419.00 1,631,726.00 - plan misses target center by 1139651.07usft at 13000.00usft MD (5943.05 TVD, 5637.86 N, -6121.71 E) - Point 2K-0411 Faulti 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 1139916.51 usft at 13000.00usft MD (5943.05 TVD, 5637.86 N, -6121.71 E) - Rectangle (sides W1.00 1-11,000.00 DO.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 1140008.27usft at 13000.00usft MD (5943.05 TVD, 5637.86 N, -6121.71 E) - Polygon Point 5,984.00 1.00 1.00 5,941,051.00 1,631,974.00 2K-04L1-02_TO5 0.00 0.00 5,942.00 5,628.321,133,986.10 5,943,899.00 1,632,184.00 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 Point4 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 5942,270.98 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 -054.67 5,942,669.98 Point 16 0.00 -1,212.23 -395.71 5,942,832.98 Point 17 0.00 -823.17 -315.81 5,943,221.98 Point 18 0.00 -413.10 -214.91 5,943,631.99 Point 19 0.00 0.00 0.00 5,944,045.00 1,632,069.00 1,632,069.00 1,632,368.01 1,632,260.02 1,632,118.05 1,632,066.06 1,631,975.08 1,631,812.09 1,631,625.10 1,631,402.10 1,631,270.11 1,631,069.11 1,631,007.10 1,631,145.09 1,631,507.08 1,631,614.07 1,631,673.06 1,631,753.04 1,631,854.02 1,632,069.00 2K-04L1_Fault1 0.00 0.00 5,984.00 2,778.981,133,775.72 5,941,050.00 1,631,973.00 - plan misses target center by 1139901.02usft at 13000.00usft MD (5943.05 TVD, 5637.86 N. -6121.71 E) 5,941,859.00 - Polygon - plan misses target center by 1139336.53usft at 13000.00usft Point 5,984.00 0.00 0.00 5,941,050.00 1,631,973.00 Point 5,984.00 1.00 1.00 5,941,051.00 1,631,974.00 2K-04L1-02_TO5 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 1140107.81 usft at 13000.00usft MD (5943.05 TVD, 5637.86 N, -6121.71 E) - Point 2K-04 CTD Polygon Soy 0.00 0.00 0.00 3,587.941,133,197.48 5,941,859.00 1,631,395.00 - plan misses target center by 1139336.53usft at 13000.00usft MD (5943.05 TVD, 5637.86 N, -6121.71 E) - Polygon Point 0.00 0.00 0.00 5,941,859.00 1,631,395.00 Point 0.00 233.02 -21.07 5,942,092.00 1,631,373.98 Point 0.00 190.92 -365.09 5,942,049.98 1,631,029.99 Point4 0.00 -31.14 -480.04 5,941,827.97 1,630,915.00 Point 0.00 -365.14 -378.94 5,941,493.98 1,631,016.02 Point 0.00 -587.11 -187.86 5,941,271.99 1,631,207.03 Point 0.00 -954.98 420.30 5,940,904.02 1,631,815.04 Point 0.00 -1,114.91 732.38 5,940,744.04 1,632,127.06 Point 0.00 -1,287.86 961.45 5,940,571.05 1,632,356.07 Point 10 0.00 -1,357.85 1,041.48 5,940,501.05 1,632,436.07 Point 11 0.00 -1,478.85 1,066.51 5,940,380.06 1,632,461.07 Point 12 0.00 -1,874.91 1,007.62 5,939,984.05 1,632,402.10 BA GHES GEcompany Latitude Longitude 70" V32.940 N 140" 55'24.450 W 70° 1'23.595 N 140° 55'37,240 W 70° V9.938 N 140° 55'36.060 W 70° V3&889 N 140° 55'20.559 W 70° 1'9.938 N 140° 55'36.060 W 70° 1' 37.303 N 140° 55' 17.915 W 70° 1'18.638 N 140° 55'49.030 W 72412017 12:59: fOPM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips BA_ ICER ConocoPhillips Planning Report U*HES aGEcempany Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project Kuparuk River Unit Site: Kuparuk 2K Pad Well: 21K-04 Wellbore: 2K-0411-02 Design: 2K-041-1-02_vsp02 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2K-04 Mean Sea Level 2K-04 @ 154.00usft (2K-04) True Minimum Curvature Point 15 0.00 -2,562.91 1,267.83 5,939,296.06 1,632,662.13 Point 16 0.00 -1,815.80 1,382.64 5,940,043.07 1,632,777.09 Point 17 0.00 -1,437.76 1,395.54 5,940,421.07 1,632,790.08 Point 18 0.00 -1,162.74 1,350.45 5,940,696.07 1,632,745.05 Point 19 0.00 -857.79 1,066.34 5,941,001.06 1,632,461.04 Point 20 0.00 -499.93 430.18 5,941,359.02 1,631,825.02 Point 21 0.00 -278.01 69.08 5,941,581.00 1,631,464.01 Point 22 0.00 0.00 0.00 5,941,859.00 1,631,395.00 21K-0411 Fault2 M 0.00 0.00 0.00 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 1140363.46usft at 13000.00usft MD (5943.05 TVD, 5637.86 N, -6121.71 E) -6,430.39 - Rectangle (sides W1.00 1-11,000.00 DO.00) 12,000.00 5,957.54 4,701.85 -6,424.62 2K -041-1-02_T01 0.00 0.00 5,977.00 3,934.971,133,187.40 5,942,206.00 1,631,385.00 70" V22.023 N 140" 55'47.835 W - plan misses target center by 1139310.38usft at 13000.00usft MD (5943.05 TVD, 5637.86 N, -6121.71 E) 5,953.90 - Point -6,323.77 10 13,000.00 5,943.05 21K -0411-02T03 0.00 0.00 5,957.00 4,635.151,133,681.29 5,942,906.00 1,631,879.00 70° 1'28.102 N 140° 55'30S16 W - plan misses target center by 1139803.45usft at 13000.00usft MD (5943.05 TVD, 5637.86 N, -6121.71 E) Hole - Point Depth 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° 1'6.179 N 140° 55 24.757 W - plan misses target center by 1140347.98usft at 13000.00usft MD (5943.05 TVD, 5637.86 N, -6121.71 E) (usft) Name - Polygon (in) Point 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 Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 13,000.00 5,943.05 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +EI -W (usft) (usft) (usft) (usft) Comment 10,580.00 5,995.91 3,628.69 -7,053.35 TIP/KOP 10,650.00 5,988.98 3,669.54 -7,108.68 Start 45 tlis 10,850.00 5,977.65 3,847.77 -7,085.64 End 45 tlis, Stan 7 dls 11,050.00 5,977.65 3,949.77 -6,914.19 4 11,250.00 5,975.11 4,051.65 -6,742.68 5 11,550.00 5,967.69 4,273.90 -6,543.81 6 11,900.00 5,959.68 4,602.10 -6,430.39 7 12,000.00 5,957.54 4,701.85 -6,424.62 8 12,300.00 5,954.13 4,995.35 -6,371.29 9 12,500.00 5,953.90 5,189.11 -6,323.77 10 13,000.00 5,943.05 5,637.86 -6,121.71 Planned TD at 13000.00 7242017 12:59: fOPM Page 5 COMPASS 5000.14 Build 85 r� E' ppe�� sgg As L ¢ A 44 \ INEEMEN a J� 'rn� J� p 0 0 a r o� w f 5 � V0a� H mOe� v CdnN..a O� 6HUJW pin tormm�a mmoAM a 1ntO Za0mmm rM�Nr�Q UIN O�N'OaT OVNV�+]N Of 1■..■■.EMENEM 9 �M M�Nm�00VV]m�OC 0■.I1. � v � '�4Or op0000000000 o �� pop0000000 o,c Y M Fo�oo,c000.ti m m N N N N O N m N V 010 0 0 0 0 0 0 0 0 0 0 m00000000000 l po.d,1r;nn1rn1 ..... 0 90111111111- W fO�]tONti M mOhVfVMGV�-f�i� ■' 1 MEN IS_ ■«.%!.�.\ ANN (/J OfVrrNOOhN�O .(O hl�r�0 O1v WM�-W Q � 0■ ZN''OfrOI�MfV^h01` W �, �fNO Or 0 (OOmTONcOp ":Z2 IBMMENm $ .■..moll �ha6 vinan.r ,+iM t1n �OCI Of Of p,q 00�0O�0 1.■m®.,f LN Vf Y)OhNh�9 of htAh ; ■.■.■■■li $ Z� �N4n V]NN��4J'ON �(ONNNMMmOrrr 1...=......,l N OO fV NSD fV �-fpOOtO� . N�N�ONM �N O V C g cl00R hMNcR 1N v O O C M N N O M 1.....�......,l o 45]5 W O 1..............,l +...... Q o 0 0 0 0 0 0 0 0 o C o 0 0 0 0 ONhhan v)00o00 loommommoommommol 1 �NMO Nip rtp OaO' 1■■■■■■■■■■■■■■.1 ZO N 5c L-ZO-1 00-N .....a. ........_ cu!Msn OS£) (+)qlloW(-)4xnoS -3500 -3850 -4200 -4550 -4900 5250 560( 595( 63IX 665[ Ll 900( ^ 735[ 3 ]]00 8050 8400 8]50 9100 9450 0 (u!/)Jsn SL) q;dad !eo!paA any I a J� 'rn� J� p 0 0 a r o� w f 5 � V0a� H mOe� v CdnN..a O� 6HUJW pin tormm�a mmoAM a 1ntO Za0mmm rM�Nr�Q UIN O�N'OaT OVNV�+]N Of 9 �M M�Nm�00VV]m�OC � v � '�4Or op0000000000 o �� pop0000000 o,c Y M Fo�oo,c000.ti m m N N N N O N m N V 010 0 0 0 0 0 0 0 0 0 0 m00000000000 l po.d,1r;nn1rn1 3a-(f°pmm`'tm 0 W fO�]tONti M mOhVfVMGV�-f�i� n�91q I? �9bb J mM 4]25 Wm (/J OfVrrNOOhN�O .(O hl�r�0 O1v WM�-W Q � ZN''OfrOI�MfV^h01` W �, �fNO Or 0 (OOmTONcOp ":Z2 m $ �ha6 vinan.r ,+iM t1n �OCI Of Of p,q 00�0O�0 LN Vf Y)OhNh�9 of htAh G� $ Z� �N4n V]NN��4J'ON �(ONNNMMmOrrr N OO fV NSD fV �-fpOOtO� N�N�ONM �N O V C g cl00R hMNcR 1N v O O C M N N O M o 45]5 W O +...... Q o 0 0 0 0 0 0 0 0 o C o 0 0 0 0 ONhhan v)00o00 1 �NMO Nip rtp OaO' ZO N 5c L-ZO-1 00-N 0 (u!/)Jsn SL) q;dad !eo!paA any I 48]5 4800 0 4]25 80 4 m $ 4650 $ 45]5 1 4500 5c L-ZO-1 00-N .....a. ........_ 4425 4350 42]5 4200 4125 4050 4�VB-J 3975 900 __.. 3825 3]50 36]5 36M 3525 _._..__.__...._. 3450 33]5 3300 3225 3150 0]5 3000 :01711 1v0 xz .............._ _... 925 2850 2]]5 700 101 -19 -NZ.... 2625 550 Y q _ 24]5 N �... � k N ..., - 2400 2325 2250 — 1]5 J >< 2100 C k — 025 0 (u!/)Jsn SL) q;dad !eo!paA any I ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2K Pad Site Error: 0.00 Left Reference Well: 2K-04 Well Error: 0.00 usft Reference Wellbore 2K-0411-02 Reference Design: 2K-041-1-02_wp02 Baker Hughes INTEQ Travelling Cylinder Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: BAFUGHES a GEmmpany Well 2K -D4 2K-04 Q 154.00usft (2K-04) 2K-04 @ 154.00usft (2K -D4) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Reference 2K-0411-02_wp02 Filtertype: GLOBAL FILTER APPLIEDAll wellpaths within 200'+100/1000 of reference To Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 10,580.00 to 13,000.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,496.45 usft Error Surface: Pedal Curve Survey Tool Program Date 7/20/2017 From To (usft) (usR) Survey (Wellbore) Tool Name Description 200.00 10,400.00 2K-04 (2K-04) BOSS -GYRO Sperry -Sun BOSS gyro multishot 10,400.00 10,580.00 2K-041_1_wp02(2K-04L7) MWD MWD -Standard 10,580.00 13,000.00 2K-0411-02_wp02(2K-0417-02) MWD MWD -Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usR) (usft) Name ("1 (") 13,000.00 6,097.05 2 3/8" 2-3/8 3 Summary Site Name Offset Well - Wellbore - Design Kuparuk 2K Pad 2K-01 - 2K-01 - 2K-01 2K-02 - 2K-02 - 2K-02 2K-03 - 2K-03 - 2K-03 2K-04 - 2K-04 - 2K-04 2K -04 -2K -041_1 -2K -04L7 wp02 2K -04-21K-041.1-01 - 2K-04L7-01_wp04 2K-05 - 2K-05 - 2K-05 2K-06 - 2K-06 - 2K-06 2K-07 - 2K-07 - 2K-07 2K-08 - 2K-08 - 2K-08 2K-08 - 2K -08A- 2K -08A 2K-08 - 2K-08APB1 - 2K-08APB1 2K-08 - 2K-08APB2 - 2K-08APB2 2K-08 - 2K-08APB3 - 2K-08APB3 2K-08 - 2K-08BPB1 - 2K-08BPB7 2K-08 - 2K-08BPB2 - 2K-08BPB2 2K-08 - 2K-08BPB3 - 2K-08BPB3 2K-09 - 2K-09 - 2K-09 2K-09 - 21K-091_1 - 21K-091_1 2K-09 - 2K-09Li-01 - 2K-0911-01 2K-10 - 2K-10 - 2K-10 2K-11 - 2K-11 - 2K-11 21K-11 - 2K -11A - 2K -11A 2K-11-2K-11AL1-2K-11AL1 2K-11 - 2K-11APB1 - 2K-11APB1 2K-12 - 2K-12 - 2K-12 2K-26 - 2K-26 - 2K-26 Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) 10,710.00 10,750.00 105.58 11,272.85 9,250.00 1,318.40 12,190.83 12, 825.00 1.32 No -Go Allowable Distance Deviation Warning (usft) from Plan (usft) Out of range Out of range Out of range 24.59 91.16 Pass - Major Risk 7.47 1,317.72 Pass - Minor 1/10 1.31 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 CC _ Min rsmtm to ranter Aiatanra or mvement mint SF - min aanaratim faMnr FS - min ellinae aanaratim 720,12017 3:52:42PM Page 2 COMPASS 5000.14 Build 85 �- Baker Hughes INTEQ BAKER ConocoPhillips Travelling Cylinder Report HUGHES a GE company Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2K Pad Site Error: 0.00 usft Reference Well: 2K-04 Well Error: 0.00 usft Reference Wellbore 2K-041-7-02 Reference Design: 2K -04L1-02 wpO2 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 2K-04 2K-04 Q 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 200-9OSSGYRO Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Semi Major Asia Offset Well - Wellbore -Design (usft) (usft) (usft) (usft) Kuparuk 2K Pad Measured Vertical Measured Vertical Reference 2K-28 - 2K -28A - 2K -28A Toolrace+ Ofrset Wellbore Centre Casing- Can[rem Out of range 2K-28 - 2K-28AL1 - 2K-28AL7 Depth Depth Depth Depth Out of range 2K-28 - 2K-28AL1 PB1 - 2K-28AL7 P81 Anmuta +N/S +Vw Hole arse Centre Out of range 2K-28 - 2K-28AL1 PB2 - 2K-28AL1 PB2 (usft) just) (sent (usft) Out of range 2K-28 - 2K-28APB1 - 2K-28APB1 11) (uenl here ('7 (usft) Out of range 2K-29 - 2K-29 - 2K-29 10.58934 6,148.94 10,60000 6,17]34 Out of range 2K-34 - 2K-34 - 2K-34 92.18 3,644.35 4.059.61 3 30.95 Out of range 2K-34 - 2K-341_1 - 2K-341_1 10,613.69 6146.44 10,62500 6.187.15 Out of range 2K-34 - 2K-34PB1 - 2K-34PB1 107.91 3,657.64 4,078.37 3 43.01 Out of range Offset Design Kuparuk 2K Pad- 2K -04 -2K -04-2K-04 enter sae Error: 0.00 sell Survey Program: 200-9OSSGYRO Rule Assigned: Major Risk Offset Well Error: 000 sell Reference enter Semi Major Asia Measured Vertical Measured Vertical Reference Mr., Toolrace+ Ofrset Wellbore Centre Casing- Can[rem No Go Allowable blaming Depth Depth Depth Depth Anmuta +N/S +Vw Hole arse Centre Distance Deviation (usft) just) (sent (usft) (usal (sea) 11) (uenl here ('7 (usft) (ustl juin) 10.58934 6,148.94 10,60000 6,17]34 0.77 3.89 92.18 3,644.35 4.059.61 3 30.95 15.37 19.77 Pass - Major Risk 10,613.69 6146.44 10,62500 6.187.15 0.78 441 107.91 3,657.64 4,078.37 3 43.01 1742 32.14 Pass - Major Risk 10,038.11 61x406 10,65000 8,196.89 0,78 494 12835 3.67091 -7.09719 3 5397 2013. 4391 Pass - Major Risk 10,660.58 6.142.04 10,675.00 6.206.59 079 sale 14508 3.684.16 -7,116.04 3 6485 22.19 55.35 Pass - Major Risk 10,679.97 6,140.33 10)00.00 6,216.29 0,79 5.99 162.50 3,697.41 4,13489 3 7677 23.51 66,39 Pass - Major Risk 10.698.33 6,138.94 10,725.00 6,225.99 080 6.51 177.87 3.71085 -7,153.75 3 9030 2425 77.90 Pass -Major Risk 10710.00 8.137.83 10]50.00 6235.69 0.80 Tot -169.04 3.72390 -7.17280 3 105.58 24.59 91.16 Pass- Major Risk, CC, ES, SF 10,721.12 8,136.97 10,775.00 6,245.39 001 7.57 .150.23 3,737.15 4,191A5 3 12248 2470 108.43 Pass - Major Risk 10,73000 6.136.32 10,800.00 6.255.09 081 see -14945 3.75040 -7,21030 3 140.76 2470 123.52 Pass - Major Risk 10,738.12 6,135,75 1D.W5.00 6.264]9 0.81 8.62 -141.84 3,76365 -7.229.15 3 160.17 2454 141.97 Pass Major Risk 10,74461 6,135.31 10,050.00 6.274.49 0.01 9.14 -135.66 3,776.90 -7,248.00 3 180.40 24.36 16154 Pass -Major Risk 11,272,05 6,128.53 9,250.00 5,529.04 0.86 0,00 113.71 3,147.07 -5,992.90 3 11310.40 1728 1,307.90 Pass - Major Risk 11,277.40 6.128.42 9,225.00 5.517.34 0.88 000 11328 3,13947 -5.97271 3 1,340.65 17.31 1.330.10 Pass -Major Risk 11,281.93 6.12830 9,200.00 5,504.96 0.07 000 112.06 3.131.95 -5.952.33 3 1,352.91 17.37 1,352.31 Pass -Major Risk 11,286.30 0.128.19 9,175.00 5,492.82 0.87 000 11246 3,12446 -5,93192 3 1,385.21 17,43 1,37456 Pass -Major Risk 11,30000 6,127.85 9075.00 5.44296 087 000 111.16 soaki -5.85058 3 1.475.14 1160 1.46132 Pass - Major Risk 11,300.00 6127.85 9.100.00 5,455.41 0.87 000 111.23 3,101.81 5,870.86 3 1,452.55 17.60 1,441]3 Pass - Major Risk 11,300.00 8,12185 9,125.00 5,46185 087 0.00 111.31 3,109.39 5,891.19 3 1,430.05 1160 1,41923 Paas - Major Risk 11,30000 6,127.85 9,150.00 5,480.25 087 0.00 111.39 3.118.94 -5,91154 3 140166 1180 1.396.84 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 7202017 3:52:42PM Page 3 COMPASS 5000.14 Build 85 (m>az)vs000 KL Vo -Az Ilia6cau6[ Nc (UI/4sn ODE)(+)iSeg/(-)isam 'JOZI- O011 0081 OOIZ OO6Z OOLZ- 000 001,1 00W 006 00 4 0056 0081 U015- 0005 OOLS 0009- 000 0099- 0009 01 10•L- OOaG NIS- 0068- OJLS 0011 01AG 011f 91eb-00 11 0t1sUtIO OIFOOIII- \ 0 Y LY[ A __t afiVVc IVII Y.Iry I'M., 00C K / j I{IdVxl M xrA; \ N / J tl'IXII W✓'MrWC 09 _ i M 006 .f611Y ,IF a`rV P - OOZI • W 4_V YII(yINyN NS r.I. 1 - tlU-WrrMll'W� 3X VNa Im, I.--0051 nv v11x O•eYM: _ _ 11Afi . INa�NZ � � 110081 oul_ + t I`.a - OOLZ S mot _ � �mu a OOOC O om �. nv� _— __� -- d {{a t... 009C �� M •A rYI 1 W � nu � I riV H0. 1 LL�N:M1UY Irr y A Im 1 � � � 7 I �OOZb uoe it �. 1 10086 0065 ' 8199n-iirrNtu Nz -...- OOLS IZ — '1n YAZl1OAZ - 0009 TY YC..1 Ill� umt '.i r I I 19 L i 1 li r ___ la,_. ni0•i _-__ 0099 .. � , ..�. - —La �.�. J 1L __.0069 I.141'I'Il'J61'I l: \'t'I'IIJf I'Il: 1101-11: JJI-I li lo-llr•I-IIY/UI-HL BIIIaV!!J wIYIIY!N %YdW upin�al'J L1ceWoe9 Irv^n Aue0wo>39¢ IIPNiI MIPY510f xz--ft 1040 ParwAY Iauw�rw (4100'NZ1V0•NZ1 ZOdrn-4100'NZ �ueld Sd�II�C�J/�1f11 OD s3H9ft 3000'NO09PRs nwa(eN alp 00'OOhol OW uo eI1 aov «w aw 160 -NZ uoellaM (MAd WIN a "Iz l0k)Ia0W0/1 ilM9wlr[5 vldr0¢ MNZ :II -M 83 8 wxa i' PNZ IRN W lyNla w o- 0 6o -NZ e1WIleM lualed was anvN w Ped NZ MluednN :9jIS NOI1tlWtlO1N130N3tl3J3tl L1>0-NZ:S11V130 M08113M awn wymq �elpn lwry 11u0 JanIN IIW+edI1N :Jaa(wd OW ,9Lebl ®lalll, to dol OW A99'£L Ol ZOdm L140 -NZ OW ,099'0L 0 lallle to dol OW ,009'£L Ol Vodm L0 -L140 -NZ OW SLV m @,n- ao all OW.000EL Ol ZOdm ZO-Ll40-NZ (OI ulw „E LBZ) OW ,6090L le alddlu-X „Z/L-E OW,9640L Rlgwossy96p9MuoOnloSw94PON (OI u!w „£ L8'Z) OW ,6940E le alddlu-X ,.Z/L-E O1N,4940L Rlgwasstla6p9MuollnloSW94PON (OI ulw „£L8'Z) OW ,44EOL le alddlu-SO mweo OW ,6ZZOL @7 N9d /MJ9N3ed 1Hd JOWEI OW ,94 LO L '.9946',4 L98',96 LL ',Z099',9LLE @7 slwpuew 811 se6 EJWW wweO „Z/L-E aOepns of 6u!gnl Pis 3n3 08-1 #E"6 ,.Z/L-E ,9£8b L 0 aogs 99-f #9Z O W ,ZZso' L - at"o L spad pues-t V L1wI ON O W ,4Zh'0 L-,ZOVO L sped Pues-4O OW.9204 aogs 99-f #9£ „8/9-6 OW .94EZ @>loega.108-1 #9Z „L ollewag3S (Ilo Pasodold 40-)IZ OW SLL KUP Pn7D 2K-04 �-yYin'{ a.A.ttl �� Well AtlribuA Max AnglB TO yoyyta. Inc. WNI, APYDWI FkIE Name WNIEare-Us ncl l•1 MD (nNBI -lam I-, .._-_._ _ 501032003900 KUPARUK RIVER UNIT PROD 6)1] 10.65000 10.851 14N.1 � �?0 f YIF: vI f II: � I FFi l H4i �]F VDII) • ! If i 4 ] �/f CJ 42 rF] Annodlbn OepM (BNB) En,f OaM E7= AWOMSW Ye1MM eY "I Gafe _..._..._......._.........._.................... ... LWTag Dayont 1Q542.0 Rev Reason: GLV C/08 PULL WRP pGmven ]/D/201] 11gNGER; s1,2-1 astng ngs GTopmrean Gasn9Gascnpwn Opp^) lolin) TaP IBNeI SNDaptn nticS) WEepWrine nlTL lase.nP... CONDUCTOR 1fi 15.062 3fi.o 115.0 115.0 62,50 H40 WELDED Cause oeac,Iptbn OOlinlIDlinl Tap lRNel Set DeP1M1 (nNB) aet Dawn lrV01... WNLen IL.. GrYe Top TnreaY SURFACE 95/8 8921 35.0 4,0284 2,913,31 36 ED J-55 BTC 1 Casing one O011n] mlln) ioP IBNBI SN MPM (ftl(8) SY Depin llVDl-WaYn 14. Grab IFI, PRODUCTION TIEBACK ] 62]8 33,0 2,3452 2,05].1 2800 LAO Hydd1563 Gaelna immi OO Iles] IDlinl TepIMB) SM CapN IRN81 Set OapU jIVD).., WtlLen 11... Gre4e Tap T --it ORIGINAL ] 62]6 2,342.5 10,835.9 6,269.0 26.00 J-55 BTC PRODUCTION Tubing Strings Tubing Description sbmg no._Sbar) I.pmKEg Deptn ln..sn NptnMD14...Il1 Grade Top Cannecnon TUBING-RW0201] last 31/2 2.992 31.1 10,515.3 6,143.2 930L-80 I EUE aid Mad �ti cauOucrOfl: s4.o-11so Completion Details Nominal lD Tap lBK Top IND)I311 Top Incl? gem Na Com lin) E Bid bad 992 SI TC -to -EN, 3-1I2'EU2 31.1 311 02] HANGER Tubing H' ISA SMC, Donom, 3PVG 10,XHA SOWS 63.62 LOCATOR LaCater sub, Baker, GBH -22 (boanm of Waticr spaced 2,992 out 3') FACHACTION PEBACK sib 10,2024 6,007.4 63-62 SEAL Seal Assembly, Baker, 8040(seal Will x 21.71) 2.990 2.342 ASSEMBLY 64 PBR R, Baker 20' 8040 4,000 10,205.5 6,0088 63PB GAauFC 31747 10,228.6 6,0198 63.76 FHLPACKER Packer, Baker47B2FHL 2940 10,344.1 6,0696 64.05 NIPPLE Nipple. Camco2813' DB Profile 2813 10,453.7 6,1174 64]] WEDGE Wedge Assembly, Northern Solutions 2992 ASSEMBLY 10,4666 6,1233 64.99 NIPPLE Nipple,Hallibuurn2.812EXPm8k 2813 SJRME.3sD4Pal 10,494.6 6,134.6 65.37 WEDGE Wedge Assembly, Northam Solutions 2992 ASSEMBLY 10,5094 5,140 It 1 6558 NIPPLE Nipple, Halliburton 2.813'X Prafle 2813 Goa LIFT: ssDeo Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top ITVDI roPIrul TOPOWS) IBNeI 1.1 Ns coinCz Run oam mlinl 10,542.0 6,154.1 1 66.02 FISH Coiled Tubing 2Y long Cllemiwlly cut in rat hole 411]/1990 0.000 GM LIFT; r.10.5 Perforations 8 Slots Spot Dens TOP DVD) BlapprAI Nh. GAS LIFT'. esv° Tap Me) a. Bear (WSJ We) zona Dat as Time coin 10,4020 10,424.0 6,095.0 8,104.8 C4,2K-04 12/11W003 6.0 APERF 2.5"HSD PJ 10,4820 10522.0 6,1294 6,14fi.0 A4,21(-04 QW1998 40 RPERF 2.F HC, 180 deg. Ptmsug, no orient Dos uFr; e,ae4s 10482.0 101522.0 6.129.4 6,146.0 Ad, 2K-04 11/411989 20 (PERE 4' Super Omnikone Ca, 180 tleg. Phasing Mandrel Inserts at GIS LIR: f0,tu8 atl Tap(wo) Valve YW parts. TRO Run N rampage) IIBIB) Mab Madel Opens Sary Type Typo (In) (psi) Run Nle Corn_ 1 3,1743 2,5004 Camrs MMG 112 GAS LIFT GLV RK 0.188 1,290.0 ]/14/201] 2 5,5026 3643.3 Cam. MMG 112 GAS LIFT GLV RK 0.188 1,2)40 ]N4201] LGCAioana,AtA 3 7,195.5 4,5046 Cam. MMG 112 GAS LIFT OV RK 0.188 0.0 11V14M17 SEALASSEMMv; ur.1 4 $513.7 6156.8 Cam. MMG 112 GAS LIFT DMV RK 0.000 ]1BI20D pan; 10=a 5 9,4845 5649] Cam. MMG 11/2 GAS LIFT DMY RK 0.000 ]/8201] FHL pACKER:ta.. 6 101446 5,9813 C... MMG 112 GAS LIFT DMY RK 0.000 Notes: General & Safety End pate Annotation 1N292010 NOTE Wes, Schematic w/ Alaska Scbemaec96 NIPpLE:t4a44.t APERF', m,4G2.a10,4N0�� WEDGEASSEMaLY;1G3Si.r NIFPIE:1be a.8 W EDGE ASSEM8LY:1 D4N.5 Ipse"; 10.4e3.Gm.SII.O RPEflF; t0Id2a10.5E.a NIPPLE: t0. 4 FlGX; 10.51$0 ablbal LPRGWCTIM 2i4 110,ft6.9 TRANSMITTAL LETTER CHECKLIST WELL NAME: Mu, PTD: ✓ Development _ Service _ Exploratory _ Stratigraphic Test Non -Conventional FIELD: POOL:(/ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit / LATERAL No. 8/ 8 - /1 API No. 50-J_- oq 00 p7 em V/ (If last two digits _ Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_ - _ --) from records, data and logs acquired for well name on permit . The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (CQmpg&y 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 sam les 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 completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 PTD#:2171280 Company CONOCOPHILLIPS ALASKA, INC _ _ _. _ __ _ Initial Class/Type _. Well Name: KUPARUK RIV UNIT 2K-041-1-02 Program DEV Well bore seg S6 DEV / PEND GeoArea 890 _ Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.0300.1.A),0.2.A-D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes ADL0025588,.Surf Loc; ADL0025589, Top Prod. lnterv; ADL0025586, T0.. 3 Unique well name and number Yes KRU 21K-041-1-02 4 Well located in defined pool Yes KUPARUK RIVER,. KUPARUK RIV OIL. -490100, governed. by Conservation Order 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 9/12/2017 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 Surface casing set in KRU 2K-04 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 diverter 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 si 3803 psig; will test BOPS to 4500 prig 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable. Yes 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-bearing. 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 9/12/2017 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: Date Com 'ssion Date Q-5��2G t �I�b�I