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219-042
DATA SUBMITTAL COMPLIANCE REPORT 815/2019 Permit to Drill 2190420 Well Name/No. KUPARUK RIV UNIT 1C-111-2.01 Operator ConocoPhillips Alaska, Inc. MD 15462 TVD 6574 Completion Date 4/28/2019 Completion Status 1-0I1 Current Status 1 -OIL REQUIRED INFORMATION Mud Log Nov/ DATA INFORMATION List of Logs Obtained: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED C 30793 Digital Data ED C 30793 Digital Data ED C 30793 Digital Data ED C 30793 Digital Data Log C 30793 Log Header Scans ED C 30799 Digital Data ED C 30799 Digital Data ED C 30799 Digital Data ED C 30799 Digital Data ED C 30799 Digital Data ED C 30799 Digital Data ED C 30799 Digital Data ED C 30799 Digital Data ED C 30799 Digital Data ED C 30799 Digital Data ED C 30799 Digital Data ED C 30799 Digital Data Samples No V/ Log Log Run Scale Media No Interval OH/ Start Stop CH 0 0 10408 15462 API No. 50-029-22714-64-00 UIC No Directional Survey Yes (from Master Well Data/Logs) Received Comments 5/17/2019 Electronic File: 1C-111-2-01 EOW - NAD27.pdf 5/17/2019 Electronic File: 1C-11 L2-01 EOW - NAD27.txt 5/17/2019 Electronic File: 1C-111-2-01 EOW NAD83.pdf 5/17/2019 Electronic File: 1C-111-2-01 EOW NAD83.txt 2190420 KUPARUK RIV UNIT 1C-111-2-01 LOG HEADERS 5/20/2019 Electronic Data Set, Filename: 1C-111-2-01 GAMMA RES.las 5/20/2019 Electronic File: 1C-1112-01_2MD Final.cgm 5/20/2019 Electronic File: 1C-11L2-01_5MD Final.cgm 5/20/2019 Electronic File: 1C-111-2-01_5TVDSS Final.cgm 5/20/2019 Electronic File: 1C-111-2-01_21VID Final.pdf 5/20/2019 Electronic File: 1C-111-2-015MD Final.pdf 5/20/2019 Electronic File:1C-11L2-01_5TVDSS Final.pdf 5/20/2019 Electronic File: 1C-1112-01 EOW - NAD27.pdf 5/20/2019 Electronic File: 1C-1112-01 EOW - NAD27.txt 5/20/2019 Electronic File: 1C-111-2-01 Final Surveys TD 15462.csv 5/20/2019 Electronic File: 1C-1112-01 Final Surveys TD 15462.xlsx 5/20/2019 Electronic File: 1C -11L2- 01 _25_tapescan_BH I_CTK.txt AOGCC Page 1 of 3, Monday, August 5. 2019 DATA SUBMITTAL COMPLIANCE REPORT 8/5/2019 Permit to Drill 2190420 Well Name/No. KUPARUK RIV UNIT 1C-111-2-01 MD 15462 TVD 6574 Completion Date 4/28/2019 ED C 30799 Digital Data ED C 30799 Digital Data ED C 30799 Digital Data ED C 30799 Digital Data ED C 30799 Digital Data Log C 30799 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report YO Production Test Informatio/ NA Geologic Markers/Tops Y COMPLIANCE HISTORY Completion Date: 4/28/2019 Release Date: 3/27/2019 Description Comments: Interval Start Stop Directional / Inclination Data Operator ConocoPhillips Alaska, Inc. API No. 50-029-22714-64-00 Completion Status 1 -OIL Current Status 1 -OIL UIC No 5/20/2019 Electronic File: 1C-1112- 01 _5_tapesca n_B H I_CT K.txt 5/20/2019 Electronic File: 1C-llL2-01_output.tap 5/20/2019 Electronic File: 1C-111-2-01 2MD Final.tif 5/20/2019 Electronic File: 1C-111-2-01 5MD Final.tif 5/20/2019 Electronic File: 1C-111-2-01 5TVDSS Final.tif 0 0 2190420 KUPARUK RIV UNIT 1C-111-2-01 LOG HEADERS Sample Set Sent Received Number Comments Mechanical Integrity Test Information Y / NA Daily Operations Summary U Date Comments Compliance Reviewed By: AOGCC Page 2 ofL Mud Logs, Image Files, Digital Data Y / IA Core Chips Y /6 Composite Logs, Image, Data Files(�1 Core Photographs YSACuttings Samples YNA Laboratory Analyses Y !A Date: -- _ Date: l � Monday, August 5. 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION EGEEII E MAY 2 8 2019 WELL COMPLETION OR RECOMPLETION REPORT AMQPMC 1a. Well Status: oil 2] Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25A10 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.: 4/28/2019 14. Permit to Drill Number/ Sundry: 219.042 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 4/9/2019 15. API Number: 50-029-22714-64-00 ' 4a. Location of Well (Governmental Section): Surface: 1225' FNL, 637' FWL, Sec 12, T11N, R10E, UM Top of Productive Interval: 3612' FNL, 567' FEL, Sec 35, T12N, R10E, UM Total Depth: 4572'FNL, 5189' FEL, Sec 25, T12N, R10E, UM 8. Date TO Reached: 4/16/2019 16. Well Name and Number: KRU 1C-111-2-01 9. Ref Elevations: KB:102 + GL:59 BF: 17. Field / Pool(s): Kuparuk River FieldlKupamk River Oil Pool 10. Plug Back Depth MDfTVD: N/A 18. Property Designation: ADL 25638, ADL 25649 41b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 561641 y- 5969009 Zone- 4 TPI: x- 560366 y- 5977171 - Zone- 4 Total Depth: x- 560986 y- 5981495 - Zone- 4 11. Total Depth MDfTVD: 15462/6574 • 19. DNR Approval Number: LONS 79-016 12. SSSV Depth MD/TVD: 2297/1994 20. Thickness of Permafrost MD/TVD: 1993/1802 - 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 1 N/A (ft MSL) 21. Re-drill/Lateral Top Window MD(rVD: 11050/6598 ' 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 41 121 41 121 24 257sx AS 1 9.625 40 L-80 42 6945 42 4440 12.25 775sx AS III, 710sx Class G, 7 26 L-80 28 10466 28 6373 8.5 112sx Class G 5 18 L-80 10279 11300 6237 7011 6.125 112sx Class G 31/2 9.3 L-80 5163 10271 3496 6231 Scab Liner 23/8 4.6 L-80 10751 16462 6578 6574 3 Slotted Liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MDfTVD of Top and Bottom; Perforation Size and Number; Date Perfd): Slotted Liner @ 10760-10791 MD and 6582-6592 TVD.... 4/16/2019 ' COMPLETION 12115-15462 MD and 6594-6573 TVD.... 4/16/2019 - ATE VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 5193 1 5203/3518 1014116143 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 5/6/2019 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 5/8/2019 Hours Tested: 1 Shins Production for Test Period Oil -Bbl: 474.2 Gas -MCF: 739 Water -Bbl: 960 Choke Size: 1 176 Gas -Oil Ratio: 1 1559 Flow Tubing Press. 389 Si I Casino Press: I 1350 Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: 7 Oil Gravity - API (cor): 1 22.6 Form 10-407 Revised 5/2017 A48 &- Act vrc 6/g/l 9 CONTINUED ON PAGE 2 RBDMS11=_ MAY 3 O 201§ubmft ORIGINAL only 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No 2 If Yes, list formations and intervals cored (MD1TVD, 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 ❑Q If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1993 1802 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk C 11050 6598 TO 15462 6574 ' Formation at total depth: ii J �✓� a sA,lc. ' 31. List of Attachments: Daily perations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloaical report, production or well test results. per 20 AAC 25,070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: William Lon Authorized Title: Staff CTD En ineer Contact Email: William. R.Lon 0co .com Authorized Contact Phone: 263-4372 Signature: Date: ��8� % INSTRUCTIONS General: This for 'and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 1C-11 Final CTO Schematic 4 x3 MLAB moe ®5v8x3 MD 1020E LA0s0ce�l Lj1 10,42r MD ®1000] MD• 3.5'x5'TTWS Y cwne wtM Iwa'0 tO,OW'-10]18'MD "o -Mo ppM M 10225' MD sur lD.Tar Mp i -2M! WUMwv ExR F91i e1 r a11o.21T-11,3W MD 0003 IhiIp IBP) Hol.'.n r wsm0 ae saeeMD iveemBt ¢-au TD'. 8.300' MD Ta of Billet 1t 050'MD Uppaaad they-2019WBL MinmR-13'WESV IZ20TMD Cama NBMG gas IS nvil C 31", 4217, 5110' 8.31 L-60 EUE alryTaNq W surface mu kslnala16193E11P 51x1 MD Goer 5103'-1D2T1'MD) FMLftNnevada paWrM x203 MO Ramat pal of 10149 MD i0N10,1P8'MD tl ourb2A0'144W) I zJle^an..a utwaw Pal al am at 10ur '2010.M0'M4' eors2V Ip(rcba4 shave 1a11LZA1 ro.tS.K MD LNar Top BilNt t0)K MO all l Lln¢10.]91'-12tt5'MD c -n zA2 TD: i5,201'MD BOOan al Llner Is.t09' MD Ta a1LNa[102N'Me tt-illy. l0.>30' � 13,385 Mp 2399i11,]x0'- 1J,308' elurrunum bilblat 11,T30'Mp KUP PROD WELLNAME 1C-11 WELLBORE 1C-11 1► ConociB'�� Well Attribub Max Angle l TD ''Ilie" FIeW Name Wellbore AP0UW1 .Ndmm EmVma nolo imod, Ac[Rlm (X1(81 Alaska, INC KUPARUK RIVER UNIT 5002922]1400 PROD 50.81 60]900 113000 TRDP 1EII.ScNN1910:Iam PM Last Tag Vw 1sp hal(..'' Anndetpn Dusho (flkB) I End BEY WelWore tans Motl BY .............................___..................................................... Last Tag: SUM 1 10900.0 lair IaN009 11C-11 Ran, Last Rev Reason HANGER, 39.7 .......... ... ... .. .. Ann... End Dahe sai Lal Mod BY Rev Reason. Replaced DV lwi,uiv 1C-11 zembaej Casing Strings easma Des=epnom 00 (in) ID rant Top MKB) Set Dkin (nks) Stl Na IrvDL. WaSen n...Gmtle Top thee# CONDUCTOR 16 15.06 41D 121.0 121.0 62.50 H40 WELDED CONDUCTOR, 4m1210 Carol Description Do (in) ID pn) Top ME) Set Won M.) Set appear GVD)_. WULan 0... G. Top Thee SURFACE 9518 853 42.3 6945.2 4,439.9 4000 L40 BT&C all 11, Casing Description 00(in) to (in) Imapisil SM OepM(XKS) Set Degn(rVOF-WOLen (L..Gnde Top Th, PRODUCTION 7 628 28.2 10,465.8 6,372.5 26.00 L40 BTC# Casing Description 00(I.) In (in) Top MM Set Dep#MKB) get DepM(TV.)... WOLen n,..G,aM Top IN. LINER 5 415 10.2794 11,300.0 7,0101 18.00 L-80 LTC Liner Details SAFETYVer;ZaA Nominal to Tappral I Top "Da PIKE) Top IIIFT Sam o0/ Com (in) 10,279.6 612365 45.22 HAN ER BAKER 5'xT' LINER HANGER & PACKER 5.000 GAsuFT:aleae wIPACKER 10,303.2 6.2536 44.42 PBR BAKER PBR 4.0M GSIrp amorphous OD(17 1011.) TOp (XKB) SN ONED61KB) SN D¢pM (NO)... VXrt.en p...GMe Top TM1reN GABLIFF,edRa WINDOW LI -W 5 400 10,750.0 10,]5]0 6,5894 2600 L40 GfMODMOr4RlonOD(N) LINER 312 10 (in) 299 TOp IDKB) 5,163.3 SN Mein Mins,sM 10,2]10 Dep# (NO)... 6230.6 VXlten (I... Grade 9.30 LAo Top Trivial3.5"SCAB EUE&JABM ON Gw III s,uTs Liner Details Nominal ID TopIftKB) Too (Foln(ME) Top Incl el Nem Gas Co. (.in 5,163.3 3,4963 5733 SLEEVE HR Liner Setting Sleeve 440 LOCATOns,V00 5.1771 3,504.1 57.34 XO BUSHING Xover Bushing 42 5,178. 35041 57.34 SDE 8040 Seat Bore Extengon 4.000 Sloe Tz5 5,1982 3,515.1 51.35 XO BUSHING Xover Bushing 2.9% 5,2029 3,517.7 57,35 PACKER FHL Retrievable Packer 2.992 10,140.9 6,142.8 49.26 PACKER Baker Premier Protlunion Packer 2.870 10,1890 6,174.5 4,06 NIPPLE 2.75'D'Nippie-MILLED TO 280"4142009 2.800 10,262.0 6,224.3 45.80 NIPPLE Fluted hi lGo 3.000 Tubing Strings ninths Description Isting III Too VIXo) set Dep"(X..sn Gepm GVu(. vngrose Gadrap eonnxlio. TUBING 3112 2.99 36.7 5,1930 3512.3 930 L-80 EUEfird=D Completion Details ropirvD) Tov m=I Nominal )7 Top IXKB) (XKeI fl tem Des Co. 10(m) SURFACE.....2- 367 000 HANGER Tubing Hanger T',38"'I9"BPVG 2.992 2,2974 1,994.1 54.51 SAFETY VU/ TRMAXX v,281 T'X-Pm6te 2.812 5,1702 3.500.0 57.34 LOCATOR BAKER LOCATOR oil 104' space out 3.999 5,172.5 3,5012 57.34 SEAL BAKER 8040 SEAL ASSEMBLY 3.999 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) iopiXKB) Top (N01 IXKBI Top Intl fl Das com Run Date M(in) UNIERIGNIL,pro...e a anti p 10,237.0 6,207.0 45.58 ZJ16" CTD 3l"Liner, lined back uD into the parent Liner. 4282019 LINER Top @ 10,237 MD 10,2660 6227.1 65.67 SEAL AS Y 8040EALA EM 5'- Teal parted 5252008 3000 where it was plugged into 6' liner (see aRadNdd drawing) --s-000- 10,271.0 6,230.6 45.50 PER Baker GBH -22 111 It 6 as•scoauNES:SNOa 10,3210 6,266.2 43.82 SHOE MULE SHOE -his 4.4"ID, causing lip at the mp of FISH 111161199 4.000 I0.2n o 6 SEAL Asap I0,2Eeo 10,684.0 6,534] 41.64 WHIPSTC= Set Baker whipstock on Rig OR-3)21,66OAL. et @ 0 Edge (high side) 4162019 10,7470 6,581.9 4165 WHIPSTOCK BAKER UEN II 11 RW, ORIENTED 15 DEGREES LEFT 5112009 2.500 OF HIGH SIDE, 173' OAL 1 10,780.0 6.606.6 4136 5M 2113W per P in : fine,, rate, 3600 psi; fishing 4202006 0.000 zee CTD LNER;10'.0 PRODUCTION, 282-10.4tra neck 1.3]5" OD; 5500# release pull - moved to 10780 CTMD 6121108 Perforations & Slots Shot 0... RPI IO,Gm.0.10,a10.0 FRAC; tpemo PERE. l0,m0.wmle0 WHIPSTOCK; 1o.fl9s.04- Top(XKBI nM(MB) R,Spit1 IXKBI B. groD) (MB) Linked Zam Mie (moister ) TYM Co. 10,6600 10,670.0 6,516.8 6524.3 C4, 1C-11 611912008 6.0 RPERF ZSEH D Deg phase 10,6]00 10.)16.0 6,526.3 ,558] C4, C-3. iC-it 11141199) 2.D IPERF Zero Eeg. asing;21 ' Eent el Frac Summary MR Pmppan,D-.Eed(M) Woppntln Fwmatlon(lb) LINER I CAILIHG; Ia..6sun 'dor&20/2008 WHIPSTOCK 10,747 WINDOW udl. t0.Ts04 to.rsro sigx 1 sdX Dam Top Dep6 gi etm Sa8l unklo nuttl amlun valclnn(XtD VoSIUTJ IeYI 6202008 10,660.0 10718.0 Mandrel Inserts FISH', i... St atl N Top(", ..talch Real Iranian,Top (XNaI IXKBI Make Model 00ne) Sery Type Type MI (Psi) Run Mie Com 3,1939 2,472.8 Camco KBMG 1 Gas LIX GLV BK 0.168 1277.0 31172019 2 4.2176 2,992.9 Camco KBMG 1 Gas lift OV BK 0250 31172019 3 5.1175 3,471.8 Camco KBMG 1 Gas Lifl OMY BK OOOp 00 5112019 xt Pkg Notes: General & Safety End Date i Annotation 41312008 NOTE: SWS LDL INDICATES IBP@ 10,385 LEAKING FROM BELOW LINER, loars.4-11,300 0 KUP PROD WELLNAME 1C-11 WELLBORE 1C-11 ConocoPhillips aaskB.IDc G F- I E i. -H. SSEEE, +zso9 PN Notes: General B Safety vaaelecMnalnl +9 End D. I Anno W, ................................................................_.........._._..__.. 5/2612008 NOTE: HOLE IN ]" CASING @ 5466MD RANEER:Oa] 6l&2008 NOTE: NEW 3I TBG INSERTED INTO 3.5 SCAB LINER @ 10272' 6(1612008 NOTE: VIEW SCHEMATIC wI Alaska SChema11c9.UREV ------- -.---------..... """"""" 111512008 NOTE: Recovered severely emEeE OV @ 5117, GLM likely damaged 7/2612009 NOTE MULTI -LATERAL 1611,10-I IL1, 7G111141, 1C -11L1-02 (OFF MAIN WELLBORE) conoucroR: al olz+o ssExvtv'. $za�a ws uFr:3lme EASUF,42174 cA6uFt41¢s LOCATOR', 4170.$ SE9L41R5 SURFACE;4ZNR4i IINER 1L11... 10E].& 1;1090 3 S SCAB LINER; 5,1®} IAMO SF ASSY: 10,M0 23Ry CTO LINER;10.=0 PROOUMNIN', M,S?10.,KME RPERR 10,8. EAM FRAC: 10,S IFee",OBiO610ISO .]180 WXIPSTCCM tO.MO LINER IC-Rt1@ 10.M1 3,03]0 WXIPSTCCH; 10,]<i0 wINOCW Ltd$: 10.7W0 +0,]s]O FISH; 10 MO LINER. 10,M. 1.300.0 1w I ConocoPhillips Alaska.ft WELLNAME 110-11 WELLBORE 1 C-11 L2-01 10-11..vtarm1912nsoe Pm Last Tag Ve,MaluNr�meclazlua) Ann Udwn Depth MKID End Date Welnore LestehoEey „_,.. Lest Tag: 1jernaer KeNGER:%7 Last Rev Reason Anndation EM D. minbare bst Mad BY ......................... Rev Reason: CTD MULTIIAT 1C -11L2-01 'Erne. Casing Strings casing Des—Siono0 an) mMt ro,MKM .I.IntratKSI S.DepMmDl...w41en U._Grade TOP Threaa LINER IC -1112-01 2318 1.99 10,]51.0 15,462.0 6573.6 4.60 L-80 STL Liner Details Co41 a121n Nominal ID Top MKIS Top IND)Mae) I Tap Incl I, Ibm Deg Lan (1n1 10,/510 6,5]8.2 61.88 AL INUM Aluminum Liner Top Biller 1.920 BILLET I 14,2483 6,565.1 8452 L ENT anon, Deployment Sleeve 1.000 WETY vLC Z.,1 SLEEVE Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) TOP ROIs) Top IND) Ihe.) Top Incl 1') Oes Com Run Oa@ ED (I.) G9811FT 31939 11,051.0 6,598.0 9101 Open Hole Anchor billet 4192019 I I JUM ANCHORED BILLET WS UF -F 42174 Frac Summary 12Proppsn[Dedpned lib) Pmppntln Fwmeaon Sir)6 120201200008 GAS LIFTI5.11 ].5 atpp Sdrteeh Top Dedra lRRe) 817LinLb Fluty 4ysRm ,Ol) VOl clean lbbq Vd SWry lb . 1 66...10, 660 0 107160 Notes: General & Safety Annd ion LOCATDREAM2 5114E.Oab NOTE: SEAL:5,1]25 SURFACE', LINER 1c-1113021AD].B 151W0 3S aces UNER:5.1 W 1 m.afo SE AaSY:M.Ra.o 2WOTD UNER 10.2510 PRODUCTION', X) V O..eW8 RPERF: 101. 0-10.BN.O FRnc +o.wxp IPERF'. 106]U.610]le.0 ' UNER 10,2]9.6 ,= LWER IC 11L2-01; 10]SI.b_� 11 I...D r Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan oepm startAme End Time our (hr) Phase Op Code AMAY Code Time P -T -X Operation (WB) End Depth (M(B) 3/26/2019 1.50 MIRU MOVE MOB P Continue RD checklist, Trucks on 0.0 0.0 20:00 21:30 location, load shop, secure stairs and 13126/2019 landings, secure BOP'S, Complete RD checklist 3126/2019 3/27/2019 2.50 MIRU MOVE MOB P PJSM, Pull utility module away from 0.0 0.0 21:30 00:00 dg and line up for move, trouble getting up hill to get off pad, hook up cat'dozer, work over hill, pull drilling sub off well. 3/27/2019 3/27/2019 2.00 MIRU MOVE MOB P Install Jeeps, ready to move, PJSM 0.0 0.0 00:00 02:00 3/27/2019 3/27/2019 3.50 MIRU MOVE MOB P Begin move from 3F -Pad to 1C -Pad 0.0 0.0 02:00 05:30 3/27/2019 3/27/2019 1.00 MIRU MOVE MOB P Park at 1 Q for changeout, walkaround 0.0 0.0 05:30 06:30 3/27/2019 312712019 3.25 MIRU MOVE MOB P Continue move to 1 C 0.0 0.0 06:30 09:45 3/27/2019 3/27/2019 1.00 MIRU MOVE MOB P Arrive on location, remove jeeps, prep 0.0 0.0 09:45 10:45 well location for rig 3127/2019 3/27/2019 2.25 MIRU MOVE MOB P Spot sub & pits over well, lay mats, 0.0 0.0 10:45 13:00 drop stairs 327/2019 3/27/2019 2.00 MIRU MOVE RURD P Begin RU checklist, get COMMS up, 0.0 0.0 13:00 15:00 set -down shop & lay mats, install scaffolding & platform around well 327/2019 3/272019 3.00 MIRU MOVE RURD P Continue RU checklist, spot tiger -tank 0.0 0.0 15:00 18:00 & MU hard-line, begin NU BOPE, MU PUTZ, grease tree valves & Tangos, complete NU BOP '• Rig Accept: 18:00 3/2712019 3/27/2019 2.50 MIRU WHDBOP RURD P Complete dg up check list, Air lest TT 0.0 0.0 18:00 20:30 line, Obtain RKB Measurments, Service tree and stack, Valve crew here. Prep for BOPE test 3/27/2019 3/27/2019 1.00 MIRU WHDBOP BOPE P PJSM, Fill slack and bleed afire out of 0.0 0.0 20:30 21:30 system. Shell lest BOPE, Swap out O - Ring on riser 3/27/2019 3/28/2019 2.50 MIRU WHDBOP BOPE P Start full initial BOPE test, Test 0.0 0.0 21:30 00:00 witness waived by Adam Earl, AOGCC, No Fail pass through midnight test #9 3/28/2019 3/28/2019 2.50 MIRU WHDBOP BOPE P Continue full BOPE test, on test 9 0.0 0.0 00:00 02:30 3/28/2019 3/28/2019 0.50 MIRU WHDBOP BOPE P Pull test joint, Make up nozzle stab on 0.0 0.0 02:30 03:00 injector. Pressure test inner reel iron and pack offs, End BOPE test 3/282019 31282019 1.00 SLOT WELLPR RURD P PJSM, Rig down BOPE test 0.0 0.0 03:00 04:00 equipment. PT PDL's TT line 3128/2019 3/28/2019 0.75 SLOT WELLPR RURD P Normal up rig, Blow down TT line, 0.0 0.0 04:00 04:45 Open Tango valves. WHP=175 PSI 3/28/2019 3/28/2019 2.75 SLOT WELLPR PULD P M/U PD, BHA #1, fishing assembly 0.0 68.5 04:45 07:30 3/28/2019 328/2019 0.50 SLOT WELLPR PULD P Surface test Coil (good -test), Tag up 68.5 68.5 07:30 08:00 reset counters 3/28/2019 3/28/2019 2.00 SLOT WELLPR TRIP P RIH 68.5 9,745.0 08:00 10:00 3/26/2019 3128/2019 0.30 SLOT WELLPR DLOG P Log formation correction of plus 3.5' 9,745.0 9,779.0 1000 10:18 3/28/2019 3/282019 2.00 SLOT WELLPR CIRC P Continue RIH, park @ 10,200', obtain 9,779.0 10,200.0 10:18 12:18 static, 8.5-8.7 ppg, bring pump on-line circ bottoms up. PUW 40 k Page 1/35 ReportPrinted: 5/312019 Operations Summary (with Timelog Depths) 1C-11: og: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time End Time Dur (hr) Phase op Code Activity GOde Time P -T -X Operation MKII) End Depth MKS) 3/28/2019 3/28/2019 0.75 SLOT WELLPR CIRC P Vac out tiger tank, 10,200.0 10,200.0 12:18 13:03 3/2812019 3/28/2019 1.50 SLOT WELLPR JAR P RIH, pumping .46 bpm latch into fish 10,200.0 10,245.0 13:03 14:33 @ 10,245', hit jars x 25, jaring at 25k (57k), straight pull to 70 k, with no success 3/28/2019 3/28/2019 1.75 SLOT WELLPR CIRC P Pump off fish, circulate 8.8 ppg drilling 10,245.0 10,200.0 14:33 16:18 fluid around 3/28/2019 3/28/2019 0.50 SLOT WELLPR CIRC P 8.8 ppg all the way around, shut down 10,200.0 10,200.0 16:18 16:48 pump, perform flow check, flow at the valve, shut back in and montior, slowly built up to 116 psi, 3/28/2019 3/28/2019 0.30 SLOT WELLPR TRIP P RBIH, pumping 0.46 bpm latch into 10,200.0 10,245.0 16:48 17:06 fish, pump 1.5 bpm at 3,451 psi, no returns 3/28/2019 3/28/2019 0.30 SLOT WELLPR JAR P Perform 5 jar hits @ 25 k PU over 10,245.0 10,245.0 17:06 17:24 1 1PUW 30 k, straight pull to 70 k 3/28/2019 312812019 1.30 SLOT WELLPR OWFF P Unlach fish, PUH to 10240. Observe 10,240.0 10,240.0 17:24 18:42 well for flow, WHP 40 PSI and slowly climbing 3128/2019 3/28/2019 0.10 SLOT WELLPR OTHR P Take static pressures. Annular @ 10,240.0 10,240.0 18:42 18:48 2934, Bore @ 2928 PSI. 3/28/2019 3/28/2019 0.10 SLOT WELLPR OTHR P Slowly stab on and latch fish, 3K 10,240.0 10,245.0 18:48 18:54 down, Annular 2925, Bore 2935, WHP=40 3/28/2019 3/28/2019 0.40 SLOT WELLPR OTHR P Set down 6K, Annular 2932, Bore 10,245.0 10,245.0 18:54 19:18 2929, WHP=40 PSI. Annular down to 2896 after 20 min. Bore at 2925 3128/2019 3/28/2019 0.10 SLOT WELLPR OTHR P Put fish in tension, DHWOB=-3K, 10,245.0 10,245.0 19:18 19:24 Annular 2864, Bore 2923, WHP=41 3/28/2019 3/282019 0.20 SLOT WELLPR OTHR P Pull fish harder, DHWOB=-7K, Annualr 10,245.0 10,245.0 19:24 19:36 2883, Bore 2924, WHP=41 3/28/2019 3/282019 0.30 SLOT WELLPR OTHR P Pull fish up to 60K, Annular 2858, 10,245.0 10,245.0 19:36 19:54 Bore 2945. 3/28/2019 3/2812019 1.30 SLOT WELLPR OTHR P Bring on pumps 1.5 BPM, release 10,245.0 10,200.0 19:54 21:12 from fish PUW=35K, PUH, Open EDC. Wait on 9.0 PPG fluid 3128/2019 3/28/2019 1.20 SLOT WELLPR KLWL P Start pumping 9.0 PPG down CT. .9 10,200.0 10,200.0 21:12 22:24 BPM with .15 BPM returns. Slow pump down to .6BPM. returns holding @.15 -.2 BPM. Jog coil to help shear fluid up to 9595 @ 80 FPM them back down to 10,200. CT displaced to 9 PPG. 328/2019 328/2019 0.90 SLOT WELLPR KLWL P Consult town, Bull head 60 BBIs 9.0 10,200.0 10,200.0 22:24 23:18 Fluid, 1.5 BPM @ 1400 PSI WHP 3/28/2019 3/292019 0.70 SLOT WELLPR KLWL P Shut down and monitor well. Would 10,200.0 10,200.0 23:18 00:00 not go to no flow,2900 PSI 6045.6 TVD, @ 9.26 PPG 3/29/2019 3129/2019 1.60 SLOT WELLPR TRIP P POOH pumping 9.0 down CT 10,200.0 90.0 00:00 01:36 3/29/2019 3/2912019 0.90 SLOT WELLPR OWFF P At surface, Flow check well. Fluid 90.0 90.0 01:36 02:30 coming out of whity valve. Open up choke and blow down to pits. No flow for 12 minutes then started. 3/29/2019 3/292019 1.00 SLOT WELLPR PULD P Tag up and space out. PUD BHA#1. 90.0 0.0 02:30 03:30 wHP up to 30 PSI. Bleed down came right back up. Lay down fishing BHA 3/29/2019 3/292019 1.50 SLOT WELLPR ELNE P Shift to running a -line with lubricator. 0.0 0.0 03:30 05:00 1 Rigging up a -line grease head 3/29/2019 3/2912019 0.60 SLOT WELLPR ELNE P PJSM, with Pallard & Rig crew for e- 0.0 0.0 05:00 05:36 I line ops, crew change Page 2/35 Report Printed: 5/312019 Operations Summary (with Timelog Depths) a 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start DepM Start Time End Time our (hr) Phase Op Code Activity Calle Time P -T -X Operation (flKa) End Depth (ftKa) 3/29/2019 3/29/2019 3.00 SLOT WELLPR ELNE P RUe-line 0.0 0.0 05:36 08:36 3/29/2019 3/29/2019 0.45 SLOT WELLPR ELNE P Stab on lubricator, PT with rig pump, 0.0 0.0 08:36 09:03 4,000 psi, good test, bleed off pressure 3/29/2019 3/29/2019 1.10 SLOT WELLPR ELNE P RIH, with 5/8" string shot, weight bar, 0.0 0.0 09:03 10:09 firing head (16.03' BHA), WHP=312 3/29/2019 3/29/2019 0.50 SLOT WELLPR ELNE P Log CCL for depth control on the way 0.0 0.0 10:09 10:39 in the hole, no-go on nipple at 10,725', obtain log of previous cut depth, looks to be clean. fire string shot 10,713'- 10,725'. 3/29/2019 3/29/2019 1.20 SLOT WELLPR ELNE P POOH, w/e-line 0.0 0.0 10:39 11:51 Note: Operator shut in well 1C-17 MI Injection well. 3/29/2019 3/29/2019 0.50 SLOT WELLPR ELNE P MU Jet cutter to a -line, stab on 0.0 0.0 11:51 12:21 lubricator PT, grease head small leak, add additional grease, re -PT 3/29/2019 3/29/2019 1.00 SLOT WELLPR ELNE P RIH, w/Spectra2 Jet Cutter 1.68" OD, 0.0 0.0 12:21 13:21 3/29/2019 3/29/2019 0.40 SLOT WELLPR ELNE P Tie into K1 10,427.5', Log CCL while 0.0 O.0 13:21 13:45 RIH, log across seal bore and 15 joints. fire cutter on depth 10,722'. PUH free, RBIH past cut depth, tempodly detained, RBIH, PUH wlincreased speed, Pull free 3/29/2019 3/29/2019 1.00 SLOT WELLPR ELNE P POOH 0.0 TO 13:45 14:45 3/29/2019 3/29/2019 1.00 SLOT WELLPR ELNE P PJSM, LD cutter and pressure 0.0 0.0 14:45 15:45 equipment, RD a -line unit and release 3/29/2019 3/29/2019 0.70 SLOT WELLPR CTOP P PJSM, move INJH cart forward, RIH 0.0 0.0 15:45 16:27 with coil into mouse hole inspecting coil, found flat spots at 10' and 15', Prep coil and cut 20 3/29/2019 3/2912019 0.80 SLOT WELLPR CTOP P Prep CT, Install CT connector. Pull test 0.0 0.0 16:27 17:15 1 1 135K 3/29/2019 3/29/2019 1.00 SLOT WELLPR CTOP P Head up BHI UQC / test wire - Good. 0.0 0.0 17:15 18:15 Pressure test UQC CTC to 4400 PSI - Good 3/29/2019 3/29/2019 2.00 SLOT WELLPR PULD P M/U and PD BHA #2 Fishing BHA with 0.0 81.3 18:15 20:15 Accelorator, weight bars, Up down jars, and sealed GS spear 3/29/2019 3/29/2019 1.80 SLOT WELLPR TRIP P Trip in hole BHA#2. Sputtering small 81.3 9,760.0 20:15 22:03 gas bubbles on trip in 3/29/2019 3/29/2019 0.20 SLOT WELLPR DLOG P Log K1 for -2.5", Close EDC 9,760.0 9,798.0 22:03 22:15 3/29/2019 3/29/2019 0.30 SLOT WELLPR TRIP P Continue in hole, Pull weight check @ 9,798.0 10,248.0 22:15 22:33 10,200' PUW=36K 3/29/2019 3/29/2019 0.70 SLOT WELLPR JAR P Latch fish, Jar up - down X5. Jar up 10 10,248.0 10,248.0 22:33 23:15 times 25K over PUW. No movement. 3/29/2019 3/29/2019 0.20 SLOT WELLPR CIRC P Start pumping to establish circulation. 10,248.0 10,248.0 23:15 23:27 Remain latched to fish. .5 BPM @ 3478, Annular 3096. Unable to move fluid to surface 3/29/2019 3/29/2019 0.45 SLOT WELLPR JAR P Go back to jarring up on fsh X15. No 10,248.0 10,211.0 23:27 23:54 movement. Pump on to release from fish 3/29/2019 3/30/2019 0.10 SLOT WELLPR CIRC P Pump on to establish returns 10,211.0 10,211.0 23:54 00:00 3/30/2019 3130/2019 0.30 SLOT WELLPR CIRC P Continue circulating with open EDC 10,211.0 10,211.0 00:00 00:18 Page 3135 ReportPrinted: 51312019 Summary (with Timelog Depths) isOperations IC -111 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (m) Phase Op Code Activity Corte Time P -T -X Operation (MB) End DepN(XKB) 3/30/2019 3/30/2019 0.50 SLOT WELLPR PRTS P Get static pressure test. BHP=3193, 10,211.0 10,211.0 00:18 00:48 TVD=6154.5, EMW=9.97 3/30/2019 3/30/2019 1.30 SLOT WELLPR CIRC P Circulate bottoms up 1.6 BBUMin with 10,211.0 10,211.0 00:48 02:06 full returns. 3/30/2019 3/30/2019 1.80 SLOT WELLPR TRIP P Trip out of hole, lost 4 BBIs on trip out 10,211.0 72.0 0206 03:54 3/30/2019 3/30/2019 1.50 SLOT WELLPR PULD P Tag up and space out, PJSM. PUD 72.0 0.0 0354 05:24 BHA#2 3/30/2019 3/30/2019 1.50 SLOT WELLPR ELNE P Prep rig floor for eline ops, standby for 0.0 0.0 0524 06:54 SLB eline travel to rig 3/30/2019 3/30/2019 0.75 SLOT WELLPR ELNE P SLB on location, PJSM, spot in unit 0.0 0.0 0654 07:39 3/30/2019 3/30/2019 0.30 SLOT WELLPR ELNE P PJSM with rig crew and SLB 0.0 0.0 07:39 07:57 3/30/2019 3/30/2019 5.00 SLOT WELLPR ELNE P RU, SLB pressure equipment to the 0.0 0.0 07:57 12:57 rig floor 3/30/2019 3/30/2019 2.00 SLOT WELLPR ELNE P PT SLB a -line lubricator 0.0 0.0 12:57 14:57 3/30/2019 3/30/2019 5.80 SLOT WELLPR ELNE P RIH, w/Shammas Chem Cutter 0.0 0.0 14:57 20:45 1.8675" OD, 2 X centralizers, CCL, Gamma. Log Kt. Run CCL. Appears liner has moved uphole -15'. Attemp to log R nipple. Set down @ 10725. right where nipple should be. CCL 13' from bottom of a -line tool string. Log K1 to ensure we are on depth. POOH 3/30/2019 3/30/2019 1.10 SLOT WELLPR ELNE P At surface with a -line. PJSM to lay 0.0 0.0 2045 21:51 down chem cutter Swap out to 1 3/8" toolstring for logging ops 3/30/2019 3/30/2019 0.50 SLOT WELLPR ELNE P P/U Next a -line run. Stab on well 0.0 0.0 21:51 22:21 3/30/2019 3/31/2019 1.65 SLOT WELLPR ELNE P Trip in hole with a -line unit with 1 3/8" 0.0 0.0 2221 00:00 logging tools 3/31/2019 3/31/2019 1.30 SLOT WELLPR ELNE P Continue tripping out with a line 0.0 0.5- 0000 01:18 logging tools 3/31/2019 3/31/2019 3.25 SLOT WELLPR ELNE P E -line at surface. PJSM. Pull logging 0.0 0.0 01:18 04:33 1 tools from well. Rig down a -line unit 3/31/2019 3/31/2019 0.70 SLOT WELLPR CTOP P PJSM, Position injector on rig floor. cut 0.0 0.0 0433 05:15 off UQC. Boot wire, 3/31/2019 3/31/2019 0.25 SLOT WELLPR CTOP P Install CT cutter, Trim 300' of coiled 0.0 0.0 0515 05:30 tubing from reel 3/31/2019 3/31/2019 1.50 SLOT WELLPR CTOP P Trim 300' of coiled tubing, String 0.0 0.0 0530 07:00 #52794, Reel #20709 3/31/2019 3/31/2019 0.30 SLOT WELLPR CTOP P RD, cutting equipment operation 0.0 0.0 07:00 07:18 3/31/2019 3/31/2019 0.75 SLOT WELLPR CTOP P Install CTC, and pull test 35 k 0.0 0.0 0718 08:03 3/31/2019 3/31/2019 0.45 SLOT WELLPR CTOP P Re -head BHI upper quick(77.5 0.0 0.0 0803 08:30 1 meg/ohms, >2000) 3/31/2019 3/31/2019 0.25 SLOT WELLPR CTOP P PT re -head 4,500 psi 0.0 0.0 0830 08:45 3/31/2019 3/31/2019 0.50 SLOT WELLPR CTOP P Stab into stump and pump 1 coil 0.0 0.0 08:45 09:15 volume forward @ 1.83 bpm at 3,299 psi, IA=110, OA=26, unstab INJH, park cart out of the way. 3/31/2019 3/31/2019 1.00 SLOT WELLPR PULD P PD fishing assembly 0.0 0.0 09:15 10:15 3/31/2019 3/31/2019 0.30 SLOT WELLPR PULD P Stab INJH, surface test BHI CoilTrak 0.0 81.3 10:15 10:33 1tools (good -lest) 3/31/2019 3/31/2019 1.75 SLOT WELLPR TRIP P RIH 81.3 9,760.0 1033 1218 Page 4/35 Report Printed: 5/3/2019 a Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start DBPih Start Time End Time our (hr) Phase Op Coda Acbwty Cade Time P-T-X Opemw MKB) End Depth (ftKS) 3/31/2019 3/31/2019 0.20 SLOT WELLPR DLOG P Log formation correction of minus 4.0' 9,760.0 9,781.0 12:18 12:30 3/31/2019 3/31/2019 0.30 SLOT WELLPR TRIP P Continue IH 9,781.0 10,200.0 12:30 12:48 3/31/2019 3/31/2019 0.50 SLOT WELLPR CIRC P Circulate bottoms up @ 1.5 bpm at 10,200.0 10,200.0 1248 13:18 3,100 psi, Diff-16 psi, WHP=36, BHP 3,651, IA=114, OA=27 3/31/2019 3131/2019 0.50 SLOT WELLPR -FFR-TS P Shut down pump, obtain static bottom 10,200.0 10,200.0 13:18 13:48 hole pressure 30 min - 10.09 ppg/3226 AP/W HP=23516148.28' ND, PUW 37 k 3/31/2019 3/3112019 0.60 SLOT WELLPR JAR P RIH latch fish @ 10,235', jar down x1, 10,200.0 10,240.0 13:48 14:24 jar up on fish x 1, jar down on fish x2, jar up on fish x 4, Pull up to 64 k, pump 1.9 bpm -10 bbl, Could not establish returns 3/31/2019 3/31/2019 2.90 SLOT WELLPR JAR P Continue to jar on fish. Stop every 5 10,240.0 10,199.0 14:24 17:18 cycles and attempt to get circulation. Jar a total of 45 cycles, release fish 3/31/2019 3/31/2019 -o t0 SLOT WELLPR TRIP P PUH to tie in 10,199.0 9,760.0 17:18 17:24 3/31/2019 3/31/2019 0.20 SLOT WELLPR DLOG P Log K1 for +75 9,760.0 9,502.0 17:24 17:36 3/31/2019 3131/2019 0.10 SLOT WELLPR TRIP P RIH to tag top of fish @ 10,225'. 9,502.0 10,225.0 17:36 17:42 Release off fist 3/3112019 3/31/2019 1.80 SLOT WELLPR TRIP P POOH 10,225.0 76.0 17:42 19:30 3/312019 3/31/2019 1.10 SLOT WELLPR PULD P At surface, Tag up and space out. 76.0 0.0 19:30 20:36 PJSM. PUD BHA#3 and lay down 3/31/2019 3/31/2019 0.80 SLOT WELLPR CTOP P PJSM. Lock out E-line. Remove LOC. 0.0 0.0 20:36 21:24 Boot wire. Stab on well. Perform slack mgmt 3/312019 3/31/2019 1.10 SLOT WELLPR CTOP P Unstab injecor. P/U hydraulic tubing 0.0 0.0 21:24 22:30 cutler. Trim CT for fatigue mgmt. Find e-line @ 38'. Trim 100'tolal 3/31/2019 3/31/2019 1.40 SLOT WELLPR CTOP P Test wire - good. Prep CT and install 0.0 0.0 22:30 23:54 connector. Pull test to 35K 3/31/2019 4/1/2019 0.10 SLOT WELLPR CTOP P Head up UQC 0.0 0.0 23:54 00:00 4/1/2019 4/1/2019 0.90 SLOT WELLPR CTOP P Complete reheading UCC. PT 0.0 0.0 00:00 00:54 connector to 4300 PSI 4/12019 4/1/2019 1.00 SLOT WELLPR PULD P PJSM, M/U and PD BHA #4 fishing 0.0 81.0 00:54 01:54 BHA. Check packoffs. Surface test BHA 4/1/2019 4/1/2019 2.00 SLOT WELLPR TRIP P RIH BHA #4, EDC open, pumping 1.5 81.0 9,760.0 01:54 03:54 BPM from surface 4/12019 4/12019 0.10 SLOT WELLPR DLOG P Log k1 for-4.5' correction, Close EDC 9,760.0 9,791.0 03:54 04:00 4/12019 411/2019 0:10 SLOT WELLPR TRIP P Confinue in well 9,791.0 10,220.0 04:00 04:06 4/1/2019 4/1/2019 3.00 SLOT WELLPR JAR P Set down @ 10,220'. Did not latch up 10,220.0 10,220.0 04:06 07:06 first time. Bring pumps on. BPM and run in faster. Set down and latch. Jar up 3X. Paint red Flag @ 51 K PUW. Line up to pump down backside. Go up to 1100 PSI WHIP. Pull up to fire jars and dump pressure. No good. Jar 5X. Stop and pump 5 BBIs down coil. No circulation. Jar 5X up and down 4/1/2019 4/1/2019 0.50161-0 1 WELLPR PULL P Continue jaring total of 30 cycles -0 10,220.0 10,195.0 07:06 07:36 10,199', hold in tention 60 k, 10,195', notice weight fall off slightly Page 5/35 Report Printed: 51312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Tome our (hr) Phase Op Cade Activity Cede Time P-T-% Operation (RB) End Depth WS) 411/2019 4/1/2019 SLOT WELLPR PULL P Continue working fish towards surface 10,195.0 9,753.0 07:36 08:06 75 k @ 3-5 fpm, notice weight change @ 10,145', continue pulling up to 9,975', 15-30 fpm, fish is pulling free 411/2019 4/1/2019 F1.20 SLOT WELLPR PULL P Park with fish, discuss with town team, 91753.0 9,753.0 08:06 11:51 plan forward to kill well, call out 10.5 ppg completion fluid. 10.5 ppg on location load into pits 4/112019 4/1/2019 SLOT WELLPR PULL P Second brine truck headed to the rig, 9,753.0 9,729.0 11:51 13:03 start displacing coil to 10.5 ppg kill fluid w/open EDC holding one for one 45 bbis, , shut down and close EDC, slowly PUH circulating 0.25 bpm 2 bbis, shutdown open EDC, bullhead 1.4 bbl, WHP increased to 1,500 psi, shutdown pump, bleed pressure off, pull up hole to confirm fish is free, fish is free, Close the EDC, 4/1/2019 4/1/2019 0.50 SLOT WELLPR PULL P PU slow, pumping down the coil 0.2 9,729.0 9,699.0 13:03 13:33 bpm at 48 psi, CTSW=36.5 it, DHWOB= -2.2 k, close choke WHP built to 1,000 psi shutdown pump, park and discuss with town team further. 4/1/2019 4/1/2019 0.20 SLOT WELLPR PULL P Attempt to RIH w/1000 psi WHP, stack 9,699.0 9,717.0 13:33 13:45 out 5k CTSW, bleed pressure off WH 4/1/2019 4/1/2019 0.15 SLOT WELLPR PULL P Open EDC, PUH @ 2 fpm, seems fish 9,717.0 9,693.0 13:45 13:54 is still on. 411/2019 4/1/2019 1.00 SLOT WELLPR OWFF P Park, bleed pressure off, perform flow 9,693.0 9,693.0 13:54 14:54 check, well still flowing, 4/1/2019 4/1/2019 0.30 SLOT WELLPR PULL P RBIH to tag @ 9,713' (Fish 9,693.0 9,713.0 14:54 15:12 depth=10,287') 4/1/2019 4/1/2019 1.50 SLOT WELLPR PULL P Circulate bottoms up, gas cut brine at 9,713.0 9,713.0 15:12 16:42 surface, take returns to tiger tank, bring back inside, 4/1/2019 4/1/2019 1.30 SLOT WELLPR OWFF P Perform flow check (no-flow) 9,713.0 9,713.0 16:42 18:00 4/1/2019 41112019 2.00 SLOT WELLPR TRIP P Close EDC, pump 2 bbis down the 9,713.0 557.2 18:00 20:00 coil, shutdown, open EDC, circlulate through the EDC, 1.19 bpm at 1,477 psi, 0.80 bpm returns, POOH 4/1/2019 4/1/2019 0.60 SLOT WELLPR OWFF P PJSM, Check well for flow (no-flow) 557.2 557.2 20:00 20:36 4/1/2019 4/112019 1.25 SLOT WELLPR PULD P Brake down BOT fishing tools, check 557.2 444.9 20:36 21:51 the hole (good) 4/1/2019 4/1/2019 1.20 SLOT WELLPR PULD P LD, fish 2-3/8" solid liner no 444.9 0.0 21:51 23:03 centrilizers. 4/1/2019 4/2/2019 0.95 SLOT WELLPR PULD P PJSM, MU cleanout assembly, Stab 0.0 23:03 00:00 on well, Surface test tool 4/2/2019 4/2/2019 0.10 SLOT WELLPR PULD P Complete surface test tool 51.3 51.3 00:00 00:06 4/2/2019 4/2/2019 1.80 SLOT WELLPR TRIP P Trip in hole, BHA#5 Clean out BHA 51.3 9,730.0 00:06 01:54 with straight motor and D-331 4/2/2019 4/2/2019 0.20 SLOT WELLPR DLOG P Log gamma tie in for-2', Close EDC 9,730.0 9,769.0 01:54 02:06 4/2/2019 4/2/2019 0.30 SLOT WELLPR TRIP P Continue in well 9,769.0 10,220.0 02:06 02:24 4/2/2019 4/2/2019 1.30 SLOT WELLPR CIRC P 10220'. Displace to 8.8 PPG milling 10,220.0 10,210.0 02:24 0342 1 fluid slowly recip up hole 41212019 4/2/2019 0.20 SLOT WELLPR TRIP P 10210', Wt check @ 35K, RIH min 10,210.0 10,276.0 03:42 03:54 rate. Tag dill @ 10,276 Page 6135 Report Printed: 5/312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operabon (MB) End Depth(ftKB) 4/2/2019 4/2/2019 1.80 SLOT WELLPR OTHR P Bring pumps on 1.85 BPM @ 3629 10,276.0 10,442.0 03:54 05:42 PSI FS. Start clean out. Taking 25' bites. Parafin coming across shaker at first bottoms up 4/2/2019 4/2/2019 0.50 SLOT WELLPR OTHR P Washing down set down @ 10442. 10,442.0 10,442.0 05:42 06:12 PUH slowly to 10356. RBIH and tag up 10442. DHWOB=2K. 4/2/2019 4/2/2019 0.90 SLOT WELLPR OTHR P Pump sweeps, PUH slowly circ 10,442.0 10,442.6 06:12 07:06 bottoms up 4/2/2019 4/2/2019 0.50 SLOT WELLPR MILL P Hole circulated clear, Bring pumps on 10,442.6 10,443.0 07:06 07:36 1.88 BPM @ 3635 PSI FS, BHP=3540, DHWOB=2K 4/2/2019 4/2/2019 0.30 SLOT WELLPR MILL P Pick up off bottom to reset. to hard to 10,443.0 10,443.0 07:36 07:54 be fill. Reset. Set back down 2.5K DHWOB, 1.88 BPM @ 3635 PSI FS. BHP-3540 4/2/2019 4/2/2019 0.50 SLOT WELLPR MILL P 10443, Metal on shaker, PUH consult 10,443.0 10,444.0 07:54 08:24 town eng. RBIH dry. Set down @ 10444 attempt to move down. Set 8K. 4/2/2019 412/2019 2.80 SLOT WELLPR TRIP P Trip out of well 10,444.0 46.0 0824 11:12 4/2/2019 4/2/2019 1.20 SLOT WELLPR PULD P At surface, PJSM, PUD BHA#5, Lay 46.0 0.0 11:12 12:24 down motor. Mill out 2.80 NO Go 4/2/2019 4/2/2019 1.30 SLOT WELLPR SLKL P Move in / spot up slickline unit 0.0 0.0 1224 13:42 4/2/2019 4/2/2019 2.40 SLOT WELLPR SLKL P PJSM, R/U slickline unit, full pressure 0.0 0.0 1342 16:06 control equipment on rig Floor 4/2/2019 4/2/2019 1.90 SLOT WELLPR SLKL P PT slick line lubricator to 2500 PSI - 0.0 0.0 1606 18:00 RIH with 2.47 LIB, POOH after tagging @ 10,462' SL depth 4/2/2019 4/2/2019 0.50 SLOT WELLPR SLKL P PJSM, pop off lubricator, LD LIB, 0.0 0.0 18:00 18:30 Picutes on S: Drive, confer w/ SL supervisor & town, decision made to to run non-retrievable spear. 4/2/2019 4/2/2019 0.40 SLOT WELLPR SLKL P PU non-retrievable spear 0.0 0.0 18:30 18:54 4/2/2019 4/2/2019 2.10 SLOT WELLPR SLKL P RIH w/ spear, attempt to spear into 0.0 0.0 18:54 21:00 fish, spang down for -45 min, unable to latch into fish, POOH to inspect tool 4/2/2019 4/2/2019 0.60 SLOT WELLPR SLKL P LD tools, small scratches on face of 0.0 0.0 21:00 21:36 grapple, decision made to run 1-1/2" braided line brush " Test non-retrievable spear on 4' piece of liner at surface to ensure engagment is possible, engages as designed 4/2/2019 4/2/2019 0.70 SLOT WELLPR SLKL P MU braided line brush 0.0 0.0 21:36 2218 4/2/2019 4/2/2019 0.20 SLOT WELLPR SLKL P PU braided line brush, stab on 0.0 0.0 2218 2230 lubricator, PT 4/2/2019 4/2/2019 1.20 SLOT WELLPR SLKL P RIH wl braided line brush, run tool into 0.0 0.0 2230 23:42 fish, see overpull of brushes in PU's 4/2/2019 4/3/2019 0.30 SLOT WELLPR SLKL P Begin POOH (to PU non-retrievable 0.0 0.0 2342 00:00 spear) 4/312019 4/3/2019 0.10 SLOT WELLPR SLKL P Complete POOH 0.0 0.0 00:00 00:06 4/312019 4/3/2019 0.20 SLOT WELLPR SLKLP Pop off lubicator & LD tools, tattle tails 0.0 0.0 00:06 00:18 bent back, marking on 2.20" swedge at -5' up tool, appear to have engaged fish, retrieved 2 small steal fish pieces Page 7135 Report Printed: 513/2019 Operations Summary (with Timelog Depths) t1 , 1c-11 1W Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time Dur(hd Phase Op Code Activity Code Time P -T -X Operation (fIKEh End Depth (W) 4/3/2019 4/3/2019 1.30 SLOT WELLPR SLKL P PU non -retrievable spear, PT, RIH, 0.0 0.0 0018 01:36 latched into fish, jarred up -25 times, sheared off spear (GR), no movement of fish 4/3/2019 4/3/2019 0.60 SLOT WELLPR SLKL P POOH 0.0 0.0 01:36 02:12 4/3/2019 4/3/2019 2.50 SLOT WELLPR SLKL P PU 3" GS, RIH, latch into fish, jar on 0.0 0.0 02:12 04:42 fish for 1.25 hrs, unable to move fish, shear off fish "BOT on the way to fish on coil 4/3/2019 4/3/2019 0.60 SLOT WELLPR SLKL P POOH 0.0 0.0 04:42 05:18 4/3/2019 4/3/2019 1.10 SLOT WELLPR SLKL P At surface, Bleed off lubricator. Lay 0.0 0.0 05:18 06:24 down slick line equipment. Put lubricator in pipe shed 4/3/2019 4/3/2019 1.40 SLOT WELLPR PULD P M/U BHA#6. Fishing BHAwith weight 0.0 67.0 0624 07:48 bars, accelorator, Jars, and GS spear. Pressure deploy. make up to coil and surface test. Tag up and set counters 4/3/2019 4/3/2019 1.80 SLOT WELLPR TRIP P Trip in hole, EDC open 67.0 9,745.0 07:48 09:36 4/3/2019 4/3/2019 0.10 SLOT WELLPR DLOG P Log Gamma tie in for -3' 9,745.0 9,770.0 0936 09:42 4/3/2019 4/3/2019 0.10 SLOT WELLPR TRIP P Continue in well, Close EDC @ 10225 9,770.0 10,441.0 0942 09:48 4/3/2019 4/3/2019 0.50 SLOT WELLPR JAR P Set down and lift off fish. Set back 10,441.0 10,050.0 0948 10:18 down and latch. P/U to 50K and fire jars. Pull up to 59K and start moving fish uphole 4/3/2019 4/3/2019 2.00 SLOT WELLPR TRIP P 10,050 stop, open EDC. See slight 10,050.0 59.0 10:18 12:18 overpull @ 10,189 milled nipple. Hang up in SSSV @ 2308. Shut EDC. Work down out of SSSV. Bring control pressure up to 5K PSI. Work free down. PUH and hung up in SSSV Cock jars down. PUH jars fire @ 43K continue out of hole 4/3/2019 4/3/2019 2.30 SLOT WELLPR PULD P At surface tag up and space out. PUD 59.0 0.0 12:18 14:36 BHA#6. Have fish. Length 20.38'. Jet cut end flared to 2.752. Overall fish recovered 465.28' 4/3/2019 4/3/2019 1.00 SLOT WELLPR PULD P PJSM, Complete HES slickline rig 0.0 0.0 1436 15:36 down. Remove spear from fish 4/3/2019 4/3/2019 1.40 SLOT WELLPR PULD P PJSM. P/U BHA#7 FCO with straight 0.0 51.3 15:36 17:00 motor and D331 mill and PD. Chek pack offs - Good 4/3/2019 4/3/2019 1.70 SLOT WELLPR TRIP P RIH BHA#7 51.3 9,730.0 1700 18:42 4/3/2019 4/3/2019 0.20 SLOT WELLPR DLOG P Log K1 for -2' correction, close EDC 9,730.0 9,760.0 18:42 18:54 4/3/2019 4/3/2019 1.60 SLOT WELLPR TRIP P Continue FCO, PUW = 37 @ 10,200', 9,760.0 10,717.0 1854 20:30 1.85 bpm, FS = 290 psi, circ = 3656 psi, WHIP = 20 psi, significant asphaltenes over shaker, pump 5x5 sweeps, taking bites & picking up, drop in MW out, begin taking returns to tiger -tank (pinch in choke), cleans up, begin taking returns back inside Page 8135 Report Printed: 513/2019 - Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Siert Depth Start Tme EM Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Dept (ftKB) 4/3/2019 4/3/2019 1.40 SLOT WELLPR CIRC P Continue FCO, clean down to 10,717' 10,717.0 10,425.0 20:30 21:54 & hard tag, PUW = 37K, pump 5x5 sweeps, recip WS setting area, circulate 2 bottoms up, asphallenes clean-up over shakers PJSM w/ LRS for hot diesel flush 4/3/2019 4/3/2019 0.30 SLOT WELLPR DLOG P Log K1 for 0' Correction, RIH to bottom 10,425.0 10,690.0 21:54 22:12 4/3/2019 4/4/2019 1.80 SLOTWELLPR CIRC P Begin circulating 100 bbl of 180° 10,690.0 10,690.0 22:12 00:00 1 diesel (1.5 bpm) 4/4/2019 4/4/2019 SLOT WELLPR CIRC P Complete diesel circulation, chased w/ 10,690.0 10,690.0 00:00 00:18 DuoVis, 4/4/2019 4/4/2019 SLOT WELLPR TRIP P POOH, tag up, open EDC failed, 10,690.0 51.0 00:18 02:18 PJSM undeploy w/ failed checks 4/4/2019 4/4/2019 F2.00 SLOT WELLPR PULD P PUD BHA#7 & LD tools, mill came out 51.0 0.0 02:18 03:42 2.80" no-go, PJSM 4/4/2019 4/4/2019 SLOT WELLPR PULD P PU BHA#8 Caliper (HES real-time), 0.0 24.0 03:42 04:24 slide in cart, check pack-offs, MU to coil, tag up, set counters 4/4/2019 4/4/2019 2.20 SLOT WELLPR TRIP P RIH w/ BHA #8 24.0 10,707.0 04:24 06:36 4/4/2019 4/4/2019 0.50 SLOT WELLPR DLOG P 10,707', Line up across the top, Open 10,707.0 10,130.0 06:36 07:06 caliper finger. Log up 25 FPM 4/4/2019 4/4/2019 0.10 SLOT WELLPR TRIP P Close finger. RBIH 10,130.0 10,350.0 07:06 07:12 4/4/2019 4/4/2019 0.20 SLOT WELLPR DLOG P Open fingers. relog 10,350 to 10,121 10,350.0 10,121.0 07:12 07:24 for comparison 4/4/2019 4/4/2019 1.70 SLOT WELLPR TRIP P Close caliper fingers. Trip out of hole 10,121.0 22.0 07:24 09:06 4/4/2019 4/4/2019 0.70 SLOT WELLPR PULD P At surface, PJSM, Shut swab. Unstab 22.0 0.0 09:06 09:48 injector. Lay down caliper and camera adapter 4/4/2019 4/4/2019 2.20 SLOT WELLPR CTOP P Pull floats from UQC. Stab injector on 0.0 0.0 09:48 12:00 well. Jet stack roll CT to water. Unstab injector. Fluid pack BOPE obtain shell test 4/4/2019 4/4/2019 6.00 SLOT WELLPR BOPS P Start full BOPE test, perform draw- 0.0 0.0 12:00 18:00 down test, test IRV. Test witness waived by Matt Herrera, AOGCC, " 250 low 13500 high 4/4/2019 4/4/2019 1.20 SLOT WELLPR CTOP P Roll coil to drilling fluid, pop off 0.0 0.0 18:00 19:12 injector, install checks in UQC, load BOT tools onto rig, bring tools to rig floor, PJSM 4/4/2019 4/4/2019 0.90 SLOT WELLPR PULD P PD BHA#9 Haily Under-Reamer 0.0 66.0 19:12 20:06 (4.10" & 4.7" blades), slide in cart, check pack-offs, MU to coil, tag up, set counters 4/4/2019 4/4/2019 1.90 SLOT WELLPR TRIP P RIH w/ BHA #9 66.0 10,435.0 20:06 22:00 4/4/2019 4/4/2019 0.10 SLOT WELLPR DLOG P Log K1 for -4' correction, close EDC, 10,435.0 10,474.0 22:00 22:01 1 PUW = 35K 4/4/2019 4/4/2019 0.20 SLOT WELLPR TRIP P Continue RIH, RIW = 12.2K 10,474.0 10,660.0 22:06 22:18 1 I Page 9/35 Report Printed: 5/3/2019 - Uperations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Start Time End Time Our (hr) Phase Op Code Ac Vfty Code Time P -T -X Operation (flKB) End DepM (ftK8) 4/4/2019 4/4/2019 1.00 SLOT WELLPR UREM P Under -reaming, start at 1 fpm, 1.87 10,660.0 10,681.0 22:18 23:18 bpm, dp = 1420 psi, annular = 3658 psi, pump = 4610 psi, CWT = 11.5K, WOB = 0.61K, vibrations into red Stall at 10,679', PUW = 38K, out rate dropped (from 1,8 bpm to 1.64 bpm), rate out continues to drop to 1.36 bpm, stall at 10,681', PUW = 37K, annular increasing, packing off, significant cement over shakers 4/4/2019 4/5/2019 0.70 SLOT WELLPR UREM P Continue under -reaming, reduce 10,681.0 10,687.0 23:18 00:00 speed to .2 fpm, dp = 1313 psi, annular = 3973 psi, pump = 4781 psi, annular dropped & rate out increased back to 1.8 bpm 4/5/2019 4/5/2019 1.80 SLOT WELLPR UREM P Continue under -reaming from 10,687' 10,687.0 10,700.0 00:00 01:48 @ 0.2 fpm, dp = 1283 psi, 1.84 bpm in, 1.79 bpm out, annular = 3619 psi, pump = 4341 psi, CWT = 8.5K, WOB =1K Stall at 10,690', 10,694', 10,699', again at 10,698' getting to bottom, ream to 10,700' 4/5/2019 4/5/2019 0.40 SLOT WELLPR UREM P Back -ream up to 10,600'@ 5 fpm, 10,700.0 10,600.0 01:48 02:12 PUW = 39K 4/5/2019 4/5/2019 1.10 SLOT WELLPR UREM P Under -ream from 10,600', dp = 1275 10,600.0 10,660.0 02:12 03:18 psi, pump = 4387 psi, 98% returns, start at 0.2 fpm, walk up to 0.5 fpm, then 1 fpm, vibrations to 4, pump 5x5 sweeps 4/5/2019 4/5/2019 0.30 SLOT WELLPR UREM P Back -ream @ 5 fpm, PUW = 38K 10,660.0 10,600.0 03:18 03:36 4/5/2019 4/5/2019 2.30 SLOT WELLPR TRIP P Open EDC, POOH 10,600.0 66.0 03:36 05:54 4/5/2019 4/5/2019 1.10 SLOT WELLPR PULD P PJSM, PUD BHA#9. All under reamer 66.0 0.0 05:54 07:00 blades intact 4/512019 4/5/2019 0.90 SLOT WELLPR PULD P M/U HES caliper, Stab on and surface 0.0 22.7 07:00 07:54 test. 4/5/2019 4/5/2019 2.10 SLOT WELLPR TRIP P RIH BHA#10 22.7 10,704.0 07:54 10:00 4/5/2019 4/5/2019 0.30 SLOT WELLPR DLOG P 10,704'. Open caliper arms. Log 10,704.0 10,148.0 10:00 10:18 uphole. Close caliper arms 415/2019 4/5/2019 1.70 SLOT WELLPR TRIP P Trip out of well 10,148.0 22.0 10:18 12:00 4/512019 4/5/2019 0.50 SLOT WELLPR PULD P PJSM. Pull BHA #10 from well 22.0 0.0 12:00 12:30 j 4/5/2019 4/5/2019 1.20 SLOT WELLPR PULD P M/U Whipstock in pipe shed/ Plan 0.0 0.0 12:30 13:42 change reset motor back to 0° and pick up under reamer 4/5/2019 4/5/2019 1.30 SLOT WELLPR PULD P PJSM, PD BHA#11 Under reamer on 0.0 66.0 13:42 15:00 straight motor, Make up injector and surface test. 4/5/2019 4/512019 1.70 SLOT WELLPR TRIP P RIH BHA#11, EDC open. Pumping 66.0 9,730.0 15:00 16:42 1 1 1 min rate 4/5/2019 4/512019 0.10 SLOT WELLPR DLOG P Log gamma tie in for -4.5 9,730.0 9,770.0 16:42 16:48 415/2019 41512019 0.30 SLOT WELLPR TRIP P Continue RIH to 10,600' 9,770.0 10,660.0 16:48 17:06 1 Page 10135 ReportPrinted: 513/2019 Operations Summary (with Timelog Depths) 113-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth StartTime End rime Dur (M Phase Op Code Activib Code nm P -T -X Operation (fil(B) End Depth (ftKB) 4/5/2019 4/5/2019 1.50 SLOT WELLPR UREM P Under -reaming, dp = 1249 psi, annular 10,660.0 10,700.0 17:06 18:36 = 3610 psi, pump =4368 psi, 1 fpm from 10,660' to 10,700', back -ream to 10,680', under -ream down to 10,700' @ 0.5 fpm •' Cement over shakers (trace asphaltenes, very little metal) 4/5/2019 4/5/2019 0.30 SLOT WELLPR UREM P Back -ream up to 10,600'(5 fpm) 10,700.0 10,600.0 18:36 18:54 4/5/2019 4/5/2019 1.80 SLOT WELLPR UREM P Under -ream from 10,600'to 10,660'(1 10,600.0 10,680.0 18:54 20:42 fpm), slow to 0.5 fpm from 10,660' to 10,680' "Stall @ 10,668', PUW = 37K 4/5/2019 41512019 0.30 SLOT WELLPR UREM P Back -ream 10,680'to 10,600'(5 fpm), 10,680.0 10,600.0 20:42 21:00 1 PUW = 37K 4/5/2019 4/5/2019 1.60 SLOT WELLPR UREM P Under -ream from 10,600'to 10,700'(1 10,600.0 10,700.0 21:00 22:36 fpm), pump 5x5 sweeps, open EDC 4/5/2019 4/612019 1.40 SLOT WELLPR TRIP P Begin POOH, PUW = 36K 10,700.0 2,600.0 22:36 00:00 4/6/2019 4/6/2019 0.60 SLOT WELLPR TRIP P Complete POOH 2,600.0 66.0 00:00 00:36 4/6/2019 4/6/2019 1.20 SLOT WELLPR TRIP P PJSM, PUD BHA#11, LD tools 66.0 0.0 00:36 01:48 41612019 4/6/2019 1.10 PROD1 RPEQPT PULD P PD BHA#12 WS Assembly, slide in 0.0 75.0 01:48 02:54 cart, check pack -offs, MU to coil, lag up, set counters 4/6/2019 4/612019 1.80 PRODi RPEQPT TRIP P RIH w/ BHA#12 75.0 10,420.0 02:54 04:42 4/6/2019 4/6/2019 0.20 PROD1 RPEQPT DLOG P Log Kt for -3.5' correction 10,420.0 10,476.0 04:42 04:54 4/6/2019 416/2019 0.20 PROD? RPEQPT TRIP P Continue RIH, arrive at setting depth, 10,476.0 10,697.0 04:54 05:06 PUW = 35K, Gose EDC, RBIH, bring up pump, shear off at 3700 psi, set - down 5K WOB, TOWS -10,684' 4/6/2019 4/6/2019 1.80 PROD1 RPEQPT TRIP P POOH w/ BHA#12, PUW = 35K 10,697.0 69.0 05:06 06:54 4/6/2019 4/6/2019 1.10 PROD1 RPEQPT PULD P Tag up and space out. PJSM PUD 69.0 0.0 06:54 08:00 1 1 BHA#12 Whipstock setting tools 4/6/2019 4/6/2019 1.30 PROD1 WHPST WPST P M/U BHA#13 with .6° AKO motor, 0.0 74.7 08:00 09:18 2.80 DSM, 2.79 String reamer, and 10' pup. Pressure deploy. Make up to coil and surface test 4/6/2019 4/6/2019 1.90 PROD1 WHPST WPST P RIH BHA#13 74.7 10,440.0 09:18 11:12 4/6/2019 4/6/2019 0.20 PROD1 WHPST WPST P Log K1 for 4.5', Close EDC, 10,440.0 10,477.0 11:12 11:24 PUW=36K 4/6/2019 4/6/2019 0.20 PROD1 WHPST WPST P Continue in well, Dry lag @ 10688. 10,688.0 11:24 11:36 PUH 4/6/2019 416/2019 4.20 PROD? WHPST WPST P PUH bring pump on 1.9 BPM @ 402410,692.611:36 15:48 PSI FS, BHP=3668, Ease onto tray call pinch point 10,688.5. r10.477.01 4/6/2019 4/6/2019 2.20 PROD1 WHPST WPST P DHWOB fall off. Call bottom of 10,695.8 15:48 18:00 window. Continue time milling for string reamer exit 4/6/2019 4/6/2019 0.90 PROD1 WHPST WPST P Begin pushing on it w/ string reamer 10,711.0 18:00 18:54 out, milling rat -hole, CWT = 11.8K, WOB = 1.3K, pump = 4114 psi, annular = 33722 psi, WHP = 18 psi Page 11135 Report Printed: 5/312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth start Time End Time Our (hr) Phase Op Cade Aawity Cade Time P -T -X Operation YMB) End Depth (flKB) 4/6/2019 4/6/2019 1.80 PROD1 WHPST REAM P Dress window (HS, 30R, 30R, & 10,711.0 10,711.0 18:54 20:42 180°), 1 fpm, dry drift window up & down, clean, tag TD of rat -hole, pump sweeps, PUW = 36K 4/6/2019 4/6/2019 1.90 PROD1 WHPST TRIP P Open EDC, POOH w/ BHA #13, PJSM 10,711.0 75.0 20:4222:36 4/6/2019 4/6/2019 1.00 PROD1 WHPST PULD P PUD BHA#13, mill came out 2.80" no- 75.0 0.0 22:36 23:36 go, string reamer came out 2.79" po- go 4/6/2019 4/7/2019 0.40 PROD1 DRILL PULD P Begin PD BHA#14 Build/Turn 0.0 72.0 23:36 00:00 Assembly (2.2° AKO motor, RS Dynamus bit) 4/7/2019 417/2019 0.70 PROD1 DRILL PULD P Complete PD BHA#14 Build/Turn 0.0 72.0 00:00 00:42 Assembly (2.2° AKO motor, RB Dynamus bit), slide in cart, check pack -offs, MU to coil, tag up, set counters 4/7/2019 4//12019 2.20 PROD1 DRILL TRIP P RIH w/ BHA#14 72.0 10,425.0 00:42 02:54 417/2019 4/7/2019 0.20 PROD1 DRILL DLOG P Log Kt for 4 correction, close EDC, 10,425.0 10,463.0 02:54 03:06 PUW = 35K 4/7/2019 4/7/2019 0.10 PROD1 DRILL TRIP P Cotninue RIH 10,463.0 10,711.0 03:06 03:12 4/7/2019 417/2019 1.20 PROD1 DRILL DRLG P Drilling, FS = 535 psi @ 1.9 bpm, 10,711.0 10,805.0 03:12 04:24 CWT = 10.5K, WOB = 2.3K, annular = 3788 psi, WHP = 79 psi, pump = 4161 psi, 98% returns, pump 5x5 sweeps, begin losing -0.1 bpm @ 10,799', drill to called TD of 10,805' 4/7/2019 4/7/2019 0.20 PROD1 DRILL TRIP P PUH to log K1 & RA, PUW = 38K 10,805.0 10,425.0 04:24 04:36 417/2019 417/2019 0.40 PRODt DRILL DLOG P Log K1 for 0' correction, log RA at 10,425.0 10,725.0 04:36 05:00 10,691' TOWS = 10,684', BOW = 10,692, RA = 10,691.5' 4/7/2019 4/7/2019 1.80 PROD1 DRILL TRIP P POOH, PUW=37K 10,725.0 67.0 05:00 06:48 4/7/2019 4/7/2019 1.30 PROD1 DRILL TRIP P At surface, Tag up and space out. 67.0 0.0 06:48 08:06 PJSM. PUD BHA#14 Build section BHA 4/7/2019 417/2019 0.80 PROD1 DRILL OTHR P M/U Nozzle. Stab on well. Jet stack. 0.0 0.0 08:06 08:54 Flush micro motion. Pull off well. Change out floats in UQC 4/712019 4/7/2019 1.20 PROD1 DRILL PULD P PJSM. M/U Mill, Motor, and FVS and 0.0 78.2 08:54 10:06 scribe. PD BHA#15 lateral BHA with .5° AKO motor, agitator, and RB HYC A3 bicenter. Make up to coil and surface test 4/7/2019 4/7/2019 2.10 PROD1 DRILL TRIP P RIH, Shallow test agitator @ 300'. 78.2 10,445.0 10:06 12:12 Continue in well 4/7/2019 4/7/2019 0.10 PROD1 DRILL DLOG P Log Kt for -0.5', Close EDC, 10,445.0 10,464.0 12:12 12:18 PUW=36K 41712019 4/7/2019 0.20 PROD1 DRILL TRIP P Continue in well, Clean pass through 10,464.0 10,803.0 12:18 12:30 window 417/2019 4/7/2019 0.80 PROD1 DRILL DRLG P 10803', Drill ahead, 1.9 BPM @ 5057 10,803.0 10,864.0 12:30 13:18 PSI FS, BHP=3833. New mud @ bit 10,844' 4/7/2019 4/7/2019 0.10 PROD1 DRILL WPRT P Pull BHA wiper, PUW=35K. 10,864.0 10,864.0 13:18 13:24 I 4/7/2019 4/7/2019 1.90 PROD1 DRILL DRLG P New mud around, 1.9 BPM @ 10,864.0 11,000.0 13:24 15:18 4634PSI FS, BHP=3807. RIW=10.5K, DHWOB=1.5K Page 12/35 Report Printed: 51312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time Our (hr) Phase Op Code AclNily Cade Time P -T -X Operatlon (aKB) End Depth (ftKB) 4/7/2019 4/7/2019 2.40 PROD1 DRILL DRLG P Start continuous rotating drilling 11,000.0 11,205.0 15:18 17:42 11,000'- 11,155', 1.9 BPM @ 4634 PSI FS, BHP=3840 4/7/2019 4/7/2019 0.20 PROD1 DRILL WPRT P Wiper up -hole, PUW = 37K 11,205.0 10,813.0 17:42 17:54 4!7/2019 4/7/2019 0.20 PROM DRILL WPRT P Wiper in-hole, RIW = 13K 10,813.0 11,205.0 17:54 18:06 4!712019 4/7/2019 1.70 PROM DRILL DRLG P Drilling, FS = 1303 psi at 1.9 bpm, 11,205.0 11,290.0 18:06 19:48 CWT= 11.51K, WOB= 1.6K, annular= 3846 psi, WHIP = 114 psi, pump = 4955, —100% returns, avg ROP = 50 fph Drilling a bit ratty, clays/sands in samples, 50K PUW from 11,241', increase to 6% KCI 4/7/2019 4!7/2019 1.50 FROM DRILL DRLG P Continue drilling from 11,290, CWT = 11,290.0 11,370.0 19:48 21:18 8.1K, WOB = 2.85K, annular = 3855 psi, WHIP = 119 psi, pumps 5x5 sweeps, 100' wiper from 11,357', PUW = 39K, PUW = 45K from 11,370', avg ROP = 53 fph Holding —87° Inc in attempt to acquire the C1 prior to Fault 1 crossing (per geology) 4/7/2019 4/7/2019 1.70 FROM DRILL DRLG P PUW= 45K from 11,370', pull heavy to 11,370.0 11,467.0 21:18 23:00 52K break -over Drilling, CWT = 10.8K, WOB = 1.9K, annular = 3851 psi, WHIP = 78 psi, PUS as required, avg ROP = 71 fph 4/7/2019 4/8/2019 1.00 FROM DRILL DRLG P Continuous rotation drilling, CWT = 11,467.0 11,511.0 23:00 00:00 1 OK, WOB = 1.7K, annular = 3875 psi, WHIP = 69 psi, avg ROP = 44 fph 4/812019 4/8/2019 1.50 FROM DRILL DRLG P Continuous rotation drilling from 11,511.0 11,600.0 00:00 01:30 11,511', CWT =7.4K, WOB =2.5K, annular= 3877 psi, WHIP = 66 psi, pump sweeps, avg ROP = 60 fph 4/8/2019 4/8/2019 0.30 PROD1 DRILL WPRT P Wiper up -hole, PUW = 40K 11,600.0 10,800.0 01:30 01:48 4/8/2019 4/8/2019 0.60 PRODI DRILL WPRT P Wiper in-hole, coil stacked at 11,400', 10,800.0 11,600.0 01:48 02:24 no WOB, PUW = 50K, reduce rate to gel through & bring back up quickly, RIW = 9.9K 4/8/2019 4/8/2019 1.60 PROD1 DRILL DRLG P BOBD (non oscillating to acquire 11,600.0 11,697.0 02:24 04:00 targets) FS = 1190 psi @ 1.85 bpm, CWT= 10.2K, WOB= 1.3K, annular= 3892 psi, WHIP = 20 psi Confer w/ town geology, decsion made drop to 84° Inc (target deeper in C1 prior to fault crossing) 4/8/2019 4/8/2019 0.60 PROD1 DRILL WPRT T Rig Link crashed, PU off bottom, PUW 11,697.0 11,697.0 04:00 04:36 = 43K, pulled heavy to 63K at 11,620' (at 7 fpm), pump 5x5 sweeps, reboot, resolve issue, RIW = 8.71K 4/8/2019 4/8/2019 3.00 FROM DRILL DRLG P Drilling, FS = 1107 psi @ 1.9 bpm, 11,697.0 12,000.0 04:36 07:36 CWT = 8.6K, WOB = 1.4K, annular = 3864 psi, pump = 4784 psi, drilling break at —11,699', PUW = 41 K from 11,756' Page 13135 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depth Start Time End Time Dur (hr) Phase op Code Aativity Code Time P -T -X Operation (ftKB) EW DepN (110) 4/8/2019 4/8/2019 1.20 PROD1 DRILL WPRT P Wiper to window with tie into RA 12,000.0 12,006.0 07:36 08:48 marker for a +7' correction. Some slight overpulls coming up. RBIH stacking multiple times. Reduce rate to get throigh 11,450, 11496' 4/8/2019 4/8/2019 3.50 PROD? DRILL DRLG P 12,006', Drill 1.9 BPM @ 4742 PSI 12,006.0 12,400.0 08:48 12:18 FS, BHP=3930, RIW=7.2K, DHWOB=2K. 12059' start working rotation 4/8/2019 4/8/2019 0.30 PROD1 DRILL WPRT P 12,400', 800 foot wiper with 5 X 5 12,400.0 11,592.0 12:18 12:36 sweeps, PUW=44K 4/8/2019 4/8/2019 1.80 PRODt DRILL WPRT P RBIH, Stack out @ 11,941. Unable to 11,592.0 12,400.0 12:36 14:24 get past at various rates and speeds. P/U heavy at 68K and dragging. -12K DHWOB. Pump more sweeps and circ bottoms up. Normal material on shakers at bottoms up Work through bad area 11940 to 12,070. Min rale, Continue to bottom at full rate 4/8/2019 4/8/2019 0.50 PRODi DRILL DRLG P 12400 Drill, 1.84 BPM @ 4722 PSI 12,400.0 12,450.0 14:24 14:54 FS, BHP=3937, Goto rotation @ 10430'. 4/8/2019 4/8/2019 2.70 PROD? DRILL DRLG P 12450'. Increase inclination to 100° 12,450.0 12,628.0 14:54 17:36 turn up to cross cut. 1.84 BPM @ 4722 PSI FS, BHP=3954, 4/8/2019 4/8/2019 0.70 PROD1 DRILL WPRT P Pull wiper to 12,400. Staking, 12,628.0 12,628.0 17:36 18:18 PUW=53K 4/8/2019 4/8/2019 3.20 PROD1 DRILL DRLG P 12628', Drill, 1.89 BPM @ 4918 PSI 12,628.0 12,796.0 18:18 21:30 FS, BHP=3970, RIW-.8K, DHWOB=I.8K. Hard to get drilling 4/8/2019 4/8/2019 0.70 PROD1 DRILL WPRT P 12796', Wiper trip to 12,300'. 12,796.0 12,795.0 21:30 22:12 PUW=55K 4/8/2019 4/8/2019 0.60 PROD1 DRILL DRLG P 12795', Drill, 1.84 BPM @ 4810 PSI 12,795.0 12,822.0 22:12 22:48 FS, BHP=3970 4/8/2019 4/9/2019 1.20 PROD1 DRILL DRLG P 12822, Drill, 1.84 BPM @ 4810 PSI 12,822.0 12,860.0 22:48 00:00 FS, BHP=4025, New mud going down coil 4/9/2019 4/9/2019 0.60 PROD1 DRILL DRLG P Difficulty starting drilling, WOB w/ no 12,860.0 12,880.0 00:00 00:36 motorwork, drilled to called TD of 12,880', pump 10x10 sweeps 4/9/2019 4/9/2019 2.90 PROD1 DRILL TRIP P POOH, PUW = 38K, open EDC in 12,880.0 78.0 00:36 03:30 eased hole, PJSM, pre -load DS PDL 4/9/2019 4/9/2019 1.00 PRODi DRILL PULD P PUD BHA#15, bit came out a 1-1 78.0 0.0 03:30 04:30 " UT coil (thinnest @.165"), inspect injector 4/9/2019 4/9/2019 2.00 PROD2 STK PULD P PU/PD BHA#16 OH Anchored Billet, 0.0 72.0 04:30 06:30 failed checks, PUD, & redeploy, check pack -offs " Crew chage 4/9/2019 4/9/2019 2.10 PROD2 STK TRIP P RIH w/ BHA#16 72.0 10,445.0 06:30 08:36 4/9/2019 4/9/2019 0.40 PROD2 STK DLOG P Log K1 tor +15' correction, clean 10,445.0 10,495.0 08:36 09:00 counter wheel, PUW = 37K Page 14135 Report Printed: 51312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depm Stan Time End Time our (hr) Phase Op Code Amimty Code Time P -T -X Operation (ftKB) End Dept (ftKB) 4/9/2019 4/9/2019 0.80 PROD2 STK TRIP P Continue RIH, park at window, close 10,495.0 11,050.0 09:00 09:48 EDC, RIH & stack weight 10,744', PUW = 40K, dragging -3.7K WOB, RBIH, setdown at 10757' 10760', 10762', continue working through 10,802' Arrive at setting depth, PU 36K, bring on pumps, shear off at 4200 psi, set down 4K WOB, TOB -11,050', oriented HS 4/9/2019 4/9/2019 1.80 PROD2 STK TRIP P POOH, open EDC, PJSM 11,050.0 78.0 09:48 11:36 4/9/2019 4/9/2019 1.00 PROD2 STK PULD P PUD BHA #16, bit came out a ... 78.0 0.0 11:36 12:36 419/2019 4/9/2019 0.40 PROD2 STK -go PE P Suck out stack, PU test jnt, function 0.0 0.0 12:36 13:00 test BOP's, LD test jnt 4/9/2019 4/9/2019 1.30 PROD2 STK PULD P PD BHA #17 KO/Drilling Assembly 0.0 78.0 13:00 14:18 (Agitator, 0.5° AKO motor, new HYC A3 bit), slide in cart, chaged out pack - offs, MU to coil, tag up, space out, set counters 4/9/2019 4/9/2019 2.20 PROD2 STK TRIP P RIH w/ BHA#17, test agitator, 1.9 78.0 10,435.0 1418 16:30 bpm, pump = 4650, FS = 1203 psi (verify on transducer) 4/9/2019 4/9/2019 0.10 PROD2 STK DLOG P Log K7 for -4' correction 10,435.0 10,473.0 16:30 16:36 4/9/2019 4/9/2019 0.40 PROD2 STK TRIP P Continue RIH, PUW = 36K, clean 10,473.0 11,050.1 1636 17:00 through window, dry tag TOB at 11,051', PUW = 39K, bring up pump &. RBIH 4/9/2019 4/9/2019 1.20 PROD2 STK KOST P Milling off billet 330° ROHS, FS = 11,051.1 11,052.1 1700 18:12 1242 psi @ 1.9 bpm, 1fph for 1 ft 4/9/2019 4/9/2019 0.40 PROD2 STK KOST P Milling off billet 330° ROHS, FS = 11,052.1 11,053.1 1812 18:36 1242 psi @ 1.9 bpm, 2fph for 1 ft 4/9/2019 4/9/2019 0.20 PROD2 STK KOST P Milling off billet 330° ROHS, FS = 11,053.1 11,054.1 1836 18:48 1242 psi @ 1.9 bpm, 3fph for 1 ft 4/9/2019 4/9/2019 0.40 PROD2 DRILL DRLG P Off billet drilling ahead -10 ft/hr, WOE 11,054.1 11,058.0 18:48 19:12 <1 k lbs. 4/9/2019 4/9/2019 1.20 PROD2 DRILL DRLG P Past OH anchered billet slips, Drill 11,058.0 11,150.0 19:12 2024 ahead with unresticted WOB. CT Wt 8.6 k lbs, WOB 2.5 k lbs, ROP 89 ft/hr 4/9/2019 4/9/2019 0.20 PROD2 DRILL WPRT P PU Wt 30 k bs, PUH to dry drift billet. - 11,150.0 11,003.0 20:24 20:36 1 k WOB tug as the bit pased the top of billet. 4/9/2019 4/9/2019 0.10 PROD2 DRILL WPRT P RBIH, CT Wt 10 k lbs, billet clean. 11,003.0 11,149.0 20:36 20:42 4/9/2019 4/10/2019 3.30 PROD2 DRILL DRLG P CT 5027 psi @ 1.87 by in and 1.86 11,149.0 11,422.0 2042 00:00 bpm out, free spin diff 1248 psi, BHP 3808 psi holding 11.1 ppg EMW, BOBO, cT Wt 8.8 k lbs, WOB 2 k Itis, 11,271' PU 40 k lbs - MM out acting up, bypass, flush/blowdown, drive gain back to normal. Average ROP over interval drilled - 83 ft/hr 4/10/2019 4/10/2019 0.30 PROD2 DRILL DRLG P OBD- 11,422.0 11,450.0 00:00 00:18 4/10/2019 4/10/2019 0.10 PROD2 DRILL WPRT P PU Wt 42 k lbs Wiper # 1 to just below 11,450.0 110112.0 00:18 00:24 the billet Page 15/35 ReportPrinted: 5/3/2019 Operations Summary (with Timelog Depths) e 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time. log Start oePtn stertlime End Time our (hr) Phase Op Code Ac" Code Time P -T -X Operation MKB) End Depth(aKB) 4/10/2019 4/10/2019 0.20 PROD2 DRILL WPRT P RBIH, RIH Wt 8.8 k Ibs - WeIIWorc 11,112.0 11,450.0 00:24 00:36 estimates 0.2 bbls cuttings returned. 4/10/2019 4110/2019 5.50 PROD2 DRILL DRLG P CT 4841 psi @ 1.88 bpm in and 1.87 11,450.0 11,850.0 00:36 06:06 bpm out, free spin diff 1300 psi, BHP 3880 psi holding 11.1 ppg @ the window. WH 87 psi, IA 122 psi, OA 34 psi. CT Wt 5.8 k lbs, WOB 2.7 k lbs, 11,545' PU - 45 k Itis 11,646' PU - 43 k lbs free spin 1313 psi 11,667' PU - 42 k lbs 11,720' PU - 43 k Itis Pump sweeps 4/10/2019 4/10/2019 0.30 PROD1 DRILL WPRT P Wiper up -hole, PUW = 43K, clean up 11,850.0 11,100.0 06:06 06:24 to 11,100' 4/10/2019 4/10/2019 0.30 PROD2 DRILL WPRT P Wiper in-hole, stack CWT at 11,267', 11,100.0 11,850.0 06:24 06:42 no WOB indication, PUW = 51 K, then got by, RIW = 10K 4/10/2019 4/10/2019 3.00 PROD2 DRILL DRLG P Drilling, FS = 1336 psi, CWT= 7.2K, 11,850.0 12,043.0 06:42 09:42 WOB = 2K, annular = 3860 psi, WHP = 46 psi, pump = 5292 psi, pump 5x5 sweeps, avg ROP = 64 fph 4/10/2019 4/10/2019 2.00 PROD2 DRILL DRLG P Drilling, CWT = 5.5K, WOB = 27, 12,043.0 12,138.0 09:42 11:42 annular = 3920 psi, WHP = 44 psi, pump = 5320 psi, begin continuous rotation drilling, avg ROP = 48 fph 100' wiper from 12,080', PUW = 44K PUW = 41 from 12,126' Drilling break at 12,114' 4/10/2019 4/10/2019 1.10 PROD2 DRILL DRLG P Drilling, CWT= 1.3K, WOB = 2.5K, 12,138.0 12,250.0 11:42 12:48 annular = 4007 psi, WHP = 18 psi, pump sweeps 4/10/2019 4/10/2019 1.20 PROD2 DRILL WPRT P Wiper to tubing tail, PUW = 45K, pull 12,250.0 10,325.0 12:48 14:00 heavy at 10,915' (55K), RBIH, PUH, pull heavy at 10,795', RIBH, stack -9K WOB, pull -13K WOB, begin packing off, work free, PUH, RBIH to surge BHA prior to pulling through window 4/10/2019 4/10/2019 0.20 PROD2 DRILL DLOG P RBIH & Log K1 for +6.5' correction 10,325.0 10,467.0 14:00 14:12 (circulate bottoms up from window at surface) 4/10/2019 4/10/2019 1.30 PROD2 DRILL WPRT P Wiper in-hole, sweeps timed to exit at 10,467.0 12,250.0 14:12 15:30 EOB, dean through build, PUH to 10,710', RBIH, stack weight at 11,677' 4/10/2019 4/10/2019 2.60 PROD2 DRILL DRLG P Drilling, FS = 1200 psi @ 1.9 bpm, 12,250.0 12,420.0 15:30 18:06 CWT = 1.5K, WOB = 1 K, annular = 4113 psi, WHP = 18 psi PUW = 47K from 12,350' Average ROP over section - 65 ft/hr 4/10/2019 4/10/2019 1.10 PROD2 DRILL DRLG P PU post crew change, CT Wt 62 k llbs, 12,420.0 12,496.0 18:06 19:12 RBIH CT 5396 psi @ 1.90 bpm in and 1.86 bpm out, Free spin 1398 psi, BHP 3991 psi, open choke, WH 16 psi, IA 124 psi, OA 42 psi CT Wt 6 k to -5 k lbs, WOB -1.8 klbs, More and more frequent pick ups, CT Wt - 55-60 k Itis Average ROP over section - 69 fUhr Page 16135 Report Printed: 513/2019 Operations Summary (with Timelog Depths) 110-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log scan Depth Start Tome End Time Dur (hr) Phase Op Code Ac" Code Time P-T.X Opembon (IIKB) End Depth ptKB) 4/10/2019 4/10/2019 0.40 PROD2 DRILL DRLG P Last PU 69 k lbs, 100' short BHA 12,496.0 12,526.0 19:12 19:36 wiper. RBIH, Drill ahead, start preparing for mud swap. Small short lived pack off event, 4/10/2019 4/10/2019 0.30 PROD2 DRILL WPRT P PU 52 k lbs, 100' BHAwiper, pump 12,526.0 12,526.0 19:36 19:54 5x5, RBIH 4/10/2019 4/10/2019 0.80 PROD2 DRILL DRLG P PU 69 k lbs, 100'short BHA wiper. 12,526.0 12,620.0 19:54 20:42 RBIH, Drill ahead, start preparing for mud swap. Small short lived pack off event, 4/10/2019 4/10/2019 0.40 PROD2 DRILL WPRT P PU , 55 k lbs, new mud started down 12,620.0 12,620.0 20:42 21:06 the coil, Slowly PUH liming out new mud to the bit while RBIH. 4/10/2019 4/10/2019 0.60 PROD2 DRILL DRLG P CT 4944 psi @ 1.9 bpm in and 1.89 12,620.0 12,738.0 21:06 21:42 bpm out. FS diff 1352 psi, BHP 4049 psi. CT Wt 5 k lbs, WOB 1.5 k lbs Average ROP over section - 148 ft/hr "New Mud at the bit 12,620' 4/10/2019 1411012019 0.50 PROD2 DRILL WPRT P PU Wt 50 k lbs - Wiper trip #1 12,738.0 11,940.0 21:42 2212 Trouble turning around, reduced rate to 1.5 bpm, 4/10/2019 4/10/2019 0.80 PROD2 DRILL WPRT P Multiple set downs while RBIH, 11,940.0 12,738.0 22:12 23:00 11,965, 11,984, 11,989, 11,982' -Hot gamma areas, - 140 API 0.4 bbls of cuttings returned per WW 4/10/2019 4/11/2019 1.00 PROD2 DRILL DRLG P CT 4785 psi @ 1.89 bpm in and 1.85 12,738.0 12,878.0 23:00 00:00 bpm out, Free psi diff 1303 psi, BHP 3940 psi, targeting 11.1 ppg EMW @ the window. WH 73 psi, IA 122 psi, OA 38 psi. CT Wt5to-5klbs, WOB 1.2 to 0.3k lbs. Average ROP over section - 140 ft/hr 4/11/2019 4/11/2019 0.20 PROD2 DRILL DRLG P CT 4785 psi @ 1.89 bpm in and 1.85 12,878.0 12,889.0 00:00 00:12 bpm out, Free psi diff 1303 psi, BHP 3940 psi, targeting 11.1 ppg EMW @ the window. WH 79 psi, IA 122 psi, OA 38 psi. CT Wt 5 to -5 k lbs, WOB 1.2 to 0.3 k lbs. Average ROP over section - 55 ft/hr 4/11/2019 4/11/2019 4.80 PROD2 DRILL DRLG P On something hard, Geo thinks 12,889.0 12,964.0 00:12 05:00 siderite CT 5127 psi @ 1.9 bpm, BHP 3898 psi, CT Wt 5.8 k lbs, WOB 3 k lbs. 12,946' PU Wt 40 k lbs RBIH CT 5000 psi @ 1.90 bpmfree spin diff 1335 psi, BHP 3947 psi, WH 117 psi, Cl Wt 7 k lbs, WOB 3 k lbs Average ROP over section - 15 1t/hr 4/11/2019 4/11/2019 2.00 PROD2 DRILL DRLG P Drilling, CWT =7.3K, WOB =3.2K, 12,964.0 12,986.0 05:00 07:00 annular = 3933 psi, WHIP = 117 psi, slow drilling w/ siderite in samples 4/11/2019 4/11/2019 3.50 PROD2 DRILL DRLG P Drilling, CWT= 6.3K, WOB = 3.4K, 12,986.0 13,035.0 07:00 10:30 annular = 3948 psi, WHP = 125 psi, pump = 5271 psi, PUW = 43K from 13,012', Continued low ROP w/ Siderite in samples, avg ROP = 14 fph 4/11/2019 4/11/2019 2.30 PROD2 DRILL DRLG P Drilling, CWT =7.9K, WOB =2.5K, 13,035.0 13,050.0 10:30 12:48 annular = 3942 psi, WHIP = 104 psi 4/11/2019 4/11/2019 0.30 PROD2 DRILL WPRT P Wiper up -hole, PU= 43, clean 13,050.0 12,250.0 12:48 13:06 Page 17135 Report Printed: 51312019 " Operations Summary (with Timelog Depths) § 1c-11 Rig: NABORS CDR3-AC Jab: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Cotte Time P -T -X Operation (ftKa) EM Depth (110) 4/11/2019 4/11/2019 0.30 PROD2 DRILL WPRT P Wiper in-hole, RIH = 6.81K, clean 12,250.0 13,050.0 13:06 13:24 4/11/2019 4/11/2019 1.10 PROD2 DRILL DRLG P Drilling, FS = 1304 psi @ 1.88 bpm, 13,050.0 13,058.0 13:24 14:30 CWT = 9.6K, WOB = 2.9K, annular = 3940 psi, WHIP = 97 psi, pump = 5306 psi 4/11/2019 4/11/2019 1.90 PROD2 DRILL DRLG P Drilling break at 13058', CWT = 7.2K, 13,058.0 13,200.0 14:30 16:24 WOB = 1.3K, annular = 3952 psi, begin snubbing, PUW = 50K, pump 5x5 beaded sweeps to good effect (39K PUW w/ beads out) Grab new parameters: FS = 1325 psi 4/11/2019 4/11/2019 2.10 PROD2 DRILL DRLG P Driling, CWT = 1.61K, WOB = 1.8K, 13,200.0 13,310.0 16:24 18:30 annular = 3961 psi, WHIP = 82 psi avg ROP = 52 fph 4/11/2019 4/11/2019 1.20 PROD2 DRILL WPRT P PU Wt 52 k lbs - Bit trip 13,310.0 10,650.0 18:30 19:42 13,137-13,048' light WOB tugs -300 lbs 12,250-12,218 firm WOB tugs - 680 lbs 11,962 - 11,934 heavy WOB tugs 2.5 - 3 k lbs 10,788'-6 k WOB tug, believe it was a tool orientation issue not a hole issue. Window clean -150 Ib WOB tug 4/11/2019 4/11/2019 2.00 PROD2 DRILL TRIP P Park, open EDC, Online @ 1.95 bpm, 10,650.0 65.0 19:42 21:42 POH Saw coil weight swing and a small pack off event when passing the Mule shoe @10,331'. Preloaded drillers side PDL in order to swap our Res tool per town request. 4/11/2019 4/11/2019 1.40 PROD2 DRILL PULD P PUD BHA 17 65.0 0.0 21:42 23:06 Lowest WH 690 psi, estimate BHP 10.8-10.9 ppg or lower. Inspected pipe, 0.174, 0.175, 0.109, 0.175" - low reading from long shallow gouge, sliding across the window or something similar. 4/11/2019 4/11/2019 0.50 PROD2 DRILL PULD P PU/PD BHA 18 0.0 65.0 23:06 23:36 Re highside motor post resistivity tool swap, 4/11/2019 4/11/2019 0.30 PROD2 DRILL PULD T PHASE 3 called - no email from 65.0 0.0 23:36 23:54 security, radio announcement, CPF 1&2 Phase 3, CPF 3 Phase 2. Pulled BHA above swab closed same. Lined up on managed pressure 4/11/2019 4/12/2019 0.10 PROD2 DRILL WAIT T Wait on weather 0.0 0.0 23:54 00:00 1 Phase 3 4/12/2019 4/12/2019 6.00 PROD2 DRILL WAIT T Waiting on weather while pumping 0.0 0.0 00:00 06:00 managed pressure. Phase 3 4/12/2019 4/12/2019 12.00 PROD2 DRILL WAIT T Waiting on weather, pumping 0.0 0.0 06:00 18:00 mangaged pressure, -16 bbl lost to formation, Phase 3 'Weather prediction calls for decreasing winds by midnight tonight. Page 18/35 Report Printed: 5/312019 Operations Summary (with Timelog Depths) 110-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time End Time Our (hr) Phase Cp Code Activity Code Time P -TA Operation (WB) Ertl Depth (10(13) 4/12/2019 4/13/2019 6.00 PRI DRILL WAIT T Convoy crew change (ova 19:30. 0.0 0.0 1800 00:00 PJSM, unslab DSPDL, LD /agitator/motor. Set PDL in dedicated mount, lower blocks below windwalls, straighten mast and insert pins. -standby Weather has improved drastically, can see the shop stationed at the other end of the pad. No change in Phase conditions. Wafting on weather, pumping mangaged pressure, 4/13/2019 4/13/2019 4.50 PROD2 DRILL WAIT T Wafting on weather while pumping 0.0 0.0 00:00 04:30 managed pressure. - Phase 3 Weather has improved drastically, can see the shop stationed at the other end of the pad. Phase2 called @ 4:15, Rousted crew, called R&P to confirm our access road was clean 4/13/2019 4/13/2019 1.50 PROD2 DRILL PULD P PJSM, PU agitator and motor, PD 0.0 68.0 04:30 06:00 BHA #18, 0.5 "AKO motor over a P104 BH bit, replace checks, check pack offs. 4/13/2019 4/13/2019 2.10 PROD2 DRILL TRIP P RIH w/ BHA#18, shallow test agitator, 68.0 10,435.0 06:00 08:06 1.87 bpm, dp = 1265 psi, pump = 5161 psi Many various alarms on HMI, park at 9054', evaluate, VFD room door open, possibly cold conditions causing issue 4/13/2019 4/13/2019 0.20 PROD2 DRILL DLOG P Log K1 for -5.5' correction, PUW = 10,435.0 10,473.0 08:06 08:18 37K 4/13/2019 4/13/2019 0.30 PROD2 DRILL DLOG P Confirm 11.1 ppg kills well, trap 3795 10,473.0 10,676.0 08:18 08:36 psi SBHP: MO = 10,676 psi, annular = 3677 psi, TVD -sensor = 6492, 10.9 ppg EMW (stopped once hitting 10.9 Ppg) 4/13/2019 4/13/2019 1.20 PROD2 DRILL TRIP P Continue RIH, 2K WOB bobble at 10,676.0 13,310.0 08:36 09:48 10,685' (window) Stack WOB 11,805', PUW = 42K, -3K WOB, & 11,785' Stack CWT at 12044' (no WOB indication) Annular increasing, PU, stack CWT at 12,711' Stack CWT at 13,088' 4/13/2019 4/13/2019 1.20 PROD2 DRILL DRLG P Drilling, FS = 1275 psi @ 1.87 bpm, 13,310.0 13,426.0 09:48 11:00 CWT= 5K, WOB = 1.6K, annular= 4285 psi, annular higher than expected w/ choke fully open (11.8 ppg at window, dropping as mud shears, cheesing over shakers), 4/13/2019 4/13/2019 1.00 PROD2 DRILL DRLG P PUW = 42K from 13,426', stacking 13,426.0 13,520.0 11:00 12:00 CWT getting to bottom, annular = 4115 psi, pump = 5419 psi, pump 5x5 sweeps (1 % LoTorq / 2% 776), -98% returns 4/13/2019 1411312019 0.60 PROD2 DRILL DRLG P Hard spot 13,520', rate out fell to 1.3 13,520.0 13,558.0 12:00 12:36 bpm( -70% returns), annular = 3944 psi, BHA wiper, PUW = 58K, rate out falls to 1.15 bpm (-62% returns) Page 19/35 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) 110-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log scan Dept, Slat Time End Tim Dur(hr) Phaee Op Code Activity Code Time P -T -X Operation (fixe) End Depth (fiKB) 411312019 4/13/2019 0.40 PROD2 DRILL DRLG T Unable to PU off bottom, tlifferentially 13,558.0 13,558.0 12:36 13:00 stuck, work pipe, pull to 70K+ multiple times, pull free @ 79.5K 4/13/2019 4/13/2019 0.30 PROD2 DRILL WPRT P Wiper up -hole, load LVT to rig & begin 13,558.0 12,753.0 13:00 13:18 warming 4/13/2019 4/13/2019 0.30 PROD2 DRILL WPRT P Wiper in-hole, work a bit to get down 12,753.0 13,558.0 13:18 13:36 beginning at 13,326' 4/13/2019 4/13/2019 1.20 PROD2 DRILL DRLG P Drilling, CWT =OK, WOB=1.2K, 13,558.0 13,640.0 13:36 14:48 annular = 4000 psi, 1.87 bpm in, 1 bpm out, drilling ahead, rate out continues to drop (.85 bpm), 61K PUW from 13,623', 68K PUW from 13,626', pumped 5x5 sweeps, difficulty drilling, stacking weight 4/1312019 4/13/2019 0.30 PROD2 DRILL WPRT P Pull 300'wiper, PUW =46K 13,640.0 13,640.0 14:48 15:06 4/13/2019 4113/2019 3.70 PROD2 DRILL DRLG P Drilling, rate out increased to 1.15 13,640.0 13,894.0 15:06 18:48 bpm, sweeps exiting bit w/ 4K CWT, WOB = 1.32K, annular = 4008 psi, nuetral to snubbing CWT, returns climb to 1.4 bpm PUW = 50K from 13,711' PUW = 47K from 13,769' PUW = 48K from 13,827' 4/13/2019 4/13/2019 0.20 PROD2 DRILL WPRT P PU Wt 54 k lbs, wiper trip 13,894.0 1,349.0 18:48 19:00 4/13/2019 4/13/2019 0.20 PROD2 DRILL WPRT P RBIH 1,349.0 13,984.0 19:00 19:12 4113/2019 4/14/2019 4.80 PROD2 DRILL DRLG P OBD CT 4481 psi @ 1.89 bpm in and 13,984.0 14,055.0 19:12 00:00 1.70 bpm out. Free spin diff 1340 psi, BHP 3970 psi. CT Wt -4 k Is, WOB 2.8 klbs. " Drilled out the top into Kuparuk D, average 165API, max 180. 4114/2019 4/14/2019 0.60 PROD2 DRILL DRLG P Ct 5424 psi @ 1.86 bpm in and 1.69 14,055.0 14,070.0 00:00 00:36 bpm out BHP 4023 psi, CT Wt -3 k lbs 2.4 k lbs WOB. Gamma - 160 +API ROP - 25 ft/hr 4/14/2019 4/14/2019 3.30 PROD2 DRILL DRLG P Gamma dropping below 160 API, ROP 14,070.0 14,208.0 00:36 03:54 increasing to - 80 ft/hr CT 5326 psi @ 1.88 bpm in and 1.69 bpm out, BHP 4069 psi, CT Wt -5.5 k Ib, WOB 600 lbs, ROP 80 ff/hr, pump 5x5 beaded lubed sweep - 1 ppb beads, no noticible effect on weight transfer. 4/14/2019 4/14/2019 2.10 PROD2 DRILL WPRT P PU Wt 45 k lbs, 14,208.0 10,330.0 03:54 06:00 13,779' Baker surface read out glitched, bore pressure shot up to 22k psi, artifact, continue wiper following tripping schedule, tools return normal read-outs, MWD feels confident RIH to contiinue drilling, Annular appears to be correct. Fault transilio(s) - clean Saw 4-5 k CT Wt over pull and -1 k WOB across hot gamma 11995-11915' billet clean, jog 5" up to mule -shoe 4/14/2019 4/14/2019 0.10 PROD2 DRILL WPRT P Log K1 for+13.5' 10,330.0 10,468.0 06:00 06:06 Page 20135 Report Printed: 5/3/2019 _ Operations Summary (with Timelog Depths) a 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time Endnme our (hr) Phase op Code Activiy Code Time PJA Operation (WB) Ertl Depth Me) 4/14/2019 4/14/2019 1.60 PROD2 DRILL WPRT P Wiper in-hole, bore pressure spikes to 10,468.0 14,208.0 06:06 07:42 21 K psi, WOB at 15K (faulty readings from DPS) beginning at 12,962' (similar issue as wiper up - hole), MWD's trouble -shoot issue, perform power cycle, returned to normal values, continue in-hole, watching closely Stack at 14,009', continue in-hole w/ negative CWT through high gamma interval, reduce rate to 0.6 bpm, bring rate up as soon a possible, stacking working to bottom, PUW = 44K, pump 5x5 sweeps, 4/14/2019 4/14/2019 1.50 PROD2 DRILL DRLG P Drilling, FS = 1260 psi @ 1.87 bpm, 14,208.0 14,288.0 07:42 09:12 CWT -6K, WOB = 0.6K, annular= 4128 psi, pump 5440 psi, rate out 1.7 bpm Bring HiVis to 2 ppb beads with lubes, pump 13 bbl pill, no significant improvement, PUW = 47 from 14288', Avg ROP = 53 for 4/14/2019 4/14/2019 1.80 PROD2 DRILL DRLG P Drilling, CWT= -8K, WOB=.6K, 14,288.0 14,352.0 09:12 11:00 annular = 4007 psi, pump = 5097 psi, pump 15 bbl, 2ppb pill to limited effect, 4/14/2019 4/14/2019 0.50 PROD2 DRILL DRLG P Drilling, CWT=-8K,W0B=0.5K, 14,352.0 14,365.0 11:00 11:30 continue struggling w/ weight transfer, continue pumping beaded pills to limited effect, unable to transfer weight to bit effectively, continual PU's 4/14/2019 4/14/2019 0.20 PROD2 DRILL WPRT P 500'wiper up -hole, PUW =46K, clean 14,365.0 11:30 11:42 pulling through high gamma interval 4/14/2019 4/1412019 0.30 PROD2 DRILL WPRT P Wiper in-hole, losing CWT through 13,865.0 14,365.0 11:42 12:00 high gamma interval, reduce running speed 4/14/2019 4/14/2019 2.00 PROM DRILL DRLG P Drilling, attempt 15 bbl 2% Drill Zone / 14,365.0 14,467.0 12:00 14:00 2% Screen Kleen pill to good effect, increased weight transfer & able to drill, continue pumping Drill Zone / Screen Kleen pills binging active to —1%, avg ROP = 51 fph PUW = 65K from 14,375' PUW = 63K from 14,403' PUW = 52K from 14,412' 4/14/2019 4/14/2019 2.00 PROD2 DRILL DRLG P Drilling, CWT= -3K, WOB =0.8K, 14,467.0 14,565.0 14:00 16:00 annular = 4081 psi, pump = 5546 psi, 85% returns, continue to struggle w/ weight transfer, pumping pills to keep weight to the bit, avg ROP = 49 fph PUW = 54K from 14,565' 4/14/2019 4/14/2019 3.60 PROD2 DRILL DRLG P Drilling, CWT= -1.8K, WOB =0.5K, 14,565.0 14,734.0 16:00 19:36 annular = 4117 psi, pump = 5620 psi, continue pumping pills as required PUW = 60K from 14,579', turn into BHAwiper Average ROP over interval drilled - 47'/hr Page 21135 ReportPrinted: 5/3/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start oeptn Start Time End Time Our (hr) Phase Op Code AMity Code Time P -T -X Operation WS) End Depth (i1KB) 4/14/2019 4/14/2019 0.40 PROM DRILL WPRT P PU Wt 45 k Is, Wiper #2 - 1000' 14,734.0 13,676.0 19:36 20:00 chasing sweep up hole Clean hole, CT puling weight smooth at 39k while POOH, slight increase to 41 k @ /after 13,848' 4/14/2019 4/14/2019 0.40 PROD2 DRILL WPRT P RBIH, - preemptively reduced rate to 1 13,676.0 14,734.0 20:00 20:24 bpm and running speed to 30 ft/min from 13,800 - 14,173, back on pump 4/14/2019 4/15/2019 3.60 PROD2 DRILL DRLG P CT 5654 psi @ 1.90 bpm in and 1.78 14,734.0 14,905.0 20:24 00:00 bpm out, Free spin dff 1287 psi, BHP 4149 psi, 11.2 EDC at the window, ( targeting 11.1 choke is full open). WH 21 psi, IA 124 psi, OA 34 psi. OBD Ct wt -5 k lbs WOB 0.67 k lbs, ROP 117 - 20 Average ROP over interval drilled - 47.5'/hr 4/15/2019 4/15/2019 2.10 PROD2 DRILL DRLG P OBD CT 5655 psi @ 1.88 bpm in and 14,905.0 14,980.0 00:00 02:06 1.77 bpm out, BHP 4175 psi, 11.26 EDC at the window, ( targeting 11.1 choke is full open). WH 17 psi, IA 125 psi, OA 39 psi. Cl wt -6 k bs WOB 0.58 k lbs, ROP -50 ROP and weight transfer fell off @ 14,945', sweeps not helping Average ROP over interval drilled - 377hr 4/15/2019 4/15/2019 2.20 PROM DRILL WPRT P PU Wt 47 k lbs, Wiper trip to the 14,980.0 10,430.0 02:06 04:18 window for tie in. CT weight stepped up from 37 k t 43 k lbs @ 13,670'. Weight slowly fell off over the remainder of the trip up hole. Saw hot gamma spot @ 11,934' on CT wt, -450 lbs WOB, and motor torqued up. Billet clean, window clean. Jog 5" 4/15/2019 4/15/2019 0.20 PROD2 DRILL DLOG P Tie into the K1 for +10' correction, set 10,430.0 10,476.0 04:18 04:30 j counters, 4/15/2019 4/15/2019 0.30 PROD2 DRILL TRIP P RIH, window, build and billet clean, 10,476.0 11,100.0 04:30 04:48 4/15/2019 411512019 1.80 PROD2 DRILL TRIP P Continue to RIH, begin pumping new 11,100.0 14,980.0 04:48 06:36 mud system #4 4/15/2019 4/1512019 2.40 PROD2 DRILL DRLG P Drilling, FS = 1150 psi @ 1.8 bpm, CT 14,980.0 15,110.0 06:36 09:00 = 3K, WOB = 0.7K, annular = 4240 psi, pump = 5712 psi. new mud at bit 15,006', avg ROP = 54 fph 4/15/2019 4/15/2019 2.50 PROD2 DRILL DRLG P Drilling, CWT= -1.5K, WOB =1K, 15,110.0 15,215.0 09:00 11:30 annular = 4004 psi, pump = 5053 psi, begin increasing active system to 2% LoTorq / 2% 776 (per town request), avg ROP = 42 fph .. Intermitent DPS glitches sending faulty readings to surface. Continue to watch closely 4/15/2019 4/15/2019 2.50 PROD2 DRILL DRLG P Drilling, CWT= -6K, WOB 0.51K. 15,215.0 15,336.0 11:30 14:00 annular = 4114 psi, pump = 5244 psi PUW = 44K from 15,266' 4/15/2019 4/15/2019 0.80 PROD2 DRILL DRLG P Drilling, additional lube all the way 15,336.0 15,380.0 14:00 14:48 around, modest results 4/15/2019 4/15/2019 0.30 PROD2 DRILL TRIP P Wiper up -hole, PUW = 45K, pump 15,380.0 14,555.0 14:48 15:06 DrillZone pill to aid trip to bottom Page 22135 Report Printed: 51312019 Operations Summary (with Timelog Depths) 1c-11 I& Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Time End Time our (hr) Phase Op Code Activity Code Time PJA Operabon (ftKB) End Depth (fIKB) 4/15/2019 4/15/2019 0.60 PROD2 DRILL TRIP P Wiper in-hole, slruggl to bottom, 14,555.0 15,380.0 1506 15:42 squatting up to -1 OK CWT, PU, continue in-hole, reduce rate to .75 bpm to reach bottom 4/15/2019 4/15/2019 2.30 PROD2 DRILL DRLG P Drilling, FS = 1233 psi @ 1.9 bpm, 15,380.0 15,437.0 15:42 18:00 CWT = -8.5K, WOB = 0.6K, annular = 4070 psi, pump = 5542 psi PUW = 42K from 15,387' PUW = 53K from 15,426' 4/15/2019 4/15/2019 1.20 PROD2 DRILL DRLG P Drilling, CWT= -3K, WOB=1.8K, 15,437.0 15,458.0 18:00 19:12 annular = 4078 psi, pump = 5557 psi, drill to called TD of 15,458', pump 10 x 10 sweeps 4/15/2019 4/15/2019 0.50 PROD2 DRILL CIRC P Wait for sweeps to exit bit 15,458.0 15,458.0 19:12 19:42 4/15/2019 4/16/2019 4.30 PROD2 DRILL WPRT P Wiper to swab, PUW = 44K, pump 15,458.0 137.0 19:42 00:00 10x10 sweeps timed for EOB, jog 5", park at 4861' & reboot Orion 4/16/2019 4/16/2019 0.20 PROD2 DRILL WPRT P Continue out of hole, tag up, reset 137.0 78.0 00:00 00:12 counters. 4/16/2019 4/16/2019 1.80 PROD2 DRILL TRIP P RBIH 78.0 10,430.0 00:12 02:00 4/16/2019 4/16/2019 0.20 PROD2 DRILL DLOG P Tie in for -3.5' correction 10,430.0 10,470.0 02:00 02:12 4/16/2019 4116/2019 0.20 PROD2 DRILL DLOG P Park @ 15458.74' CTMD, 6473.88' 10,650.0 10,650.0 02:12 02:24 TVD, trap psi and observe bleed down. Time Pressure EMW Initial 3765 11.18 !min 3748 11.13 2min 3695 10.98 3min 3634 10.79 5 min 3606 10.71 4/16/2019 4/16/2019 3.80 PROM DRILL TRIP P Continue to RIH 10,650.0 15,462.0 02:24 06:12 Some CT Weight bobbles and motor work sliding by 11,900. CT Wt set downs @ 13,770' and 13,852'. Reducet pump rate to 1 bpm @ 13,950', increased to 1.48 bpm @ 14,100'. Continue in hole. S/D 14,2041, PU 45 k lbs, continue in hole, reduce RIH speed to 25 ft/min @ 14518, reduce running speed to 14 fit/min @ 14,740'. 8 fUmin @ 14,800'. PU @ 15,120' for a restart, 40 k lbs, Continue in hole, 0.71 bpm & 7 ft/min. Stall out 15428, pump liner running pill, RIH on LRP, tag bottom with 5-6 k lbs CT Wt. 4/16/2019 4/16/2019 3.70 PROD2 DRILL TRIP P POOH laying in LRP. 15,462.0 72.0 06:12 09.54 Park and paint Yellow flag @ 13570.75' Park and paint White flag @ 9378.29' Continue out of hole Top of beaded liner running pill 4/16/2019 4116/2019 1.10 PROD2 DRILL PULD P LD BHA#18,over a dead well. Inspec 72.0 0.0 09:54 11:00 coil and CTC 4/16/2019 4/16/2019 0.40 COMPZ2 CASING PUTS P Prep floor for running liner. 0.0 0.0 11:00 11:24 4/16/2019 4/16/2019 1.90 COMPZ2 CASING PUTS PU / MU jointed pipe, 12-01 fret run, 0.0 1,212.0 11:24 13:18 40 joints with a solid bullnose under a IP shorty deployment sleeve. ( Liner 1212.44' LOA 1213.69') Page 23135 ReportPrinted: 51312019 -, Uperations Summary (with Timelog Depths) 1c-11 I& Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Siad Depth Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKS) Ertl Depth (MKa) 4/16/2019 4/16/2019 0.70 COMPZ2 CASING PULD P PJSM, PU BHA #19, L2-Ot lower 1,212.0 1,265.0 13:18 14:00 completion BHA. 4/16/2019 4/16/2019 4.10 COMPZ2 CASING TRIP P RIH with L2-01 liner. Tie into flag for - 1,265.0 15,462.0 14:00 18:06 10.68'. PU Wt 38 k WOB -6 k Itis. Contiune in hole, drive by the K1, + 6'. No correction made. Continue in hole S/D 11,648'- PU 49 k bs. 4/16/2019 4/16/2019 0.85 COMPZ2 CASING CIRC P Line up to 40 beaded LRP, recep pipe 15,462.0 14,457.0 18:06 18:57 4/16/2019 4/16/2019 1.50 (TO M -PZ 2 CASING TRIP P POOH, while laying in beaded LRP 14,457.0 10,670.0 18:57 20:27 4/16/2019 4/16/2019 1.90 COMPZ2 CASING TRIP P Pull through the window, continue 10,670.0 44.2 2027 22:21 POOH 4/16/2019 4/16/2019 0.50 COMPZ2 CASING OWFF P At surface, check well for flow, PJSM 44.2 44.2 22:21 22:51 4/16/2019 4/16/2019 0.25 COMPZ2 CASING PULD P LD liner running tools 44.2 0.0 22:51 23:06 4/16/2019 4/16/2019 0.60 COMPZ2 CASING PUTS P Prep RF for liner ops, inspect 0.0 0.0 23:06 23:42 Traveling Blocks, inspect INJH 4/16/2019 4/17/2019 0.30 COMPZ2 CASING PUTB P Start PU upper liner segment 0.0 151.7 23:42 00:00 4/17/2019 4/17/2019 1.50 COMPZ2 CASING PUTB P Continue PU upper liner segment, 151.7 2,970.0 00:00 01:30 filling the hole every 10 jts, Joint #40 @ 01:30 ,Joint #80 @ 03:10,Joint #99 @ 04:00 4/172019 4/17/2019 3.30 COMPZ2 CASING PUTB P Continue picking up upper 1-2-01 2,970.0 3,497.0 01:30 04:48 completion. 4/17/2019 4/17/2019 0.90 COMPZ2 CASING PULD P PU BHA#20, Lower 12-01 BHA. 3,497.0 3,541.0 04:48 05:42 4/17/2019 4/17/2019 1.50 COMPZ2 CASING RUNL P RIH with upper 1-2-01 oompelion. 3,497.0 10,599.0 05:42 07:12 4/172019 4/172019 0.10 COMPZ2 CASING DLOG P Tie into fag, note flag painted without 10,599.0 10,554.0 07:12 07:18 tying in prior to painting, it showed as a -17.2' correction, we arbitrarily set the correction tO 4.5 to better reflect typical corrections. PU Wt 45 4/17/2019 4/17/2019 6.60 COMPZ2 CASING RUNL P Continue to RIH, first SD @ 11,438', 10,554.0 14,246.0 07:18 13:54 multiple set downs after ROP slowed @ 12,977' and really slowed down @ 13,695' Fight liner to bottom. Multiple S/D's @ 14,245' up to -25 k Ibis CT Wt. Hard bottom. consult with town, Pump off liner PU 38 k WOB -5 klbs. Guestimate top @ 10747.7 Drive by of K1 showed -4.5' correction drive by of the RA tag showed -3' correction. 4/17/2019 4/17/2019 2.00 COMPZ2 CASING TRIP P PUH, park, reset counters. POOH 14,246.0 58.0 13:54 15:54 4/17/2019 4/17/2019 0.80 COMPZ2 CASING PULD P LD BHA 20 over a dead well. 58.0 0.0 15:54 16:42 Losses 4 bbpl/hr 4/17/2019 4/17/2019 1.25 PROD3 STK CIRC P Skid cart, pull checks, stab on, flush 0.0 0.0 16:42 17:57 stack.test inner reel valve, inner reel iron, and stripper. -0 4/17/2019 4/17/2019 1.50 PRODS STK CTOP P Prep RF for testing operations, grease 0 0.0 17:57 1927 crew on location service tree valves and tango's. 4/17/2019 4/18/2019 4.55 PRODS STK BOPE P Start bi-weekly BOPE test, low 250 0.0 0.0 19:27 00:00 psi/High 3,500 psi, Annular 2,500 psi, , witness waived by AOGCC (Adam Earl) Page 24/35 ReportPrinted: 5/3/2019 Uperations Summary (with Timelog Depths) IC -11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Start Time End Time Our (hr) Phase Op Code Activity Code Mme PJA Operation (WS) EM DepM (KKB) 4/18/2019 4/18/2019 2.50 PROD3 STK BOPE P Continue bi-weekly BOPE test, low 0.0 0.0 00:00 02:30 250 psUHigh 3,500 psi, Annular 2,500 psi, , witness waived by AOGCC (Adam Ead), call out greasetvalve crew re -test Tango #1 (pass). Fail/pass=Swab #2 Fail/pass=Tango #1 Fail/pass=R3 4/18/2019 4/18/2019 0.50 PROD3 STK CTOP P Coil Mangement (flat spot @ 0.0 0.0 02:30 03:00 7' (WT=0.120'), Slide cart forward, remove UQ, cut/remove CTC, trim coil (9.0') 4/18/2019 4/18/2019 1.00 PROD3 STK CTOP P Install CTC 0.0 0.0 03:00 04:00 4118/2019 4/18/2019 0.80 PROD3 STK CTOP P Re -head BHI UQ, PT UQ to 4,500 psi 0.0 0.0 04:00 04:48 (good -test) 4/18/2019 4/18/2019 0.30 PROD3 STK CTOP P Install QTS, MU build assembly 0.0 0.0 04:48 05:06 4/18/2019 4/18/2019 1.20 PROD3 STK PULD P PU BHA#21, turn build assemble, 2.2 0.0 90.0 05:06 06:18 "AKO motor over a rerun P14 BH bit with an agitator. 4/18/2019 4/18/2019 2.00 PROD3 STK TRIP P Bump up, set counters, RIH. 90.0 10,435.0 06:18 08:18 Shallow agitator test, 1.9 bpm diff 1451 psi, strong vibrations. Continue in hole, star turning the coil over to mud. 4/18/2019 4/18/2019 0.20 PROD3 STK DLOG P Tie into the K1 for a -3.5' 10,435.0 10,468.0 08:18 08:30 4/18/2019 4/18/2019 1.10 PROD3 STK TRIP P Open EDC, circulate well to mud. 10,468.0 10,625.0 08:30 09:36 Mud to surface, Cose EDC, PU Wt 35k lbs. 4/18/2019 4/18/2019 0.10 PROD3 STK TRIP P RIH, window clean, dry tag billet @ 10,625.0 10,706.0 09:36 09:42 10743' PU Wt 37 k lbs 4/18/2019 4/18/2019 0.20 PROD3 STK KOST P Set rale, RBIH, CT 5118 psi @ 1.90 10,706.0 10,742.4 09:42 09:54 bpm in and 1.81 bpm, Free spin 1025 psi, CT Wt 11.37 k lbs, 4/18/2019 4/18/2019 1.00 PROD3 STK KOST P Tag TOB start time milling @ 1 ft/hr 10,742.4 10,743.6 09:54 10:54 4/18/2019 4/18/2019 0.60 PROD3 STK KOST P Increase ROP to 2 R/hr 10,742.4 10,744.6 10:54 11:30 4/18/2019 4/18/2019 0.10 PROD3 STK KOST P Increase ROP to 3 R/hr 10,744.6 10,745.2 11:30 11:36 4/18/2019 4/18/2019 0.30 PROD3 STK KOST P Gradually target 1 k lbs WOB 10,745.2 10,752.0 11:36 11:54 CT Wt 13 k lbs, WOB 0.8 k lbs - 50 R/hr 4/18/2019 4/18/2019 0.60 PROD3 DRILL DRLG P Drilling ahead, 10,752.0 10,800.0 11:54 12:30 CT 4844 psi @ 1.88 bpm in and 1.83 bpm out BHP 3787 psi, 11.1 ppg EMW at the window. CT Wt 11.79 k lbs, WOB 1.61 k lbs ROP 62 R/hr 4/18/2019 4/18/2019 0.20 PROD3 DRILL WPRT P PU Wt 39 k lbs, PUH for dry drift. 10,800.0 10,800.6- 12:30 12:42 RBIH Window clean 4/18/2019 4/18/2019 4.20 PROD3 DRILL DRLG P Ct 4776 @ 1.88 bpm in and 1.84 bpm 10,800.0 11,018.0 12:42 16:54 out, free spin diff 837 psi, BHP 3823 psi, WH 16, IA 121 psi, OA 26 psi, OBD, CT Wt 11.7 k lbs, WOB 3.8 k lbs, ROP 50 Page 25/35 Report Printed: 5/3/2019 . Operations Summary (with Timelog Depths) r IC -11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth StartTime End Time Our (hr) Phase Op Code ANvity Code Time P -T -x Operatlon (WS) End Depth (tlKB) 4/18/2019 4/18/2019 1.10 FROM DRILL DRLG P Ct 4776 Q 1.88 bpm in and 1.84 bpm 11,018.0 11,070.0 16:54 18:00 out, free spin diff 837 psi, BHP 3823 psi, WH 16, IA 121 psi, OA 26 psi, OBD, CT Wt 11.7 k lbs, WOB 3.8 k lbs, ROP 50 4/18/2019 4/18/2019 0.20 FROM DRILL TRIP P Pull up hole allowing sweep to exit the 11,070.0 10,684.0 18:00 18:12 bit, PUW 39k, continue pulling to the window, jog the 5 inch. 4/18/2019 4/18/2019 0.20 FROM DRILL TRIP P At the TOW, shut down pump, open 10,684.0 10,684.0 18:12 18:24 EDC 4/18/2019 4/18/2019 1.60 FROM DRILL TRIP P POOH, pumping 2.0 bpm at 3,822 psi 10,684.0 1,584.0 18:24 20:00 4/18/2019 4/18/2019 0.20 PROD3 DRILL TRIP P Active choke plugged off (B) 900 psi 1,584.0 1,389.0 20:00 20:12 WHP line up to choke (A), choke (A) plugging off, cycle choke to advoid plugging off, continue POOH slowly, clearing choke (B) Q 35 fpm 4/18/2019 4/18/2019 0.60 FROM DRILL TRIP P Continue POOH taking returns 1,389.0 69.0 20:12 20:48 through choke (A) 4/18/2019 4/16/2019 0.15 FROM DRILL PULD P At surface, space out 69.0 69.0 20:48 20:57 4/18/2019 4/16/2019 1.10 FROM DRILL PULD P PUD build section assembly 69.0 0.0 20:57 22:03 4/18/2019 4/18/2019 0.60 FROM DRILL PULD P Crew change (Nabor's), Tools OOH, 0.0 0.0 22:03 22:39 LD motor and brake off agitator 4/18/2019 4/18/2019 0.75 FROM DRILL CTOP P MU Nozzle and jet BOPE stack and 0.0 0.0 22:39 23:24 flush choke (B) 4/18/2019 4/19/2019 0.60 FROM DRILL PULD P MU S PD Lateral Drilling Assembly, 0.0 17.2 23:24 00:00 w/0.5° ako motor and RB bi-center bit 4/19/2019 4/19/2019 0.30 FROM DRILL PULD P MU 8 PD Lateral Drilling Assembly, 17.2 78.3 00:00 00:18 w/0.5° ako motor and New A3 HYC, bi-center bit, stab onto tools, perform surface test (good -test), check pac- offs (good -test) 4/19/2019 4/19/2019 2.00 FROM DRILL TRIP P Tag up, reset counters, RIH 78.3 10,430.0 00:18 02:18 4/19/2019 4/19/2019 0.20 FROM DRILL DLOG P Log formation (Kt) for depth control 10,430.0 10,463.0 02:18 02:30 minus 2.0' 4/19/2019 4/19/2019 0.38 FROM DRILL TRIP P Continue IH 10,463.0 11,070.0 02:30 02:52 4/19/2019 4/19/2019 3.00 FROM DRILL DRLG P OBD, 1.87 bpm at 4,057 psi, 11,070.0 11,470.0 02:52 05:52 Diff -1,250 psi, WHP=14, BHP=3,920, IA=120, OA=22, avg ROP 133 ft/min, 4/19/2019 4/19/2019 0.10 FROM DRILL WPRT P PU Wt 35 k IDS, Wiper #1 to just below 11,470.0 11,070.0 05:52 05:58 the build - 400' 4/19/2019 4/19/2019 0.20 FROM DRILL WPRT P RBIH 11,070.0 11,470.0 05:58 06:10 4/19/2019 4/19/2019 8.20 FROM DRILL DRLG P 1.87 bpm at 5007 psi, Free spin diff 11,470.0 11,900.0 06:10 14:22 1080 psi, WHP=14, BHP=3885psi, IA=122, OA=28, OBD CT 6 k lbs, WOB 2.8 k lbs. Ran into siderite - 11,490-11,584' and many more stringers 11,601' PU 39 k lbs 11,777' PU 38 k lbs 11,890' PU 40 k lbs avg ROP 52 ft/min, 4119/2019 4/19/2019 0.30 FROM DRILL WPRT P PU Wt 40 k IDS, Wiper 11,900.0 11,078.0 14:22 1440 Page 26135 ReportPrinted: 513/2019 Operations Summary (with Timelog Depths) IC-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Deem Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (tlKB) End Depth rRI(S) 4/19/2019 4/19/2019 0.20 PRODS DRILL WPRT P RBIH 11,078.0 11,900.0 1440 1452 S/D 11634' - CT Wt -3 k Is, WOB 1.7k lbs, PU and continue in hole 11,779 WOB spike to 700 lbs, 11,797' WOB spike to 835 lbs 4/19/2019 4/19/2019 2.20 PRODS DRILL DRLG P 1.86 bpm at 5951 psi, Free spin diff 11,900.0 11,984.0 14:52 17:04 1034 psi, WHP=15, BHP=3944 psi, IA=124, OA=29, CT 1 k lbs, WOB 2.11 k lbs. 11,935' PU 41 k lbs avg ROP 38 ft/min, 4/19/2019 4/19/2019 1.50 PRODS DRILL DRLG P OBD, 1.86 bpm at 4,107 psi, 11,984.0 12,057.0 17:04 18:34 Diff=1,100 psi, WHP=13, BHP=3,922, IA=125, OA=32 4/19/2019 4/19/2019 0.90 PRODS DRILL WPRT P Ratty Drilling, with increased weight 12,057.0 10,430.0 18:34 19:28 on pickup's, pull early wiper up hole, pull through window, jog the 5inch. RIH to log K1 marker 4/19/2019 4/19/2019 0.20 PRODS DRILL DLOG P Log formation (K1), correction of plus 10,430.0 10,463.0 19:28 19:40 4.0' 4/19/2019 4/19/2019 0.60 PRODS DRILL WPRT P Continue wiper IH 10,463.0 12,057.0 19:40 20:16 4/19/2019 4/19/2019 2.15 PRODS DRILL DRLG P BOBD, 1.87 bpm at 4,078 psi, 12,057.0 12,156.0 20:16 22:25 Diff-1,G48 psi, WHP=14, BHP=3,910, IA=122, OA=28 New mud at the bit @ 12,110' 4/19/2019 4/19/2019 0.20 PROD3 DRILL DRLG P PUH, obtain new pumping 12,156.0 12,156.0 22:25 22:37 parameters, PUW 40 k 4/19/2019 4/19/2019 0.20 PRODS DRILL DRLG P BOBD, 1.87 bpm at 4,078 psi, Diff--1, 12,156.0 12,173.0 22:37 22:49 psi, WHP=222, BHP=3,897, IA=122, OA=289 4/19/2019 4/19/2019 0.50 PRODS DRILL DRLG P Hard spot, PUW 38 k, restart, BOBD, 12,173.0 12,184.0 22:49 2319 1.87 bpm at 4,078 psi, Diff--1,060 psi, WHP=222, BHP=3,897, IA=122, OA=289 4/19/2019 4/19/2019 0.30 PRODS DRILL WPRT P PUH, mud weight falling, MM out 0.00, 12,184.0 12,184.0 23:19 23:37 take returns outside (35 bbls), returns cleaned up, bring returns back inside. 4/19/2019 4/19/2019 0.20 PRODS DRILL DRLG P BOBD, 1.87 bpm at 4,078 psi, 12,184.0 12,195.0 23:37 23:49 Diff--1,060 psi, WHP=222, BHP=3,897, IA=122, OA=289 4/19/2019 4/20/2019 0.18 PRODS DRILL WPRT P PUH, PUW 51 k, pull short wiper up 12,195.0 11,795.0 23:49 00:00 hole, pumping BU 4/20/2019 4/20/2019 0.25 PRODS DRILL WPRT P Wiper back in hole, RIW 6 k 11,795.0 12,195.0 00:00 00:15 4/20/2019 4/20/2019 0.50 PRODS DRILL DRLG P BOBD, 1.86 bpm at 4,050 psi, 12,195.0 12,198.0 00:15 00:45 Diff-1,049 psi, WHP=227, BHP=3,910, IA=122, OA=26 4/20/2019 4/20/2019 1.10 PRODS DRILL WPRT T HOT has failed, circulate 5x5 sweep 12,198.0 10,684.0 00:45 01:51 and chase to the window 4/20/2019 4/20/2019 0.25 PROD3 DRILL WPRT T Jog the 5inch x1, Open EDC, POOH 10,684.0 10,348.0 01:51 02:06 4/20/2019 4/20/2019 2.00 PRODS DRILL TRIP T Shut down the pump, open EDC, 10,348.0 67.0 02:06 04:06 POOH pumping 2 bpm 4/20/2019 4/20/2019 1.50 PRODS DRILL PULD T LD BHA#22 67.0 0.0 04:06 0536 4/20/2019 4/20/2019 1.50 PRODS DRILL PULD T PU BHA #23 0.0 72.0 05:36 07:06 4/20/2019 4/20/2019 1.20 PRODS DRILL TRIP T RIH, shallow tested agitator, 940 psi 72.0 10,440.0 07:06 08:18 1 1 free spin diff @ 1.83 bpm Page 27/35 Report Printed: 5/312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stmt Time End Time Our(hn Phase Op Code Activity Code Time P -T -X Operation StaM1 Depth (flRe) End Depth (Wit) 4/20/2019 4/20/2019 0.20 PROD3 DRILL DLOG T Tie into the K1 for a -5' correction 10,440.0 10,464.4 08:18 08:30 4/20/2019 4/20/2019 0.50 PROD3 DRILL TRIP T PU Weight 35 k lbs, continue to RIH. 10,464.4 12,198.0 08:30 09:00 Window and billet clean, S/D @ 10,669', both CT Wt and WOB, PU clean continued to RIH, we were oriented as drilled on both runs. 4/20/2019 4/20/2019 0.10 PROD3 DRILL DRLG P CT4522 psi, @ 1.86 bpm in and 1.82 12,198.0 12,207.0 09:00 09:06 bpm out, free spin diff 1005 psi, OBD, CT Wt 0 k lbs, WOB 2.3 k lbs. ROP 90 ft/hr 4/20/2019 4/20/2019 3.20 PROD3 DRILL DRLG P OBD, CT 4726 psi, @ 1.86 bpm in and 12,207.0 12,332.0 09:06 12:18 1.82 bpm out, BHP 3896 psi, CT Wt 0 k lbs, WOB 1.9 k lbs. .• Faulted into the D, -180 API rock ROP 40 ff/h 12,327' PU 40 k Ibs 12,332' PU 40 k lbs Average ROP 39 fUhr 4/20/2019 4/20/2019 0.90 PROD3 DRILL WPRT P PU 42 k lbs, PUH on BHA wiper, 12,332.0 11,079.0 12:18 13:12 12,225' CT wt increased from 37k to 44 k lbs, Some -1 k WOB tougs up to 12,147' RBIH SID @ 12,184' 2.6 k WOB. PUH, -6 k WOB 54k CT Wt, slight pack off event pump 5x5, slow pull UH whie sweep exits, tum around once sweep in cased hole .• 1253' wiper #1 4120/2019 4/20/2019 0.40 PRODS DRILL WPRT P RBIH, 11,079.0 12,332.0 13:12 1336 Saw spot @ 12,230', dropped pump rate bumped through 4/20/2019 4/20/2019 1.30 PROD3 DRILL DRLG P CT 4573 psi, @ 1.86 bpm in and 1.85 12,332.0 12,361.0 13:36 1454 bpm out, BHP 3899 psi, CT Wt -1.6 k lbs, WOB 2.6 k lbs. Diff pressure jumpingg, assuing plugged noale(s) Geared. 12,339' PU 40 k lbs 12,355' PU 40 k lbs 12,355' PU 40 k lbs Average ROP 221[/hr 4/20/2019 4/20/2019 0.60 PROD3 DRILL DRLG P Required the sand 12,361.0 12,439.0 14:54 15:30 CT 4893 psi @ 1.85 bpm on bottom diff 1304 psi, BHP 3905 psi, WH 99 psi, IA 125 psi, OA 29 psi CT Wt 4 k lbs, WOB 1.8 k lbs, ROP 220 R/hr in between siderite stringers. Average ROP ft1hr 4/20/2019 4/20/2019 0.40 PROD3 DRILL WPRT P PU 41 k Pull up above the fault, 12,439.0 12,439.0 15:30 15:54 12,151' RBIH, set down @ fault 3 times, tried reducign rale and orienting. Made it through by orienting TF to low side and droping the pump. 4/20/2019 4/2012019 1.10 PRODS DRILL DRLG P CT 4633 psi, @ 1.85 bpm in and 1.83 12,439.0 12,581.0 15:54 17:00 bpm out, BHP 3896 psi, CT Wt -2 k lbs, WOB 2. k lbs. Average ROP R/hr 4/20/2019 4/20/2019 1.00 PROD3 DRILL DRLG P OBD, 1.86 bpm at 4,050 psi, 12,581.0 12,700.0 17:00 18:00 Diff -1,049 psi, WHP=227, BHP=3,910, IA=122, OA=26 4/20/2019 4/20/2019 0.35 PROD3 DRILL WPRT P Wiper up hole, PUW 38 k 12,700.0 11,700.0 18:00 18:21 4/20/2019 4/20/2019 0.20 PRODS DRILL WPRT P Wiper back in hole, RIW 10 k 11,700.0 12,183.0 18:21 18:33 Page 28135 Report Printed: 5/3/2019 Uperations Summary (with Timelog Depths) / 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sart Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time PJA Operation (ftKB) End Depth (ftKB) 4/20/2019 4/20/2019 0.20 FROM DRILL WPRT P Work pipe past Kuparuk D, PUW's 38- 12,183.0 12,183.0 18:33 18:45 40 k, minipulating pump rate 4/20/2019 420/2019 0.25 PRODS DRILL WPRT P Continue IH 12,183.0 12,700.0 18:45 19:00 4/20/2019 4/202019 3.50 PRODS DRILL DRLG P OBD, 1.86 bpm at 4,050 psi, 12,700.0 13,115.0 19:00 22:30 Diff=1,049 psi, WHP=227, BHP=3,910, IA=122, OA=26 4/20/2019 420/2019 1.25 FROM DRILL WPRT P Wiper up hole, PUW 38 k, pull through 13,115.0 10,324.0 22:30 23:45 window, jog the 5 inch, w/sweep 4/20/2019 4/21/2019 0.25 PRODS DRILL WPRT P RIH to log formation 10,324.0 10,361.0 23:45 00:00 4/21/2019 4/21/2019 0.10 PRODS DRILL WPRT P Continue IH 10,361.0 10,430.0 00:00 00:06 4/21/2019 4/21/2019 0.20 PRODS DRILL DLOG P Log formation (Kt), correction of plus 10,430.0 10,458.0 00:06 00:18 8.0' 4/212019 4/21/2019 1.00 PRODS DRILL WPRT P Continue wiper back in hole, RIW 10,458.0 12,300.0 00:18 01:18 4/21/2019 4/21/2019 0.50 PRODS DRILL WPRT P Work pipe through rough area 12,300.0 12,371.0 01:18 01:48 maniplulating pump rale, one pickup, PUW 43 k, continue IH 4/21/2019 4/21/2019 4.20 PRODS DRILL DRLG P BOBD, 1.89 bpm at 4,950 psi, 13,115.0 13,205.0 01:48 06:00 Diff--1006, WHP=77, BHP=4,017, IA=125, OA=32 4121/2019 4/21/2019 6.70 FROM DRILL DRLG P Post crew change Pick up. CT Wt 43 13,205.0 13,494.0 06:00 12:42 lbs CT 5002 psi @ 1.89 bpm in, 1.83 bpm out, BHP 4124 psi, free spin diff 1010 psi Cl Wt -5 k lbs, WOB 1.1 k lbs WHP=96, IA=131, OA=48 13307' PU 48 k lbs 13342' PU 46 k lbs 13377' PU 49 k lbs add 1 pbb beads to the high vis 5x5 sweep pumped with good results. 421/2019 4/21/2019 0.40 PROD3 DRILL WPRT P PU Wt 45 k lbs, Wiper #1 - 1000' 13,494.0 12,495.0 12:42 13:06 4/21/2019 4/212019 0.80 PRODS DRILL WPRT P RBIH Wt 9 k to 5 k CT @ 5011/min 12,495.0 13,494.0 13:06 13:54 Stack out CT Wt 12896, reduce rate and running speed, struggle to bottom. 4/21/2019 4121/2019 3.10 FROM DRILL DRLG P CT 4767 psi @ 1.79 bpm in and 1.73 13,494.0 13,679.0 13:54 17:00 bpm out, Free spin diff 884 psi, BHP 413 psi, OBD, CT W -7.7 k lbs, WOB 0.5 k Is, ROP 70-30 fl/hr 13,632' PU W153 k lbs 4/21/2019 421/2019 4.50 FROM DRILL DRLG P OBD, 1.80 bpm at 4,814 psi, 13,679.0 13,910.0 17:00 21:30 Diff--1,100 psi, WHP=214, BHP=4,123, IA=135, OA=46 4/21/2019 4/21/2019 0.40 FROM DRILL WPRT P Wiper up hole PUW 45 k, leave 13,910.0 13,110.0 21:30 21:54 beaded sweep in hole 4/21/2019 4/21/2019 0.60 FROM DRILL WPRT P Wiper back in hole, RIW 6 k 13,110.0 13,910.0 21:54 22:30 4/21/2019 42212019 1.50 PRODS DRILL DRLG P OBD, 1.86 bpm at 4,050 psi, 13,910.0 13,955.0 22:30 00:00 Diff--1,100 psi, WHP=163, BHP=3,910, IA=122, OA=26 422/2019 4/22/2019 4.50 FROM DRILL DRLG P OBD, 1.86 bpm at 4,050 psi, 13,955.0 14,045.0 00:00 04:30 Diff--1,100 psi, WHP=163, BHP=3,910, IA=122, OA=26 4/22/2019 4/22/2019 0.30 FROM DRILL WPRT T Unable to achieve DLGS to stay within 14,045.0 14,045.0 04:30 04:48 the polygon PUH, PUW 46 k, Circ beaded sweep 4/22/2019 4/22/2019 0.70 PRODS DRILL WPRT T POOH, laying 8.76 ppg beaded pill 14,045.0 12,543.0 04:48 05:30 Page 29135 Report Printed: 51312019 Operations Summary (with Timelog Depths) .4 110-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depart Stan Time Ertl Time Our(hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (WB) 4/22/2019 4/22/2019 0.20 PROD3 DRILL WPRT T Pulled 10 k over CT WT and up to -8 k 12,543.0 12,132.0 0530 0542 WOB. Motor stalled, bit stuck, worked pipe over interval, pulled free. 4/22/2019 4/22/2019 2.80 PROD3 DRILL TRIP T Continue to POOH, Billet and window 12,132.0 65.0 05:42 08:30 clean, Jog the 6, POOH, bump up 4/22/2019 4/22/2019 1.40 PROD3 DRILL PULD T PUD BHA 23, checks not holding, 65.0 0.0 08:30 09:54 close EDC, follow new PUD procedure. Bit graded out 1-1 4/22/2019 4/22/2019 1.20 PROD3 DRILL PULD T PD BHA 24, 1.1-AKO, over RR 0.0 64.0 09:54 11:06 P104 BH bit. Swap checks post pumping beads, check pack offs, stab injector, tool test good, bump up and space out. 4/22/2019 4/22/2019 2.00 PROD3 DRILL TRIP T RIH, shallow test agitator. 64.0 10,440.0 11:06 13:06 4/22/2019 4/22/2019 0.20 PROD3 DRILL DLOG T Tie into the K1 for -3.5' correction 10,440.0 10,469.0 13:06 13:18 4/22/2019 4/22/2019 0.20 PROD3 DRILL DLOG T Continue to RIH. Park at 10,469.0 10,679.0 13:18 13:30 10,679.18CTMD - 6494.82 TVD and measure BHP. Trapped 3860 psi and watched it climb to 3987, bled off 20 psi, observed pressure climb back to 3987 - 11.82 EMW 4/22/2019 4/22/2019 1.20 PROD3 DRILL TRIP T PU W133 k Is, continue to RIH, 10,679.0 12,175.0 13:30 14:42 window and billet clean. 12,175' observe gas at surface, export returns to the tiger tank. S/D 3 K WOB @ 12,295', PUH, pulling -5 k WOB @ 12,215' Clean after 12,179' 4/22/2019 4/22/2019 0.40 PROD3 DRILL TRIP T PUH whil holding 12 ppg EMW @ the 12,175.0 12,225.0 14:42 15:06 window and exporting returns to the tiger tank. turn around @ 11,596', Atempt to RBIH. Returns cleaned up, brought back inside ( 100 bbls to the tiger tank) 4/22/2019 4/22/2019 0.60 PROD3 DRILL TRIP T S/D 12,220' 11 times, varied running 12,225.0 12,395.0 15:06 15:42 speed, pump rates, TF until popping through to 12,306 varied parameters 3 times popped through 4/22/2019 4/22/2019 1.30 PROD3 DRILL TRIP T Continue to RICH. Struggling W poor 12,395.0 14,045.0 15:42 17:00 weight transfer, pump 20 bbl bead sweep, ride to bottom on beads. 4/22/2019 4/22/2019 1.80 PROD3 DRILL TRIP T On bottom drilling, rammped up purr 14,045.0 14,074.0 17:00 18:48 as we kissed bottom, no free spin diff. CT 5562 psi @ 1.78 bpm, OB diff 1245, BHP 4381 argeting 12 ppg at the window. CT -5 k lbs, WOB 2.55 k lbs ROP 20 ft/hr 4/22/2019 4/22/2019 1.70 PROD3 DRILL TRIP T **New mud at the bit 14,074' 14,074.0 14,100.0 18:48 2030 New mud all the way around @ 19:30 -14,085', PU Wt 44 k lbs, CT 4984 psi @ 1.81 bpm in and 1.71 bpm out, Free spin Diff 1141 psi, BHP 4339 psi holding 12.1 ppg @ the window. CT Wt -8 k lbs, WOB 2.2 k lbs, ROP 15 ft/hr 14,108' PU Wt 47 k Ibs 4/22/2019 4/23/2019 3.50 PROD3 DRILL TRIP T Reaquired sand 14,100.0 14,285.0 20:30 00:00 OBD, CT 5294 psi, @ 1.86 bpm, BHP 4357 psi, CT -8.4 k lbs, WOB 1.64 k lbs, WH 357 psi, IA 124, OA 50 psi Page 30136 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) IC -11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth start Time End Time Our (hr) Phase Op Code Activity Code Time P -T-% Operation (WB) End Depm (fIKB) 4/23/2019 4/23/2019 4.00 PRODS DRILL DRLG P OBD, 1.87 bpm at 5,446 psi, 14,285.0 14,447.0 00:00 04:00 Diff -1,150 psi, WHP=347, BHP=4,388, IA=133, OA=54 —Osculating: 14,302'-14309' 14,333'-14,416' 14,4381-14,447' 4/23/2019 4/23/2019 0.50 PROD3 DRILL WPRT P Wiper up hole to 13,447', PUW 47 k 14,447.0 13,647.0 04:00 0430 4/23/2019 4/23/2019 0.40 PRODS DRILL WPRT P Wiper back in hole, RIW 04k CTSW 13,647.0 14,447.0 04:30 04:54 4/23/2019 4/23/2019 1.90 PRODS DRILL DRLG P OBD, 1.87 bpm at 5,446 psi, 14,447.0 14,577.0 04:54 06:48 Diff -1,150 psi, WHP=347, BHP=4,388, IA=133, OA=54 "` Osculation 14,447'-14,574' 4/23/2019 4/23/2019 0.60 PRODS DRILL WPRT P 800' wiper up hole, 55 k 14,577.0 14,577.0 06:48 07:24 4/23/2019 4/23/2019 6.00 PROD3 DRILL DRLG P OBD, 1.87 bpm at 5,446 psi, 14,577.0 14,850.0 07:24 13:24 Diff --1,150 psi, WHP=347, BHP=4,388, IA=133, OA=54, (average DLGS 4" while osculating) Osculation 14,613'-14,644' 14,6681-14,717' 4/23/2019 4/23/2019 0.40 PRODS DRILL WPRT P 800'vdper up hole, PUW 47 k 14,850.0 14,050.0 13:24 13:48 4/23/2019 4/23/2019 0.60 PRODS DRILL WPRT P Wiper back in hole,RIW 0.0-2.Ok 14,050.0 14,850.0 13:48 14:24 4/23/2019 4/23/2019 2.50 PRODS DRILL DRLG P OBD, 1.87 bpm at 5,446 psi, 14,850.0 14,942.0 14:24 16:54 Diff --1,150 psi, WHP=347, BHP=4,388, IA=133, OA=54,(average DLGS 4° while osculating), Heavy PU @ 14,920' 4/23/2019 4/23/2019 0.20 PRODS DRILL WPRT P 14942, BHA wiper, PUW=62K 14,942.0 14,942.0 16:54 17:06 4/23/2019 4/24/2019 6.90 PROD3 DRILL DRLG P 14942', Drill, 1.8 BPM @ 4970 PSI 14,942.0 15,152.0 17:06 00:00 FS, BHP=4430. RIW=-7.1K, DHWOB=.9K, ROP=45-25 FPH. Oscillate from 15017. Pump sweeps with BHa wipers as needed 424/2019 4/24/2019 1.60 PRODS DRILL DRLG P Continue drilling, 1.8 BPM @ 5207 15,152.0 15,190.0 00:00 01:36 PSI FS, BHP=4417 PSI, RIW=-5.5, DHWOB=I.1K, ROP=33 FPH 4124/2019 4/24/2019 0.50 PRODS DRILL CIRC P Call TO @ 15190'. PUH for sweeps 10 15,190.0 15,190.0 01:36 02:06 low vis 50 Hi vis with beads. PUW=47K 4/24/2019 4/24/2019 2.30 PRODS DRILL WPRT P Start swab wiper. See ratty area 15,190.0 10,437.0 02:06 04:24 12,300' to 12,100' with light over pulls. Did not have to RBIH. See RA marker - 20 off. PUH and jog 5" tubing. Continue up hi=ole 4/24/2019 4/24/2019 0.10 PRODS DRILL DLOG P Log K1 for+17.5 10,437.0 10,455.0 04:24 04:30 1 4/242019 4/24/2019 2.00 PRODS DRILL WPRT P Continue swab wiper 10,455.0 78.3 04:30 06:30 4/2412019 4/24/2019 1.70 PRODS DRILL TRIP P Tag up reset counters, RBIH 78.3 10,435.0 06:30 08:12 4/24/2019 4/24/2019 0.20 PRODS DRILL DLOG P Log formation (K1), correction of plus 10,435.0 10,467.0 08:12 08:24 2.0' 4/24/2019 4/24/2019 0.20 PRODS DRILL TRIP P Continue IH 10,467.0 10,680.0 08:24 08:36 Page 31135 Report Printed: 513/2019 "a~ Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth StertTime EM Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 4/24/2019 4/24/2019 0.50 PRODS DRILL OWFF P Obtain static hole pressure @ 10,680', 10,680.0 10,680.0 08:36 09:06 6495.91' TVD, 11.806 ppg (3,984 psi AP), 973 WHIP, weight check 4/24/2019 4/24/2019 1.50 FROM DRILL TRIP P Continue IH through window exit, SID 10,680.0 15,201.0 0906 10:36 12,238', and 14,607', confirm TO (03 15,201' 4/24/2019 4/24/2019 0.50 PRODS DRILL TRIP P Circulate 12.1 ppg completion fluid, 15,201.0 15,201.0 10:36 11:06 1 1 PUH slowly 4/24/2019 4/24/2019 4.50 PRODS DRILL TRIP P POOH, laying in 12.1 ppg beaded liner 15,201.0 78.3 11:06 15:36 running pill, painting EOP flags 13,960' (yellow) 4/24/2019 4/24/2019 0.50 FROM DRILL OWFF P At surface, check well for flow, PJSM 78.3 78.3 15:36 16:06 4/24/2019 4/24/2019 0.50 PRODS DRILL PULD P LD drilling assembly on a dead well. 78.3 0.0 16:06 16:36 4/24/2019 4/24/2019 2.80 PROD3 DRILL CTOP P Test coil for flat spot wall thickness 0.0 0.0 16:36 19:24 @ .100. Trim 14' of CT. Prep CT install connector. Pull test CTC to 35K. Rehead E -line to UQC. Test wire +2000 / 75.6. Pressure test to 4500PSI 4/24/2019 4/24/2019 0.60 PRODS DRILL BOPE P Perform Biweekly BOPE function test 0.0 0.0 19:24 20:00 4/24/2019 4/24/2019 2.20 COMPZ3 CASING PUTS P PJSM, Prep floor for liner pick up. PIU 0.0 1,223.1 20:00 22:12 1-2-02 lower liner segment with non ported bullnose, 41 joints 2 3/8" slotted liner, and shorty deployment sleeve 4/24/2019 4/24/2019 0.70 COMPZ3 CASING PULD P M/U coil trek to liner. M/U injector and 1,223.1 1,267.0 22:12 22:54 surface test. Check pack offs 4/24/2019 4/25/2019 1.10 COMPZ3 CASING TRIP P Trip in hole, BHA #25 1,267.0 7,450.0 22:54 00:00 4/25/2019 4/25/2019 0.60 COMPZ3 CASING TRIP P Continue in hole with BHA#25 1-2-02 7,450.0 10,567.0 00:00 00:36 lower liner segment, First pick up 10,490' start working liner in hole 4/25/2019 4/25/2019 0.10 COMPZ3 CASING DLOG P Stop and correct to flag + 13.5' 10,567.0 10,580.0 00:36 00:42 4/25/2019 4/25/2019 0.80 COMPZ3 CASING RUNL P Continue in hole with liner. Working 10,580.0 11,635.0 00:42 01:30 liner with headway 4/25/2019 4125/2019 0.20 COMPZ3 CASING CLOG P Log K1 for -22' 11,635.0 11,685.0 01:30 01:42 4/25/2019 4/25/2019 5.40 COMPZ3 CASING RUNL P Continue working liner to bottom 11,685.0 12,185.0 01:42 07:06 4/25/2019 4/25/2019 2.30 COMM CASING TRIP T Unable to get liner to bottom, POOH 12,185.0 1,267.0 07:06 09:24 4/25/2019 4/25/2019 0.50 COMPZ3 CASING OWFF T At surface, check well for flow (no- 1,267.0 1,267.0 09:24 09:54 flow), 5 bbl static losses 4/25/2019 4/25/2019 0.50 COMPZ3 CASING PULD T LD, CoilTrak tools 1,267.0 1,222.8 09:54 10:24 4/25/2019 4/25/2019 2.50 COMPZ3 CASING PULL T PJSM, lay down liner segment#1 1,222.8 0.0 10:24 12:54 4/25/2019 4/25/2019 0.70 COMPZ3 CASING PULD T MU cleanout assembly 0.0 68.4 12:54 13:36 4/25/2019 4/25/2019 1.80 COMPZ3 CASING TRIP T Tag up, reset counters, RIH with BHA 68.4 10,430.0 13:36 15:24 #26, surface lets agitator, 1.8 bpm at 1,050 psi, 4/25/2019 4/25/2019 0.20 COMPZ3 CASING DLOG T Log formation (Ki) correction of minus 10,430.0 10,469.2 15:24 15:36 4.5' 4/25/2019 4/25/2019 0.30 COMM CASING TRIP T Continue IH 10,469.2 10,859.0 15:36 15:54 Page 32135 ReportPrinted: 5/3/2019 Operations Summary (with Timelog Depths) 113-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time EM Time Dur(hr) Phase Op Code Activity Cme Tare P -T -X Operation (MB) End Depth (WB) 4/25/2019 4/2512019 0.60 COMPZ3 CASING TRIP T Set down @ 10,859', PUH, PUW 38 k, 10,859.0 12,193.0 15:54 16:30 adjust TF RBIH, popped through, continue IH to next SD Q 12,193' 4/25/2019 4/25/2019 1.10 COMPZ3 CASING CIRC T PUH slowly displacing well to drilling 12,193.0 10,700.0 16:30 17:36 fluid 4/25/2019 4/25/2019 1.20 COMPZ3 CASING REAM T Clean out 10,700'to setdown @ 10,700.0 12,190.0 1736 18:48 12,190 4/25/2019 4/25/2019 2.90 COMPZ3 CASING REAM T Set down@ 12,190, Start working 12,190.0 12,365.0 1848 21:42 area 12,190 to 12,365 with 100' bites and wipers up to 11,800'. Good amount of material over shaker. Circulate multiple Bottoms up. 4/2512019 4125/2019 0.90 COMPZ3 CASING REAM T 12,365 able to run in hole (off 1.8 BPM. 12,365.0 13,800.0 21:42 22:36 25 FPM with minor slacking untill 13,800 4/2512019 4/26/2019 1.40 COMPZ3 CASING REAM T 13,800'. Loose surface weight, 13,800.0 15,170.0 22:36 00:00 Continue to work pipe to 15170 with multiple attempts to get there. Multiple BHA wipers. Get gas cut mud at surface. Ship returns to tiger tank. Send 60 BBIs out. 4/2612019 4126/2019 1.10 COMPZ3 CASING REAM T Pick up from 15170 to 15127. Unable 15,170.0 15,170.0 00:00 01:06 1 to get back to 15170. RIW=-8K. 4/2612019 4126/2019 2.00 COMPZ3 CASING REAM T Back at 15,165. Trip up to tie into RA 15,170.0 10,700.0 01:06 03:06 for hole assessment. Good trip up. Some slight overpulls 12,250 to 12,150. Looks good coming up Pumping 1.8 BPM 4/26/2019 4/2612019 0.10 COMPZ3 CASING DLOG T Log RA in for+13' 10,700.0 10,721.0 03:06 03:12 4/26/2019 4/26/2019 1.30 COMPZ3 CASING REAM T RBIH 50 FPM, 1.86 BPM. Set down 10,721.0 14,125.0 03:12 04:30 12,284, P/U went right through. Clean down to 12,354'. Pick up and went right through. Continue in. Set down 13034 No DHWOB. Pick up went right through 4/26/2019 4/26/2019 1.30 COMPZ3 CASING REAM T Lost surface weight, RIW=-6K, Slow 14,125.0 15,186.0 04:30 05:48 1 run in speed 4/26/2019 4/26/2019 1.70 COMPZ3 CASING TRIP T PUH laying in beaded 8.8 ppg LRP 15,186.0 10,684.0 05:48 07:30 4/2612019 4126/2019 1.60 COMPZ3 CASING TRIP T Above window, continue POOH 10,684.0 1,500.0 07:30 09:06 pumping beads, encountered gassed up returns, set out 12 bbl of fluid to tiger tank, returns cleaned up, continue POOH 4/2612019 4/26/2019 0.20 COMPZ3 CASING TRIP T Perform jog back in hole 1,500.0 2,186.0 09:06 09:18 4/26/2019 4126/2019 0.60 COMPZ3 CASING TRIP T Continue POOH 2,186.0 (T8-4- 09:18 09:54 4/2612019 4/26/2019 2.00 COMPZ3 CASING TRIP T Tag up, reset counters, RIH 68.4 10,435.0 09:54 11:54 4/2612019 4/26/2019 0.30 COMPZ3 CASING DLOG T Log formation (K1) correction of minus 10,435.0 10,680.0 11:54 1212 4.5', continue IH to check pressures 4/26/2019 4/26/2019 0.15 COMPZ3 CASING OWFF T Obtain static pressure above window 10,680.0 10,680.0 12:12 12:21 6502.79' TVD, 11.852 ppg, 864 psi WHP, 4,004 AP 4/26/2019 4/26/2019 0.50 COMPZ3 CASING TRIP T Continue IH to 10,900', PUH slowly 10,680.0 10,900.0 12:21 12:51 circulating 12.1 ppg beaded completion fluid down coil. 4/26/2019 4/26/2019 0.80 COMPZ3 CASING TRIP T POOH, laying in beaded 12.1 ppg 10,900.0 7,640.0 12:51 13:39 LRP, encounter gas cut returns 8,670', send out to the tiger tank. Paint EOP flag 13,180' Page 33135 Report Printed: 5/312019 Operations Summary (with Timelog Depths) IC -11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log S ea Depth Steri Tme End Time Dur (hr) Phase Op Cade Adivity Code Time P -T -X Operation (ftKB) EM Depth (WB) 4/26/2019 4/26/2019 0.50 COMPZ3 CASING TRIP T Stop moving OOH, continue 7,640.0 7,640.0 13:39 14:09 displacing well to completion fluid. 4/26/2019 4/26/2019 1.25 COMPZ3 CASING TRIP T Continue POOH, paint EOP flag 7,640.0 68.4 14:09 15:24 7,639.3- 4/26/2019 4/26/2019 0.50 COMPZ3 CASING PULD T Check well for flow (no -flow), PJSM 68.4 68.4 15:24 15:54 4/26/2019 4/26/2019 0.50 COMPZ3 CASING PULD T LD cleanout BHA on a dead well. 68.4 0.0 15:54 16:24 Note: 2.80 no-go 4/26/2019 4/26/2019 0.50 COMPZ3 CASING SHAH T Prep RF for liner ops 0.0 0.0 16:24 16:54 4/26/2019 4/26/2019 3.00 COMPZ3 CASING PUTS T PU 66 joints of slotted Iliner 0.0 1,973.0 16:54 19:54 4/26/2019 4/26/2019 1.40 COMPZ3 CASING PULD T P/U Coiltrak tools. Make up to liner. 1,973.0 1,018.0 19:54 21:18 M/U coil and surface test tools 4/26/2019 4/26/2019 1.60 COMPZ3 CASING TRIP T Trip in well, EDC shut 1,018.0 10,627.0 21:18 22:54 4126/2019 4/26/2019 0.10 COMPZ3 CASING DLOG T Tip into EOP flag for -9.7', PUW=38K 10,627.0 10,618.0 22:54 23:00 4/26/2019 4/27/2019 1.00 COMPZ3 CASING TRIP T Continue in well. Initial setdown with 10,618.0 12,247.0 23:00 00:00 P/U @ 12047'. Work pipe down to midnight depth (off 12,247 4/27/2019 4/27/2019 1.90 COMPZ3 CASING RUNL T Continue working liner to bottom 12,247.0 12,580.0 00:00 01:54 4/27/2019 4/27/2019 0.10 COMPZ3 CASING RUNL T Pump down coil in compression, .5 12,580.0 12,580.0 01:54 02:00 BPM 4/27/2019 4127/2019 1.10 COMPZ3 CASING RUNL T S/D pump. Continue to work liner 12,580.0 12,713.0 02:00 03:06 4/27/2019 4/27/2019 0.10 COMPZ3 CASING RUNL T Roll pump in compression, .5 BPM 12,713.0 12,713.0 03:06 03:12 4/27/2019 4/27/2019 0.60 COMPZ3 CASING RUNL T Work liner towards bottom 12,713.0 12,767.0 03:12 03:48 4/27/2019 4/27/2019 0.10 COMPZ3 CASING RUNL T Roll pump 12,767.0 12,767.0 03:48 03:54 4/27/2019 4/27/2019 1.20 COMPZ3 CASING RUNL T Continue Working liner, 12,878 tough 12,767.0 12,901.0 03:54 05:06 spot. Pump 1 BPM in compression. No returns. 4/27/2019 4/27/2019 1.65 COMPZ3 CASING RUNL P Continue IH, setting down 15,188', 12,901.0 15,201.0 05:06 06:45 4/27/2019 4/2712019 0.20 COMPZ3 CASING CIRC P Bring pump up to 1.9 bpm and 1,230 15,201.0 13,214.0 06:45 06:57 psi diff, PUW 35 k 4/27/2019 4/27/2019 3.75 COMPZ3 CASING TRIP P Remove liner length from counters, 13,214.0 10,900.0 06:57 10:42 circulate 8.8 ppg drilling fluid around to clear annulus of mixed fluids, PUH laying in beaded 8.8 ppg LRP up to 10,900- 4/2712019 4/27/2019 0.25 COMPZ3 CASING TRIP P Continue POOH, laying in 12.1 ppg 10,900.0 10,420.0 10:42 10:57 1 1 beaded LRP 4/27/2019 4/27/2019 0.20 COMPZ3 CASING DLOG P Log formation (K1) for depth control 10,420.0 10,458.0 10:57 11:09 plus 11.0 412712019 4/27/2019 2.00 COMPZ3 CASING TRIP P Continue POOH, laying in 12.1 ppg 10,458.0 44.2 11:09 13:09 beaded LRP 4/27/2019 4/27/2019 0.50 COMPZ3 CASING OWFF P Tag up, check well for flow (no -flow), 44.2 44.2 13:09 13:39 PJSM 4/27/2019 4/27/2019 0.75 COMPZ3 CASING PULD P LD setting tools 44.2 0.0 13:39 14:24 4/27/2019 4/27/2019 0.50 COMPZ3 CASING PUTB P Prep RF for liner OPS 0.0 0.0 14:24 14:54 Page 34135 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operaton (ftKB) End Depth(ftKB) 4/27/2019 4/27/2019 4.40 COMPZ3 CASING PUTB P Start picking up liner segment #2 with 0.0 2,976.3 1454 19:18 large ported, 1.25" bullnose, 99 jts slotted liner and shorty deployment sleeve 4/27/2019 4/27/2019 0.90 COMPZ3 CASING PULD P PJSM, P/U Coiltrak, M/U to liner and 2,976.3 3,020.6 1918 2012 hang in deployment rams. Change out floats in UQC. Inspect packoffs. M/U coil and surface test. Strip on. Tag up and set counters 4/27/2019 4/27/2019 1.60 COMPZ3 CASING TRIP P RIH BHA# 28, EDC closed pumping 3,020.6 10,628.0 20:12 21:48 min rate 4/27/2019 4/27/2019 0.10 COMPZ3 CASING CLOG P Tie into flag for -8.1', PUW=37K 10,628.0 10,619.0 21:48 21:54 4/27/2019 4/27/2019 0.30 COMPZ3 CASING RUNL P Continue in well, Initial stack out @ 10,619.0 11,415.0 21:54 22:12 11,415 4/27/2019 4/28/2019 1.80 COMPZ3 CASING RUNL P 11,415, Working liner to bottom 11,415.0 12,305.0 22:12 00:00 4/28/2019 4/28/2019 3.40 COMPZ3 CASING RUNL P Continue working 12-021iner to 12,305.0 13,213.0 00:00 03:24 bottom 4/28/2019 4/28/2019 0.10 COMPZ3 CASING RUNL P Hard tag @ 13213, PUW=62K. 13,213.0 13,195.6 0324 0330 Repeat twice. Same spot. Bring pumps online 1.5 BPM @ 3145 PSI. Release liner. PUW=32K 4/28/2019 4/28/2019 0.40 DEMOB WELLPR PRTS P PUH to 13195. Remove liner length 13,195.6 10,219.2 03:30 0354 left in hole 2976.34. Perform static test, Sensor depth TVD 6184.98', Pressure stabilized @ 3882 PSI, EMW=12.07 25 Minute test 4/28/2019 4/28/2019 2.00 DEMOB WELLPR CIRC P Dispace well to seawater 10,219.2 10,219.2 0354 0554 4/28/2019 4/28/2019 1.20 DEMOB WELLPR TRIP P POOH 10,219.2 2,500.0 0554 0706 4/28/2019 4/28/2019 1.00 DEMOB WELLPR FRZP P LRS on location, PJSM, move unit in, 2,500.0 2,500.0 07:06 08:06 RU, and PT hose to 4,000 psi, Freeze protect well from 2,500' with 32 bbls of deisel 4/28/2019 4/28/2019 0.55 DEMOB WELLPR TRIP P Continue POOH 2,500.0 44.2 08:06 08:39 4/28/2019 4/28/2019 1.25 DEMOB WELLPR PULD P At surface, PUD and LD setting tools 44.2 0.0 08:39 09:54 FTP 1,200 psi 4/28/2019 4/28/2019 2.00 DEMOB WELLPR CTOP P MU Nozzle, stab onto stump, flush 0.0 0.0 09:54 11:54 stack and surface lines to tiger tank, vac truck on location remove returns from tank 4/28/2019 4/28/2019 6.10 DEMOB WELLPR RUFF, P RDMO 0.0 0.0 11:54 18:00 Rig Release 18:00 hrs Page 35135 Report Printed: 5/3/2019 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1C Pad 1C -11L2-01 50-029-22714-64 Baker Hughes INTEQ Definitive Survey Report 15 May, 2019 BA ER F�UGHES GE ,.o.. ConoeoPhIllips sa W„Fs ✓ , -,�a. C0n0C0P�11111(JS Definitive Survey Report camps”: ConowPhillips Alaska lnc Kupamk Prefect: Kupamk River Unit SRS'. Kupamk 1C Pad Well: 1611 Wellbore: 1C-1111-01 Design'. 161112-01 Project Kupamk River Und, NOM Slope Alaska, United Slates Map System: US Stale Plane 1927 (Exact solution) System Dam Geo O4tum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 611 Local Co-ordinate Reference: Well 1C-11 TVD Reference: 1C-11®102.00usfl (1C-11) MD Reference: 1C-11 102.00usfi (1C-11) North Salamanca: Tee Survey Calculation Method: Minimum Curvature Database: EDT 14 Masks Production Well Position +WS 0.60 usfl Norman, +E, -W 0.00 usfl Fasting: Position Uncertainty 000 usfl Wellhead Elevation: Walli.. 10411.2-01 Magnetics Model Name Sample Data BGGM2018 41112019 Design 1C -11L2-01 Audit Nate.: version: 10 ph... : ACTUAL Vesical Section: Depth From (WD) (us") 41.50 Survey Program out. From To (udt) learn (U t) S..,(WGIIOOR) 121,00 10,495.53 1C-11 (1611) 10,684.00 10,77266 1C-1112 MWD -INC (16111-2) 10,802.06 11,041.25 iC-11L2MWD(1611L2) 11,05000 15,424.76 IC -111.2-01 (16111.2-01) Mean Sea Level Using Well Reference Point Using gom el,c scala Factor 5.969,008.74usfl 56164106ua8 usfl Declination r 18]1 Tk On 11 11041.25 eW4 Esgg Jesse) (udt) 0.00 0.00 Teolwma MWD M1N41NC_ONLV MWD MWD Description MWD - Standard MWD-INC_ONLY FILLER MWD-Stendmd MWD-SMedard Latitude: Longitude: Ground Level: OIPAngM r( 80.88 Dlraetlon Survey 91ar1ones 8,2512000 4,52019 4192019 411612019 70° 19' 33.128 N 149° 30' 0.514 W 0,00 ash FMW Mrsingth I -T) 57,423 Survey End Data 4152019 4192019 41162019 5H51101910 1605444 Page 2 COMPASS 500014 Budd 650 Annotation TIP KOP o+ b YIWO191016: 05404 PaR3 COMPASS 5000.14 Build 856 ConocoPhillips ConocoPhillips DefiniOde Sunday Report Company. ConocoPhillips Alaska lnc Kuyamk Local Coovdinate Reference: Wall 1C -it Pre)eCL Kuparuk River Unit TVD Reference: 1C-11@ 102.00usD(1P11) site: Kupamk 1C Pad MO Reference: IC -11 @ 102.00usn(1G11) Well: 1P11 NOrth Refiencz: Tme Wellhore: 1C -11L2-01 Survey Glculatlon Method Minimum Curvatura Design: 1G11L2-01 Database: EDT 14 Alaska Production Survey Map Map Vertical MD 1. A15 TVD TVD55 ♦NISeVl Northing Eaating OLS section 6urv¢y Total Ndme I1MM 11 11I lusnl (us") loan) lusnl Irtl Inl 1'1100l (rt) 11,04125 9147 6.68 659618 6496.10 8,164.39 -1 ID9.43 5,977,16214 56036472 3,40 &16439 MWO(3) 11,050.00 9090 6.34 65911.00 649n. sinna -1218.44 5,971,170.04 564365.64 7.64 0,173.08 MND(4) 11,080.32 8436 675 659&00 6494.60 0,203,17 -1,NkIsg 5,977,264.95 560,360,04 1149 8,213.17 MJJD(4) 111m 3 65.64 3.95 6594.03 6,49203 0332.83 -0.20231 5977,230.63 560,371.218 inns &23283 MJN(4) 11140.On 94.15 5.30 6591,53 6,489.53 8,26240 4,199.80 5,977,26031 560,373.55 6.59 0,26240 MJN(4) 11175,15 9215 614 6.589.60 0,48160 0,2973+ -119528 5,97,295,15 550396]8 6.09 6297.31 lasso (4) 11215.22 89,14 740 6,589.26 8407.26 8,87.17 1.19273 5,977,325.03 55(138064 1065 8,32717 MAD (4) 11,235.21 BB.75 6.63 0.589.55 6407.55 8.356.93 -1,18807 5,9nant c 55D,383.50 320 8,35693 MMD(4) 11,55.10 93.05 3.05 6.58666 6,487.60 0,386,79 -1,181 5,97.384.70 561030570 11.911 8,30&79 MJ/D(4) N,M5.24 89.35 359.8 6,509.75 6,487.75 0,41684 -1,185.92 5,8741415 560,386.16 1262 8,41684 MIND (4) 1132545 89.54 355.47 659004 6,45.04 8,447,01 -1187.N 597.444.90 %0,384.54 1276 8,44701 MMD(4) 11355.18 90.95 355.30 one act 0,4818 8,476.64 -1189.66 5,97.47451 550.381.92 415 8,47664 MAD (4) 11,385.23 91.57 35750 6589.5 6.487.25 &5@063 -1,191.53 5,97,SG.40 560.379.81 7.35 8,506.63 MAID(4) 11415.5 91.60 358.68 6,58842 6,485.42 8,53612 -1W27 5,97,53457 560378.82 724 8,536.72 Mr4D(4) 11,44531 91.17 1.60 6.50170 6,48510 8.556.67 -1,191.94 5.97.564.51 560,370,91 657 Brie.) MWD(4) 11475.3a 9028 3.61 6,58732 6,485.32 8.59672 -1,190.57 5,977,594.57 56103 7.31 8.516.8 MD (4) 11,505.23 9092 5.91 6,58703 6,485.00 8,62645 -1186.09 5,877.62431 560.30226 8,00 8.85.45 MWD (4) 11534.91 80.7 7,47 6,581 6464.57 0,655.92 -1,104.64 597.65381 560.385A0 5.5 8,655,92 MWD (4) 11555.03 90m 8% 6,5%.34 6404.34 LAW 71 -1160.17 5,977.003.63 560,381 7.36 8.685.71 MD (4) 11,59504 as'. 1087 6,5%,83 6,48483 8715.24 -1,174.85 5,977.71328 560,394.70 olo 8,715.24 MD (4) 11. o5so 0739 6.62 650805 6486.05 0,745.22 4,169.64 5,977,74322 560.399,74 7.05 0.745.04 MD (4) 116$5.41 0748 5.91 650939 6487.39 877407 .1,165.81 5,97.7890 560.40132 an 8.774.87 MWD(4) 1168531 88.22 364 6590,51 6480.51 0,80453 -1.163.33 5,877.802.57 6%.405,56 0.01 8.804.53 "D (4) 11715.40 88.83 103 6591.28 6,4NM 6034.60 -1.162.10 5,97.M.73 SW.406.54 6,88 0,834.68 MAID) 11145,5 88.5 228 6,591.89 6409.09 &864.54 -1,16124 597,652.59 560.407.18 Al. 0,854.54 MND(4) 11,7487 90.98 444 6,59193 6489.93 8.494.07 -1,150.51 5,97,89214 560,408.65 1023 8,89407 MND(4) 11,644,95 9184 5.53 6,591,18 6,489.19 892403 -1.1%.89 5,97,9811 56041101 461 8,92403 MAD (4) 11.0521 90.89 4.30 659047 6,488.47 8,95417 -1.15420 5.98952.27 550413.38 4.93 8,95417 MMD(4) 11.81 89,78 5.02 6,590.29 6,480.29 6984.32 -1,15180 5,97,98244 %0415.61 423 8984.8 MAID (4) 11,895.04 67.64 696 6,560.96 640696 9,01372 -1140.8 5970,61106 560416.45 9.77 9,0138 MND(41 Annotation TIP KOP o+ b YIWO191016: 05404 PaR3 COMPASS 5000.14 Build 856 ConocoPhillips a?htI�GMES ✓ 9�.. ConocoPhillips Definitive Survey Report Company: ConowPhillips Alaska Inc_ Kupamk Local Coordinate Reference: Mil IC -11 Project: Kupamk River Unit TVD Reference: 1C-11@102,00usR(10-11) 5he: Kupamk lC Pad MD Reference: 1C-11@102.00us0(1C-11) Well; 1C-11 North RNerence: True Wellbore: 1C-1112-01 Survey Calculation Method: Minimum Curvature Design: 1C-11LMl Database: EDT 14 Alaska Production Survey 57/52019 10: 16:054" Page 4 COMPASS 5000.14 Build 850 Map Map Vertical MD Om A! TVO TWSS rNIS rVY NO Easier, DLS S Section Survey Tool Name Ann018llOn (usR) r) 19 (.sit) (U.11) ju.1Q (uaM) (it) 1 IRI I, tt 91499 BG,B] BN 6591 .92 6,46993 9,03348 46 -t 1.12 5,91781 0 031.64 5.99 00.42-1 6.81 900 33.40 MWD(4( 11945.9 8242 10.49 6,591 649145 8,06332 -1,14126 5910,06152 560.425,51 831 9,60092 MND(4) 11,975.15 8003 12.47 859464 6,48264 9,09258 -titui31 5,91609082 660.43131 693 9.082.36 VIVA) (4) 12005.06 89.42 15.21 6,5634) 6493.30 9.12L61 -1,128.16 5,910,11990 560.438.12 1031 9,12161 MD (4) 12035.12 9600 11)4 6,58545 6,493.45 9,150.44 .,119.63 691814819 560400.41 063 %150.44 .66.0 (4) 12,084.55 90.95 3L05 6,59521 8,493.21 9,178,28 .,110.10 5,810,11611 560.455.11 0,52 9,11828 MNO(4) 12,095.41 91.57 21.04 6,594.53 6,49253 920216 -100,27 5,91820568 561 316 9,ID7.16 MD 12,12530 9012 21.92 8.594.00 6,49209 9,23468 -1,00(1,36 5,910,23349 560.416.96 568 9,224.80 MND(4) 12 IUM Mae 20.83 8.59415 6,49215 9,26244 -101156 5,918261.13 550,46154 4.00 988244 MJ4D(4) 12186.09 9452 21,13 6.59301 6,491.01 9,29163 -106638 5,910,25041 550,498.49 1558 929163 ME 12315.91 9400 19.8 6.520iM 6480]9 9,319.52 -tadism 5,910,31&30 560,508.65 SA2 9,31952 MAD (4) 12245,11 Mail 2017. 6.58920 6,48630 9.34240 .,00598 5,918,34634 550,51653 lids 8,341.40 MAID (4) 12275.31 93.9a 2132 6,58563 648343 931498 -107.44 5.978.374.00 560,520]5 1.90 9,374.98 MND(4) 1230483 9199 21.09 6551,09 6482.09 9,402,46 -1,024" 5.978,401.57 550,539.19 &M 9402.8 MMD(4) 12345.63 82.113 told 6502,30 648038 9,"0.17 8009,18 5978,43959 950,55387 310 9.44037 level) (4) 1237804 9tA1 1246 65Bt18 6,479,18 941004 4t8B,83 5,978.410.15 %0.564.57 14.90 9,47084 MJUD(4) 12408,12 81.47 1&70 6580.@ 6,47642 9,49941 E8941 5,918498,80 560,573.60 439 949941 INAM(4) 12,"0.91 9237 %. 6,57832 0,1"32 9,00,40 979.03 5,978.5.84 580583.87 300 9,5ffi4B MJUD(4) 12,18873 9301 1960 6,5"92 6,47583 9,555.72 48902 5,976.556.26 56059218 7.52 9,S%M MOD(4) 1249&32 9869 2255 6.575.89 647389 9,56424 65934 5,978,58306 58060322 695 9,58424 MWD(4) 1252001 9363 2&57 657399 6,47198 9,1311.35 .64713 5,978,811.16 SW61510 10.13 9,61135 MWD(4) 1255768 9378 9.91 657206 6,47008 9,637.73 93384 5,978.83756 5006..18 790 963273 MWD(4) 12,58041 92.98 2&46 6,51037 6.468.27 9,664.77 419.35 5,97868".71 560,842" 3.19 966471 MWD(4) 1261&11 92.24 ,am 6,568.89 8400.90 9,681.59 -90592 5,Men." 560,65&25 6At 9,681.59 MWD(4) 1265343 .0 2414 8,561." 646544 9,122.84 1190.25 5.978.723.01 560671 W 5.88 9,72284 MWD(4) 1267043 W,W 1258 6,56926 6.46426 9.745.00 4,8006 5,978.71833 500,601.04 8.00 9,14&00 MWD(4) 1270011 9427 2104 6,56.4.42 6,462.42 9,773.11 %800 5,978.77410 560.69169 7.00 9,71311 MWD(4) 12730.31 92" 1800 6,562.60 6,460.60 9.80160 459.11 5,98.802.02 56070155 11.19 9,80160 MWD(4) 1218974 9117 1652 6,56152 6.459.52 9,831.67 45003 5,918632.15 56071038 8.60 9,83187 MWD(4) 1279947 9157 1350 6,560.81 6,45681 985044 .14259 5,WB66i0W 560,1259 6@ 9890.44 "D14) 1202897 9249 1202 5,55916 6451]5 8,809.19 .3698 5978889.79 56072186 5.90 9,889.19 MWD(4) 57/52019 10: 16:054" Page 4 COMPASS 5000.14 Build 850 ConocoPhillips 4 ConocoPhillips Definitive Survey Report Company . ConocoPhillips Alaska lnc_Kupamk Pmject Kupamk River unit bile: Kupamk 1C Pad Well: 1611 Wellho2: 161112-01 Design: 161112-01 Survey Local Cooani site Reference: TV. Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1611 1C-11®102.00ue%(1611) 1C-11® 102.00.0 (1611) True Minimum C..W. EDT 14 Alaska Pmd.Own Annalalion "Wo 19 10:16:054M Page 5 WMPA55500014 Build 850 Map Map Vacuo MD bio Atl TVD TVDSS +WB +EUk NO(Mrq Ea(1t) OLS 9ectidn Survey Tool Name (usn) (7) (1) (--ft) (ush) (..ft) (-M ml ml 1-11OPl ml 4,05131 94.25 tO.D 6,556.10 6456.10 891698 4330.00 5,9]8,96].58 SfiO,]2H.11 830 9.916 95 MID (4) 12,901]] W.12 7,81 6555[3 646,at 9,960]8 A230 5,9]8,9514] 560.731T3 7.36 9,1160]8 MD (4) 1293147 9123 300 6.554]6 6,462.76 9,990.31 .2062 5,970,991.02 560,73048 1302 9,990.31 MD (4) 12,MD.25 90.34 35].]1 6554.35 6452.36 10,019.07 821124 5.9]9,019]8 560.738,V 2138 10,ol9.07 MD (4) 1300].09 90.92 35.84 6.55384 6.45104 10,0.63 822.92 5,9]906].31 560.73558 4.11 10O".53 knAO(4) 1303255 89.11 35.12 6,553.03 6.45196 10,091.23 424.65 5.9]8,09189 560 MW ]43 10,09123 MIND (4) 13065.45 83.58 366.03 6,555.03 6453.93 10.123.97 928.90 5,978124.61 56073111 16.01 10,12397 MWD(4) 13,CB2.M 88.19 M.70 6,557.85 6,45505 10,150.63 92682 5,9]$151.25 500.728.96 17.24 10,15063 MWC(4) 13121.58 91,n 355.80 6,557.07 6,45588 10,1110.27 830]] 5,9A]BO Bfi 560.]5]8 12.G 10,1802] MWD(4) 13,162.19 0631 357.13 6,55].0] 6455.87 10.21045 43237 5,0092"M 563 M4.93 1133 1021045 MWD(4) 13'02.91 875 358.78 6,550.90 6,455.08 10.24113 433.46 5,9]9M120 580.]23.58 591 10.24113 MWD(4) 13.211.80 8939 129 8,56975 645]]5 10.2]000 93144 5979.2]n.6] 550.83.316 10.]] 10270.00 MWD(4) 1324223 89.02 1.]5 6,560.17 8,456.17 10,30042 93200 58IN,% 580.723.93 2.02 10,30042 MAID(4) 132]1.75 89.00 128 6.56051 6458.51 10,32993 .3184 5,98.330.00 SB].72447 2.75 10,33993 MM (4) 13,300.98 a Z. 6,560]] 8,450.]] 10,35914 433d 91 5,969.3`8.8 500.85.16 387 10,359.14 MO 13,330.94 09.00 3.14 6.550.90 6450.98 1D.38907 AN.48 5.9]9.309.65 4A.M6.35 320 10,389.07 MWD(4) 13,09078 09.05 1]5 6.51.25 5459.23 10416" 927.18 59]9.41942 560.87.90 345 10,410.83 MM (4) 13,3921] 8923 424 6.66174 6,459.]4 10.45016 4,25.00 5,9]9,40.7] 51O.88.03 163 10.460.16 MWD(4) 13 421147 OBP 4,19 6.562.M 6,48024 10,471LM 923.42 5.979,479." 598.731.68 1.53 10.47630 MD (4) 1345085 87.45 400 6.563.24 6,461.24 10,500." 482108 5,979.509.23 88.733.76 4.57 10.508.5 MID (4) 13 MIN Be'. 5.14 6.54.10 646210 10,538.37 4165 5,978,6N.02 580.7M.09 631 10.538.37 MD (4) 13,51041 91.23 4.45 6,5639] 6461.87 10,57,95 416.05 5,979,36..5 560]38.30 7." 10,57.98 MID (4) 13,54306 9335 2.74 6,552.67 6,400.67 lo.ey.S4 41A01 6.979,60123 5")400] 0.34 10.8".51 MNO(4) 13,57090 9255 3.35 656123 6.469.23 1062636 412.53 5,979.623.07 560.741.33 162 10.82638 MD (4) 13.606.71 9191 420 .559.22 6,457.22 10,663.98 41015 5,978664.68 560,74342 161 10,W3.98 MID (4) 13.0143 9298 509 655].]3 64".]3 10,188.57 X8.14 5.9]9 ,68923 56074523 asks 10,688.57 MID (4) 13.660.48 9110 5.42 6,55.70 6.45110 10,7846 405.48 5,009718.19 560,]4]" 657 10,]1].48 MVW)(4) 13,"0.90 9212 4.31 8.555.04 6.453.84 10.72]] 40290 5,823,748.63 560]49.90 4,95 1074777 MND(4) 1371987 94.43 5.36 0,554.19 6,452.19 10.7]6.59 900411 5,9]9.77236 500,762.10 SM 10.77659 MWD(4) 1375098 9504 3.11 6651.62 6+19.62 10,00252 -79017 5,979,80630 6W,754.22 247 10B0].52 hold) (4) 13]90.30 9421 241 6549.25 644725 %.1331570 49fi.]6 5979.83249 SW.755.30 310 1063670 MM (4) Annalalion "Wo 19 10:16:054M Page 5 WMPA55500014 Build 850 G011000Phllllp5 ConocoPhillips Definitive Survey Report u�611Es Company: ConOcoPhillips Alaska lnc_Kupamk Local Co.om(nate Rehrtnce: Mail 10-11 Project Kupamk RNer Unit TVD Reference: 1C-11®10200us0(10.11) Site: Kupamk I Pad MD Reference: 1C-11 @ 102.00usft nC-11) Well. 10.11 North Reference: True Wellbore: 10.111241 Survey Calculation Method: Minimum Curvature Demon: 10.1112-011 Database: EDT 14 Alaska Production Survey 5//52019 10. 16 05A Pages COMPASS 5000.149udG 850 Map Map vertical MD was M TVD TVD55 aN12 aEsN Northing Fasting DL6 Saetlan Survey Taal Nems Annotation (vain PI PI form (-am foul (-ft)(110in) Plow) (ft) 13,81038 91.60 3.33 6547M 6,45.73 1405670 -79526 5,919,86TM 56075664 920 10,60670 MWO(4) 1384100 91.72 3.71 6,546.95 8,44495 10,88725 -093.30 5,979.890.08 560750.21 1.54 10,09725 MWD(4) 13011.01 92.60 4.$ 6,54507 5443.81 10,827.16 -09122 5,919,921.99 560160.18 5.67 10,921.16 MD (4) 13900.12 93.07 3,76 6.544.38 644230 10,956.16 -78811 5,919,951.00 560,162.06 286 10956.16 MD (4) 13,929.58 92.92 4.85 6,54284 6440.84 10,985.50 -186.91 5,979,9m 35 560164.@ 373 10,905.50 MID (4) 13,958.05 91,1 5.44 6,54170 6,439 O 11,01562 484.19 5,960.01649 560766.46 535 11,015.62 MWD (4) 13,990.12 89.45 6.76 6,54tA7 6,439.47 1104552 400.% 5,984046.61 560.789.45 7.81 11,046.8 MIND (4) 14019.62 86.41 6.94 6,5@.54 6,440.54 11,014.00 -711.46 5,980015.90 560.11253 10.32 11,074.98 MND (4) 14,019.40 "I'M 932 6,544.77 644211 11104.]6 -1]3.26 588010533 560.76.68 9.29 1110433 MND(4) 14001.M 84.93 11.91 6.54759 644559 11,135.78 46730 5,98013678 540.182.31 8.04 11135]8 MND(4) 14.110.26 03.38 13.57 6.560.52 6.448.52 44.163.44 -761W 6980,164.15 560.780.39 785 11.163.11 MWD (4) 14,140.90 8432 15.68 6,55380 6.45180 11.19318 -153.7 590019429 560.195.84 119 11.193.18 MND(4) 14.16942 63.30 race 6.555.81 6,154.87 11Y20.32 -045.15 5,960,221.40 580,803.84 0.91 fl.220.32 MAD (4) 14200.38 8379 18.37 6,550.35 5450.35 11,249,54 -035..4 6,800.25078 560,61331 1.80 11,249.54 MAD(4) 1423023 84.50 1791 655337 6.461.31 11,271.78 -2.30 6,880,27910 560.022.14 3.80 44,7779 MAD lit 1435995 0447 15.44 6.560.20 6,464.20 11,33506 -718.03 5,900.30744 W,830.25 747 '11.306 Out MWO(4) 1429030 0iiii 1261 6.560.68 6,465.86 11.33550 -710.70 5,assdo 6.97 560,831.34 9.50 11335.50 MMD (4) 14,321N a5"0 11.68 6,57129 6,469.29 11,35565 -104.21 5,980.36713 560.843.59 306 1176565 MWDl4) 1435185 85.48 10.29 6573.71 6,471.71 11,396.10 498.37 5,911° .39721 560649.11 451 11.39570 MAD(4) 14383.61 03M 11.10 651681 6,474.87 11,42671 492.49 5.903,428.28 56daii"fi 001 11 426.T1 NAM) (4) 140.1055 82.13 10.71 656026 647044 11,45282 48754 5,901454.53 5508595] 4.31 11452,92 MWD(4) 14411.30 82.96 11.73 6,584.16 640211 11,482.85 461.74 5,980.484.61 55086608 5.17 11.48205 MWO(4) 14,72.51 85.12 12.58 6,567tl 6485,41 11,513211 -67520 5.963.514.90 560.871.-6 7.43 11,51320 MWD (4) 14.50758 li 13.04 6.509.99 640799 1154730 46745 5,980.54905 560,87885 3.96 11,541.30 MWD (4) 14,M791 0560 12.99 6,59183 8.460.83 1151679 48063 5,980.578.61 560, Sit 058 11516.M MWD (4) 14569.66 88.65 12.51 6.591.70 6,01,70 11807.13 65363 5,900.609.60 560,892.17 1.52 11807.73 MAD (4) 14.599.90 Nam 11.14 6,685.41 6.493.41 1163734 -641.43 5,980,63935 560,899.12 459 ttfir7.31 MAD (4) 14,03060 8501 9,45 8.6al 6,494.13 11,660.84 44207 S,9w. 80 560,903.44 6.04 11,666.04 MND(4) 14659.69 09.08 7.21 6.597.46 6.495.46 11,8815.21 43157 5980,650.20 560.907.30 627 11,698.21 MWD (4) 1471312 0849 711 6,59860 6,495.60 1114821 43111 5.980 751.25 560.91352 1.12 11,749.21 MWO(4) 14745% 08.83 640 6599.36 6,497,36 11781.74 426.60 5980,18181 560.91760 4.06 117.74 MWD (4) 5//52019 10. 16 05A Pages COMPASS 5000.149udG 850 Annotation armee 50,52019 f0: f6'05AM Pape 7 COMPASS 500014 Budd 115D ConocoPhililps ConocoPhillipe Definitive Survey Report company: ConocoPhill,s Alaska lnc Kuperuk Local CpardlnMe Reference: Well 1C-11 Project: Kuparvk River Unit TVD Reference: 1C-11®102.00usfl(1C-11) Site: Kuparek I Pad MD Relerence: 1C-11®102.00usfl(1C-11) Well: 1P11 Nonh Reference: True Wellbore: 14111251 Survey Calculation Method: Melmumcurvature orsl9n: iC-111241 Database EDT 14 Alaska Production Survey Map Map VeNcal MD Inc Ael TVD TVDSS ♦W46 aE/M NoMing seeing DLS section Survey Tool Name (u -M (11 (1) luef) (-it) (uafl) (es"I (It) IR) (.1100') ID) 14.]]3.05 6911 6.68 6.599.85 649].85 11M o. £23.13 5997.810[1 560.921.01 p 4 11,80659 MWD(4) 14.806.84 BBN ].M 6.600.39 6,498.]9 11842.11 41887 5,90,,8442] 560.925.0, 332 1194211 "D (4) 14.83665 8068 7.22 6,60097 6498.97 11,0165 b1498 6,980.8]381 56,,@65 236 1197165 MD (4) 14.85668 MR6 7,79 6601.51 6,499.61 11,0,1.32 b11ID 5,960 903.50 50,.93231 2.00 11,90132 MD (4) 14,8909i 08.03 7.59 66MM 6,500.26 11,93141 408.73 5.997935.63 550,93,38 062 1103.41 MD (4) 1492773 69.08 761 660379 6,500.79 11,96192 402.93 5.980,964.16 50,.939.95 0.87 11,96192 NAND (4) 14970.61 8065 7,70 6,633.. 8,50164 12004.41 59722 519-1 subl9 50,.945.31 102 12.004A1 MAD(4) 15019.14 88]7 555 6604.73 650273 12,052. 59182 5,901054.92 59.4,90,.81 444 12.05260 MD (4) 150,1.34 89.51 498 6,805.39 8,503.36 12 ,0,4.61 58776 5.981,0.6.95 560,954.03 224 1209481 MJult(4) 15,10664 9285 430 6,604.39 650.39 12.139.75 -581.07 5,981.142.12 560,957.35 7.70 12,138.75 MAD (4) 15.136.01 9409 476 660259 6,800.58 12,169.00 58173 5,981,171]8 Saneso44 4X9 12,169.00 MWD(4) 15.166.16 9483 4.83 660024 6.49824 12,19692 579.22 5.981201.32 550,961.71 2.47 12,199.92 MWD(4) 15.19886 94,95 5.18 659.45 6.495.45 12.231.40 576.38 5,981.233.82 50,98428 1.13 12.231.40 MD (4) 15,226.]2 0,.74 541 6,595.10 6,403.10 1225902 573.82 5.901281.45 56,96662 U2 12.25902 MD (4) 15257.36 9588 584 6,511 6,490.27 12209.39 57088 5,901,291.65 560969.30 3.79 12,20839 MWD (4) 1526.6 WAS 5.60 6.56.20 6,48730 12318.30 560.0, 5,90134078 50,,971 81 107 12.31030 MD (4) 15321.12 95.32 5ffi 8,58573 6,48173 12,352.51 364.70 5,981 355M 5..974.80 270 13,35251 MD (4) 15 M.76 94.95 4.73 6.5..44 6,401.44 12,377.95 562.58 5,981380.47 56.976.80 251 12.37795 )AVID (4) 153756 95. 5.44 6511091 8,47691 12,405.65 560.01 5,981403.19 56.97931 249 12 Asset MWD(4) 1540440 9455 4.89 6,578.50 6.476.50 1213515 467.43 5,981, ] 71 560.61.55 260 12435.15 NAVE) (4) 1542/76 94.6 A. 6,576.01 6,474.81 1245538 15580 6,981,45794 560.9. 02 331 12.455.30 MAD (4) • 15.4112.. 94.98 4.30 6,57157 6.47167 12,49237 352.98 5,set 4..95 55)985.54 06 12,192.37 PROJECTED Ia To Annotation armee 50,52019 f0: f6'05AM Pape 7 COMPASS 500014 Budd 115D BA ER %' PRINT DISTRIBUTION LIST UGHES aGEcompany COMPANY ConocoPhillips Alaska, Inc. WELL NAME 147-111,2-01 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL bakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTnENTION V 1 BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 1900 E. Benson Blvd. .Anchorage, Alaska 99508 2 Conoco Phillips Alaska Inc. Atm: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 ExxonMobil,Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C St Suite 505 reet, Anchorage, AK 99503 4.State of Alaska -AOGCC Attn: Natural Resources Technician II 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division ofOil & Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR j 2 190 42 30799 ie sign and return one copy of this transmittal form to: 3coPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. 3oraee. Alaska 99510 LOG TYPE GR - RES LOG DATE April 16, 2019 TODAYS DATE May 16, 2019 Revision No Details: Rev. Requested by: --- FIELD I FINAL CD/DVD FINAL PRELIM (las, dlis, PDF, META, SURVEY REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES IF OF COPIES 1# OF COPIES IG IG jj J; 4 9 AOGCC i 6 RP Exploration (Alaska) Inc. Petrotechnical Data Center, IR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 BA ER F�UGHES a GE company r ate: May 16, 2019 Abby Bell AOGCC 333 West 7m Ave, Suite 100 Anchorage, Alaska 99501 219042 30793 Letter of Transmittal Harvey Finch Baker Hughes, a GE Company 795 East 94`h Avenue Anchorage, Alaska 99515 find enclosed the directional survey data for the following well(s): 1C -11L2 1C -11L2-01 1C -11L2-02 (1) Total print RECEIVED MAY 17 2019 AOGCC 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. Harvey Finch, Baker Hughes, Wellplanner Harvey. Finch(eDBakerHughes.com 219042 30793 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1C Pad 1 C-11 L2-01 50-029-22714-64 Baker Hughes INTEQ B"i�`UGHES a GE company Definitive Survey Report 15 May, 2019 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co -Ordinate Reference: Project: Kupamk River Unit TVD Reference: Site: Kuparuk 1C Pad MD Reference: Well: 1C-11 North Reference: Wellbore: 1C-111-2-01 Survey Calculation Method: Design: 1C-1112-01 Database: Project Kupamk River Unit, North Slope Alaska, United States Date Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Survey (Wellbore) Map Zone: Alaska Zone 04 1C-11 (1C-11) Well ic-11 1C-111-2 MWD -INC (1C-111-2) Well Position -NAS 0.00 usft Northing: 11,050.00 +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 1C-111-2-01 Magnetics Model Name Sample Date BGGM2018 4/1/2019 Design 1C-1112-01 Audit Notes: Well 1C-11 1C-11 @ 102.00usft(1 C-11) 1C-11 @ 102.00usft(1 C-11) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,969,008.74 usft Latitude: 561,641.06usft Longitude: usft Ground Level: Declination Dip Angle (1) (1 16.71 80.88 Version: 1.0 Phase: ACTUAL Tie On Depth: 11,041.25 Vertical Section: Depth From (TVD) (usft) 41 60 Survey Program Date From TO Description (usft) (usft) Survey (Wellbore) 121.00 10,495.53 1C-11 (1C-11) 10,684.00 10,772.66 1C-111-2 MWD -INC (1C-111-2) 10,802.06 11,041.25 1C-111-2 MWD (1C-111-2) 11,050.00 15,424.76 1C -11L2 -01 (1C-111-2-01) +N/ -S +E/ -W Direction (usft) (usft) (°) 0.00 0.00 0.00 HAq( HE S 70" 19'33.128 N 149° 30'0.514 W 0.00 usft Field Strength (nT) 57,423 5/152019 10:16:05AM Page 2 COMPASS 5000.14 Build 850 Survey Survey Tool Name Description Start Date End Data MWD MWD - Standard 8/25/2000 MWD-INC—ONLY MWD-INC—ONLY—FILLER 4/5/2019 4/5/2019 MWD MWD -Standard 4/9/2019 4/9/2019 MWD MWD- Standard 4/16/2019 4/16/2019 5/152019 10:16:05AM Page 2 COMPASS 5000.14 Build 850 ConocoPhillips BA FPUGNESER ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc Kupamk Local Co-ordinate Reference: Well 1C-11 Project: Kupamk River Unit TVD Reference: 1C-11 @ 102.00usft (1C-11) Site: Kupamk 1C Pad MD Reference: 1C-11 @ 102.00usR (1C-11) Well: 1C-11 North Reference: True Wellbore: 1C-1112-01 Survey Calculation Method: Minimum Curvature Design: 1C-1112-01 Database: EDT 14 Alaska Production Survey Annotation TIP KOP 5715/2019 10:16:05AM Page 3 COMPASS 5000.14 Build 85D Map Map Vertical - MD Inc Azi TVD TVDSS +NIS +El.W Northing Easgng DLS Section (usR) (') (°) (usft) (usR) (usR) (usR) (11100') Survey Tool Name (R) (ft) IRI 11,041.25 91.47 6.69 6,598.18 6,496.18 8,164.39 -1.209.43 5,977,162.14 560,364.72 348 8.164.39 MWD (3) 11,050.00 90.90 6.34 6,598.00 6,496.00 8,173.08 -1,208.44 5,977,170.84 560,365.64 764 8,173.08 MWD(4) 11,080.32 W36 675 6,596.60 6,494.60 8,203.17 -1204.99 5,977,20095 56,368.84 11.49 8,203.17 MWD(4) 11,110.23 95.50 3.95 6,594.03 6,492.03 8,232.83 -1,202.21 5,977,23063 56,371.38 10.08 8,232.83 MWD (4) 11,140.00 94.15 538 6,591.53 6,489.53 ,262.40 -1,199.80 5,977,260.21 56,373.55 6.59 8,262.40 MWD(4) 11,175.15 WAS 6.14 6,589.60 6,487.60 8,29731 -1,196.28 5.977,295 15 560,37678 6.09 8,297.31 MWD (4) 11,20522 89.14 7.40 6,589.26 6,48726 8,327.17 -1,192.73 5,977,325.03 560.380.08 10.85 8,327.17 MWD (4) 11,23521 89.75 6.63 6,589.55 6,48755 8,356.93 -1,189.07 5,977,354.82 560,383.50 3.28 8,356.93 MWD(4) 11,265.18 90.06 3.05 6,589.60 6,487.60 8,386.79 -1,186.54 5,977,384.70 560,385.78 11.99 8,386.79 MWD (4) 11,295.24 89.36 359.32 6,589.75 6,487.75 8.416.64 -1,185.92 5,977,41475 560,386.16 1262 8,416.84 MM (4) 11,325.45 89.54 355.47 6.590.04 6,488.04 8,447.01 -1,187.29 5,977,444.90 560,384.54 12.76 8,447.01 MWD(4) 11,355.18 90.95 355.38 6,589.92 6,487.92 8,47664 -1189.66 5,977,474.51 56,381.92 4.75 8,47664 MWD (4) 11,38523 91.57 357.50 6,589.25 6,487.25 8,506.63 -1,191.53 5,977,504.48 560,379.81 7.35 8,506.63 MWD (4) 11,415.35 91.60 359.68 6,588.42 6,486.42 8,536.72 -1,192.27 5,977,534.57 560,378.82 7.24 8,536.72 MWD (4) 11,445.31 91.17 1.60 6,58770 6,485.70 8,566.67 -1,191.94 5,977564.51 550,378.91 6.57 8,566.67 MWD (4) 11,475.39 90.28 3.61 6,587.32 6,485.32 8,59672 -1,190.57 5.977,594.57 560,380.03 7.31 8,596.72 MWD(4) -- 11,505.23 90.92 5.91 6,587.00 6,485.00 8,626.45 -1,188.09 5,977,624.31 560,382.26 8.00 8,626.45 MM (4) 11,534.91 90.77 747 6,586.57 6,484.57 8,655.92 -1.184.64 5,977,653.81 560,385.48 5.28 8,655.92 MWD (4) 11,565.03 90.09 9.58 6,586.34 6,464.34 8,685.71 -1,18017 5,977,68363 560,389.70 7.36 8,68571 MM (4) 11,595.04 88.03 10.87 6,586.83 6,484.83 8,715.24 -1,174.85 5,977,713.20 560,394.78 8.10 8,71524 MWD (4) 11,625.50 87.39 8.82 6,588.05 6,486.05 8,74522 -1,169.64 5,977,743.22 56,399.74 7.05 8,745.22 MWD (4) 11655.43 87.48 5.91 6,569.39 6,487.39 8,774.87 -1,165.81 5,977,772.90 560,403.32 9.72 8,774.87 MWD(4) 11,685.21 88.22 3.64 6,590.51 6,488.51 8,804.53 -1,163.33 5,977,802.57 560.405.56 8.01 8,804.53 MWD (4) 11,71540 88.83 1.03 6,591.28 6,489.28 6,834.68 -1,162.10 5,977,832.73 560,406.54 8.88 8,834.68 MWD(4) 11,745.28 88.66 228 6,591.89 6,489.89 8,864.54 -1,161.24 5,977,862.59 560,407.16 4.18 8,864.54 MM (4) 11]7487 90.98 4.44 6.591.93 6,489.93 8,894.07 -115951 5,9]7,892.14 560,403.65 10.23 8,894.07 MWD(4) 11,804.95 91.64 5.53 6,591.19 6,489.19 8,924.03 -1,156.89 5,977,922.11 560,411.01 4.61 8,924.03 MWD (4) 11,835.21 90.89 4.38 6,590.47 6,488.47 8,954.17 -1,154.28 5,977,95227 560,413.38 4.93 8,954.17 MWD (4) 11,865.47 89.78 502 6,590.29 6,488.29 8,984.32 -1,151.80 5,977,982.44 560,415.61 4.23 8,964.32 MWD (4) 11,89564 8764 6.96 6,590.96 6,488.96 9,013.72 -1,148.72 5,978,01186 560,41845 9.77 9,01372 MWD (4) Annotation TIP KOP 5715/2019 10:16:05AM Page 3 COMPASS 5000.14 Build 85D Survey ConocoPhillips DA ER i�uctll�s ConocoPhillips Definitive Survey Report Map Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1C-11 Project: Kuparuk River Unit TVD Reference: 1C-11 @ 102.00usft (1611) TVD Site: Kuparuk 1C Pad MD Reference: 1C-11 @ 102.00usft (1611) Northing Well: 1C-11 North Reference: True Wellbore: 1C-111-2-01 Survey Calculation Method: Minimum Curvature (usft) Design: 1C-111-2.01 Database: EDT 14 Alaska Production Survey 5/1Y2019 10:16:05AM Page 4 COMPASS 5000.14 Build 65D Map Map Vertical MD Inc AN TVD TVDSS +Nl-S -El-W Northing Easting DLS Section (usft) (1) (') (usft) (usft) (usft) (usft) (°I100.) Survey Tool Name Annotation (ft) (ft) (ftl 11,914.99 86.80 8.03 6,591.92 6,489.92 9,033.48 -1,146.12 5,978,031.84 560,420.69 6.81 9,033.48 MWD (4) 11,945.27 87.42 1049 6,593.45 6,491.45 9,063.32 -1,141.25 5,978,061.52 560,425.51 8.37 9,063.32 MWD (4) 11,975.15 86.03 12.47 6,594.64 6.492.64 9,092.58 -1,135.31 5,978,09082 560,431.21 6.93 9,092.58 MWD (4) 12,005.06 89.42 15.21 6,595.30 6,493.30 9,121.61 -1,128.16 5,978,11990 560,438.12 10.27 9,12161 MWD (4) 12,035.12 90.00 1774 6,595.45 6,493.45 9,150.44 -1,11963 5,978,14879 560,446.41 8.63 9,150.44 MWD (4) 12,064.55 90.95 20.06 6,595.21 6,493.21 9,17828 -1,110.10 5,978,176.71 560,455.71 8.52 9,178.28 MWD (4) 12,095.41 91.57 21.04 6,694.53 6,492.53 9,207.16 -1,099.27 5,978,205.68 560,466.30 3.76 9,207.16 MWD (4) 12,125.20 90.12 21.92 6.59409 6,49209 9,234.88 -1,088.36 5,978,233.49 560,476.98 5.69 9,234.88 MWD (4) 12,154.80 89.66 2083. 6,594.15 6.492.15 9262.41 -1077.58 5,978,261.13 550,487.54 4.00 9,262.44 MWD(4) 12,18609 94.52 21.13 6,593.01 6,491.01 9,291.63 -1,066.38 5,978,290.41 560,498.49 15.56 9,291.63 MWD (4) 12,215.93 94.00 19.72 6,590.79 6.488.79 9.319.52 -1.056.00 5,978,318.38 560,50865 5.02 9,319.52 MWD (4) 12,245.71 96.00 20.17 6,588.20 6,486.20 9,347.40 -1,04688 5.978,346.34 560,518.53 6.88 9,347.40 MWD (4) 12,275.31 93.96 2132 6,585.63 6,483.63 9,374.98 -1,035.44 5,978,374.00 560,528.75 7.90 9,374.98 MWD (4) 12,304.83 9199 21.09 6,584.09 6,482.09 9,402.46 -1,024.77 5,978,401.57 560,539.19 6.72 9,402.46 MWD (4) 12,345.63 92.83 22.08 6,582.38 6,480.38 9,440.37 -1,009.78 5,978439.59 560,553.87 3.18 9,440.37 MWD (4) 12,378.04 91.41 17.46 6,581.18 6,479.18 9.470.84 -998.83 5.978,470 15 560,564.57 14.90 9,470.84 MM (4) 12,408.12 9147 18.78 6,580.42 847842 9,499.41 -989.47 5,978,498.80 560,573.68 4.39 9,499.41 MWD (4) 12,440.91 92.37 18.38 6,579.32 6,477.32 9,530.48 -979.03 5,978,529.94 550,583.87 3.00 9,530.48 MWD (4) 12,468.73 93.81 19.90 6,577.82 6,475.83 9,556.72 -969.92 5,978,556.26 560,592.76 7.52 9,556,72 MWD (4) 12,498.32 93.69 22.55 6,575.89 6,473.89 9,584.24 -959.24 5,978,583.86 560,603.22 8.95 9,584.24 MM (4) 12,52807 93.63 25.57 6,573.99 6,471.99 9,611.35 -947.13 5,978,611.06 560,615.10 10.13 9.611.35 MWD(4) 12,557.68 93.76 27.91 6,572.06 8,470.06 9,637.73 -933.84 5,978,637.56 580,628.18 7.90 9,637.73 MWD (4) 12,588.41 92.98 28.46 6,570.27 6,468.27 9,664.77 -919.35 5,978,664.71 560,64244 3.10 9,664.77 MM (4) 12,61811 92.24 26.76 6,568.89 6,466.90 9,691.59 -905.32 5,978,69164 560,656.25 6.11 9,691.59 MWD (4) 12,653.43 92.55 24.74 6,567.44 6,465.44 9,722.84 -890.25 5,978723.01 560,671.06 5.88 9,722.84 MWD (4) 12,678.83 92.80 22.56 6,566.26 6,464.26 9,746.08 -880.08 5,978,746.33 560,681.04 8.63 9,746.08 MWD (4) 12,70871 9,117 2104 6,554.42 6,462.42 9,773.77 -869.00 5,978,774.10 560,691.89 707 9,773.77 MWD (4) 12,738.31 92.77 1808 6,56260 6.460.60 9.801.60 -859.11 5,978,602.02 560,701.55 11.19 9.801,60 MWD (4) 12.769.74 91.17 15.52 6,561.52 6,459.52 9.831.67 -850.03 5,978,832.15 560,710.38 9.60 9,831.67 MWD (4) 12,799.47 91.57 13.50 6.560.81 6,458.81 9,850.44 4142.59 5,978,860.98 560,717.59 6.92 9860.44 MWD (4) 12,828.97 9249 12.02 6,55976 6,457.76 9,889.19 -836.08 5,978,889.79 560,723.86 5.90 9,889.19 MWD (4) 5/1Y2019 10:16:05AM Page 4 COMPASS 5000.14 Build 65D Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Cc -ordinate Reference: Well 1C-11 Project: Kuparuk River Unit TVD Reference: 1C-11 a 102.00usft (1C-11) Site: Kupamk 1C Pad MD Reference: 1C-11 @ 102.00usft (1C-11) Well: 1C-11 North Reference: True Wellbore: 1C-1112-01 Survey Calculation Method: Minimum Curvature Design: 1C-1112-01 Database: EDT 14 Alaska Production Survey BAms 5/15/2019 10:16.05AM Page 5 COMPASS 5000.14 Build 86D Map Map Vertical _ MD Inc Azl TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (weft) (1) (1) (usft) Waft) (waft) (use) MGM Survey Tool Name Annotation (ft) (ft) (ft) 12,857.31 9425 10.29 6,558.10 6,456AD 9,916.95 -83060 5,978,917.58 560,729.11 8.70 9,916.95 MWD (4l 12,901.77 92.12 7.81 6,555.63 6,45363 9,960.78 -823.62 5,978,96147 560,735.73 7.35 9,960.78 MWD (4) 12,931.47 91.23 3.80 6,554.76 6,452.76 9,990.31 -820.62 5,978,991.02 560,738.48 13.82 9,990.31 MWD (4) 12,960.25 90.34 357.71 6,554.36 6,452.36 10,019.07 -820.24 5,979,019.78 560,73863 21.38 10,019.07 MWD (4) 13,007.89 90.92 35584 6,553.84 6,451.84 10,066.63 4822.92 5,979,067.31 560,735.55 4.11 10,066.63 MWD (4) 13,032.55 89.11 356.12 6,553.83 6,451.83 10,091.23 -824.65 5,979,091.89 560,733.63 7.43 10,091.23 MWD (4) 13,065.45 83.58 356.03 6,555.93 845393 10,123.97 -826.90 5,979,124.61 560,731.11 16.81 10,123.97 MWD (4) 13,092.26 88.19 355.70 6,557.85 6,465.85 10,150.63 -828.82 5,979,151.25 560,728.96 17.24 10,150.63 MWD (4) 13,121.96 91.72 356.80 6,557.87 6,455.88 10,18027 -830.77 5,979,180.86 560,726.78 12.45 10,18027 MM (4) 13,152.19 88.31 357.13 6,557.87 6,455.87 10,210.45 -832.37 5,979,21103 560,724.93 11.33 10,210.45 MWD (4) 13,182.91 87.55 358.78 6,558.98 6,456.98 10,241.13 -833.46 5,979,241.70 560,723.58 5.91 10,241.13 MWD (4) 13,211.80 89.39 1.29 6,55975 6,457.75 10,270.00 -833.44 5,979,270.67 560,723.36 10.77 10270.00 MWD (4) 13,242.23 89.02 1.78 6,550.17 6,458.17 10,30042 -832.63 5,979,300.99 560,723.93 2.02 10,300.42 MWD(4) 13271.75 89,66 1.28 6,560.51 6,458.51 10,329.93 -831.84 5,979,330.50 560,724.47 2.75 10,329.93 MWD (4) 13,300,98 69.32 2.36 6,560.77 6,458.77 10,359.14 -830.91 5,979,359.72 560,725.16 3.87 10,359.14 MWD (4) 13,330.94 89.86 3.14 6,550.98 6,458.98 10,389.07 .829.48 5,979,389.65 560,725.35 3.20 10,389.07 MWD (4) 13,360.76 89.05 3.75 6,561.26 6,459.26 10.418.83 -827.68 5,979,419.42 560,727.90 3.45 10,41883 MWD (4) 13,392.17 8920 4.24 6,561.74 6,459.74 10,450.16 .825.50 5,979,450.77 56,729.83 1.63 10,450.16 MWD(4) 13,420.47 8877 4.19 6,562.24 6,460.24 10,47838 -823.42 5,979,47900 560,73168 1.53 10,478.38 MWD (4) 13,450.85 87.45 4.62 6,563.24 6,461.24 10,50665 -82108 5,979,509.29 560,733.76 4.57 10,50665 MM (4) 13480.69 8926 5.14 6564.10 6,462.10 10,538.37 -818.55 5,979,539.02 560,736.06 6.31 10,538.37 MWD (4) 13510.41 91.23 4.45 6,563.97 6,46197 10,567.98 -816.06 5,979,568.65 560,738.30 7.02 10,567.96 MM (4) 13,54306 93.35 2.74 6,56267 6,460.67 10,600.54 -814.02 5,979,601.22 560,740.07 8.34 1,W0.54 MWD (4) 13,570.98 92.55 3.36 6,55123 6,459.23 10,628.38 -812.53 5,979,629.07 560,741.33 3.62 10,628.38 MWD (4) 13,606.71 93.91 429 6,559.22 6,457.22 10,663.98 -810.15 5,979,664.68 560,74342 461 10,663.98 MWD (4) 13,631.43 92.98 5.09 6,557.73 6,455.73 10,688.57 .808.14 5,979,689.29 560,745.23 4.96 10,688.57 MWD (4) 1360.46 91.10 5.42 6,556.70 6,454.70 10,717.46 -80548 5,979,718.19 560,747.65 6.57 10,717.46 MWD (4) 13,690.90 92.12 4.31 6,555.84 6,453.84 10,747.77 -802.90 5,979,748.53 560,749.98 4.95 10,747.77 MWD (4) 13,719.87 94.43 5.36 6,554.19 6,452.19 10,76.59 -800.46 5,979,777.36 560,752.18 8.76 10,776.59 MWD (4) 1375099 9504 3.11 6,551.62 6,449.62 10,1107 52 -798.17 5,979,808.30 560,754.22 ]47 10,807.52 MM (4) 13,780.30 9421 2.41 6,54925 6447.25 10,836.70 -796.76 5,979,83749 560,755.38 3.70 10,836.70 MWD (4) BAms 5/15/2019 10:16.05AM Page 5 COMPASS 5000.14 Build 86D ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1C-11 Project: Kuparuk River Unit TVD Reference: 1C-11 @ 102.00usft (1C-11) Site: Kuparuk 1C Pad MD Reference: 1C-11 @ 102.00usft (1C-11) Well: ICA 1 North Reference: True Wellbore: 1C-111-2-01 Survey Calculation Method: Minimum Curvature Design: 1C-111.2-01 Database: EDT 14 Alaska Production Survey BA (ER F�UGHES Annotation COMPASS 5000 14 Build 850 Map Map Vertical MD Inc TVD TVDSS ♦NW) +E/.W DLS _ Northing Easting Section Survey Tool Name ( usft) (°) (1) (7 Wait) (usft) (MR) lust) (ft) (ft) (ft) 13,810.38 91.60 3.33 6,547.73 6,445.73 10,866.70 -795.26 5.979,867.50 560,756.64 9.20 10,866.70 MWD (4) 13,841.00 91.32 3.71 6,546.95 6,494.95 10,897.25 -793.38 5,979,898,06 560,758.27 1.54 10,897.25 MWD (4) 13,87101 92.80 4.55 6,545.87 6,443.87 10,927.16 -791.22 5,979,927.99 560,760,18 5.67 10,927.16 MWD(4) 13,900.12 9307 3.76 6,544.38 6,442.38 10,956.16 -789.11 5,979,957,00 560,762.05 2B6 10,956.16 MWD (4) 13,929.58 92.92 4.85 6,542.84 6,440.84 10,985.50 -786.91 5,979,986.35 560,764.02 3.73 10,985.50 MWD (4) 13,959.85 91.41 544 6,541.70 6,439.70 11,015.62 -784.19 5,980,016.49 560,76648 5.36 11,015.62 MWD (4) 13,990.12 89.45 6.76 6,541.47 6,439.47 11.4572 -78098 5,980,046.61 560,769.45 7.81 11,045.72 MWD (4) 14,019.62 86.41 6.94 6,542.54 6,440.54 11,074.98 -777.46 5,980,075.90 560,772.73 10.32 11,074.98 MWD (4) 14,049.40 84.99 9.32 6,544.77 6,442.77 11,104.38 -773.26 5,980,10533 560,776.68 9.29 11,104.38 MWD (4) 14.81.48 84.93 11.91 6,547.59 6,445.59 11,135.78 -767.38 5,980,136.78 560,782.31 8.04 11,135.78 MM (4) 14,110.26 83.39 13.57 6,550.52 6,448.52 11,163.71 -761.06 5,980,16475 560,788.39 7.85 11.163.71 MWD (4) 14,140.90 84.32 15,68 6,553,80 6,451.80 11,193.18 -753.37 5,980,194.29 560,795.84 7.49 11,193.18 MWD(4) 14,169.42 83.30 18.04 6,556.87 6,454.87 11,22032 -745.15 5,980,22148 560,803.84 8.97 11,220.32 MWD (4) 14,200.38 83.79 18.37 6,560.35 6,458.35 11,249.54 -735.54 5,980,250.78 560,81321 1.90 11,249.54 MWD (4) 14,230.23 84.59 17.56 6,563.37 6,461.37 11277.79 -726.38 5,980,279.10 560,822.14 3.80 11,27779 MWD (4) 14,259.85 84.47 15.39 6,566.20 6.464,20 11,306.06 -718.03 5,980,307.44 560,830.25 7.47 11,306.6 MWD (4) 14,290.30 85.51 12.63 6,568.86 6,466.86 11,33550 -710.70 5,980,336.93 560,837.34 9.50 11,335.50 MWD (4) 14,321.24 8548 1168 6.571.29 6.469.29 11,365.65 .704.21 5,986367 .13 560,843.59 3.08 11,36565 MWD (4) 14,351.95 8548 10.29 6,573.71 6.471.71 11.395.70 698.37 5,980,39723 560,849.17 4.51 11,39570 MWD (4) 14,38367 8309 11.18 6,576.87 6,474.87 11,426.71 692.49 5,986428.28 560,854.79 8.04 11,426.71 MWD (4) 14,410.56 82.43 10.22 6,580.26 6,47826 17452.92 687.54 5,980,454.53 560,859.53 4.31 77,452.92 MWD (4) 14,447.30 82.96 11.73 6589.16 6,482.17 11,482.85 681.74 5,980,484.51 560,865.09 5.17 11,482.85 MWD(4) 14,472.51 85.12 12.58 6,587.41 6,485.41 77,513.20 675.20 5,980,514.90 560,871.38 7.43 11513.20 MWD (4) 14,507.58 86.43 13.04 6,589.99 6,487.99 11,547.30 667.45 5,980,549.6 560,878.85 3.% 11,547.30 MWD(4) 14,537.91 86.60 12.99 6,591.83 6,489.83 11,576.79 660.63 5,980,578.61 560,885.42 0.58 11,576.79 MWD (4) 14,56968 8665 12.51 6,593.70 6,491.70 11,607.73 653.63 5,980,60960 560,892.17 1.52 11,607.73 MM (4) 14,599.98 86.90 11.14 6,595.41 6,493.41 11,637.39 69743 5,980,639.25 560,898.12 4.59 11,637.34 MWD (4) 14,630.00 88.07 945 6,596.73 6,494.73 11,666.84 642.07 5,980,66860 560,90324 6.84 11,666.84 MWD (4) 14,659.69 89.08 7.21 6,597.46 6,495.46 11,696.21 63777 5,980,698,20 560,907.30 8.27 11,696.21 MWD(4) 14,713.12 88.49 7.11 6,598.60 6,496.60 11,74921 631.11 5,98075125 560,913.52 1.12 11749.21 MWD (4) 14,745.96 88.83 8.40 6,599.36 6,497.36 11,78774 626.66 5,980,78381 560,917.68 4.06 11,781.74 MWD (4) 5%52019 10:16:05AM Page 6 BA (ER F�UGHES Annotation COMPASS 5000 14 Build 850 Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska lnc_Kuparuk Local Co-ordinate Reference: Well 1C-11 Project: Kuparuk River Unit TVD Reference: 1C-11 Q 102.O0usft (1C-11) Site: Kupamk 1C Pad MD Reference: 1C-11 @ 102.00usft (1C-11) Well: 1C-11 North Reference: True Wellbore: 1C-111-2-01 Survey Calculation Method: Minimum Curvature Design: 1C-111-2-01 Database: EDT 14 Alaska Production Survey Annotation B% REs 5115/2019 10:16:05AM Page 7 COMPASS 5000.14 Build 85D Map Vertical MD Inc AN TVD TVDSS +NIS +E/ -W DLS _ Northing Northing EMap Section gurvey Tool Name (usft) (') (') (usft) Will) Wit) (usft) (ft (ft) 14,773.05 89.11 668 6,599.85 6,497.85 11,808.59 -623.13 5,980,810.68 560,921.01 6.43 11,808.59 MWD (4) 14,806,84 89.08 7.80 6,600.39 6,498.39 11,842.11 81887 5,980,84423 560,925.00 3.32 11,842.11 MWD (4) 14,836.65 88.68 7.22 6,600.97 6,498.97 11,871.65 514.98 5,980,873.81 56892865 2.36 11,871.65 MWD (4) 14,866.58 88.86 7.79 6,601.61 6,499.61 11,901.32 511.07 5,980,903.50 560,932.31 2.00 11,901.32 MWD (4) 14,898.97 88.83 7.59 6,602.26 6,500.26 11,933.41 806.73 5,980,93563 560,936.38 0.62 11,93341 MWD (4) 14,927.73 89.08 7.61 6,602.79 6,500.79 11,961.92 802.93 5,980,954.16 560,939.95 0.87 11,961.92 MWD (4) 14,970.61 68.65 7.70 6,603.64 6,501.64 12,004.41 -597.22 5.981,006.69 560,945.31 1.02 12,004.41 MWD (4) 15,019.14 88.77 5.55 6,604.73 6,502.73 12,052.60 -591.62 5,981,054.92 560,950.51 4.44 12,05260 MWD (4) 15,081.34 89.51 4.96 6,605.36 6,503.36 12,09461 587.76 5,981,096.96 560,954.03 2.24 12,094.61 MWD (4) 15,106.64 92.95 4.38 6,604.39 6,502.39 12,13975 -584.07 5,981,142.12 560,957.35 7.70 12,139.75 MM (4) 15,136.04 94.09 4.76 6,602.59 6,500.59 12,169.00 -581.73 5,981,171,38 560,959.44 4.09 12,169.00 MWD (4) 15,166.16 94.83 4.83 6.600.24 6,498.24 12,198.92 579.22 5,981,201.32 560,961]1 2.47 12,198.92 MWD (4) 15,198.88 94.95 5.18 6,597.45 6,495,45 12,231.40 -576.38 5,981,233.82 560,964.28 1.13 12,231.40 MWD (4) 15,226.72 94.74 541 6,595.10 6,493.10 12,259.02 -573.82 5,981,261.46 560,966.62 1.12 12,259.02 MWD (4) 15,257.36 95.88 5.64 6,592.27 6,490.27 12,289.39 -570.88 5,981,291.85 560,969.30 379 12,289.39 MWD(4) 15,288.58 96.19 5.60 6,589.20 6,487.20 12,318.30 -568.04 5,981,320.78 560,971.91 1.07 12,318.30 MWD (4) 15,321.12 �- 95.32 5.26 6,585.73 6,483.73 12,352.51 -564.78 5,981,355.02 560,974.88 2.70 12,352.51 MWD (4) 15,346.76 94.95 4.73 6,58344 6,48144 12,377.95 -562.56 5,981,380.47 560,976.90 2.51 12,377.95 MWD (4) 15,375.68 95.08 5.44 6,580.91 6,478.91 12,406.65 560.01 5,981,409.19 560,979.21 2.49 12,406.65 MWD (4) 15,404.40 94.55 4.88 6,578.50 6,476.50 12,435.15 -557.43 5,981,437.71 560,981.55 2.68 12,435.15 MWD(4) 15,424.76 94.98 4.36 6,57681 6,474.81 12,455.38 -555.80 5,981,457.94 560,983.02 3.31 12,455.38 MWD (4) 15,462.00 94.98 4.36 6,573.57 6,471.57 12,492.37 -552.98 5,981,494.95 560.985.54 000 12,492.37 PROJECTED to TD Annotation B% REs 5115/2019 10:16:05AM Page 7 COMPASS 5000.14 Build 85D THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kupandc River Field, Kuparuk River Oil Pool, KRU IC -11L2 -O] ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-042 Surface Location: 1225' FNL, 637' FWL, SEC. 12, TI IN, RI OE, UM Bottomhole Location: 99]' FSL, 43' FWL, SEC. 25, T12N, R10E, UM 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.olaska.gov Dear Mr. Ohlinger: Enclosed is the approved application for the permit to drill the above referenced development well The permit is for a new wellbore segment of existing well Permit No. 196-172, API No. 50-029-22714-00- 00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this day of March, 2019. �r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISo ON PERMIT TO DRILL ?n AAc 91; nn.-; 1a. Type of Work: 1 It. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for. Drill ❑ Lateral ❑D Stratigraphic Test ❑ Development - Oil ❑� Service - Winj ❑ Single Zone ❑� Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ I Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑� • Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 • KRU 1 C-11 L2-01 - 3. Address: 6. Proposed Depth: 70> -. &,7// 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 15,800' • TVD7fj,' 6609' Kuparuk River Pool / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: .fes Surface: 1225' FNL, 637' FWL, Sec. 12, Tt t N, R10E, UM Z S6 ADL 25638 3 z 8. DNR Approval umber: 13. Approximate Spud Date. Top of Productive Horizon: 2253' FNL, 139' FEL, Sec. 35, T12N, R10E, UM LONS 79-016 3/27/2019 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 1 991' FSL, 43' FWL, Sec. 25, T12N, R10E, UM 2560 3000' . 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 102 15. Distance to Nearest Well Open Surface: x- 561641 y- 5969009 , Zone- 4 GL / BF Elevation above MSL (ft): 59 to Same Pool: 2784' (1C-152) 16. Deviated wells: Kickoff depth: 12,490 • feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 99 degrees Downhole: 3585 . Surface: 2955 - 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.6 L-80 ST -L 5020' 10,780' • 6486— 15,800'. Uncemented Slotted Liner ZZ 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): 11,300 7011 N/A 11,211 6939 10,266, 10,780 Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 257 sx AS 1 121' 121' Surface 6902' 9-5/8" 775 sx AS 111, 710 sx G, 60 sx AS 1 6943' 4439' Production 10,386' T' 112 sx Class G 10,427' 6344', Liner 1029' 5" 112 sx Class G 11,300' 7011' Scab Liner 5108' 3-1/2" 1 10,271' 6231' Perforation Depth MD (ft): 10,660 - 10,716 Perforation Depth TVD (ft): 6517-6559 Hydraulic Fracture planned? Yes[] No D 20. Attachments: Property Plat ❑ BOP Sketch Drilling Program v Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch E] Seabed Report e Drilling Fluid Program e 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be ��-'//� 7/ deviated from without prior written approval. Contact Name: William Long& Authorized Name: James Ohlinger Contact Email: William. R. Lon COP.Com Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4372 3//r Authorized Signature: Date: Commission Use Only Permit to Drill c� ,. / 2 API Numbea�:: / C�/_ G� Permit Approval See cover letter for other requirements. Number: /—D'72-^ 50-0�?- —2-7'-71'`7-6r Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane,, gas hydrates, or gas contained in shales: d Other: 2 Samples req'd: Yes E]No LTJ Mud log mq'd: Yes,❑,/ NoR -VP-e �o 00 HOP trS� p y"�55 J 5 � S �� HzS measures: Yes 52r No❑ Directional svy req'd: Yes L� No,❑✓ iI ✓1✓/U/GY✓ �7 /—<✓G�h f<r . Spacing exception req'd: Yes ❑ IN Inclination -only svy req'd: Yes[] LJ /-z, 2 5-a 0 p5 -c J Post initial injection MIT req'd: Yes❑ NoR� f% ver/�ct�7cc to a��9✓4CZS.0/5�b) Y3 �r�rntr�i a//ew tic jc7`c,�e{� pn.;-,a- to .bc ctn� ��o/�-i- ct-long �l-hcpc/rrr77-/atr.-mac/, APPROVED BY Date: 7( Approved by' COMMISSIONER THE COMMISSION / suomit Farm and Form 10401 Revised 5/2017 This pe mit is v'�tQ1fp��f4 th o t to Of approval per 20 AAC 25.005(8) Attachments in Duplicate lJ 1 \ �V f� 1 _<2� 3•2Z1% ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 13, 2019 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 sundry application to set a whipstock and applications for permits to drill three laterals out of the KRU 1C-11 (PTD# 196-172) using the coiled tubing drilling rig, Nabors CDR3-AC. Also included in this submission is a sundry application to cut and remove liner from KRU 1 C-11 L1-02 (PTD# 209-078) to gain access to the kick off point in 1 C-11. CTD operations are scheduled to begin in late March 2019. The objective will be to drill thre laterals, KRU 1 C- 11 L2, 1C-111-2-01, and 1C-111-2-02, targeting the Kuparuk C -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 — AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to the sundry applications are the following documents: - Sundry Application Forms (10-403) for 1C-11 and 1C-11 L1-02 - Operations Summary in support of the 10-403 Sundry Applications - Current Wellbore Schematic - Proposed CTD Schematic Attached to permit to drill applications are the following documents: - Permit to Drill Application Forms (10-401) for 1C-11 L2, 1C-11 L2-01, and 1C-111-2-02 - Detailed Summary of Operations - Directional Plans for 1C-11 L2, 1C-111-2-01, and 1C-11 L2-02 - Current Wellbore Schematic - Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-2634372. Sincerely, William R. Long Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 1C-111-2, 1C-111-2-01, & 1C-111-2-02 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20AAC 25.005(0 and 20AAC 25.005(b))....._ ..... .......... ........._._... .. ................ .................. _._..........2 2. Location Summary ................... ....... ....... ...... ...... ...... .... ....... 2 (Requirements of 20 AAC 25.005(c)(2))... ..._..... . ... ........... .......... .............2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005 (c)(3)) ................... ........... .............. ................. ............................_................._..._ 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005 (c)(4)) .. ............_.............. .... ..... ........ .... ...... .........._.... ......... _..... ......._......... ..............2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)). ............_..... ...._.... _...... ....._........... ..................2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)) .................... ._................ _.................. ..-...... ............. .............. --- ............. ................... .... 3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7)) ..... ..................... ........ ................... ................. .... ...................._...,..... ..................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)) ... ......................... ..... ............ ................... . .......... ............... ..............._... ................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9))... ....._....... ........_..................... .................... ....—..................... .......... ................. ..............4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10)) ._................. ..... . .............................__........... _._................ ............ ............ ..... ..4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AA C 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. ........... — ...... ................................................. ...... . 6 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 1C-111-2, 1C-111-2-01, & 1C-111-2-02 laterals.........................................................6 Attachment 2: Current Well Schematic for 1C-1 1 ............................................................................................................6 Attachment 3: Proposed Well Schematic for 1C-111-2, 1C-1112-01, & 1 C-1112-02 laterals...........................................6 Page 1 of 6 January 30, 2019 PTD Application: 1C-11 L2, 1C-111-2-01, & 1C-111-2-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1C-11 L2, 1C-111-2-01, & 1 C-111-2-02. All laterals will be classified as "Development' wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the C sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1C-111-2, 1C-111-2-01, & 1C-111-2-02. 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 3,500 psi. Using the maximum formation pressure in the area of 3585 psi in 1C-06 (i.e. 10.9 ppg EMW), the maximum potential surface pressure in 1C-11, assuming a gas gradient of 0.1 psi/ft, would be 2955 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 Pressureyy mac!/ vsa� rp� (Requirements of 20 AAC 25.005 (c)(4)) �/yS Zein % yS / 9 10 Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1 C-11 was measured at the datum to be 2615 psi (8.0 ppg EMW) on 5/12/2015. The maximum downhole pressure in the 1C-11 vicinity is to the south in the 1C-06 injector. Pressure was measured to be 3585 psi, at the datum, (10.9 ppg EMW) in July of 2017. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) ,/ The offset injection wells to 1C-11 have injected gas, so there is a possibility of encountering free gas while drilling the 1 C-11 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) ✓ The major expected risk of hole problems in the 1 C-11 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 C-11 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 March 14, 2019 PTD Application: 1C-11 L2, 1C-111-2-01, & 1C-111-2-02 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 1C -11L2 62.5 H-40 Welded Surface Lateral is planned to be left unlined. Surface 121' 1640 670 Surface 2-3/8", 4.7#, L-80, ST -L slotted liner; 1C-111-2-01 10,780' 15,800' 6486' 6609' aluminum billet on to 4440' 5750 3090 Production 7" 2-3/8", 4.7#, L-80, ST -L slotted liner; 1C-111-2-02 10,600' 15,600' 6370' 6169' deployment sleeve on to Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top ND Btm ND Bust Collspse Conductor 16" 62.5 H-40 Welded Surface 121' Surface 121' 1640 670 Surface 9-5/8" 40.0 1-80 BTC Surface 6943' Surface 4440' 5750 3090 Production 7" 26.0 L-80 BTC -MOD Surface 10,427' Surface 6373' 7240 5410 Liner 5" 18.0 L-80 LTC 10,279' 11,300' 6237' 7011' 10,140 10,500 Scab Liner 3-1/2" 9.3 L-80 EDE-Brd MOD 5163' 10,271' 3496' 6231' 10,160 10,540 Tubing3-1/2" 9.3 L-80 EUE-8rd MOD Surface 5193' Surface 3512' 10,160 1 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 AA C 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: Water -Based PowerVis milling fluid (8.6 ppg) — Drilling operations: Water-based PowerVis mud (8.6 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 11.4 ppg NaCl / 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 1C-11 laterals we will target a constant BHP of 11.4 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 March 14, 2019 PTD Application: 1C-11 L2, 1C-111-2-01, & 1C-111-2-02 Pressure at the 1C-11 Window (10.684' MD. 6534' TVD) Usinq MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations KRU well 1 C-11 is a Kuparuk C -Sand producer equipped with 3-1/2" tubing and 5" production casing. The CTD sidetrack will utilize three laterals to target the C -sands to the north and north-east of 1 C-11. The laterals will increase C -sand resource recovery and throughput. Prior to CTD rig up, the CTD liner landed in the 1C-11 L1-02 will be cut. CDR3-AC will pull the cut liner and set a mechanical thru tubing whipstock inside the 5" casing at the planned kick off point of 10,684' MD. The 1 C-11 L2 lateral will exit through the 5" and drill to a planned TD at 13,000' MD, targeting the C sand to the north. The lateral will be left unlined. An aluminum billet for kicking off will be set at 12,490' MD. The 1 C-11 L2-01 lateral will kick off at 12,490' MD and drill to a planned TD of 15,800' MD targeting the C sand to the north. It will be completed with 2-3/8" slotted liner from TD up to 10,780' MD with an aluminum billet. The 1C -11L2-02 lateral will kick off at 10,780' MD and drill to a planned TD of 15,600' MD targeting the C sand to the north-east. It will be completed with 2-3/8" slotted liner from TD up into the 5" casing at 10,600' MD with a deployment sleeve. Page 4 of 6 March 14, 2019 Pumps On 1.9 bpm) Pumps Off C -sand Formation Pressure 8.0 2718 psi 2718 psi Mud Hydrostatic 8.6 2922 psi 2922 psi Annular friction i.e. ECD, 0.080 si/ft 855 psi 0 psi Mud + ECD Combined no chokepressure) 3777 psi overrbalanced -1059psi) 2922 psi underbalanced ^204psi) Target BHP at Window 11.4 3873 psi 3873 psi Choke Pressure Required to Maintain Target BHP 96 psi 951 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations KRU well 1 C-11 is a Kuparuk C -Sand producer equipped with 3-1/2" tubing and 5" production casing. The CTD sidetrack will utilize three laterals to target the C -sands to the north and north-east of 1 C-11. The laterals will increase C -sand resource recovery and throughput. Prior to CTD rig up, the CTD liner landed in the 1C-11 L1-02 will be cut. CDR3-AC will pull the cut liner and set a mechanical thru tubing whipstock inside the 5" casing at the planned kick off point of 10,684' MD. The 1 C-11 L2 lateral will exit through the 5" and drill to a planned TD at 13,000' MD, targeting the C sand to the north. The lateral will be left unlined. An aluminum billet for kicking off will be set at 12,490' MD. The 1 C-11 L2-01 lateral will kick off at 12,490' MD and drill to a planned TD of 15,800' MD targeting the C sand to the north. It will be completed with 2-3/8" slotted liner from TD up to 10,780' MD with an aluminum billet. The 1C -11L2-02 lateral will kick off at 10,780' MD and drill to a planned TD of 15,600' MD targeting the C sand to the north-east. It will be completed with 2-3/8" slotted liner from TD up into the 5" casing at 10,600' MD with a deployment sleeve. Page 4 of 6 March 14, 2019 PTD Application: 1C -11L2, 1C -11L2-01, & 1C -11L2-02 Pre -CTD Work 1. RU wire line: Change out GLV's, record SIBP, and drift 2-3/8" liner. Pull 2-3/8" x 3-1/2" liner top packer. Cut 2-3/8" Liner 2. Prep site for Nabors CDR3-AC. Ria Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Prep wellbore for sidetrack a. Pull 2-3/8" slotted liner above cut b. Set Thru-Tubing Whip Stock in 5" Casing 3. 1C -11L2 Lateral (C sand -North) a. Mill 2.80" window at 10,684' MD. b. Drill 3" bi-center lateral to TD of 13,000' MD. c. Run an aluminum billet with open hole anchor at 12,490' MD. 4. 1 C-11 L2-01 Lateral (C sand - North) a. Kickoff the aluminum billet at 12,490' MD. b. Drill 3" bi-center lateral to TD of 15,800' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 10,780' MD. 5. 1C -11L2-02 Lateral (C sand -North-East) a. Kickoff of the aluminum billet at 10,780' MD. b. Drill 3" bi-center lateral to TD of 15,600' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 10,600' MD. 6. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post -Rip 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 slick -line. - 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. Page 5 of 6 March 14, 2019 PTD Application: 1C -11L2, 1C-111_2-01, & 1C-111-2-02 - 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 undeployment, the steps listed above are observed, only in reverse. Liner Running - The 1C-11 laterals will be displaced to an overbalancing fluid (11.4 ppg NaCl / NaBr) prior to running liner. See "Drilling Fluids' section for more details. - While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AA 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (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 1C -11L2 5300' JC -11E2 --o1 3000' 1C-111-2-02 3425' Distance to Nearest Well within Pool Lateral Name Distance Well 1C-111_2 37' 1C-11 L1 1C-111_2-01 2784' - 1C-152 1C-111_2-02 36' 1C -11L1 16.Attachments Attachment 1: Directional Plans for 1C-11 L2, 1C-11 L2-01, & 1C-11 L2-02 laterals Attachment 2: Current Well Schematic for 1C-11 Attachment 3: Proposed Well Schematic for 1C -11L2, 1C -11L2-01, & 1C -11L2-02 laterals Page 6 of 6 March 14, 2019 ConocoPhillips PmIM: KuparNRIVOFUMLI Uo: KuparukICPWParent VVELLSORE DETAILS: IC -111.2-01 M,IREKE wwwTvm Wellbore: IC.111.2 T -W* Well: 1C xxx.sn.mT T wxsaaawi LH Wellbore: C41V Latitude Longitude PMn:1C.IIU4I vp02(DMftA)(IC41MC.IIL2AP1) 596900814 561641.06 70* 13M InWj ImWj 12000� 11600 11200 INN +1_11 I. woo I mw WWI 8800 WIN) BATER ES UGH .GE." WELLDETAILS: 1c-1 I I I +N1 -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 596900814 561641.06 70* 19 33.128 N 149* 39 00.514 W Sec MD Inc Azi TVDSS +N/ -S -E/-W Dleg TFaw vsmt Kn-rdaw 1 12420.00 94.91 13.25 6499.60 9464.61 -799.44 0.00 0.00 9491.74 TIP 2 12490.00 98.67 16.43 6491.33 9531.78 -781.65 7,0) 40.00 9558.00 KOP/Stad 7 US 3 12650+00 DOM 9.20 6479.13 9687.10 -746.37 7.00 -140.00 9711.49 3 4 12950.00 86.44 348.50 6488.22 9985.22 -752.31 7.00 -100.00 10009.57 4 5 13325.00 86.44 14.81 6511+50 10356.07 -741.60 7.00 90.00 10379.50 5 6 13725.00 86.44 346.75 8536.32 10751.28 -736.23 7.00 -90.00 10774.02 6 7 14125b0 93.69 13.82 6535.86 11147.31 -734,28 7.00 75.00 11169.52 7 8 14525.00 86.44 346.75 6535.41 11543.33 -732.32 7.00 -105.00 11565.01 8 9 14725.00 74.32 35187 6568.76 1173720 -765.58 TOD 150.00 11760.22 9 10 14925.00 73.10 8.40 6624.86 11928.61 -761.85 7.00 95.00 11951.25 10 11 15125.00 87.10 8.40 6659.16 12123.04 -733.16 7.00 0+00 12144.11 11 12 15375.00 95.85 23.57 665233 12362.37 .664.65 7.00 60.00 12379.95 12 13 15800.00 95.115 353.67 6609.42 12775+65 -602.01 7.00 -90.00 12789+83 Planned TD at 15800.00 13M InWj ImWj 12000� 11600 11200 INN +1_11 I. woo I mw WWI 8800 WIN) BATER ES UGH .GE." West( -)./East(+) (400 usftlin) I I I IC4111C-41. 6000 p imom n.dTD.1156W,Wl I I ME111011 ME 61W .110 It 11 1_T01 1_T0101 IC IL IlL I TM I lium-M Effilmimmo I IN ON I I 6300 ME, no f� IM11110m, i . � I 011 mim MILI1 I IN low FA wilummmmi 64 M I IN EMPIRMIMMENIM "lomm"12, MEMO --mmml West( -)./East(+) (400 usftlin) Vertical Section at 357300 (100 uaft/in) I I I IC4111C-41. 6000 p n.dTD.1156W,Wl I I 61W It 11 1_T01 1_T0101 IC IL IlL I TM I lium-M K-111,2 I I IN ON I 6300 III -ILT MILI1 PL2 64 M 913M.00 ,3 + P moned' D4H 8W.W 65M 6600 ON 14 A IL2 F.M 3 M1 3 60 11 12 ON TIPI K IDLI 7M - - - - - - - - - - - - - - - - . . . . . . e e e e. . . . . . . . . . . . Vertical Section at 357300 (100 uaft/in) ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1C Pad 1C-11 1 C-11 1-2-01 Plan: 1C-11 L2-01_wp02 (Draft A) Standard Planning Report 08 March, 2019 BTGE company ConocoPhillips ConocoPhillips Planning Report B F�UGHES aGEcompany Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit Site: Kupawk 1C Pad Well: 1C-11 Wellbore: 1C-1112-01 Design: 1 C-11 L2-01_wp02 (Draft A) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1C-11 Mean Sea Level 1C-11 @ 102.00usft (1C-11) True . Minimum Curvature aroject Kuparuk River Unit, North Slope Alaska, United States Nap System: US State Plane 1927 (Exact solution) • System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Nap Zone: Alaska Zone 04 Using geodetic scale factor His Kuparuk 1C Pad 1C-11 Tie On Depth: 12,420.00 We Position: Northing: 5,968,522.46 usft Latitude: 70° 19'28.285 IN 'rom: Map Easting: 562,372.05 usft Longitude: 149° 29' 39.293 N 'osition Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.48 ° Nell 1C-11 Tie On Depth: 12,420.00 Depth From (TVD) +N/ -S +EI -W Nell Position +NAS 0.00 usft Northing: 5,969,008.74 usft Latitude: 70° 19' 33.128 h 0.00 +EI -W 0.00 usft Easting: 561,641.06 usft Longitude: 149° 30' 0.514 N aositton Uncertainty Turn 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1C-1112-01 Magnetics Model Name Sample Date Design Audit Nates: Version: Vertical Section: BGGM2018 1C -11L2-01 wp02(Draft A) 4/1/2019 Declination Dip Angle Field Strength (nT) 16.71 80.88 57,423 Phase: PLAN Tie On Depth: 12,420.00 Depth From (TVD) +N/ -S +EI -W Direction (usft) (usft) (usft) (°) -60.40 0.00 0.00 357.30 Plan Sections Measured TVD BelovA �/ Dogleg Build Turn Depth Inclination Azimuth System +NIS +EI -W Rate Rate Rate TFO (usft) (°) V) (usft) (usft) (usft) (°/100usft) (°/t00usth (°/100usft) (°) Target 12,420.00 94.91 13.25 6,499.60 9,464.61 -799.44 0.00 0.00 0.00 0.00 12,490.00 98.67 16.43 6,491.33 9,531.78 -781.65 7.00 5.36 4.55 40.00 12,650.00 90.09 9.20 6,479.13 9,687.10 -746.37 7.00 -5.36 4.50 -140.00 12,950.00 86.44 348.50 6,488.22 9,985.22 -752.31 7.00 -1.22 -6.91 -100.00 13,325.00 86.44 14.81 6,511.50 10,356.07 -741.60 7.00 0.00 7.01 90.00 13,725.00 86.44 346.75 6,536.32 10,751.28 -736.23 7.00 0.00 -7.01 -90.00 14,125.00 93.69 13.82 6,535.86 11,147.31 -734.28 7.00 1.81 6.78 75.00 14,525.00 86.44 346.75 6,535.41 11,543.33 -732.32 7.00 -1.81 -6.77 -105.00 14,725.00 74.32 353.87 6,568.76 11,737.20 -765.58 7.00 -6.06 3.64 150.00 14,925.00 73.10 8.40 6,624.86 11,928.61 -761.85 7.00 -0.61 7.29 95.00 15,125.00 87.10 8.40 6,659.16 12,123.04 -733.16 7.00 7.00 0.00 0.00 15,375.00 95.85 23.57 6,652.73 12,362.37 -664.65 7.00 3.50 6.09 60.00 15,800.00 95.85 353.67 6,609.42 12,775.65 -602.01 7.00 0.00 -7.04 -90.00 3/a2019 2:41:30PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips BA ER ConocoPhllllps Planning Report F�IGHES a GE company Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1C-11 Company: ConocoPhillips Alaska Inc Kuparuk TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1C-11 @ 102.00usft (1C-11) Site: Kuparuk 1C Pad North Reference: True Well: 1C-11 Survey Calculation Method: Minimum Curvature Wellbore: 1C-111-2-01 Design: 1C-11 L2-01_wp02 (Draft A) Planned Survey TV D57 (� Measured TVD Below , 2 Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System . -NIS +E1 -W Section Rate Azimuth Northing Easting (usft) (I (_) (usft) (usft) (usft) (usft) (*1100usft) C) (usft) (usft) 12,420.00 94.91 13.25 6,499.60 9,464.61 -799.44 9,491+74 0.00 0.00 5,978,465.55 560,763.98 TIP 12,490.00 98.67 16.43 6,491.33 9,531.78 -781.65 9,556.00 7.00 39.83 5,978,532.86 560,781.22 KOP1Start 7 DLS 12,500.00 98.13 15.97 6,489.87 9,541.28 -778.89 9,567.36 7.00 -139.97 5,978,542.38 560,783.90 12,600.00 92.77 11.45 6,480.38 9,637.93 -755.32 9,662.80 7.00 -139.75 5,978,639.22 560,806.67 12,650.00 90.09 9.20 6,479.13 9,687.10 -746.37 9,711.49 7.00 -139.96 5,978,688.45 560,815.22 3 12,700.00 89.48 5.75 6,479.32 9,736.67 -739.86 9,760.70 7.00 -100.00 5,978,738.07 560,821.31 12,800.00 88.26 358.86 6,481.29 9,836.50 -735.85 9,860.24 7.00 -100.06 5,978,837.93 560,824.51 12,900.00 87.05 351.96 6,485.38 9,936.04 -743.84 9,960.03 7.00 -100.13 5,978,937.38 560,815.70 12,950.00 86.44 348.50 6,488.22 9,985.22 -752.31 10,009.57 7.00 -100.09 5,978,986.49 560,806.83 4 13,000.00 86.44 352.01 6,491.32 10,034.40 -760.75 10,059.09 7.00 90.11 5,979,035.59 560,797.98 13,100.00 86.44 359.02 6,497.53 10,133.84 -768.55 10,158.78 7.00 90.22 5,979,134.95 560,789.37 13,200.00 86.44 6.04 6,503.74 10,233.49 -764.14 10,258.11 7.00 90.22 5,979,234.63 560,792.96 13,300.00 86.44 13.05 6,509.95 10,331.85 -747.60 10,355.59 7.00 90.22 5,979,333.11 560,808.69 13,325.00 86.44 14.81 6,511.50 10,356.07 -741.60 10,379.50 7.00 90.05 5,979,357.38 560,814.49 5 13,400.00 86.44 9.54 6,516.16 10,429.21 -725.81 10,451.82 7.00 -90.16 5,979,430.64 560,829.67 13,500.00 86.44 2.53 6,522.36 10,528.40 -715.32 10,550.40 7.00 -90.22 5,979,529.91 560,839.35 13,600.00 86.44 355.52 6,528.57 10,628.13 -717.02 10,650.10 7.00 -90.22 5,979,629.61 560,836.83 13,700.00 86.44 348.50 6,534.77 10,726.91 -730.88 10,749.42 7.00 -90.22 5,979,728.26 560,822.16 13,725.00 86.44 346.75 6,536.32 10,751.28 -736.23 10,774.02 7.00 -90.05 5,979,752.58 560,816.61 6 13,800.00 87.80 351.83 6,540.09 10,824.86 -750.14 10,848.17 7.00 75.14 5,979,826.04 560,802.10 13,900.00 89.61 358.59 6,542.35 10,924.42 -758.48 10,948.01 7.00 75.09 5,979,925.52 560,792.94 14,000.00 91.42 5.35 6,541.44 11,024.30 -755.04 11,047.62 7.00 74.99 5,980,025.41 560,795.56 14,100.00 93.24 12.12 6,537.37 11,122.99 -739.88 11,145.49 7.00 74.88 5,980,124.21 560,809.91 14,125.00 93.69 13.82 6,535.86 11,147.31 -734.28 11,169.52 7.00 74.95 5,980,148.57 560,815.31 7 14,200.00 92.33 8.74 6,531.93 11,220.73 -719.64 11,242.17 7.00 -104.86 5,980,222.11 560,829.35 14,300.00 90.52 1.97 6,529.44 11,320.20 -710.32 11,341.09 7.00 -104.90 5,980,321.65 560,837.85 14,400.00 88.71 355.21 6,530.12 11,420.11 -712.77 11,441.00 7.00 -105.00 5,980,421.52 560,834.57 14,500.00 86.90 348.44 6,533.95 11,518.96 -726.96 11,540.41 7.00 -105.11 5,980,520.24 560,819.57 14,525.00 86.44 346.75 6,535.41 11,543.33 -732.32 11,565.01 7.00 -105.05 5,980,544.57 560,814.01 8 14,600.00 81.90 349.39 6,543.02 11,616.31 -747.75 11,638.63 7.00 150.11 5,980,617.40 560,797.99 14,700.00 75.83 352.96 6,562.33 11,713.20 -762.81 11,736.12 7.00 150.31 5,980,714.16 560,782.13 14,725.00 74.32 353.87 6,568.76 11,737.20 -765.58 11,760.22 7.00 150.11 5,980,738.13 560,779.17 9 14,800.00 73.86 359.30 6,589.32 11,809.17 -769.88 11,832.32 7.00 95.73 5,980,810.06 560,774.28 14,900.00 73.25 6.57 6,617.63 11,904.89 -764.97 11,927.70 7.00 96.01 5,980,905.80 560,778.40 14,925.00 73.10 8.40 6,624.86 11,928.61 -761.85 11,951.25 7.00 95.25 5,980,929.55 560,781.32 10 15,000.00 78.35 8.40 6,643.35 12,000.49 -751.24 12,022.55 7.00 0.00 5,981,001.51 560,791.34 15,100.00 85.35 8.40 6,657.52 12,098.36 -736.80 12,119.63 7.00 0.00 5,981,099.48 560,804.98 15,125.00 87.10 8.40 6,659.16 12,123.04 -733.16 12,144.11 7.00 0.00 5,981,124.19 560,808.42 11 15,200.00 89.73 12.94 6,661.24 12,196.69 -719.28 12,217.02 7.00 60.08 5,981,197.94 560,821.69 15,300.00 93.23 19.01 6,658.66 12,292.73 -691.78 12,311.67 7.00 59.95 5,981,294.20 560,848.39 15,375.00 95.85 23.57 6,652.73 12,362.37 -664.65 12,379.95 7.00 59.84 5,981,364.05 560,874.95 3/82019 2:41:30PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BA ER ConocoPhillips Planning Report t IGHES BAT 6E ccmpany Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1C-11 Company: ConocoPhillips Alaska Inc_Kuparuk TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1C-11 @ 102.00usft (1C-11) Site: Kuparuk 1C Pad North Reference: True Well: 1C-11 Survey Calculation Method: Minimum Curvature Wellbore: 1C-1112-01 Design: 1 C-11 12-01_wp02 (Draft A) Planned Survey /n �y q r Measured TVD Below3^v2 Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI -S +E/.W Section Rate Azimuth Northing Easting (usft) (•) (_) (usft) (usft) (usft) (usft) ('1100usft) C) (usft) (usft) 12 15,400.00 95.85 21.81 6,650.18 12,385.31 -655.05 12,402.42 7.00 -89.91 5,981,387.07 560,884.36 15,500.00 95.85 14.78 6,639.99 12,479.71 -623.85 12,495.24 7.00 -89.64 5,981,481.71 560,914.78 15,600.00 95.85 7.74 6,629.80 12,577.21 -604.44 12,591.72 7.00 -89.64 5,981,579.36 560,933.39 15,700.00 95.85 0.70 6,619.61 12,676.36 -597.12 12,690.41 7.00 -89.64 5,981,678.55 560,939.89 15,800.00 - 95.85 353.67 6,609.42 12,775.65 -602.01 12,789.83 7.00 -89.64 5,981,777.80 560,934.19 Planned TD at 18600.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 15.800.00 6,609.42 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth -NAS +E/ -W (usft) (usft) (usft) (usft) Comment 12,420.00 6,499.60 9,464.61 -799.44 TIP 12,490.00 6,491.33 9,531.78 -781.65 KOP/Start 7 DLS 12,650.00 6,479.13 9,687.10 -746.37 3 12,950.00 6,488.22 9,985.22 -752.31 4 13,325.00 6,511.50 10,356.07 -741.60 5 13,725.00 6,536.32 10,751.28 -736.23 6 14,125.00 6,535.86 11,147.31 -734.28 7 14,525.00 6,535.41 11,543.33 -732.32 8 14,725.00 6,568.76 11,737.20 -765.58 9 14,925.00 6,624.86 11,928.61 -761.85 10 15,125.00 6,659.16 12,123.04 -733.16 11 15,375.00 6,652.73 12,362.37 -664.65 12 15,800.00 6,609.42 12,775.65 -602.01 Planned TD at 15800.00 3/8/2019 2:41.30PM Page 4 COMPASS 5000.14 Build 85D r, ConocoPhillips BA (ER 0 ConocoPhillips Anticollision Report I IUGHES a GE company Company: ConocoPhillips Alaska lnc Kuparuk Project: Kupamk River Unit_? Reference Site: Kuparuk 1C Pad Site Error: 0.00 usft Reference Well: 1C-11 Well Error: 0.00 usft Reference Wellbore 1C-11 1-2-01 Reference Design: IC -11 L2-01_wp02 (Draft A) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well IC -11 10-11 @ 102.00usft(1C-11) 1C-11 @ 102.00usft(1C-11) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Reference lC-llL2-01_wP02(Draft A) 1 C Pad - 1 C-11 - 1 C-11 L2 - Filter type: NO GLOBAL FILTER: Using user defined selection 8 fiitenng criteria 0,41 Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 12,420.00 to 15,800.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum ellipse separation of 3,000.00 usft Emor Surface: Combined Pedal Curve Warning Levels Evaluated at: 2.79 Sigma Casing Method: Added to Error Values Survey Tool Program Date 3/612019 1 C Pad - 1 C-11 - 1 C-11 L2 - From To 0,41 Reference (usft) (usft) Survey (Wellbore) Tool Name Description 121.00 10,495.50 1C-11 (1C-11) MWD MWD - Standard 10,495.50 12,420.00 1C-1112_wp03(Dmft A)(1C-llL2) MWD MVVD- Standard 12,420.00 15,800.00 1C-111-2-01_wp02(Draft A)(1C-111-2-01) MWD MWD - Standard (usft) (usftl Jusft) (usft) Summary Kuparuk 1 C Pad - 1 C-11 - 1 C-11 L2 - lC-11 L2_wp03 (Draft A) 0,41 Reference Offset Distance 12,824.46 6,584.10 Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well - Wellbore - Design (usft) (usftl Jusft) (usft) Aamutb Kuparuk 1C Pad Centre Depth Depth Depth Depth 1C -11 -1C -1112-1C-11 L2_wp03 (DraftA) 12,724.24 12,725.00 50.54 39.40 4.533 CC, ES, SF 1C-11-1C-1112-02-lC-11L2-02_wp02(Dmft A) 12,506.08 13,875.00 2,035.55 1,875.17 12.692 SF 1C-11-1C-1112-02-1C-111-2-02_wp02(Dmft A) 12,586.65 14,100.00 2,015.14 1,867.53 13.651 ES 1C-11-1C-1112-02-1C-llL2-02_wp02(Dmft A) 12,595.00 14,125.00 2,014.51 1,868.63 13.810 CC 1C -152 -1C -152-1C-152 12,520.00 12,406.00 2,784.26 2,676.42 25.820 CC, ES, SF Offset Design Kuparuk 1 C Pad - 1 C-11 - 1 C-11 L2 - lC-11 L2_wp03 (Draft A) 0,41 Survey Program'. 121 -MWD. 10493 -MM 1.103 Take Immediate Action 12,824.46 6,584.10 12,825.00 6,532.77 Reference offset -52.63 Semi Major Axis 79.56 12,849.22 6,585.04 Measured Vertical Measured vertical Red ¢... n offset Aamutb Onset Wellbore Centre Depth Depth Depth Depth 9.41 -48.91 from North 'NIS aEl-W (ueft) Juan) (am) lush) Juan) haan) (1) Jose) (usft 12,425.00 6,601.04 12,42500 6,601.17 0.10 0.10 -95.64 9,469.46 -79831 12,450.00 6,598.44 12,450.00 6,598.95 0.60 0.60 -98,67 9,493.81 -793.12 12.474.81 6,595.50 12475.00 6,596.60 1.09 1.11 -94.18 9,518.30 -788.67 12,499.56 6,591.93 12,500.00 6,594.13 1.58 1.62 -93.52 9,542.90 -784.913 12,524.49 6588.6a 12,525.00 6,591.55 2.07 2.14 -91,29 9,587.58 482.01 12,5,u)A9 6.586.01 12,550.00 6,588.73 2.56 2.65 -87,38 9,592.32 -779.76 12.574.49 6,583.91 12,575.00 6,585.52 3.07 3.18 -82,53 9,617.06 -7)8.17 12,599.44 6,582.40 12,600.00 6,581.94 3.57 3.70 -77.34 9,641]9 - 77.25 12,624.29 6,581.48 12.625.00 6,578.00 4.0 4.23 42.20 9,666.47 -777.00 12,649.00 6,581.13 12,650.00 6,573.68 4.58 4.75 -67.33 9,691.09 -777.41 12,674.02 6,581+16 12,67600 6,569.00 5.10 5.28 -63.77 9.715.63 478.49 12,699.13 6581.31 12,700.00 6563.96 5.61 5.80 -61.00 9]40.05 -780.23 12,724.24 6,581.60 12,725.00 6558.57 6.13 6.33 -58.81 9,764.34 -782.64 12,749.35 6582.03 12,750.00 6552.83 6.65 6.85 -57.06 9.788.48 -785.71 12,774.45 6,582.59 12,775.00 6546.75 7.18 7.37 -55.67 9,812.44 -789." 1279951 658328 12800.00 8540.13 7.70 7.89 -5427 9,836.20 -793.47 Distance Between Between Cannes Ellipses hose) (mfl) 040 -0.01 1.46 0.14 3.22 1.02 6.67 3.57 10.40 6.31 14.16 9.01 18.07 2226 26.91 32.16 37.94 44.06 50.54 57.38 64.58 72.00 11.82 14.96 18.65 23.06 28.07 33.52 39.40 45.69 52.41 59.45 68.79 74.55 82.67 91.62 Onset Site Error. 0.00 ush Offset Well Error: 0 m us8 Minimum separation Warning Separation Factor (use) 4.908 0,41 0.976 STOP Drilling 1.33 1.103 Take Immediate Action 12,824.46 6,584.10 12,825.00 6,532.77 8.23 8.40 -52.63 9,859.76 -797.48 79.56 12,849.22 6,585.04 12,850.00 6,524.69 8.75 8.91 -50.82 9,883.08 -801+44 87.39 12,873.70 6586.10 12,875.00 6,515.69 9.26 9.41 -48.91 9,906+15 -8WW 95.61 12,89282 6,587.27 12,900.00 6,508.38 9.77 9.91 -46.98 9,928.94 -809.23 104.32 11.82 14.96 18.65 23.06 28.07 33.52 39.40 45.69 52.41 59.45 68.79 74.55 82.67 91.62 Onset Site Error. 0.00 ush Offset Well Error: 0 m us8 Minimum separation Warning Separation Factor (use) 4.908 0,41 0.976 STOP Drilling 1.33 1.103 Take Immediate Action 2.20 1.464 Take Immediate Action 3.10 2.153 Caution Monitor Closely 4.10 2.539 Normal Operations 5.17 2.745 Normal Operations 625 2.890 Normal Operations 7.30 3.049 826 3.258 9.10 3.533 9.86 3.847 10.54 4.180 11.15 4.533 CC, ES, SF 11.69 4.908 12.17 5.306 12.55 5.737 12.77 6230 12.84 6.807 12.74 7.503 12.50 8.3" CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 3/6/2019 10:13:49AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Project: Kupsrul,RNertlnX 1 rrtb3rmxwe u=m,+�rvonn'err IAI=LLBOREDETAILS: IC -1112 R3�R[xce Krowmnw Cpmtllmm Mn:lRMxene>: ww1Flt, i,uxwm Patent Walt. 1C-11 Sec: KupomkIC Pad u.alxxrxn ve6cs(twlRel.m<m tOm ®ID3.OWrRItFH1 Welt IC -11 smay,+n.n w.. T100n MD: 10685.50 SxOm Ivsl Rdemnce: SM-(OOON,o60E) WWpDS(: DOAryL.0Or0' Menuee0epr RBklena: tau g01100m01,c.nl Plan:1C-11L1.wp091DrsRAlI1C•11IIC-11L2) AA)(I �,,.. w,,,,, c6lwbxx MCMm'. M'n'n,nmcxrvMm B F UGI ES cecDlnDRlry USft/jn) ICMA— 1C-11 ® 102.00usft(1C-11) If 1111' 16 I4 -TONIN -103 IH-IBNH-1031.1 111-19NLL-103 1H-Im/Ifl-IDbt 111-Im111-IOA.2 14-IdLIR1O11.2 IH-0Nn-IOSIH_IM651-IaF1'� 111-IWIH-300 )X1W/IH-1091 1141ONN-103U ➢1-IW4410n.1 r It. ILL-1WZ _T dry I r -T III tl lasso , I � o i 199ao I l 139M- 3950-IJiXX 13W: •. u 1 I,INrn Hlnanll lli Ic 11HC`-IIL]-0I IJONr m rvnol3. -. r, -� 6111 I 12150,. ' ' � IH�r1II111111 � :u 114➢1 9(� � � - I ' '� �. i1 �' 1. yy�" 111-104151-IDH'91 j' 6' 1a-11nc uLao2 'Ibp W � ISP. u3-1oNi1 man. � �I IIIiN1131A1d y Q'� O b 6!)Bi 10350- $ e ➢HNxryJ3 6161 A tU 1111[�Il62 - @!3111 v o if W,t` iN ..JSS �❑❑�y�� �: III -INTI -IS nV¢u ]b3" SY•16 9950 iu 1nY'nl mYA IFII/IC ILLI If-r1Y1C 15] '. y v a ]CM 6f06 IC -IS IC -IR � I 9000 h - 1(•..I X✓11'.1N '1 �. 101 _._. }j _ ]g91 ` Sgt -IC-1SN11: 135 0 8550:.. IZI g4 p \ ~`� �S Ic 131no-111 x Ion[ m 1011 8100 345 ' 7650 $t 60. 5 .111G1➢C-IILId 'lOIJO- loalx] r 17 IC- , f-nnc-n µy5 rM'nla ypo. 6]50 $5 � 60 -}9- 01IIn 101 � IC-0lrl1t A111111 V OVP C 19n(%19 USft/jn) ICMA— 1C-11 ® 102.00usft(1C-11) If 1111' 16 1C-11 L1, L1-01, L1-02 Actual CTD Sidetrack ConocoPhillips Update: 07/27109 Alaska 10.244! on 6943' MD 7"26#L -80 shoe @ 10,42T MD C -sand parts (sgfd) 10,660' - 10,716' MD er3.5"x5" TTOVS al 1 g747'MD set 15 deg LOHS - 2.80" W ndow Exit Fish at 10,990' (tailed IBP) 5", 18# LAO liner a110;271'-11,300' MD Z P liner -top packer el 10,271' Hole in 7" casing at 5466'MD (5/26/08) D = 1.71" Pell packe = 1 sa• ID = 1.00" Cannon TRMAXX-5E SCSSV (412297' MD Minimum ID = 2.813" (X-profle) Cameo KBMG gas lit mandrels @ 3194', 421 T. 5118' 9.3# L-80 EUE Brd Tubing to surface 80-00 seal assembly @ 517T MD muleshoe at 5193' MD Scab Liner (5163'-10271' MD) FHI. Retrievable backer at 5203' MD Baker Premier packer at 10,149' MD D -nipple at 10,189' MD Milled out to 2.80" (414109) Muleshoe Jnt at 10,260-10,266' MD, inside of 5.25" ID Be ID = 4.40", OD = 5.2" Fish -8D-00 Seal Assembly, 10266'- 10313' (5125/2008) Length = 46.55', ID = 3.00" Muleshoe at 10,313' MD 1C -11L1-02: 11,4DT- 13,031' MD 2-318" liner 10,248' -13,030' sWtletl 11,388' -12,992' anchor billet e111,40T MD M� J 1C '-13,3 85 MID 2-318-liner11,750'-13,369' aluminum billet at 11,750' MD 9-5/8" 40# L-80 shoe 6943' MD 7.2611 L-80 shoe 1D,427' MD KOP @ 10,686 MD Baker 3.5" x 5" TTINS C sand pads (sgtd) 10.660' -10.716' MD g -Nipple at 10726 MD 1C-11 Proposed CTD Schematic Il IID=1.71" e r3 10,747' MD er 3.5" x 5" TOWS at 10,747' set 75 deg LOHS - 2.811" Window Exil Fish at 10,990' (failed IBP) 5",188L4101ineraf10,271'-11,300'MD 7 ZXP liner -top pecker at 10,277' Hole in ""'a casing al 5466' MD (526/08) 1C-111.2 Plan TD: 13,000' MD Top of Billet: 12,490' MD S 11 packer at 10,75BMD D = 1.68" Updated: 13 -Mar -2019 WRL Camco TRMPXXSE SCSSV @ 2297' MD Minimum ID = 2.813" (X -profile) Camw KBMG gas lift mandrels Q 3194', 4217', 5118' 9.3k L-80 EUE 8rd Tubing to surface 8040 seal assemblv A 5172' MD sinter packer at 10,149' MD at 10,189'MD out to 2.80" (414109) 26U-10,266' MD, inside of 5.25" ID tieback sleeve = 5.2" ssemby, 1026V -10313' (5252008) 1C-07L2.DI Plan TD: 15,600' MD Top of Billet: 10,780' MD iC-171.2-02 Plan TD: 15 600' MD Top o(Liner. 10,600' MD ---------------- ---------------- 1C-11L1-02:11,407'- 1C-77L7-01: 11,750'- 12,875' MD 2-3/8" liner 11,40' -11,802' anchor billet at 11,407' MD 1C -11L1: 10,750'- 13,385' MD 2-3/8" finer 11,750'- 13,369' aluminum billet at 11,750' MD TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: /� G3�u� POOL: /�� ci ✓t(�/i P_.� Lel / Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK=60-69 TEXT FOR APPROVAL LETTER The perms is for a new wellbore segment of existing ell Permit '� 7Z API No. 50-MO- / (Ifgits No. Production should continue to be reported as a function of the original are API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_- from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 Permit. can be issued w/o hydrogen sulfide measures Well Name: KUPARUK RIV,UNIT IC -11L2-01 — _ Program DEV Well bore seg d❑ PTD#:2190420 Company CONOCOPHILLIPS ALASKA INC. __— _. _ __ __ _ _— __ Initial Class/Type DEV/PEND GeoArea 890. . Unit 11160 _ __. On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.0300. 1.A),0.2.A-D) NA Seismic analysis of shallow gas. zones.. NA 1 Permit fee attached. NA _ formation pressures and stabilize shale sections with constant BHP of about 11.4 ppg EMW. 2 Lease number appropriate _ Yes Surface location in ADL025649; top prod interval & TO in ADL025638.. 3 Unique well. name and number Yes 4 Well located in defined pool _ Yes Kuparuk River Oil Pool, governed by Conservation Order No. 4320 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 432D has no interwell spacing. restrictions.. Wellbore will be. more than 500' 6 Well located proper distance from other wells. _ _ Yes from an external property line where. ownership or. landownership. changes. As proposed,. well will... 7 Sufficient acreage available in drilling unit Yes conform to spacing. requirements. 8 If deviated, is. wellbore plat. included Yes 9 Operator only affected party. Yes 10 Operator has. appropriate bond in force _ Yes _ Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative approval Yes SFD 3/22/2019 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 for KRU 1C-11. Engineering 19 Surface casing protects all knovm USDWs NA Surface casing set for KRU 1C-11 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 uncemented 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 10403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Anti-coftion 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 3585 psig(10.0 ppg .EMW ); will drill. w/ 8,6. ppg EMW and maintain overbal w/ MPD VTL 3/26/2019 29 BOPEs, do they meet regulation _ _ _ Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 2955 psig; will test BOPS to 3500 psig 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 Primary well 1C-11 measured 52 ppm H2S on 1/25/19. H2S measures required. Geology 36 Data. presented on potential overpressure zones Yes Max. potential res. pressure is 10.9 ppg EMW; expected res. pressure is 8.0 ppg EMW. Well will be Appr Date 37 Seismic analysis of shallow gas. zones.. NA drilled using 8.6 ppg mud, a ooiled-tubing rig, and. managed pressure drilling technique to control SFD 3/22/2019 38 Seabed condition survey (if off -shore) NA_ formation pressures and stabilize shale sections with constant BHP of about 11.4 ppg EMW. 39 Contact name/phone for weekly. progress reports [exploratory Only] NA.. NOTE: Chance of encountering free gas while drilling due to gas injection performed in this area. Geologic Engineering Public Date NOTE: Chance of encountering free gas while drilling due to gas injection performed in this area. Date: Date Commissioner: Commissioner: Commissioner SJZ�vtr�"L( 3121/iq
