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219-041
DATA SUBMITTAL COMPLIANCE REPORT 8/5/2019 Permit to Drill 2190410 Well Name/No. KUPARUK RIV UNIT 1C -11L2 Operator ConocoPhillips Alaska, Inc. API No. 50-029-22714-63-00 MD 12880 TVD 6515 Completion Date 4/28/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log No Samples No ,/ Directional Survey Yes DATA INFORMATION List of Logs Obtained: GR/Res (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Fant Number Name Scale Media No Start Stop CH Received Comments ED C 30792 Digital Data 5/17/2019 Electronic File: 1C-11 L2 EOW - NAD27.pdf ED C 30792 Digital Data 5/17/2019 Electronic File: 1C-11 L2 EOW - NAD27.txt ED C 30792 Digital Data 5/17/2019 Electronic File: 1C -11L2 EOW NAD83.pdf ED C 30792 Digital Data 5/17/2019 Electronic File: 1C-11 L2 EOW NAD83.txt Log C 30792 Log Header Scans 0 0 2190410 KUPARUK RIV UNIT 1C-11 L2 LOG HEADERS ED C 30798 Digital Data 10408 12880 5/20/2019 Electronic Data Set, Filename: 1C -11L2 GAMMA RES.Ias ED C 30798 Digital Data 5/20/2019 Electronic File: 1C-11L2_2MD Final.cgm ED C 30798 Digital Data 5/20/2019 Electronic File: 1C-11L2_5MD Final.cgm ED C 30798 Digital Data 5/20/2019 Electronic File: 1C-1 lL2_5TVDSS Final.cgm ED C 30798 Digital Data 5/20/2019 Electronic File: 1C-11L2_2MD Final.pdf ED C 30798 Digital Data 5/20/2019 Electronic File: 1C-11L2_6MD Final.pdf ED C 30798 Digital Data 5/20/2019 Electronic File: 1C-llL2_5TVDSS Final.pdf ED C 30798 Digital Data 5/20/2019 Electronic File: 1C-11 L2 EOW - NAD27.pdf ED C 30798 Digital Data 5/20/2019 Electronic File: 1C-11 L2 EOW - NAD27.txt ED C 30798 Digital Data 5/20/2019 Electronic File: 1C-11 L2 Final Surveys TO 12880.csv ED C 30798 Digital Data 5/20/2019 Electronic File: 1C-111_2 Final Surveys TO 12880.xisx ED C 30798 Digital Data 5/20/2019 Electronic File: 1C- C- 111-225 tapescan BHI CTK.txt 11L225tapescanBHICTK.txt AOGCC Pagel oft Monday, August 5. 2019 DATA SUBMITTAL COMPLIANCE REPORT 8/5/2019 Permit to Drill 2190410 Well Name/No. KUPARUK RIV UNIT 1C-1112 MD 12880 TVD 6515 Completion Date 4/28/2019 ED C 30798 Digital Data ED C 30798 Digital Data ED C 30798 Digital Data ED C 30798 Digital Data ED C 30798 Digital Data Log C 30798 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report YO Production Test Informatior©/NA Geologic Markers/Tops U Interval Start Stop Operator ConocoPhillips Alaska, Inc. API No. 50-029-22714-63-00 Completion Status 1-0I1- Current Status 1 -OIL UIC No 5/20/2019 Electronic File: 1C- Mechanical Integrity Test Information Y / NA 11 L2_5_tapescan_BHI_CTK.tM 5/20/2019 Electronic File: 1C-11 L2_output.tap 5/20/2019 Electronic File: 1C-11 L2 2MD Final.tif 5/20/2019 Electronic File: 1 C-11 L2 5MD Final.tif 5/20/2019 Electronic File: 1C -11L2 5TVDSS Final.tif 0 0 2190410 KUPARUK RIV UNIT 1C-111-2 LOG HEADERS Sample Set Sent Received Number Comments Directional / Inclination Data 0 Mud Logs, Image Files, Digital Data / lA Core Chips Y /leA Mechanical Integrity Test Information Y / NA //Y Composite Logs, Image, Data Files PYA Core Photographs Y /6) Daily Operations Summary YO Cuttings Samples �Y I lA Laboratory Analyses Y /A� COMPLIANCE HISTORY Completion Date: 4/28/2019 Release Date: 3/27/2019 Description Date Comments Comments: Compliance Reviewed By:\ A06(( Page 2 of $. Date: -=--.- Monday, August 5, 2019 STATE OF ALASKA MAY 2 8 ALASKA OIL AND GAS CONSERVATION COMMISSION ZC�9 WELL COMPLETION OR RECOMPLETION REPORT AND&JAZYC 1a. Well Status: Oil ❑� Gas El SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG[-] WDSPL ❑ No. of Completions: 1b. Well Class: ' Development El Exploratory❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 4/28/2019 14. Parmitto Number/ Sundry: 219-041 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 417/2019 15. API Number: 50-029.22714-63-00 4a. Location of Well (Governmental Section): Surface: 1225' FNL, 637' FWL, Sec 12, T11N, R10E, UM Top of Productive Interval: 1324' FSL, 563' FEL, Sec 35, T12N, R10E, UM Total Depth: 1856' FNL, 122' FEL, Sec 35, T12N, RIDE, UM 8. Date TD Reached: 4/9/2019 16. Well Name and Number: KRU 1C -11L2 9. Ref Elevations: KBA02 GL: 59 • BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: _ ADL 25638, ADL 25649 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 561641 y- 5969009 Zone- 4 TPI: x- 560373 y- 5976826 Zone- 4 Total Depth: x- 560795 y- 5978928 Zone- 4 11. Total Depth MDlrVD: 12880/6515 ' 19. DNR Approval Number: LONS 79.016 12. SSSV Depth MD/TVD: 2297/1994 20. Thickness of Permafrost MD/TVD: 199311802 5. Directional or Inclination Survey: Yes ❑+ (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 1068416535 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 SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 41 121 41 121 24 257sx AS 1 9.626 40 LA0 42 6945 42 4440 12.25 775sx AS III, 710sx Class G, 7 26 L-80 28 10466 28 6372 6.5 112sx Class G 5 18 L-80 10279 11300 6237 7011 6,125 112sx Class G 3.5 9.3 L-80 5163 10271 3496 6231 Scab Liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Perforations @ COMPLETION 10684-12880 MD and 6535-6515 TVD .... 419/2019 3" Open Hole Left Unlined ,Vl V RIFIED +�PRROO-DUCTION 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 5193 5203/3518 10141/6143 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No [D Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNTAND KIND OF MATERIAL USED 27. TEST Date First Production: 5/6/2019 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 5/8/2019 Hours Tested: 5hrs Production for Test Period Oil -Bbl: 474.2 Gas -MCF: 739 Water -Bbl: 960 Choke Size: 176 Gas -Oil Ratio: 1 1559 Flow Tubing Press. 389 Si Casino Press: 1350 Calculated 24 -Hour Rate Oil -Bbl: 227 Gas -MCF: 3547 Water -Bbl: 1 4607 Oil Gravity- API (corr): 22. Form 10407 Revised 512017 lir 6�¢�! 9 ' /�7 CONTINUED ON PAGE 2 RBDMS±L6vMAY 2 9 2019 Submit OGRIGI `IAL only-� 28. CORE DATA Conventional Corals): Yes ❑ No 0 Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MD/ VD, From[To), and summarize lithology and presenceof 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 ❑� Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Permafrost - Base 1993 1802 - Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 10684 6535 - information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk C TD 12880 6515 - Formation at total depth: I Ku aruk D Shale 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, 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. A /y/ Authorized Name: James Ohlin er Contact Name: William Lon 40157-- Authorized Title: Staff CTD Engineer Contact Email: William. R.Lon co .com Authorized���� Contact Phone: 263-4372 Signature: Date: 10 INSTRUCTIONS General: This forth 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 85M'40.e L-0DSMe @6Mr MD TL-0Oslue� Lei 1o,42 4zr Mo ].5'x4T1WS , czm4-1D. (iI5 10.667 -ID, WM MD MIY q0M5 Y,1ML-0D Xner rttD,2l1'-11,207 ND� 2XP &xr-bopaIXar W topt' XNMDDeswgrt 544 65 (61tB.09� : TD12.] TD12B90'MD To WB a 1MD'MO 11 1N: 1AIay2T9.L iE SCSSV ®RR9T MD it (xcmMet IM mendmk C 31M'. 4217'. 51 I5 T.Ssr,b umn W�5172 MD eRMO 1' MO cMraz MD 10.+47 MD ua91 55'MS P 0,MMO InsIEe o15.RS IDtieOack slttrx .15A t TD:15,462M0 LNer Top,10. gT42M0 Blink L'uu¢ 10.]91'-12115 MO U11L 2 TD: 15,2M' MD aWvn mlMr+5.IW MD T o1 War, 10,239' MD ;c-35/7 L1er 10.,50'-1],315'11,1W-13367MD N slumNum MM a111,T6UM0 ConocoPhillips Alaska, Inc. KUP PROD WELLNAME 1C-11 RIVER UNIT TRDP W0: WELLBORE 1C-11 s -n. srmafa rzaxe vM Last Tag vwYale lenutt (MW1 Annig iun oeptn(rn(el 1 nd Bile W llsone Loan Motl et' ................................................................................... Last Tag. SLMI 10,900.0411921%5 1C-11 India, HANGER, Eri.7 Last Rev Reason Annntafmn End cafe We11Lort test MM By ............................... .. .. .._.... Rev Reason: Replaced OV 5/112019 I 1C-11 3e,dbael Casing Strings Casing Description (in) IDpnl ToFigre) set Depth Me) SN Dam Torag... NNLen pi.. ..do Top rM1reatl IOD CONDUCTOR 16 1506 410 121.0 1210 62.50 H40 WELDED CONDUCTOR. 1161110 CasiW Descrynear OD en) ID (in) Too PIKB) Sat Dep�n( s) BAOep1o(Tied—WV-perP.GrWe Top Thread SURFACE 9518 853 427 6,9452 44399 6000 L-80 BTBC OULtg Deredptlon Do (in) ID Nd Top We) Set DeptM1(Me, III, print TTVIl WO'lsn 9.1Grede top TM1wtl PRODUCTION 7 6.28 28.2 10.4658 163725 26.00 L-80 BTCM casing Description 10(ln) top M e) aN Depth (XKB) Bept01 .I,_ WtlLe ft16Me rop TMeW III Into LINER 5 4.15 10,2]9.4 11,3000 ],010] 1800 L-80 LTC I SAFETYKY 2.4 Liner Details Nominal lB TOPM(B) Top (DID)MB) Top nal p) Hem Des Cam fin) 10,279.4 6,236.5 4522 HAN ER BAKER 5'x7' LINER HANGER 8 PACKER 5.000 MSUET;3,1039 w1PACKER 10,303. 6,2534 4X.62 PRR BAKER PER 4000 Caein00eecripWn c0 (Int ID(In) Top RKES Sel BeplM1 me) Set SepM (ND)... WVten p...GMe rop TM7 GAS UW: 4,0174 WINDOW LI -02 5 4.00 10,]50.0 1075].0 6,5894 26.00 L6 Casing Description OB(InI ID (inI Tap(XKB) 5,1 Depth ggag Set Be.go nolo vai IT GOde Toprreaatl 35"SCAB LINER 3112 2.99 5.1633 10271 fi230.fi 9.30 L-80 EUE8rdABM 00 can Li 6.117 Liner Details Nonondgl Tog(Ma) Top UvOHMS) Top and p) 1hm Des Co. br) 5,163.3 3,496.3 57.33 SLEEVE HR Liner Setting Sleeve 4.421) LIXATO'sU00 51777 3,504.1 57.34 NO BUSHING sneer Bushing 42M 5,178.9 3,504.7 57.34 SBE 8040 Seal Bore Extntlol 4.0M RPAL:SmS 5,1982 3,5151 57.35 NO BUSHING Xover Bushing 2.990 5,202.9 3,517 7 57.35 PACKER FHL Reviewable Packer 2992 10,140.9 6.1428 4926 PACKER Baker Premier Production Packer 2.870 10,189.0 6,174.5 48.06 NIPPLE 275'D'Nipple-MILLED TO 280"4142009 2803 10,262.0 6,224.3 45.80 NIPPLE Fluted No1Go 3000 Tubing Strings Tudor, Description String Ma... l0(in) rop(Ma) set D.pa,uk-Sm Dean (rvgl.. weBn'K) cmde Top connection TUBING 312 299 36.7 5193.0 3,5123 9.30 L-80 EUEBrdABMOD Completion Details TopnVD) Top In, Nmnlnet Top IM1KB) (MB) Ll 1Mn Dee Co. Upping 4z3.M2— 363 3fi.J 0.00 HANGER Tubing Hatper 6"x35""ISA "BPVG 2.992 2297.4 1,994.1 54.61 SAFETY VLV TRMAXX %2.813" X-Pnofue 2.812 5170.2 3,500.0 57.34 LOCATOR BAKER LOCATOR .11.04 space out 3.9W 5,1]2.5 3,501.2 57.34 SEAL BAKER 8040 SEAL ASSEMBLY 3.999 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, ate.) Top(Ma) Top(TVDI (Mel Topmcl PI Des Com Run Done III (in) uxER 1G111$az 10]3IP t s.1m0 10,23)0 02 Z0 46.58 did -CTD CTD 2318" Liner , lined back up into the Parent Liner. 412812019 LINER Toi 10,237 No 10,2660 6,227.1 456] SEAL ASSY 8040 SEAL ASSEMBLY, CAL 46.55' -seal paned 5252008 3030 where it sees plugged into 5-ther (see avached dravnng) 10,271.0 fi2306 4550 PER Baker GBH -22 111161199 3000 6 3Y SCAB LINER: 5.1631 10,3210 %2662 43.82 SHOE MULESHOE-has 4.4" D, Causing lip at the top Of FISH 11118/19 4000 o.m a 6 REAL Asst'; 10'103.0 10684.0 5534.] 41.64 WHIPSTOCK Set Begin shiDstoCk on Big (CDR -3)2186' OAL. Seth 4 2019 0 delta (high side) 10]4]0 6,5819 4145 WHIPSTOCK BAKER GEN II TTRW, ORIENTED 15 DEGREESLEFT 5,112099 2SM OF HIGH SIDE, ITT GAL 10,]80.0 6,fi0fi.fi 41.36 FISH 118'Baker lBPinSleas rated psi; fiSol 4/202088 0.000 33e'CTB .. 10.D7o PRotwcnox; ffiz10,46xe neck may neck 1.3]5" GD; SSIJBU release pull - moved 1010)80 CTMO612lAI8 Perforations & Slots Shot ceps FRAC;10.Y0.0 RPERF:10..,e a ]DIl;4 PERP:10.6I66r 0na0 TOP(MB) BM(MB) Top o UND (MB)) Bun o ( 0 l IAkM Zone Dat (a,a Type Com 10,6600 10,6)00 6,5168 6,524. C4, IC -11 91912008 80 RPERF YH D 5 HJ, Deg WNIPRTOCK 100 211836 10,fi700 107160 %524.3 6,550.7 C4, 63, 1C-11 1114/199] 201PERF arde9. Phasing; I" Enerjet Frac Summary LINER IC-11Lt@10.]226 SWR Dare p,ppinnt Oeaderea10) eroppanNn Farmationfle) 13030.0 6202008 A.PopOCK 10.7470 WINWWL1L3, 10,7EEP 10.7sro B LMk So '"Pedtm vacken(t1) voltuny(beH m (M l Ye g tl Riad OaM TOp pepal(MBI 77716,S' 1 61202008 106600 10,71fi0 Mandrel Inserts FISN:10]tq.0 at aN p Top(1VDl YAM ta1Ca POd SMe TRORun Top(RKB) (MBl Mne MMN Calls Se,v Type Type (in) (psg Run DAM Co. 3.193.9 2,472.6 Camco KING i Gas Lie GLV BK 0.188 12]].0 3117 1 2 4,217.4 2,992.9 Cameo KBMG1 Gas Litt OV BK 0250 00 3'17201 HA meo DMY BK 0000 00 Ext 3 5.117.5 3,6)1.6 CaKBMG 1 Gas IlViShIng I Pkg Notes: General & Safety End DoM Ann.. 41"32008 NOTE. SWS LDL INDICATES IBP @ 10, 385 LEAKING FROM BELOW 1 LINER; 10.319.611,3W0 KUP PROD WELLNAME IC -11 WELLBORE 1C-11 ConocoPhillips Alaska, Inc. 1o11.—I-1221,1 PM Notes: General & Safety Vw VAnuK (3-1) End II Mnolalbn .____. .. ........ ......... 512612008 NOTE. HOLE IN ]" CASING @ 5466 MD HANGER, w.] 6/812000 NOTE-. NEW 3.5"TBG INSERTED INTO 3.5" SCAB LINER @102]2' ..................................--- ---6/1612008 NOTE'. VIEW SCHEMATIC wl Alaska Schemalicg.OREV 111512008 NOTE. Recovered severely ereded OV @ 5117', GLM likely damageel ]126120 NOTE: MULTI LATERAL 1C-11, IC -11 L1, 1C-11 L1-01, 1C-11 L1-02 (OFF MAIN WELLBORE) CONWCTOR-, 4161210 SAFETVV10V;2.2974 QiS LIFT; 3,18}B Gas LIFT, a 21.4 Gas um s lees LCCATOR:41mz SE Eima BIIRFACE;42M.9,52— IINER 1.11 NS. 10237b IO16B0 3SSCABLINER;5.1630- 0.211.0 SEAL ABSr; 10,MO 2310' CTO LINER; IOD].o PRODUCTION SO -10,408 RPERP 10,assr, S6]0.0 FRAC; 10.6900 (PERF; 10.0)0.610,]180 WKIPOTOCK; 1(%F`wo LINER 1C-11 L1$10)2'[.a 15.N30 WHIPSTOCK 10]4]0 wINOJ'N L1V 10,]50.6 10mo FISH 10]0.0 LINER, 10,MR 11.31CO KUP PROD WELLNAME 1C-11 WELLBORE 1C -11L2 [—j�� ps9Q[NKLJGPAR AttribuG Max Angla,r 1 TD C—" "''I't -ame WNIMeeAPNRN W lleoleShcui MQIM1 B IXXB) Alaska. IncLIK RIVER UNIT 5002922]1463 PROD 1094 1284367 ID.00 m -n¢, EEMNNI1zm 111'M Frac Summary v.multlwrah lace W) 5larcoah pwpMloeagretlpbl Pmppem In Fwmemn pel syr 741 i sun wy srzazooe rpP OepM plNe) snn ln2a) 1ssw.o 1a,nso Lmx to Fww syarem vol clualws volswr�y lebp RANGER. W., CONOVCTORI a1.121.o SAFEIVVLV,ZW4 WSIIFT; 3,1R39 wsLE rT;4mza .0G :EJM2 sFwL:5lrz.s suxvac E: 42se.ea52� LINER IC-liL ,,1QZf].6 ie,15&0 35-MAE LINER; 5,181} f O.Zl10 MAL AMY, 10.260 2 W CTD LINER; to,wo PRODUCTION: M D%,NS8 RPERF: I0.RB lIXEM0 FRAC:1QBb0 PERF: 10$ 10.0.10.0 LINER: 103R = 0.11,3N. Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth start Time End Time D" (hr) phase Op Code Activity Cade Time p -T -X Operation (Po®) End Depth(flt(6) 3/26/2019 3/2612019 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 landings, secure BOP's, Complete RD checklist 3/26/2019 3/27/2019 2.50 MIRU MOVE MOB P PJSM, Pull utility module away from 0.0 0.0 21:30 00:00 rig 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 1Q for changeoul, walkaround 0.0 0.0 05:30 06:30 3/27/2019 3/27/2019 3.25 MIRU MOVE MOB P Continue move to 1C 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 dg 3127/2019 3127/2019 2.25 MIRU MOVE MOB P Spot sub & pits over well, lay mats, 0.0 0.0 10:45 13:00 drop stairs 3127/2019 3/2712019 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 3/27/2019 327/2019 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 3/272019 3/272019 2.50 MIRU WHDBOP RURD P Complete rig up check list, Air test TT 0.0 0.0 18:00 20:30 line, Obtain RKB Measurments, Service tree and stack, Valve crew here. Prep for BOPE test 327/2019 3/27/2019 1.00 MIRU WHDBOP BOPE P PJSM, Fill stack and bleed Eire out of 0.0 70- 20:30 21:30 system. Shell test BOPE, Swap out 0- I Ring on riser 3/272019 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 3/282019 328/2019 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 3/28/2019 1.00 SLOT WELLPR RURD P PJSM, Rig down BOPE lest 0.0 0.0 03:00 04:00 equipment. PT PDL's TT line 3282019 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 328/2019 3/28/2019 2.75 SLOT WELLPR PULD P WU PD, BHA #1, fishing assembly 0.0 68.5 04:45 07:30 328/2019 3282019 0.50 SLOT WELLPR PULD P Surface test Coil (good -test), Tag up 68.5 68.5 07:30 08:00 reset counters 328/2019 3/282019 2.00 SLOT WELLPR TRIP P RIH 68.5 9,745.0 08:00 10:00 3/282019 3128/2019 0.30 SLOT WELLPR DLOG P Log formation correction of plus 3.5' 9,745.0 9,779.0 10:00 10:18 3/282019 3/28/2019 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 1135 ReportPrinted: 513/2019 Summary (with Timelog Depths) 1c-11 lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth SM Time End Time Dur (hr) Phase Op Code Activity Cafe Time P -T -X Operd im ME) End Depth (Wfl) 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 3/28/2019 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 1433 16:18 1 1 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 3/2812019 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 3/2812019 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 PUW 30 k, straight pull to 70 k 3/28/2019 3/28/2019 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 3/28/2019 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 3/28/2019 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 3128/2019 0.20 SLOT WELLPR OTHR P Pull fish harder, DHWOB=-7K. Annualr 10,245.0 10,245.0 19:24 19:36 1 2883, Bore 2924, WHP=41 3/28/2019 3128/2019 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 3/28/2019 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 3/28/2019 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. 3/28/2019 3/28/2019 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 3/29/2019 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 3/29/2019 1.60 SLOT WELLPR TRIP P POOH pumping 9.0 down CT 10,200.0 90.0 00:00 01:36 3/29/2019 3/29/2019 0.90 SLOT WELLPR OWFF P At surface, Flow check well. Fluid 90.0 90.0 01:36 02:30 coming out of whiy valve. Open up choke and blow down to pits. No flow for 12 minutes then started. 3/29/2019 3/29/2019 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 3/29/2019 1.50 SLOT WELLPR ELNE P Shift to running a -line with lubricator. 0.0 0.0 03:30 05:00 Rigging up a -line grease head 3/29/2019 3/29/2019 0.60 SLOT WELLPR ELNE P PJSM, with Pallard & Rig crew for e- 0.0 0.0 05:00 05:36 line ops, crew change Page 2135 ReportPrinted: 513/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Tme P-T-X Operation (flKa) End Depth MKS) 3/29/2019 3/29/2019 3.00 SLOT WELLPR ELNE P RU a-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 cul depth, looks to be clean. fire string shot 10,713'- 10,725'. 3129/2019 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 culler 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/Spectre2 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 0.0 13:21 13:45 RIH, log across seal bore and 15 joints. fire cutter on depth 10,722'. PUH free, RBIH past cut depth, lemporily detained, RBIH, PUH wlincreased speed, Pull free 3/29/2019 3/29/2019 1.00 SLOT WELLPR ELNE P POOH 0.0 0.0 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 1 equipment, RD e-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 fiat spots at 10' and 15', Prep coil and cut 20 3/29/2019 3/29/2019 0.80 SLOT WELLPR CTOP P Prep CT, Install CT connector. Pull test 0.0 0.0 16:27 17:15 135K 3/29/2019 3/29/2019 1.00 SLOT WELLPR CTOP P Head up BHI UQC / lest wire - Good. 0.0 0.0 17:15 18:15 Pressure test LOC 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 Acceloralor, 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 Kt 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 upon fish 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 3/30/2019 0.30 SLOT WELLPR CIRC P Continue circulating with open EDC 10,211.0 10,211.0 00:00 00:18 Page 3135 Report Printed: 51312019 Operations Summary (with Timelog Depths) 1c-11 s Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log stmt Depm Start Time End Time Dur (hd Phase OD cote Activity Code Time P-T-X Operation (WB) End Depen tf KB) 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 02:06 03:54 3/30/2019 3130/2019 1.50 SLOT WELLPR PULD P Tag up and space out, PJSM. PUD 72.0 0.0 03:54 05:24 1 1 BHA#2 3/30/2019 3/30/2019 1.50 SLOT WELLPR ELNE P Prep rig floor for aline ops, standby for 0.0 0.0 05:24 06:54 SLB eline travel to rig 3130/2019 3/30/2019 0.75 SLOT WELLPR ELNE P SLB on location, PJSM, spot in unit 0.0 0.0 06:54 07:39 3/30/2019 3/30/2019 0.30 SLOT WELLPR ELNE P PJSM with dg 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 K1. 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 20:45 21:51 down chem cutter. Swap out to 13/8" toolstring for logging ops 3/30/2019 3/30/2019 0.50 SLOT WELLPR ELNE P PIU Next e-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 22:21 00:00 logging tools 3/31/2019 3131/2019 1.30 SLOT WELLPR ELNE P Continue tripping out with a line 0.0 0.0 00:00 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 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 04:33 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 05:15 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 05:30 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 07:18 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 08:03 08:30 meg/ohms, >2000) 3/31/2019 3/312019 0.25 SLOT WELLPR CTOP P PT re-head 4,500 psi 0.0 0.0 08:30 08:45 3/31/2019 3/3112019 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 3131/2019 3/31/2019 0.30 SLOT WELLPR PULD P Slab INJH, surface test BHI CoilTrak 0.0 81.3 10:15 10:33 tools (good-test) 3/31/2019 3/31/2019 1.75 SLOT WELLPR TRIP P RIH 81.3 9,760.0 10:33 12:18 1 Page 4135 Report Printed: 51312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sfarl Depth SrmtTne End Time Dur (hr) Phase OP Code Activity Code Trrie P -T-% operation (N(6) EM Depth (N(8) 3/31/2019 3/3172019 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 12:48 13:18 3,100 psi, Diff=16 psi, WHP=36, BHP 3,651, IA=114, OA=27 3/31/2019 3/3112019 0.50 SLOT WELLPR PRTS 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/WHP=235/6148.28' TVD, PUW 37 k 3/31/2019 3/31/2019 0.60 SLOT WELLPR JAR P RIH latch fish @ 10,235', jar down x1, 10,200.0 10,240.0 13:48 1424 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 0.10 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 3/31/2019 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 3/31/2019 3/31/2019 1.80 SLOT WELLPR TRIP P POOH 10,225.0 76.0 17:42 19:30 3/31/2019 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 UQC. 0.0 0.0 20:36 21:24 Boot wire. Stab on well. Perform slack mgmt 3/31/2019 3/31/2019 1.10 SLOT WELLPR CTOP P Unstab injecor. P/U hydraulic tubing 0.0 0.0 21:24 22:30 cutter. Trim CT for fafigue mgmt. Find e -line @ 38'. Trim 1 00'total 3/31/2019 3/3112019 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 4/112019 0.90 SLOT WELLPR CTOP P Complete reheading UQC. PT 0.0 0.0 00:00 00:54 connector to 4300 PSI 4/1/2019 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 4/112019 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 4/1/2019 4/1/2019 0.10 SLOT WELLPR DLOG P Log k1 for 4.5' correction, Close EDC 9,760.0 9,791.0 03:54 04:00 4/1/2019 4/1/2019 0.10 SLOT WELLPR TRIP P Continue in well 9,791.0 10,220.0 04:00 04:06 4/1/2019 4/112019 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. Pain/ red flag @ 51K PUW. Line up to pump down backside. Go up to 1100 PSI WHP. 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 0.50 SLOT WELLPR PULLP Continue jadng total of 30 cycles @ 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 5135 ReportPrinted: 5/3/2019 Operations Summary (with Timelog Depths) _I. 1C-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth SM rime End Time Wr(h 0 Phase OP Code Adlviy Cotla Tim P -T-% Operatlon (NCB) Ertl oepN (NCB) 4/112019 4/1/2019 0.50 SLOT WELLPR PULL P Continue working fish towards surface 10,195.0 9,753.0 07:36 08:06 75 k Q 3-5 fpm, notice weight change 10,145', continue pulling up to 9,975', 15-30 fpm, fish is pulling free 4/1/2019 4/1/2019 3.75 SLOT WELLPR PULL P Park with fish, discuss with town team, 9,753.0 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 4/1/2019 4/1/2019 1.20 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 bbls, , shut down and Gose EDC, slowly PUH circulating 0.25 bpm 2 bbls, 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 k, 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. 4/1/2019 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 1 1 check, well still flowing, 4/1/2019 4/1/2019 0.30 SLOT WELLPR PULL P RBIH to tag (d) 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 4/1/2019 2.00 SLOT WELLPR TRIP P Close EDC, pump 2 bbls down the 9,713.0 557.2 18:00 20:00 coil, shutdown, open EDC, cirolulate 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 4/1/2019 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 cenlrilizers. 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 lest 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 03:42 fluid slowly recip up hole 4/212019 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 Q 10,276 Page 6/36 ReportPrinted: 5/3/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Deplh SW rime End Time DW (hr) Pheee Op code Acdvq Code Time PJA Operation (BNB) End Depth (11M) 412/2019 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. Paraffin coming across shaker at first bottoms up 4/2/2019 4/212019 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 1 1 bottoms up 4/212019 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 4/212019 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 4/2/2019 2.80 SLOT WELLPR TRIP P Trip out of well 10,444.0 46.0 08:24 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 412/2019 4/2/2019 1.30 SLOT WELLPR SLKL P Move in I spot up slickline unit 0.0 0.0 12:24 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 13:42 16:06 control equipment on rig floor 4/212019 4/2/2019 1.90 SLOT WELLPR SLKL P PT slick line lubricator to 2500 PSI - 0.0 0.0 16:06 18:00 RIH with 2.47 LIB, POOH after lagging @ 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 Picules on S: Drive, confer w/ SL supervisor & town, decision made to Ito run non -retrievable spear. 4/212019 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 tan 1-1/2" braided line brush "Test non -retrievable spear on 4' piece of liner at surface to ensure engagmem is possible, engages as designed 4/212019 4/2/2019 0.70 SLOT WELLPR SLKL P MU braided line brush 0.0 0.0 21:36 22:18 4/2/2019 4/212019 0.20 SLOT WELLPR SLKL P PU braided line brush, stab on 0.0 0.0 22:18 22:30 lubricator, PT 4/2/2019 4/212019 1.20 SLOT WELLPR SLKL P RIH w/ braided line brush, run tool into 0.0 0.0 22:30 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 23:42 00:00 spear) 41312019 4/3/2019 0.10 SLOT WELLPR SLKL P Complete POOH 0.0 0.0 00:00 00:06 4/3/2019 4/3/2019 0.20 SLOT WELLPR SLKL P 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 ReportPrinted: 5/3/2019 Operations Summary (with Timelog Depths) IC -11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Tune End Tune Dur(hr) Phase Op Code mt%ty Code Time P -T -x Operetlon (1110) End Depth (MB) 4/3/2019 4/3/2019 1.30 SLOT WELLPR SLKL P PU non -retrievable spear, PT, RIH, 0.0 0.0 00:1801:36 latched into fish, jarred up -25 times, sheared off spear (GR), no movement of fish 413/2019 413/2019 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 BHA with weight 0.0 67.0 06:24 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 09:36 413/2019 4/3/2019 0.10 SLOT WELLPR DLOG P Log Gamma tie in for -3' 9,745.0 9,770.0 09:36 09:42 4/3/2019 4/312019 0.10 SLOT WELLPR TRIP P Continue in well, Close EDC @ 10225 9,770.0 10,441.0 09:42 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 09:48 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 4/312019 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 14:36 15:36 down. Remove spear from fish 4/3/2019 4/3/2019 1.40 SLOT WELLPR PULD P PJSM. PIU 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 17:00 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 18:54 20:30 1.85 bpm, FS = 290 psi, circ = 3656 psi, WHP = 20 psi, significant asphaltenes over shaker, pump 5x5 sweeps, laking biles & 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: 5/3/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depen Start Time End Time our (hr) Phase Op Code AcOviy Code Time P -T -X OR== (WS) End Depen (flKB) 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, asphaltenes 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 SLOT WELLPR CIRC P Begin circulating 100 bbl of 180° 10,690.0 10,690.0 22:12 00:00 diesel (1.5 bpm) 4/4/2019 4/4/2019 0.30 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 2.00 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 1.40 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 0.70 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. Unslab 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 BOPE P Start full BOPE test, perform draw- 0.0 0.0 12:00 18:00 down test, test IRV. Test witness waived by Matt Herrara, AOGCC, " 250 low / 3500 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 4correction, close EDC, 10,435.0 10,474.0 22:00 22:06 PUW = 35K 4/4/2019 4/4/2019 0.20 SLOT WELLPR TRIP P Continue RIH, RIW = 12.21< 10,474.0 10,660.0 22:06 22:18 Page 9/35 ReportPrimed: 51312019 Operations Summary (with Timelog Depths) 1c-11 s Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Sten Tune EM Time Dur (hr) Phase Op Cade Activity Code Time P -T -X Operation (MB) End Depth (ftl(e) 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 4/512019 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 4/512019 4/512019 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 415/2019 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 41512019 4/5/2019 0.90 SLOT WELLPR PULD P M1U 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 4/512019 0.30 SLOT WELLPR DLOG P 10,704'. Open caliper arms. Log 10,704.0 10,148.0 1000 10:18 uphole. Close caliper arms 4/5/2019 4IM019 1.70- SLOT WELLPR TRIP P Trip out of well 10,148.0 22.0 10:18 12:00 4/5/2019 4/5/2019 0.50 SLOT WELLPR PULD P PJSM. Pull BHA #10 from well 22.0 0.0 1200 12:30 4/5/2019 4/512019 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 415/2019 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. 41512019 4/5/2019 1.70 SLOT WELLPR TRIP P RIH BHA#11, EDC open. Pumping 66.0 9,730.0 15:00 16:42 1 1 min rate 4/5/2019 4/5/2019 0.10 SLOT WELLPR DLOG P Log gamma tie in for 4.5 9,730.0 9,770.0 16:42 16:48 4/5/2019 4/5/2019 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 Summary (with Timelog Depths) 1c-11 lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tine End Tme our (hr) Phase Op code Activity Code Time P -T -x Openskm Pth S (flK13)) End Depth (N(B) 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 @ 10,6681, PUW = 37K 4/5/2019 4/5/2019 0.30 SLOT WELLPR UREM P Back -ream 10,68010 10,600'(5 fpm), 10,680.0 10,600.0 20:42 21:00 PUW = 37K 4/6/2019 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 4/6/2019 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 4/6/2019 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, tag up, set counters 4/6/2019 4/6/2019 1.80 PROD1 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 4/6/2019 0.20 PROD1 RPEQPT TRIP P Continue RIH, arrive at setting depth, 10,476.0 10,697.0 04:54 05:06 PUW = 35K, close 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.5'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 tag @10688. 10,477.0 10,688.0 11:24 11:36 1 1 PUH 4/6/2019 4/6/2019 4.20 PROD1 WHPST WPST P PUH bring pump on 1.9 BPM @ 4024 10,688.0 10,692.8 11:36 15:48 PSI FS, BHP=3668, Ease onto tray call pinch point 10,688.5. 4/6/2019 4/6/2019 2.20 PROD1 WHPST WPST P DHWOB fall off. Call bottom of 10,692.8 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 10,695.8 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 11136 - ReportPrinted: 5/312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start DepN Stmt Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Opemtlon (IHfB) End Depth (WB) 4/6/2019 4/6/2019 1.80 PRODt 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 TO of rat -hole, pump sweeps, PUW = 36K 416/2019 4/6/2019 1.90 PROD1 WHPST TRIP P Open EDC, POOH w/ BHA#13, PJSM 10,711.0 75.0 20:42 22:36 4/6/2019 4/612019 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 41712019 0.40 PROD1 DRILL PULD P Begin PD BHA#14 Buildrrurn 0.0 72.0 23:36 00:00 Assembly (2.2° AKO motor, RS Dynamus bit) 4/712019 47/2019 0.70 PRODt DRILL PULD P Complete PD BHA#14 Buildf rum 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 41712019 4/712019 2.20 PROD1 DRILL TRIP P RIH w/ BHA #14 72.0 10,425.0 00:42 02:54 4/7/2019 4/712019 0.20 PROD1 DRILL DLOG P Log K1 for -4' correction, Gose EDC, 10,425.0 10,463.0 02:54 03:06 1 1 PUW = 35K 477/2019 41712019 0.10 PROD1 DRILL TRIP P Cotninue RIH 10,463.0 10,711.0 03:06 03:12 4/712019 417/2019 1.20 PROD1 DRILL DRLG P Drilling, FS = 535 psi @ 1.9 bpm, 10,711.0 10,855-0- 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' 477/2019 417/2019 0.20 PROD1 DRILL TRIP P PUH to log K1 & RA, PUW = 38K 10,805.0 10,425.0 04:24 04:36 4/712019 41712019 0.40 PROD1 DRILL DLOG P Log K1 for O'coni 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' 477/2019 417/2019 1.80 PROD1 DRILL TRIP P POOH, PUW=37K 10,725.0 67.0 05:00 06:48 477/2019 41712019 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 4/7/2019 0.80 PROD1 DRILL OTHR P M/U N=le. Stab on well. Jet stack. 0.0 0.0 08:06 08:54 Flush micro motion. Pull off well. Change out floats in UOC 4/72019 4/7/2019 1.20 PRODt 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 bicenler. Make up to coil and surface test 4/7/2019 4772019 2.10 PROD1 DRILL TRIP P RIH, Shallow lest agitator @ 300'. 78.2 10,445.0 1006 12:12 Continue in well 4/7/2019 4172019 0.10 PROD1 DRILL DLOG P Log K1 for -4.5', Close EDC, 10,445.0 10,464.0 12:12 12:18 PUW=36K 4/7/2019 4172019 0.20 PROD1 DRILL TRIP P Continue in well, Clean pass through 10,464.0 10,803.0 12:18 12:30 1 window 4/7/2019 4172019 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' 4/72019 417/2019 0.10 PROD1 DRILL WPRT P Pull BHA wiper, PUW=35K. 10,864.0 10,864.0 13:18 13:24 4/7/2019 477/2019 1.90 PROD1 DRILL DRLG New mud around, 1.9 BPM @ 10,864.0 11,000.0 13:24 15:18 17 4634PSI FS, BHP=3807. RIW=10.5K, DHWOB=I.5K Page 12/35 Report Printed: 5/312019 Operations Summary (with Timelog Depths) 113-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth startTime End Time Dur(hr) Phase Op Code Activity Code Tane P -T -X Operation (ftKB) End Depth(/tl(B) 4/7/2019 47/2019 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 4/72019 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 PRODt DRILL WPRT P Wiper in-hole, RIW = 13K 10,813.0 11,205.0 17:54 18:06 4/7/2019 4/7/2019 1.70 PROD1 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, WHP = 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 4/72019 1.50 PROM DRILL DRLG P Continue drilling from 11,290, CWT= 11,290.0 11,370.0 1948 21:18 8.1 K. WOB = 2.85K, annular = 3855 psi, WHP = 119 psi, pumps 5x5 sweeps, 100'wiperfrom 11,357', PUW = 39K, PUW = 45K from 11,370', avg ROP = 53 fph Holding -87° Inc in attempt to acquire the Cl prior to Fault 1 crossing (per geology) 4/7/2019 4/7/2019 1.70 PRODt 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, WHP = 78 psi, PU's as required, avg ROP = 71 fph 4/7/2019 4/82019 1.00 PROD1 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 PROD1 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 PROM 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 PROD1 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 get through & bring back up quickly, RIW = 9.9K 4/812019 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= 10.21K, WOB = 1.31K, annular= 3892 psi, WHP = 20 psi Confer w/ town geology, decision made drop to 84° Inc (target deeper in Cl 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 PROD1 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: 5/312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op code Activity Code Time P -T -x Operation (ftKB) End Depth (WS) 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 0736 0848 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 PROD1 DRILL DRLG P .12,006', Drill 1.9 BPM @ 4742 PSI 12,006.0 12,400.0 06:48 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 PROD1 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 rate, Continue to bottom at full rate 4/8/2019 4/8/2019 0.50 PROD1 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 PROD1 DRILL DRLG P 12450'. Increase inclination to 100° 12,450.0 12,628.0 14:54 17:36 tum up to cross cut. 1.84 BPM @ 4722 PSI FS, BHP=3954, 4/8/2019 4/8/2019 0.70 PRODt DRILL WPRT P Pull wiper to 12,400. Staking, 12,628.0 12,628.0 17:36 18:18 PUW=53K 4/812019 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 PRODi DRILL DRLG P 12795', Drill, 1.84 BPM @ 4810 PSI 12,795.0 12,822.0 22:12 22:48 FS, BHP=3978 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 wl 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 cased hole, PJSM, pre -load DS PDL 4/9/2019 4/9/2019 1.00 PROD1 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 njector 4/9/2019 4/912019 2.00 PROD2 STK PULD P PU/PD BHA#16 OH Anchored Billet, 0.0 72.0 04:30 06:30 failed checks, PUD, R redeploy, check pack -offs `* Crew chage 4/9/2019 4/9/2019 2.10 PROD2 STK TRIP P RIHw/BHA#16 72.0 10,445.0 06:30 08:36 1 4/9/2019 4/9/2019 0.40 PROD2 STK DLOG P Log K1 for +1 5'correction, clean 10,445.0 10,495.0 08:36 09:00 1 counter wheel, PUW = 37K Page 14135 Report Printed: 5/312019 i Operations Summary (with Timelog Depths) IC-11 lip Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depth Stan Time End Time our (hr) Prase Op Code Activity Code Tuna P-T-% Operation (n(e) End Depth (111(8) 4/9/2019 419/2019 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 419/2019 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 4/9/2019 4/9/2019 0.40 PROD2 STK BOPE 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 1300 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 14:18 16:30 bpm, pump = 4650, FS = 1203 psi (verify on transducer) 4/9/2019 4/9/2019 0.10 PROD2 STK DLOG P Log K1 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 16:36 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 17:00 18:12 1 1 11242 psi @ 1.9 bpm, lfph 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 18:12 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 18:36 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, WOB 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 20:24 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. 419/2019 4/9/2019 0.10 PROD2 DRILL WPRT P RBIH, CT Wt 10 k Ibs, billet dean. 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 20:42 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 lbs, 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 4110/2019 4/10/2019 0.30 PROD2 DRILL DRLG P OBD- 11,422.0 11,450.0 00:00 00:18 4/1012019 4/10/2019 0.10 PROD2 DRILL WPRT P PU Wt 42 k lbs Wiper # 1 to just below 11,450.0 11,112.0 00:18 00:24 the billet Page 15135 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 EM Time our (hr) Phase op co" Activity Code Time P -T -X Operation O KB) EM Depth (N(B) 4/10/2019 4/10/2019 0.20 PROD2 DRILL WPRT P RBIH, RIH Wt 8.8 k lbs - Wellworc 11,112.0 11,450.0 00:24 00:36 estimates 0.2 bbls cuttings returned. 4/10/2019 4/10/2019 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 IDS, 11,545' PU - 45 k lbs 11,646' PU - 43 k lbs free spin 1313 psi 11,667' PU - 42 k lbs 11,720' PU - 43 k lbs Pump sweeps 4/10/2019 4/10/2019 0.30 PROD1 DRILL WPRT P Wiper up -hole, PUW = 43K, dean 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, PINY = 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 4110/2019 4/10/2019 2.00 PROD2 DRILL DRLG P Drilling, CWT= 5.5K, WOB = 2K, 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 iph 1 00'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 4/1012019 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, clean 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 Q 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 Whir 4/10/2019 4/10/2019 1.10 PROD2 DRILL DRLG P PU post crew change, CT Wt 62 k Ilbs, 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, OA42 psi CT Wt 6 it to -5 k lbs, WOB -1.8 klbs, More and more frequent pick ups, CT Wt - 55-60 k lbs Average ROP over section - 69 ft/hr Page 16135 Report Printed: 51312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stott Tam End Time D r (hr) Phase Op code Activity Code Time P -T -x Cperaaon (NCB) End Depth (fll(B) 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 4/1012019 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 4/1012019 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 timing 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 4/10/2019 0.50 PROD2 DRILL WPRT P PU Wt 50klbe-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' -Hol 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 2300 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 Wt to-5klb5, 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 Wt5to-5klbs, WOB 1.2 to 0.3k 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, Ct Wt 7 k lbs, WOB 3 k lbs Average ROP over section - 15 ft/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, WHIP = 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 1 annular= 3942 psi, WHP= 104 psi 4111/2019 4111/2019 0.30 PROD2 DRILL WPRT P Wiper up -hole, PUW = 43, clean 13,050.0 12,250.0 12:48 13:06 Page 17136 Report Printed: 5/3/2019 . Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Mme Dur (hr) Phu. D code P Ad Code h Time P.T.X o peraEon shut sten Depth De End Depth (flKe) 4/11/2019 4/11/2019 0.30 PROD2 DRILL WPRT P Wiper in-hole, RIH = 6.8K, 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, WHP = 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 4111/2019 4/11/2019 2.10 PROD2 DRILL DRLG P Driling, CWT= 1.6K, WOB = 1.8K, 13,200.0 13,310.0 16:24 18:30 annular = 3961 psi, WHP = 82 psi avg ROP = 52 fph 4/112019 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 - 3klbs 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 4/1212019 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 4/122019 12.00 PROD2 DRILL WAIT T Wafting 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 18135 ReportPrinted: 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 Da(hr) Phase Op cede AcU yCode Time P -T -x Operation (ftKB) End Depth(fil(B) 4/12/2019 4/13/2019 6.00 PROD2 DRILL WAIT T Convoy crew change @ 19:30. 0.0 0.0 18:00 00:00 PJSM, unstab 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. Waiting on weather, pumping mangaged pressure, 4/13/2019 4/13/2019 4.50 PROD2 DRILL WAIT T Waiting 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 PROM DRILL TRIP P RIH w/ BHA#18, shallow lest agitator, 68.0 10,435.0 06:00 08:06 1.87 bpm, dp = 1265 psi, pump = 5181 psi Many various alarms on HMI, park at 91 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 08:16 08:36 psi SBHP: MD = 10,676 psi, annular = 3677 psi, TVD sensor = 6492, 10.9 ppg EMW (stopped once hitting 10.9 ppg) 4113/2019 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 wiindow, dropping as mud shears, cheesing over shakers), 4/13/2019 4/13/2019 1.00 PROM 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 4/13/2019 0.60 PRI 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 19135 ReportPrinted: 51312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log stan7me EM Tana our (hr) Phase Op Code Ad yCove Time P -T -X Operation Stan Depth (Po(B) End Depth(tIKB) 4/13/2019 4113/2019 0.40 PROD2 DRILL DRLG T Unable to PU off bottom, differentially 13,558.0 13,558.0 12:36 13:00 stuck, work pipe, pull to 70K+ multiple times, pull free @ 79.5K 4/1312019 4/13/2019 0.30 PROD2 DRILL WPRT P Wiper up -hole, load LVF 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 oontiinues to drop (.85 bpm), 61 K PUW from 13,623', 68K PUW from 13,626', pumped 5x5 sweeps, difficulty drilling, stacking weight 4/13/2019 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 4/13/2019 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, mistral 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 W154 k lbs, wiper trip 13,894.0 1,349.0 15:48 19:00 4/13/2019 4/1312019 0.20 PROD2 DRILL WPRT P RBIH 1,349.0 13,984.0 19:00 19:12 4/13/2019 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, WOS 2.8 klbs. •. Drilled out the top into Kuparuk D, average 165 API, max 180. 4/14/2019 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 4/1412019 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 fl/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 fUhr, 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 transitio(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 20/35 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) IC -11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Time EMTme our h (d Phase Op Catle Activity Code Time P -T -X Oparatlon Start Depth (ItKB) EM Depth (flKB) 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 rale 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 Q 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 fph 4/14/2019 4/14/2019 1.80 PROD2 DRILL DRLG P Drilling, CWT =$K, 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, 4114/2019 4/14/2019 0.50 PROD2 DRILL DRLG P Drilling, CWT= -8K, WOB=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 4/14/2019 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 PROD2 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 Keen 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' 4/1412019 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', tum into BHA wiper Average ROP over interval drilled - 477hr Page 21135 Report Printed: 5/312019 Operations Summary (with Timelog Depths) 1c-11 li p Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SmnTune Eno Time our (hr) Phase op Code Activky Cade Tme P -T -X operation smn oepm (flKB) End Dept, (MB) 4/14/2019 4/14/2019 0.40 PROD2 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 - 47.57hr 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. Ct 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 - 37'/hr 4/15/2019 4/15/2019 2.20 PROD2 DRILL WPRT P PU W147 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 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 4/15/2019 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 4/15/2019 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 0.5K, 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: 513/2019 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 Operation (RKB) End Depth(MB) 4/15/2019 4/15/2019 0.60 PROD2 DRILL TRIP P Wiper in-hole, struggl to bottom, 14,555.0 15,380.0 1506 1542 squatting up to -10K CWT, PU, continue in-hole, reduce rale to .75 bpm to reach bottom 4/15/2019 4/1512019 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 W PRT P Continue out of hole, tag up, reset 137.0 78.0 00:00 00:12 1 1 1counters. 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 4/16/2019 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 tmin 3748 11.13 2min 3695 10.98 3min 3634 10.79 5 min 3606 10.71 4/16/2019 4/16/2019 3.80 PROD2 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 14,204', PU 45 k lbs, continue in hole, reduce RIH speed to 25 ft/min @ 14518, reduce running speed to 14 ft/min @ 14,740'. 8 ft/min @ 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 4/16/2019 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 PUTB P Prep floor for running liner. 0.0 0.0 11:00 11:24 4/16/2019 4/16/2019 1.90 COMPZ2 CASING PUTB P PU / MU jointed pipe, L2-01 first run, 0.0 1,212.0 11:24 13:18 40 joints with a solid bullnose under a shorty deployment sleeve. (Liner 1212.44' LOA 1213.69') Page 23/35 Report Printed: 51312019 Operations Summary (with Timelog Depths) IC -111 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stmt Time End Time Dur (hn Phase Op Cotle Activity Cotle Time PJA Operation Stan Depth (nKB) End Depth (RKB) 4/16/2019 4/16/2019 0.70 COMPZ2 CASING PULD P PJSM, PU BHA#19, 1-2-01 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 1-2-011 liner. Tie into flag for - 1,265.0 15,462.0 14:00 18:06 10.68'. PU Wt 38 k WOB -6 k lbs. Contiune in hole, drive by the K1, + 6'. No correction made. Continue in hole SID 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 COMP7-2 CASING TRIP P POOH, while laying in beaded LRP 14,457.0 10,670.0 18:57 2027 4/16/2019 4/16/2019 1.90 COMPZ2 CASING TRIP P Pull through the window, continue 10,670.0 44.2 20:27 2221 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 PUTB 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 4/17/2019 4/17/2019 3.30 COMPZ2 CASING PUTS 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 112-01 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 12-011 competion. 3,497.0 10,599.0 05:42 07:12 4/17/2019 4/17/2019 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 lbs 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. 4/17/2019. 4/17/2019 1.50 PROD3 STK CTOP P Prep RF for testing operations, grease 0.0 0.0 17:57 19:27 crew on location service tree valves and tango's. 4/17/2019 4.55 PROD3 STK BOPE Start bi-weekly BOPE test, low 250 0.0 0.0 14/18/2019 19:27 00:00 psUHigh 3,500 psi, Annular 2,500 psi, IP witness waived by AOGCC (Adam Earl) Page 24135 ReportPrinted: 5/3/2019 AdIMML . Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log 5 D Start Time End Tune Our (hr) Phase Op Code Acini Cod. dY Time P -T-% Operation (flK8)pin EM DepN (flKB) 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 psi/High 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 Mangemenl (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 4/18/2019 4/1812019 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 Ki for a -3.5' 10,435.0 10,468.0 08:18 08:30 4/18/2019 4/1812019 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, Coss EDC, PU Wt 35k lbs. 4/1812019 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 Itis 4/18/2019 4/18/2019 0.20 PROD3 STK KOST P Set rate, 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, 4118/2019 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 4/1812019 4/18/2019 0.60 PROD3 STK KOST P Increase ROP to 2 ft/hr 10,742.4 10,744.6 10:54 11:30 4118/2019 4/1812019 0.10 PROD3 STK KOST P Increase ROP to 3 ft/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 Ibs - 50 ft/hr 4/18/2019 4/1812019 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 ft/hr 4/18/2019 4/18/2019 0.20 PROD3 DRILL WPRT P PU Wt 39 k Itis, PUH for dry drift. 10,800.0 10,800.0 12:30 12:42 RBIH Window clean 4118/2019 4/16/2019 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 25135 Report Printed: 51312019 Operations Summary (with Timelog Depths) 1c-11 s Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log stair Depth start Time EtMTime Dur(hn Phase Op Code Acdvily CoEe Time P -T -X Oper = (MB) End Depth (W13) 4/18/2019 4/18/2019 1.10 PRODS DRILL DRLG P Ct 4776 @ 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 PRODS 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 PRODS DRILL TRIP P At the TOW, shut down pump, open 10,684.0 10,684.0 18:12 18:24 EDC 4/18/2019 4118/2019 1.60 PRODS 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 PRODS 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) @ 35 fpm 4/18/2019 4/18/2019 0.60 PRODS DRILL TRIP P Continue POOH taking returns 1,389.0 69.0 20:12 20:48 through choke (A) 4/18/2019 4/18/2019 0.15 PRODS DRILL PULD P At surface, space out 69.0 69.0 20:48 20:57 4/18/2019 4/18/2019 1.10 PRODS DRILL PULD P PUD build section assembly 69.0 0.0 20:57 22:03 4/18/2019 4/18/2019 0.60 PRODS 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 PROD3 DRILL CTOP P MU Nozzle and jet BOPE stack and 0.0 0.0 22:39 23:24 flush choke (B) 4/18/2019 4/1912019 0.60 PRODS DRILL PULD P MU & 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 PRODS DRILL PULD P MU & 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 PRODS 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 PRODS 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 PROD3 DRILL TRIP P Continue IH 10,463.0 11,070.0 02:30 02:52 4/19/2019 4/19/2019 3.00 PRODS 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 it/min, 4/19/2019 4/19/2019 0.10 PRODS DRILL WPRT P PU Wt 35 k lbs, 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 PROD3 DRILL WPRT P RBIH 11,070.0 11,470.0 05:58 06:10 4/19/2019 4/19/2019 8.20 PROD3 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, 4/19/2019 4/19/2019 0.30 PRODS DRILL WPRT P HU Wt 40 k lbs, Wiper 92 11,900.0 11,078.0 14:22 14:40 Page 26135 Report Printed: 5/3/2019 - Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stam Depth Stmt Time End Time our (M Phase Op Code Activity Code Time P -T -X Operation Mat End Deplh(flKB) 4/19/2019 4/19/2019 0.20 PRODS DRILL WPRT P RBIH 11,078.0 11,900.0 14:40 14:52 S/D 11634'- CT Wt -3 k Is, WOB 1.7 k 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' 4119/2019 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 --1,048 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 PRODS DRILL DRLG P PUH, obtain new pumping 12,156.0 12,156.0 22:25 22:37 paramaters, PUW 40 k 4/1912019 4/19/2019 0.20 PRODS DRILL DRLG P BOBO, 1.87 bpm at 4,078 psi, Diff -11, 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 PROD3 DRILL DRLG P Hard spot, PUW 38 k, restart, BOBD, 12,173.0 12,184.0 22:49 23:19 1.87 bpm at 4,078 psi, Diff -11,060 psi, WHP=222, BHP=3,897, IA=122, OA=289 4/19/2019 4/19/2019 0.30 PROD3 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, bang returns back inside. 4/1912019 4/19/2019 0.20 PROD3 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 PROD3 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 FROM DRILL WPRT T Jog the 5inch x1, Open EDC, POOH 10,684.0 10,348.0 01:51 0206 4/20/2019 4/20/2019 2.00 FROM 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 05:36 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 free spin diff @ 1.83 bpm Page 27135 Report Printed: 513/2019 . Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stmt Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (nt Sten Depth End Depth (ftKe) 4120/2019 4/2012019 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 dean, SID @ 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 CT 4522 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 W10 k lbs, WOB 2.3 k Ibs. ROP 90 ft/hr 4/2012019 4120/2019 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 ft/h 12,327' PU 40 k lbs 12,332' PU 40 k lbs Average ROP 39 ft/hr 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 bugs 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 4/20/2019 4/20/2019 0.40 PROD3 DRILL WPRT P RBIH, 11,079.0 12,332.0 13:12 13:36 Saw spot @ 12,230', dropped pump rate bumped through 4/20/2019 4/2012019 1.30 PROD3 DRILL DRLG P CT 4573 psi, @ 1.86 bpm in and 1.85 12,332.0 12,361.0 13:36 14:54 bpm out, BHP 3899 psi, CT Wt -1.6 k lbs, WOB 2.6 k lbs. Diff pressure jumpingg, assuing plugged n=le(s) cleared. 12,339' PU 40 k lbs 12,355' PU 40 k lbs 12,355' PU 40 it lbs Average ROP 22 ft/hr 4/202019 420/2019 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 k Ibs, WOB 1.8 k lbs, ROP 220 ft/hr in between siderite stringers. Average ROP ft/hr 420/2019 4/2012019 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 rate and orienting. Made it through by orienting TF to low side and droping the pump. 4/202019 4/202019 1.10 PROD3 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 ft/hr 4202019 420/2019 1.00 PRODS 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 PROD3 DRILL WPRT-----[P-7 Wiper back in hole, RIW 10 k 11,700.0 12,183.0 18:21 18:33 Page 28135 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) Fes, 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log StartTime End Tele our (hr) Phase Op code I Activity Code Tyne P -T -X Operation sten Depth (MB) End Depth (fiKB) 4/20/2019 4/2012019 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 4/20/2019 0.25 FROM DRILL WPRT P Continue IH 12,183.0 12,700.0 18:45 19:00 4/20/2019 4/2012019 3.50 FROM 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, —1 BHP=3,910, IA=122, OA=26 4/20/2019 4/20/2019 25 PROD3 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 FROM 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 FROM DRILL DLOG P Log formation (K1), correction of plus 10,430.0 10,458.0 00:06 00:18 8,01 4/2112019 4/21/2019 1.00 FROM 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 FROM DRILL WPRT P Work pipe through rough area 12,300.0 12,371.0 01:18 01:48 maniplulating pump rate, one pickup, PUW 43 k, continue IH 4/21/2019 4/21/2019 4.20 FROM 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 4/21/2019 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 Ct 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. 4/21/2019 4/21/2019 0.40 FROM DRILL WPRT P PU Wt 45 k lbs, Wiper#1 - 1000' 13,494.0 12,495.0 12:42 13:D6 4/21/2019 4121/2019 0.80 FROM DRILL WPRT P RBIH Wt 9 k to 5 k CT @ 50 ft/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 4/21/2019 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 Wt -7.7 k lbs, WOB 0.5 k Is, ROP 70-30 fl/hr 13,632' PU Wt 53 k lbs 4/21/2019 4/21/2019 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 4/212019 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 421/2019 4/212019 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 4122/2019 1.50 FROM 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 4/22/2019 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 4/222019 4/222019 0.70 FROM DRILL WPRT T POOH, laying 8.76 ppg beaded pill 14,045.0 12,543.0 04:48 05:30 Page 29136 Report Printed: 513/2019 Summary (with Timelog Depths) 1c-11 lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Time End Time Dur(hr) Phase Op Code Activity Cnde Time P -T -x Operation (fi(B) End Depth (Po(B) 4/22/2079 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 05:30 05:42 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 5', 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. Bitgmded out 1-1 4/22/2019 4/22/2019 1.20 PROD3 DRILL PULD T PD BHA24, 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 Wt 33 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. _ SID 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 SID 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 bbi bead sweep, ride to bottom on beads. 4/22/2019 4/22/2019 1.80 PROD3 DRILL TRIP T On bottom drilling, rammped up pum 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 4122/2019 1.70 PROD3 DRILL TRIP T "`New mud at the bit 14,074' 14,074.0 14,100.0 18:48 20:30 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 Itis, ROP 15 ft/hr 14,108' PU Wt 47 k lbs 4/22/2019 3.50 PROD3 DRILL TRIP T Reaquired sand 14,700.0 14,285.0 14/23/2019 20:30 - 00:00 OBD, CT 5294 psi, @ 1.86 bpm, BHP 4357 psi, CT -8.4 k lbs, WOB 1.64 k Ibs. WH 357 psi, IA 124, OA 50 psi Page 30/35 Report Printed: 51312019 Summary (with Timelog Depths) 113-11 lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Staa Tnne End Tnne Dur (hr) Phase Op Code Activar Corse Time P -T -X Operation S�fl � d De End Depth (flKB) 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' 14,438'-14,447' 4/23/2019 4/23/2019 0.50 PRODS DRILL WPRT P Wiper up hole to 13,447', PUW 47 k 14,447.0 13,647.0 04:00 04:30 4/232019 4/23/2019 0.40 PRODS DRILL WPRT P Wiper back in hole, RIW 0-4k 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' 423/2019 423/2019 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 PRODS 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' 14,668'-14,717' 423/2019 4/23/2019 0.40 PRODS DRILL WPRT P 800' wiper 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 423/2019 0.20 PROD3 DRILL WPRT P 14942, BHA wiper, PUW=62K 14,942.0 14,942.0 16:54 17:06 4/232019 4/24/2019 6.90 PRODS 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 4/242019 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 4242019 4/24/2019 0.50 PRO03 DRILL CIRC P Call TD @ 15190'. PUH for sweeps 10 15,190.0 15,190.0 01:36 02:06 low vis 50 Hi vis with beads. PUW=47K 424/2019 4/24/2019 2.30 PROD3 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 - 4/24/2019 4/24/2019 2.00 PRODS DRILL WPRT P Continue swab wiper 10,455.0 78.3 04:30 06:30 4/24/2019 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 0824 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 31/35 Report Printed: 513/2019 Operations Summary (with Timelog Depths) 113-11 • Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depthstart Time End Time our lnrl Phase Op Cade Activity Code Tim P -T -X Opemdon (fll(a) End OePN (fiKB) 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 WHP, weight check 4/24/2019 4/2412019 1.50 PRODS DRILL TRIP P Continue IH through window exit, SID 10,680.0 15,201.0 09:06 10:36 12,238', and 14,607', confirm TO 15,201- 4/2412019 4124/2019 0.50 PRODS DRILL TRIP P Circulate 12.1 ppg completion fluid, 15,201.0 15,201.0 10:36 11:06 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) 4124/2019 4/24/2019 0.50 PRODS DRILL OWFF P At surface, check well for flow, PJSM 78.3 78.3 15:36 16:06 4124/2019 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 PRODS 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 +2000175.6. Pressure test to 450OPSI 4/24/2019 4/24/2019 0.60 PRODS DRILL BOPE P Perform Biweekly BOPE function lest 0.0 0.0 19:24 2000 4/24/2019 4/24/2019 2.20 COMPZ3 CASING PUTS P PJSM, Prep floor for liner pick up. P/U 0.0 1,223.1 20:00 22.12 L2-02 lower liner segment with non ported bullnose, 41 joints 2 318" 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 Qc 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 4/25/2019 0.20 COMPZ3 CASING DLOG P Log K1 for -22' 11,635.0 11,685.0 01:30 01:42 4/25/2019 4/25/2019 5.40 COMM 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 COMPZ3 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 4/2512019 4125/2019 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 1254 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 COMM 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 4/2512019 0.20 COMPZ3 CASING DLOG T Log formation (K1) correction of minus 10,430.0 10,469.2 15:24 15:36 4.5' 4/25/2019 4/25/2019 0.30 COMPZ3 CASING TRIP T Continue IH 10,469.2 10,859.0 15:36 15:54 Page 32135 Report Printed: 5/312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Slat Depth Stat Time End lime Our the) Phase Op Code Activity Code Time PJ -X Operation (MB) End Depth(fl<B) 4/25/2019 4/25/2019 0.60 COMPZ3 CASING TRIP T Set down @ 10,859', PUH, PUW 38 k, 10,859.0 12,193.0 15:54 16:30 adljust TF RBIH, popped through, continue IH to next SO @ 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 seldom @ 10,700.0 12,190.0 17:36 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 18:48 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. 4/25/2019 4/25/2019 0.90 COMPZ3 CASING REAM T 12,365 able to run in hole @ 1.8 BPM. 12,365.0 13,800.0 21:42 22:36 25 FPM with minor stacking until] 13,800 4/25/2019 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. 4/26/2019 4/26/2019 1.10 COMPZ3 CASING REAM T Pick up from 15170 to 15127. Unable 15,170.0 15,170.0 00:00 01:06 1 1 to get back to 15170. RIW=-8K. 4/26/2019 4/26/2019 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 4/26/2019 0.10 COMPZ3 CASING DLOG T Log RA in for+13' 10,700.0 10,721.0 03:06 03:12 4/26/2019 4/2612019 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 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 4/26/2019 4/26/2019 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 4/26/2019 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 4/26/2019 0.60 COMPZ3 CASING TRIP T Continue POOH 2,186.0 68.4 09:18 09:54 4/26/2019 4/26/2019 2.00 COMPZ3 CASING TRIP T Tag up, reset counters, RIH 68.4 10,435.0 09:54 11:54 4/26/2019 4/26/2019 0.30 COMPZ3 CASING DLOG T Log formation (K1) connection of minus 10,435.0 10,680.0 11:54 12:12 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 33136 ReportPrinted: 5/312019 . Operations Summary (with Timelog Depths) IC -11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start rime End Time our (hr)Phase Op Cade Activity Coda Time P -T -X operation Start Depth (flKB) End Depth(ftKB) 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- 4126/2019 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 BHAH 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 4/26/2019 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 @ 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 4/27/2019 1.10 COMPZ3 CASING RUNL T S/D pump. Continue to work liner 12,580.0 12,713.0 02:00 03:06 4127/2019 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 412712019 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 4/27/2019 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' 4/27/2019 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 beaded LRP 4/27/2019 4/27/2019 0.20 COMPZ3 CASING DLOG P Log formation (Kt) for depth control 10,420.0 10,456.0 10:57 11:09 plus 11.0 4/272019 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 4272019 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 -0 PJSM 4/27/2019 4/27/2019 75 6OMPZ3 CASING PULD P LD setting tools 44.2 0.0 13:39 14:24. 427/2019 4/27/2019 0.50 COMPZ3 CASING PUTB P Prep RF for liner OPS 0.0 0.0 14:24 1454 Page 34135 Report Printed: 5/312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log StartTime EM Time our (ho Phase O Corse P Ad Code 'aH Time P-T-% Operelbn n De sten Depth EM Depth (fl(B) 4/27/2019 4/27/2019 4.40 COMPZ3 CASING PUTS P Start picking up liner segment #2 with 0.0 2,976.3 14:54 19:18 large ported, 1.25" bullnose, 99 its 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 19:18 20:12 hang in deployment rams. Change out floats in UQC. Inspect packofts. 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 4/2712019 0.10 COMPZ3 CASING DLOG 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 4/2812019 4/28/2019 3.40 COMPZ3 CASING RUNL P Continue working 1-2-02 liner 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 03:24 03:30 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 03:54 left in hole 2976.34. Perform static test, Sensor depth TVD 6184.98', Pressure stabilized @ 3882 PSI, EMW=12.0725 Minute test 4/28/2019 4/28/2019 2.00 DEMOB WELLPR CIRC P Dispace well to seawater 10,219.2 10,219.2 03:54 05:54 4/28/2019 4/28/2019 1.20 DEMOB WELLPR TRIP P POOH 10,219.2 2,500.0 05:54 07:06 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 4/282019 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 4/282019 4/282019 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 4/282019 6.10 DEMOB WELLPR RURD P RDMO 0.0 O.0 11:54 18:00 "" Rig Release 18:00 hrs Page 35/35 Report Printed: 5/3/2019 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1C Pad 1 C-11 L2 50-029-22714-63 Baker Hughes INTEQ Definitive Survey Report 15 May, 2019 BA ER I UGHES Conocolahillips ConocoPhillips Definitive Survey Report Company ConsocPhillips Abska lnc Kupamk Local Corottlinate Reference: Well 10-11 Prolepe Kupemk River Unit TVD Reference: 1C-11@ 102.00us0(1611) Sib: Kupamk IC Pad MO Reference: 1G11®102.00usR(1611) Wall: 1611 Month Rabrcnce: Tore Wallhob: 16111.2 Survey Calculation Methi Minimum Curvature Dealgm 1611 L2 Dumb... EDT 14 Alaska Production Prolatl Kupamk River Unit North Slope Alaska, United States Map System: US State Plane 1827 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Porerence Point Map Zana: Alaska Zone 04 Using gcod.n. scale factor Well 1C-11 _ Well Reopen aW5 000 usIt Northing: 5,969008.74usg Latitude: 70-l9'33.120N rEf.W 0.00 usH Eastur, 561,641.O6usB Longitude: 149° 30' 0.514 W Poahion Utrcedainty 0.00 use Wellhead Elevation: unit Ground Level: 0.00 ua8 Wellbore 1C-111-2 Magnetics Model Name Sample Date Decantation Dip Angle Fadd Strengb PI V) (nTl BGGM2018 4/1/2019 16.71 80.08 57423 Design 16111-2 --- Audit Notes: Version: 10 Phase: ACTUAL To on Depth: 10.495.53 Vadical Section: DepW From I114D) •WS �.w olmmbn (twlry (Daft) Iui (1 4160 0.00 000 9.00 Survey Program Dam From To Survey Survey lung) 1--M Sure"i WallUom) Taal M. Deacdption Stand Data End Dab 12100 10,495.53 lC-11 (1611) MWD MWD - Standartl 012512000 10,04.00 10,772.66 1C-1113 MWD-INC(I C-111.2) MWD-INCONLY MiAti ONLY FILLER 4/52019 4/5/2019 10,802.06 12,843.67 1C-1112 MAID (I G 111.2) MWD MWD - Standard 4/92019 4/92019 StUSZD19 10: 15'3SAM Page 2 COMPASS 500014 Sued 95D Suety Conocolphillips r, ConocoPhillips Definitive Survey Report eD Camparry: ConacoPhil9ps Alaska lnc_Kupamk Local OoaNinale Reference: Well 10-11 Propct: Kupamk River Unit ND Reference: lC-11®102.00ue%(10-11) She: Kupamk 1C Pad No Reference: 10.11 a 102.00usS (1C-11) IAl 10-11 North Reference: Tete W6Wem 1G11L2 Survey Calculation Method Minimum Curvature Design: 161172 Database: EDT 14 Alaska Production Suety FIT& 4 Annotation TIP NOP IntePolated Azimuth Imeryolated Azimuth Interyolaied Azimuth 5715801910: 16 39A Patio ] COMPASS SOOO.f/ BuiM 350 Map eD Venkal MO Ma Atl TVD TVDSS +w5 .0m Northing Event, US OLS Secdon Survey Tool Nanta foae) 17 P) (olm) (USMluae) Wall) ml mi m( 10,495.53 42.24 346.93 6391,53 6292.53 ])04.62 -1,4901 5,906)02]2 550.398.12 Ofid 7,70067 MWWNL ONLY (2) 160.°4.00 41,64 350.88 6,53974 6,432]4 2,82022 -1,206.06 5,976,B2S2fi %.372.85 144 7.8264 M INC_ONLY(2) 1071299 45.37 351.00 653]8 6,453,26 ],84]93 -1,207.20 5.9]6,84524 560,369.55 12.07 7,84793 MWD-1NC_DNLY(2) 1.243.23 58.54 351.50 8.52036 6,4M6 ],8]142 -1,210.81 5.9]696919 560,355.25 4357 ],8]142 M NC_ONLY (2) 1.222.66 71,19 352.50 658683 648983 7,89].]3 -1,21950 5.976995.40 560,351.85 4309 7,69735 MN0.1NC_ONLY (2) 16353.06 6261 356.98 6,593.49 6,49149 7,925.21 -1.21209 5,976.92393 550.35601 41.52 7,92621 MWD(3) 10,831.52 84.53 357,52 6,596.79 6,49479 7,95550 -1,21049 5,978,953.20 560.357.39 6.80 7,35550 MM (3) 1D,86224 02.11 35282 6.599 6.49703 2,905.06 -1,219.72 5,9mQ98375 560,355.90 048 7,96,06 M (3) 1D, 35208 8252 359.27 6.6M41 8,498.41 0,01580 -1,22642 5,972.013.54 560.354,9 3.09 8,015.86 NAND (3) 10,92163 8665 131 6,601.39 6,499.39 0,045.39 -1,22632 5,97].043,07 560.354.81 2.81 8,04539 MWD(3) 1685210 91.23 381 8.80142 6,49942 6,07592 -1,21696 5.972,0nel 560,355.92 11.75 8.07582 MWD (3) 10992.45 9258 5.99 8,607.41 649841 0,106,04 -1.21630 5.912.103.24 560,358.26 BA7 8.10504 MM (3) 11.012.07 9233 7.23 659.14 8,492.14 0.13544 y21292 5,9]],133.16 560.36142 922 613544 MWD(3) 11,04125 9142 6,68 6.598 18 6495.10 0,107,38 -142943 5,92].16214 56u.36A,n 340 UGA39 MWD (3) 11,0]2.39 8945 5.46 6,5979 649593 0.195.35 -1,20614 5,927.193,12 560,367.76 7.59 819535 MM (3) 11.102.21 8811 4.07 6.59 .30 6495.30 0,22505 42946 597.222.84 560370.20 228 8.22505 MM (3) 11,13165 89.54 4.]11 8,5965 6,4%55 0,254.30 -1,20100 5,972,25219 56637241 1.52 625930 MWD (3) 11,161.53 Ban S.w 8.5982 64982 8,284.15 -719696 5,972.201.80 580,374.71 IAA B,28915 MWD(3) 11,191.78 BILN 6.12 6.599,32 6,49732 6314,25 -119.51 59]].312.10 560.372.41 5.84 8,31925 MWD (3) 11,231.41 66.53 6.57 6,69.64 6,49864 8.343,67 y19224 5,9]].341.54 560.350.44 67 8,34362 MWD (3) 11,25152 111B2 931 6,E9d3 65913 0,323.45 -0,18809 5,9]!.371.3ii 560.38935 1085 8,37343 MM (3) 11,261,61 0638 12.34 6,603.9 8,50166 0,40296 .118244 5.977,40050 560.389.75 1118 8,40296 MWD(3) 11312.03 8216 14.79 6.605,26 6503.26 8,43249 -117532 5,97743049 560,39.63 940 643249 MWD(3) 11.341.86 87.05 1760 6.6[6,40 6,50440 6461.11 -1.267X1 5.8]7459.1] 560.404.70 992 8,461,11 MWD (3) 11,372.25 91X8 21.20 6,606,68 6,50968 8,40922 -1.15 77 5,97248786 W.41970 17M 8,48972 MND(3) "rAn'93 89]5 23.46 6.60647 6504A7 0,51711 y14536 5,977513.34 550.42580 7.R 8,517.11 MD (3) 11431.93 8683 2314 6.607.34 6,50534 0.544.69 4,13359 597],54301 560.437.43 9.70 654969 GhNo p) 1146144 85.9 21.10 6,603.19 6,50119 8,571X0 -04122.58 5,977520A1 560.448.21 836 0,57200 MD (3) 11491.61 85.9 2036 6.611.35 65936 08914 -1111.91 5,9]],59.63 560.458.85 271 8.600.14 MWD(3) 11,521.40 86.74 26.31 6.61322 6,511.27 682601 -1,1019 59776269 560,460.06 2.89 8.62801 MWD (3) FIT& 4 Annotation TIP NOP IntePolated Azimuth Imeryolated Azimuth Interyolaied Azimuth 5715801910: 16 39A Patio ] COMPASS SOOO.f/ BuiM 350 Survey ConocoPhiliips y: CorvocoPhillips DeNnifive Survey Report Company: ConacoPhillips Alaska Inc Kupnuk Local C.mlmam Reference: Milk -11 Project: Kupaok River Unit WD Remrence: 1C-11®102.00ustl(1C-11) Sim: Kulsaruk 1C Pad MD Reference: 1C41 ®102.00ush (1611) Well 1611 North Reference: Toe Wellhore: 10111-2 Survey Calculation Method: Minimum Curvature Design: 161112 Diumha6e: EDT 14 Alaska PmducOon Survey Annotation ER y 1 WHFS 5715201910:16:39AM Pegs 4 COMPAS5Woo 14 Budd 850 Map Map widlool M MD O n Inc Atl TVO TVDSS ♦NIS 9�yy Northing fasting OLS Section Survey Tool Name 1°) (-ft) 1u6R1 Iu6R1 lush) RI (ft) 1.1100'1 IN) 1155195 0]e] law 6.61460 6,51268 865.5]2 -1.09122 5,9]1,655.36 5544]60) 5.19 0,656]2 MWD(3) 11,50217 88.37 18.50 e61&65 651365 0,605.29 -1,001.43 5,97,684.03 55.4.48043 305 0,68529 "D (3) 11,61260 87.61 1753 6,616.70 6,514.70 871371 -1,0,2.19 5,877,71252 560,497.44 4.12 871571 MWD (3) 11 GV.R 84.13 16.40 6,619.67 651767 671K03 -1 WAS 5,977751.93 560,509.71 807 8753.03 MD (3) 11694.19 82.10 14.37 6623.35 6521.35 0,78260 -1052.65 5,977.78157 560,517.00 660 6,78260 MAD) (3) 11,715.60 8223 12.24 662755 6,525.56 8,81256 -1,044.97 5.977.61150 Moen84 6]9 8,01256 MND(3) 11744]9 02.05 939 663100 6.SiS.60 0,841.29 -1,039.40 5,977.84435 560529.09 958 6.61129 says)(3) 11,774.39 02.77 1135 663551 6,533.51 8,870.15 -1034.22 5.977.069.25 560,534.11 6.69 8.070.15 MAD(3) 11,60421 85.05 9.43 66306.4 6.536.60 0.699.32 -1,02&90 5,977860.46 560.539.18 9.76 0609.32 ~p) 11,82427 W.32 9.20 6.610.18 6.538.10 0,919,W -1,025.67 5,97791022 500,542.26 643 8,919.06 "D (3) 11&54.11 58.19 BIS 664161 6,538.61 8940.51 -102100 5,977,90.70 560.546.60 6.70 0.94&51 MWD(3) 11.81 90.15 6.71 6,642.05 654005 6970.54 -101700 5,977977.76 55o5W36 874 0,97&54 MWD(3) 11.914.01 0932 8,60 6,64209 6,54009 9,60787 -1,013.00 S,970,W7.12 560,554.12 7.21 9,00707 MAD (3) 11,943.60 91.26 1227 664183 6,539.93 9,037.32 -1060.61 5.978,OW.62 56055935 12.67 9,037.32 MWD(3) 11,9711,3 90.37 18.40 664140 6.539.41 9,008.23 -1,000.71 5.878,065.59 560560.60 14.15 9,06633 MAD (3) 12004.57 09.72 1633 6641.36 eliKiy30 8.09573 -ie1.% 5.978.09515 WG574.92 213 9.065.73 MAD (3) 12,034.35 90.80 17.16 6.61125 6539.25 9,124.22 -962.90 5,978,12371 560.56034 5.25 9,124,3 Mrfll(3) 12,06166 91.01 184 6.840.50 6,538.50 9,152.09 -973.84 5,978.151.60 560,`92.17 5.12 9.152,09 MW➢(3) 12,09421 9126 17.71 66,276 0,53776 9,781.11 964.33 5,970.181 360,601.41 3.34 9,181.11 MWD(3) 1214432 9166 18.27 6,638 99 6,536.99 9,209.74 -855.04 5,97820844 360.61050 229 92119]4 MWD(3) 12.154.E 9157 16.81 6,635.15 653615 923033 546.00 5 a 238.10 560.679.30 407 9,238.33 SAID (3) 12,104.49 SIX 15.74 6,836.88 664460 9,26726 53755 5,978.267.10 560.627.51 663 9,26726 MM (3) 12,214.85 95]5 16.04 6634.49 6,56.49 929637 ..'26 5.978,296.20 580635.55 026 829637 Il (3) 12,244.73 95.25 15.97 6,63163 6,51163 9,324.96 A2106 5,976.32493 58064352 169 9.32460 MM (3) 12274.49 95.04 1599 66'20.96 6,526.95 9,353.46 412.90 5.970,353.48 55065144 0.71 9,353.48 ~ p) 1229401 94.92 15.0 6,6)719 6,52519 9,377.92 507.33 5,978,3899 560.656.86 0.59 9,372.@ MAD(3) 12,324.79 94.52 1573 66N]3 6522.73 9.401.66 499.16 5,878.401]9 S6g6W39 1S9 94010 anyo(3) 12.35409 9,158 15.31 6,822.34 6,520.34 9,43057 49113 5,978,430]7 560,67.50 141 9,430.57 MAID(3) 12.38427 94.60 15.0 6,61992 6517.92 8,458.80 40338 5,970,439.60 560,683.10 1.02 9,45600 MWo(3) 12414.E 95.16 15.@ 661731 6,51631 9440759 -87551 5,97848791 550.687.70 167 948759 "D (3) 12444.33 W. 14.59 6,614.37 8,51237 9,51656 46789 5.97651691 560695.4 322 9515.60 MWD(3) Annotation ER y 1 WHFS 5715201910:16:39AM Pegs 4 COMPAS5Woo 14 Budd 850 C-ortocoPlllllps Conocolahillips DefinMive Survey Report Company: CDnomPhilllps Alaska Inc Kupamk Local Coordinate Reterenre: Well 1C-01 Proiecc Kupamk River Unit TVD Reference: 1C-11®10290usN(1C-11) Site: Kupamk IC, Pad MD Reference: 1CA1@ 102.00us%(1G11) Well: IC -11 Nenh Reference: Tme Wellbore: IC -11L2 Survey Calculation Method: Minimum Cunmture Design: IC -1112 Database: EDT 14 Alaska Production survey 14, Y W019 10.16.3114114 Pegs 5 COMPA535000.14 Butld 655 Map Map Vertical MD Ina A9d TVD NDSS .115 avm NerN11n9 Fasting OLS SeoNan Survey Toel Name Annotation (usN) r) (1) (usn) IusN) (.aft) (-am R1 (.1iow) 1247410 9L92 14.45 6.610.89 6,500 e9 9,545.16 AWA] 5.9)654562 560]02.69 6C 23 4 9545.18 MWD (3) 12503]4 98.84 14.22 6,605.69 6,504.69 9,Sn61 JI53.21 5.9]8.5]4.10 560]0.932 4.65 9.573.61 MND(3) 12534.53 105.31 14.03 6,60157 6,499.57 9803.05 b 5.80 5,976603.50 550,716.49 4.81 9.W305 MND(3) 12.564.85 104" 13,B4 6, a6.01 6,494.01 efi3198 -83662 5976632.58 550.83,43 1.85 9.63198 MND(3) 12,59925 10033 4.46 6,5119]0 6,40]]0 9,E5A.91 -83093 5,90.885.57 5.,M.85 4.24 9.66491 1AWD(3) 1262424 99.01 1374 6.585.33 6ow" 9,688.07 425.35 5,970,689.59 560.7N.23 541 9,688.87 ~(3) 12654.37 100.81 13.33 6,5]9." 64)]." 9,717.69 418.41 5,9]0.]1645 550.742.93 3.50 9,]1].69 IAWD(3) 1268433 10210 1336 8,9401 64801 9.745.17 -811.96 5.970.74690 563.749.45 4.32 9,745.17 MrW(3) 1271400 103.46 14.03 6,567,41 6,405A1 9,77445 -804.7T 590.77531 560,79511 505 9]74.45 IWDC) 12744.19 105.22 14.25 5,55995 6,4.4.95 9,802]4 19." 5,9]8,80}W 560.763.00 589 9,8@.74 M D) 1277433 150.% 14.38 6551.50 8.449.50 9,830.77 -790.49 5,90.83174 560,769.92 711 9,83077 MCC) 12.95058 109]0 1524 lis@17 6.440.17 9,857.67 -76138 5,98.85670 560,776.81 644 9857.9 MD (3) 12613.40 110.83 15.18 6,531." 6.429.80 9,884.57 -77606 5,98.605.E6 5607010 381 9,8849 MWD(3) 4.843.9 110.94 la'. 6.528.22 6A26.22 9,893.61 -17349 5,978.6".92 Y-0)8641 L" 9693.81 "D (3) 12"O(i) 110." 1600 6.515.23 641323 9,92643 964.13 5,970,92761 30,79549 000 9,9211.43 PROJECTED to TD 14, Y W019 10.16.3114114 Pegs 5 COMPA535000.14 Butld 655 BAN(UGHES PRINT DISTRIBUTION LIST a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1C-111,2 FIELD Greater Kuparuk Area CD/DVDFINAL COUNTY North Slope Borough PRELIM BHI DISTRICT Alaska SURVEY AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider�akerhuohes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. 60X) PERSON ATTENTION V f BP North Slope. EOA. PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glasaaaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 Conoco Phillips Alaska Inc. Atm: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 _I 3 EXxonMObkl,Alasks Atm: Lynda M. Yaskell and'or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC Attn: Natural Resources Technician If 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 No 219041 50798 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WINS Petroleum Technician) 700 G Street. Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE April 9, 2019 TODAYS DATE May 16, 2019 Revision Details: Rev. Requested by: --- FIELDI FINAL CD/DVDFINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRIN OF PRIN # OF COPIES I# OF COPIES # OF COPIES 4 4 4 a a !1 RECEIVED AOG 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 6 RP Exploration (Alasla) Inc. Petrotechnical Data Center, tR2-1 900 E. Renson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 BA ER BAT a GE company 2190��1 ' ( 30792 Letter of Transmittal Date: May 16, 2019 Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Harvey Finch Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 se 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@BakerHughes.com 4' ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1C Pad IC -11L2 50-029-22714-63 Baker Hughes INTEQ Definitive Survey Report 15 May, 2019 BAT(ER UGHES a GE company 219041 30792 ConocoPhillips BAER ConocoPhillips Definitive Survey ReportW Company: ConocoPhillips Alaska lnc_Kuparuk Project: Kuparuk River Unit Site: Kuparuk 1 Pad Well: 1G71 Wellborn: 1C-111-2 Design: 1C-1112 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 1C-11 Local Co-ordinate Reference: Well 1C-11 TVD Reference: 1C-11 @ 102.00usft(1C-11) MD Reference: 1C-11 @ 102.00usft (1C-11) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Well Position +NIS 0.00 usft Northing: *El -W 0.00 usft Easting: Position Uncertainty Depth From (TVD) 0.00 usft Wellhead Elevation: Wellbore 1C-111-2 Magnetics Model Name (usft) Sample Date BGGM2018 4/1/2019 Design IC -111.2 0.00 Audit Notes: Date Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,969,008.74usft Latitude: 561,641.06 usft Longitude: usft Ground Level: Declination Dip Angle Pl (1) 16.71 80.88 70° 19'33.128 N 149'30'0,514 W 0.00 usft Field Strength (nT) 57,423 Version: to Phase: ACTUAL Tie On Depth: 10,495.53 Vertical Section: Depth From (TVD) +NIS +E/ -W Direction (usft) (usft) (usft) (•) 41.60 0.00 0.00 0.00 Survey Program Date From TO Survey Survey (usft) (usft) Survey (Wellborn) Tool Name Description Start Date End Date 121.00 10,495.53 1C-11 (1C-11) MWD MWD- Standard 8/25/2000 10,684.00 10,772.66 1C-11 L2 MWD -INC (I C-111-2) MWD-INC—ONLY MWD -INC ONLY FILLER 4/52019 4/MO19 10,802.06 12,843.67 1C-11 L2 MWD (1 C-111.2) MWD MWD -Standard 4/92019 4/9/2019 5/15/2019 10: 16:39AM Page 2 COMPASS 5000.14 Build 85D Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1C-11 Project: Kupamk River Unit TVD Reference: 1C-11& 102.00usft(1C-11) Site: Kuparuk 1C Pad MD Reference: 1C-11 @ 102.00usft (1C-11) Well: 1C-11 North Reference: True Wellbore: 1C-1112 Survey Calculation Method: Minimum Curvature Design: 1C-111.2 Database: EDT 14 Alaska Production Survey HA UER S Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth 5/15/2019 10:16:39AM Page 3 COMPASS 5000.14 Build 850 Map Map Vertical MD Inc As[ TVD TVDSS +W.S +E/.W DLg (usft) (°) (°) (ush) (usrt) (usn) (usrt) Northing Easting (°M00') gectlon Survey Tool Name (fl) (ftl (� 10,495.53 42.24 346.93 6.394.52 6,292.52 7,704.67 -1,179.81 5,976,70272 560,398.12 0.69 7,704.67 MWD -INC _ONLY (2) 10,684.00 41.64 350.88 6,534.74 6,432.74 7,828.22 -1.204.06 5,976,82666 560,372.85 144 7,82822 MWD -INC _ONLY (2) 10,71299 45.37 351.00 6,555.76 6,453.76 7,647.93 -1,207.20 5,976,845.74 560,369.55 12.87 7,847.93 MWD-INC_ONLY (2) 10,743.23 58.54 351.50 6,57436 6,472.36 7,871.42 -1,210,81 5,976,869.19 560,365.75 43.57 7,871.42 MM -INC _ONLY (2) 10,772.65 71.19 352.50 6,586.83 6,484.83 7,897.75 -1,214.50 5,976,89549 560361.85 43.09 7,897.75 MWD -INC ONLY(2) 10,802.06 82.61 356.98 6,593,49 6,491.49 7,926.21 -1,217.09 5,976,923.93 560,359.02 41.57 7,926.21 MWD (3) 10,831.57 64.53 357.57 6,596.79 6,494.79 7,955.50 -1,218.49 5,976,953.20 560,357.38 6.80 7,95550 MWD (3) 10,862.24 87.11 357.82 6,599.03 6,497.03 7,966.06 -1,219.72 5,976,983.75 560,35590 8.45 7,96606 MWD (3) 10,892.08 87.57 359.27 6,600.41 6,498.41 8,015.86 -1,22047 5,977,013.54 560,354.90 5.09 8,015.86 MWO(3) 10,921.63 88.65 1.31 6,601.39 6,499.39 8,045.39 -1,220.32 5,977,043.06 560,354.81 7.81 8,045.39 MWD(3) 10,952.20 91.23 3.81 6,801.42 6,499.42 8,075.92 -1,218.96 5,977,073.61 560,355.92 11.75 8,075.92 MWD (3) 10,982.45 92.58 5.99 6,60041 6,49841 8,106.04 -1,218.38 5,977,103.74 560,35826 9.47 8,106.04 MWD (3) 11,012.07 92.33 7.23 6,599.14 6,497.14 8,13544 -1,212.97 5,977,133.16 560361.42 427 8,135.44 MWD (3) 11,041.25 91.47 6.69 6,598.18 6,496.18 8,164.39 -1,209.43 5,977,162.14 550,364.72 3.48 8,164.39 MWD (3) 11,072.39 89.45 546 6,59793 6,49593 8,195.35 -1,206.14 5,977,193.12 560,367.76 7.59 8,195.35 MWD (3) 11,10221 89.11 4.87 6,598.30 6,496.30 8,225.05 4,20346 5,977,222.84 560,370.20 2.28 8,225.05 MWD (3) 11,131.65 89.54 4.70 6,598.65 6,496.65 8,254.38 -1,201.00 5,977,252.19 560,372.41 1.57 8,254.38 MWD (3) 11,161.53 89.79 5.06 6,598.82 6,496.82 8,284.15 -1,198.46 5,977,281.98 560,374,71 1.47 8264.15 MWD (3) 11,191.78 88.34 6.12 6,59932 6,497.32 8,314,25 -1,195.51 5,977,312.10 560,377.41 5.94 8,314.25 MM (3) 11,221.41 86.53 6.57 6,60064 6,49864 6,343.67 -1,192.24 5,977,341.54 560,380.44 6.29 8,343.67 MVD (3) 11,251.52 87.82 9.31 6,602.13 6,500.13 8,37345 -1,188.03 5,977,371.35 560,384.35 10.05 8,373.45 MWD (3) 11,28161 86.28 12.34 6,603.68 6,501.68 8,402.96 -1,18244 5,977,400,90 560,389,75 11.28 8,402.96 MWD (3) 11,312.03 8776 14.79 6,605.26 6,50326 8,432.49 -1,17532 5,977,430.49 560,396.63 9.40 8,432.49 MWD (3) 11,341.86 8785 17.60 6,606.40 6,504.40 8,461.11 -1,167.01 5,977,459.17 560,404]0 9.42 8,461.11 MWD (3) 11,372.25 9106 21.78 6,606.68 6.504.68 8,48972 -1,156.77 5,97,487,86 560,414.70 17.38 8,489.72 MWD (3) 11,401.93 89.75 23.46 6,60647 6.504.47 8,517.11 -1,145.36 5,9T/,515.34 560,425.89 7.22 8,517.11 MM (3) 11,431.93 8693 22.74 6,607.34 6,505.34 8,54469 -1,133.59 5,977,543.01 56D,437,43 9.70 8,544.69 MWD (3) 11,461.44 85.88 21.18 6,809.19 6,507.19 8,572.00 -1,122.58 5,977,570.41 560,448.21 6.35 8,572.00 MWD (3) 11,49161 85.88 20.36 6,611.36 6,509.36 8,600.14 -1,111.91 5,977,598.63 560,458.65 2.71 8,600.14 MWD (3) 11,52140 86.74 20.33 6,613.27 6,511.27 8,628.01 -1,101.57 5,977,626.59 560,468.76 289 8,628.01 MWD(3) HA UER S Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth 5/15/2019 10:16:39AM Page 3 COMPASS 5000.14 Build 850 ✓ ConoCoPhillIp5 ConocoPhillips Definitive Survey Report Company: ConowPhillips 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: 1C-11 North Reference: True Wellbore: 1C-11 L2 Survey Calculation Method: Minimum Curvature Design: 1C-11 L2 Database: EDT 14 Alaska Production Survey BA ER 1UGHFS 5115@019 10.16:39AM Page 4 COMPASS 5000.14 Build 850 Map Map Vertical MD Inc ANTVD TVDSS +N/3 -iNorthing DLS _ (usft) (1) (1) (usft) (usft) (usft) (usft) Easting (°1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 11,551.95 87.97 19.33 6,614.68 6,512.68 8,656.72 -1,091.22 5,977,655.38 560,478.87 5.19 8,656.72 MWD (3) 11,582.17 88.37 18.50 6,61565 6,513.65 8,685.29 -1,081.43 5,977,684.03 560,488.43 3.05 8,685.29 MWD (3) 11,612.07 8761 17.53 6,616,70 6,514.70 8,713.71 -1,072.19 5,977,712.52 560,497.44 4.12 8,713.71 MWD(3) 11,653.29 MM3 16.40 6,619.67 6,517.67 8,753.03 -1,060.19 5,977,751.93 560,509.11 8.87 8,753.03 MWD (3) 11,684.19 82.18 14.37 6,623.35 6,521.35 8,782.60 -1,052.05 5,977,781.57 560,517.00 9.08 8,782.60 MWD (3) 11715.26 82.23 12.24 6,627.56 6,525.56 8,812.56 -1,04197 5,977,811.58 560,523.84 6.79 8,812.56 MWD (3) 11,744.79 82.05 9.39 6,631.60 6,529.60 8,841.29 -1,039.48 5,977,84035 560,529.03 9.58 8,841.29 MWD (3) 11,774.39 82.77 11.25 6,635.51 6,533.51 8,870.15 -1,034.22 5,977,869.25 560,534.11 6.69 8,870.15 MWD (3) 11,804.21 85.05 9.43 6,638.68 6,536.68 8,899.32 -1,028.90 5,977,89846 500,539.19 916 8,899.32 MM (3) 11,824.27 86.32 920 6,640.18 6,538.18 8,919.06 -1,025.67 5,977,91822 560,542.26 6.43 8,919.06 MWD (3) 11,854.11 88.19 849 6,641.61 6,539.61 8,948.51 -1,021.08 5,977,947.70 560,546.60 6.70 8,948.51 MWD (3) 11,884.41 90.15 6.71 6,642.05 6,540.05 8,978.54 -1,017.08 5,977,97776 560,550.36 814 8,978.54 MWD (3) 11,914.01 89.72 8.80 6,642.09 6,540.09 9,007.87 -1,013.08 5,978,007.12 560,554.12 7.21 9.007.87 MWD (3) 11,943.98 91.26 12.27 6,641.83 6,539.83 9,D37.32 -1,007.61 5,978,036.62 560,55935 12.67 9,037.32 MWD (3) 11,973.83 90.37 16,40 6,641.40 6,539.41 9,066.23 -1,000.22 5,978,065.59 560,556.50 14.15 9,066.23 MWD (3) 12,004.57 89.72 16.33 6,641.38 6,539.38 9,095.73 -991.56 5,978,095.15 560,574.92 2.13 9,095.73 MWD(3) 12,034.35 90.80 17A6 6,64125 6,53925 9,124.22 -982.90 5,978,123.71 560,583.34 5.25 9,124.22 MWD(3) 12,053.66 91.81 18.57 6.640.58 6,$38.58 9,152.09 -973.84 5,978,15164 560,592.17 5.12 9,152.09 MWD(3) 12,094.21 91.26 17.71 6,639.76 6,53716 9.181.11 -964.33 5,978,18014 560,601.44 3.34 9,181.11 MM (3) 12,124.32 91.66 18.27 6,638.99 6,536.99 9,209.74 -955.04 5,978,209.44 560,610.50 2.29 9,209.74 MWD (3) 12,154.32 91.57 16.81 6,638.15 6,536.15 9,238.33 -946.00 5,978,238.10 560,619.30 4.87 9,238.33 MWD(3) 12,184.49 93.26 15.74 6,636.88 6,534.88 9,267.26 -937.55 5,978,267.10 560,627.51 6.63 9,267.26 MWD (3) 12,214.85 9575 16.04 6,634.49 6,532.49 9,296.37 -929.26 5,978,296.28 560,635.55 8.26 9,296.37 MWD (3) 12,244.73 95.25 15.97 6,631.63 6,529.63 9,32496 -921.06 5,978,32493 500,643.52 1.69 9,324.96 MM (3) 12,274.49 95.04 15.99 6,628.96 6,526.96 9,353.46 -912.90 5,978,353.49 560,65144 0.71 9,353.46 MWD (3) 12,294.81 94.92 15.99 6,627.19 6,525.19 9,372.92 -907.33 5,978,372.99 560,656.86 0.59 9,372.92 MWD (3) 12,324.79 94.52 15.73 6,624.73 6,522.73 9,40166 -899.16 5,978,401.79 560,664.79 1.59 9,401.66 MWD(3) 12,354.89 94.58 15.31 6,622.34 6,$20,34 9,430.57 -891.13 5,978,43077 560,672.58 1,41 9,430.57 MWD (3) 12,384.27 94.85 1542 6,619.92 6,517.92 9,458.80 -883.38 5,978,459.06 560,680.10 1.02 9,458.80 MWD (3) 12,414.22 95.16 15.02 6,617.31 6,515.31 9,487.59 -875.54 5,978,48791 560,687.70 1.67 9,487.59 MWD (3) 12.444.33 96.03 1459 6614.37 6,512.37 9,516.56 4'67.89 5,978,51694 560,695.12 3.22 9,516.% MWD (3) BA ER 1UGHFS 5115@019 10.16:39AM Page 4 COMPASS 5000.14 Build 850 Survey MD ConocoPhillips Azi ConocoPhillips Definitive Survey Report +NIS Company: ConocoPhillips Alaska Inc_Kuparuk Local Coordinate Reference: Well 1C-11 Project: Kupamk River Unit TVD Reference: 1C-11 @ 102.00usft (1C-11) Site: Kupamk 1C Pad MD Reference: 1C-11 @ 102.00usft (1C-11) Well: 1C-11 North Reference: True Wellbore: 1C-111-2 Survey Calculation Method: Minimum Curvature Design: 1C-111-2 Database: EDT 14 Alaska Production Survey MD Inc Azi TVD TVDSS +NIS +E7 -W Map Map Vertical (usft) (°) (1) (usft) (usft) (usft) (usft) Northing Easting C1DL Section Survey Tool Name (ft) (ft) (ft) 12,474.10 97.42 14.45 6,610.89 6,508.89 9,545.18 -660.47 5,978,545.62 560,702.29 4.69 9,545.18 MWD (3) 12,503.74 98.84 14.22 6,606.89 6,504.69 9,573.61 -853.21 5,978,574.10 560,709.32 4.85 9,573.61 MWD (3) 12,534.53 100.31 14.03 6,601.57 6,499.57 9,60305 -845.80 5,978,603.60 560,716.49 4.81 9,603.05 MWD (3) 12,564.85 10084 13.84 6,59601 6,494.01 9,631.98 -838.62 5,978,632.58 560,723.43 1.85 9,631,98 MWD(3) 12,599.25 10030 12.46 6,589.70 6,487.70 9,66991 -830.93 5,978,665.57 560,730.85 4.24 9,664.91 MM (3) 12,624.24 99-81 13.74 6,585.33 6,483.33 9,688.87 -825.35 5,978.689.58 560,736.23 5.41 9,688.87 MWD (3) 12,659.37 100.81 13.33 6,579.94 6,477.94 9,71769 -818.41 5,978,718.45 560,742.93 3.58 9,71769 MWD(3) 12,684.23 102.10 13.36 6,57401 6,47201 9,746.17 -811.66 5,978,74698 56,74945 4.32 9,746.17 MWD(3) 12,714.08 103.46 14.03 6,557.41 6,465.41 9,774.45 A 1477 5,978,775.31 560,756.11 5.0$ 9,774.45 MWO(3) 12,744.19 10522 14.25 6,559.95 6,457.95 9,802.74 -797.64 5,978,803.66 560,763.00 5.89 9,802.74 MWD(3) 12,774.33 107,36 14.38 6,551.50 6,449.50 9.830.77 -790.49 5,978,831.74 560,769.92 7.11 9,830.77 MWO(3) 12,503.68 109.70 15.24 6,542.17 6,440.17 9,857.67 -783.38 5,978,858.70 560,776.81 8.44 9,857.67 MWD (3) 12,833.40 110.83 15.18 6,531.88 6,429.88 9,884.57 -776.06 5,978,885.66 560,783.90 3.81 9,884.57 MWD (3) 12,843.67 110.94 16.00 6,528.22 6,426.22 9,893.81 -773.49 5,978,894.92 560,786.41 7.54 9,893.81 MWD(3) 12,680.00 110.94 16.00 6,515.23 6,413.23 9.926.43 -764.13 5,978,927,61 560,795.49 0.00 9,92643 PROJECTED to TD Annotation BA, ((EGRN� 5/752019 10:16:39AM Page 5 COMPASS 5000.14 Build 85D THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohl inger Staff CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1C -I IL2 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-041 Surface Location: 1225' FNL, 637' FWL, SEC. 12, Tl IN, RIOE, UM Bottomhole Location: 1768' FNL, 181' FEL, SEC. 35, TI2N, RIOE, UM 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .00gcc.alaska.gov Dear Mr. Ohlinger: Enclosed is the approved application for the permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 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. STATE OF ALASKA I L '' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL '' 20 AAC 25.005 Ia. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1c. Specify if well is proposed for: Drill ❑ Lateral ❑' Stratigraphic Test ❑ Development - Oil ❑-' Service - Winj ❑ Single Zane ❑' ' Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ I Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ral• Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 • KRU 1C-11 L2 3. Address: 6. Proposed Depth: _7VC, 6; &,/ 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 13,000' TVDi5; 6359' - Kupamk River Pool / 9 Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): 7. Designation: j.Z2. Surface: 1225' FNL, 637' FWL, Sec. 12, T11 N, R10E, UM ' /Property r404- Z�G 77 ADL 25638 Top of Productive Horizon: 8. DNR Approval umber: 13. Approximate Spud Date: 1324' FSL, 563' FEL, Sec. 35, T1 2N, R1 OE, UM LONS 79-016 3/27/2019 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 1768' FNL, 181' FEL, Sec. 35, T12N, R1 OE, UM 2560 5300' 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: 37'(1C -11L1) 16. Deviated wells: Kickoff depth: 10,684, feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 120 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) 31, nft- /2b8g 33 1300o 4,3s9 No Casing Planned 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' 7" 112 sx Class G 10,427' 6344' Liner 1029' 5" 112 sx Class G 11,300' 7011' Scab Liner 5108' 3-1/2" 10,271' 6231' Perforation Depth MD (ft): 10,660 - 10,716 Perforation Depth TVD (ft): 6517-6559 Hydraulic Fracture planned? Yes❑ No ❑� ' 20. Attachments: Property Plat ❑ BOP SketchDrilling Program Time v. Depth Plot Shallow Hazard Analysis g H Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements8 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: William Long ��•/�� Authorized Name: James Ohlinger Contact Email: William. R. Lon COP.COm Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4372 Date: -511 s17 Authorized Signature: Commission Use Only Permit to Drill ,CT { �f Ui� API Number: / / 2 - Permit Approval See cover letter for other Number: / 50- (� - Z��/ 7 "'�J Date: 211clrequirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane,gas hydrates, or gas contained in shales: Other: [j fJ P fit,$ f �!'f $SVY� �'o ,3500 5L Samples req'd: Yes ❑ NoLjv Mud log req'd: Yes,_❑,( No Qr HzS measures: Yes � No❑ Directional svy req'd: Yes y� No ❑J �/71i3 (/� G /� n /-< VL r7 t� �'-' ,/ PSpacing E] 140L9/ exception req'd: Yes ❑ No4/ Inclination -only svy req'd: Yes ftjr .IJ /�C SS' vYt 7b Z 57DO P5 r 7 Post initial injection MIT req'd: Yes ElNo NOF E' APPROVEDBY Approved by: COMMISSIONER THE COMMISSION Date: 11r1_ ZV.7& / Submit Form and Form 10401 Revised 512017 This er It Is IR �rrrrrJJJ'DDD,RRRt 'kOv�r t ate of approval per 20 AAC 25.005(9) Attach"gents in Duplicate p lJ- 1 \� V i A PP P _,-;& P" 3PLG Lam% 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 1 C-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-11 L2-02, 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 10403 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-11 L2-02 - Detailed Summary of Operations - Directional Plans for 1C -11L2, 1C-111-2-01, and 1C-111-2-02 - Current Wellbore Schematic - Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4372. Sincerely, William R. Long Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals - 1 C-11 L2, 1 C-111-2-01 9 & 1 C-11 L2-02 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b))...................................................................................................................2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2 S. 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)(6))..................................................................................................................................................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4 12. Evidence of Bonding......................................................................................................................4 (Requirements of 20 AAC 25.005(c)(12))..................................................................................--..........................................................4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................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-11 L2, 1C-111-2-01, & 1C-111-2-02 laterals.........................................................6 Attachment 2: Current Well Schematic for 1 C-11............................................................................................................6 Attachment 3: Proposed Well Schematic for 1C-111-2, 1C-111-2-01, & 1C-111-2-02 laterals...........................................6 Page 1 of 6 January 30, 2019 PTD 1. Well Name and Classification (Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b)) ication: 1C-111-2, 1C-111-2-01, & 1C-111-2-02 The proposed laterals described in this document are 1C -11L2, 1C -11L2-01, & 1C-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-11 L2-02. 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 Pressure] ; lC-11 au�e<k (Requirements of 20 AAC 25.005 (c)(4)) 6Ld�Kt c Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)5 s' aZ.ry The formation pressure in KRU 1 C-11 was measured at the datum to be 2615 psi (8.0 ppg EMW) on 5112/2015. 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 1 C-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 of20 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 1C-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-111-2, 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. 1C-11 L2-01 10,780' 15,800' 6486' 6609' 2-3/8", 4.7#, L-80, ST -L slotted liner; 40.0 L-80 BTC Surface 6943' 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 TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded Surface 121' Surface 121' 1640 670 Surface 9-5/8" 40.0 L-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 EUE-8rd MOD 5163' 10,271' 3496' 6231' 10,160 10,540 Tubing 3-1/2" 9.3 L-80 EUE-8rd MOD Surface 5193' Surface 3512' 10,160 10,540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: 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-11 L2-02 Pressure at the 1C-11 Window (10.684' MD, 6534' TVD) Using MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations 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. Priorto CTD rig up, the CTD liner landed in the 1C -11L1-02 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-111-2-02 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, 0.080psi/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. Priorto CTD rig up, the CTD liner landed in the 1C -11L1-02 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-111-2-02 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-11 L2, 1C-11 L2-01, & 1C-11 L2-02 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. Rig 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, 1 C-11 L2 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. 1C-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. Kick off 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 -Rig Work 1. Return to production Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via 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 AAC 25.005(c)(14)) • No annular injection on this well. - • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(6)) - 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 Distant' 1C -11L2 5300' 1 C-11 L2-01 3000' 1 C-11 L2-02 3425' - Distance to Nearest Well within Pool Lateral Name Distance Well 1 C-111-2 37' 1 C-111-1 1C-111-2-01 2784' 1C-152 1C-111-2-02 36' 1C-11 L1 16.Attachments Attachment 1: Directional Plans for 1C -11L21 1C -11L2-01, & 1C -11L2-02 laterals Attachment 2: Current Well Schematic for IC -11 Attachment 3: Proposed Well Schematic for 1C-11L2,1C-11L2-01,&1C-11L2-02laterals Page 6 of 6 March 14, 2019 'w, ConocoPhillips Pmjea: KUp,rAR"rUnfL1 Sfte: KuparuklClPad Northing VVELLSORE DETAILS: IC -11L2 R WE WOR.TM Parent W.111bnx IC -11 "ncnj.� Well: 1c-11 sno awn Tin on MD: 10495.50 veinal x'kxixe._ Mon Lo4 IC411-2 o ow 0:1 39 00.514 W n I PIAn: IC AIL 2 j..A)j1c-1Imc-11U) xana TVDSS �Npft� Icn@ no.", _.p0. TFace VSect Annotation WELL DETAILS: I C-11 +N1 -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 5969008.74 561641.06 70P 19'33.128 N 149* 39 00.514 W Sm MD Inc Azi TVDSS +N/ -S -111-IN Dleg TFace VSect Annotation I 10495.50 42.24 346.93 6292+50 7704.65 -1179S0 0.00 0.00 7704.65 TIP 2 10684.04 41.64 350.88 643214 7828.22 4204.06 1.44 104.27 7828.22 KOP 3 10709.00 45.14 350.88 6450.90 7845.18 .1206,78 14.00 0+00 7845.18 End 14 DLS, Start 42 DL 4 10811.05 88.00 350.88 6490.54 7935.49 -1221.28 42.00 0.00 7935.49 End42DLS,Stan7DU 5 11200+00 88.22 18.12 650161 8319,38 -1191.06 7.00 90.00 8319.38 5 6 11375.00 88.47 5.87 650817 8490.16 -1154.78 7.00 -89.0D 8490.16 6 7 11775.00 89.12 33.87 6517.23 8862.53 -1020.21 7.00 89.00 8862.53 7 8 12100.04 91.12 11.20 6516.53 9160.74 -896.46 7.00 45.00 9160.74 9 9 12275.00 93.21 2128 6509.90 9327.44 944.73 7.00 80,00 9327.44 10 10 12525.00 96.06 5.96 6489.55 9567.58 -782.01 7.00 .80.00 9567.58 11 11 12775.00 104.49 350+36 6444.75 9812.44 -789.44 7.00 90.00 9812.44 12 12 13000.00 120.24 350+36 6359+42 10016.93 924.19 7.00 0.00 10016.93 Planned TO at 13000.00. ElArU GHES .GE.Iaan, West( -)/East(+) (400 usiVin) NONE WPM F, 0_1111 m EUMME1110 MEN mM "mom M -INIMUM----- -womommso MAN m■ENE■SOw MEMNEEMEM■MENEE1111111M■SEE■MMmmMMmmMmM I No■ INN M MM ,fill owl West( -)/East(+) (400 usiVin) Vertical Section at 0-000 (65 mftlin) WPM F, 0_1111 m EUMME1110 MEN mM "mom M -INIMUM----- -womommso MAN m■ENE■SOw MEMNEEMEM■MENEE1111111M■SEE■MMmmMMmmMmM I No■ Vertical Section at 0-000 (65 mftlin) ConocoPhillips ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 1C Pad 1c-11 1C -11L2 Plan: 1 C-11 L2_wp03 (Draft A) Standard Planning Report 08 March, 2019 BTGE company 1W1 ConocoPhillips g ER ConocoPhillips Planning Report FUGHES aGEcompany Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit Site: Kuparuk 1C Pad Well: 1C-11 Wellbore: IC -111.2 Design: 1C-11 L2_Wp03 (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 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1C Pad 1C-11 Tum Rate Site Position: Northing: 5,968,522.46usft Latitude: 70° 19'28.285 N From: Map Easting: 562,372.05 usft Longitude: 149' 29' 39.293 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.48 ° Well 1C-11 Tum Rate Rate Well Position +N/ -S 0.00 usft Northing: 5,969,008.74 usft Latitude: 0.00 +E/ -W 0.00 usft Easting: 561,641.06 usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: Wellbore 10-1112 0.06 7.00 7.00 Magnetics Model Name Sample Date Declination (9 Dip Angle P) 7.00 BGGM2018 4/1/2019 16.71 80.88 Plan Sections 7.00 1.14 -6.93 - ii -6.24 Design 10-11 L2_wp03(Draft A)-� Audit Notes: Build Tum Rate Rate Rate ('1100usft) Version: (°/10ousft) 0.00 0.00 0.00 Phase: PLAN Vertical Section: 14.00 14.00 0.00 42.00 Depth From (TVD) +NI -S 7.00 0.06 7.00 7.00 0.14 (usft) (usft) 0.16 7.00 7.00 0.62 -6.97 -60.40 0.00 Plan Sections 7.00 1.14 -6.93 7.00 ii -6.24 Measured 7.00 0.00 h TVDIBelow -' (1 Depth Inclination Azimuth System+N/-S +EI -W (usft) (1 (1) (usft) (usft) (usft) 10,495.50 42.24 346.93 6,292.50 7,704.65 -1,179.80 10,684.00 41.64 350.88 6,432.74 7,828.22 -1,204.06 10,709.00 45.14 350.88 6,450.90 7,845.18 -1,206.78 10,811.05 88.00 350.88 6,490.54 7,935.49 -1,221.28 11,200.00 88.22 18.12 6,503.61 8,319.38 -1,191.06 11,375.00 88.47 5.87 6,508.67 8,490.16 -1,154.78 11,775.00 89.12 33.87 6,517.23 8,862.53 -1,020.21 12,100.00 91.12 11.20 6,516.53 9,160.74 -896.46 12,275.00 93.21 23.28 6,509.90 9,327.44 -844.73 12,525.00 96.06 5.96 6,489.55 9,567.58 -782.01 12,775.00 104.49 350.36 6,444.75 9,812.44 -789.44 13,000.00 120.24 350.36 6,359.42 10,016.93 -824.19 Tie On Depth: +EJ•W (usft) 0.00 70° 19' 33.128 N 149'30'0.514W 0.00 usft Field Strength (nT) 57,423 10,495.50 Direction (I 0.00 Dogleg Build Tum Rate Rate Rate ('1100usft) ('1100usft) (°/10ousft) 0.00 0.00 0.00 1.44 -0.32 2.10 14.00 14.00 0.00 42.00 42.00 0.00 7.00 0.06 7.00 7.00 0.14 -7.00 7.00 0.16 7.00 7.00 0.62 -6.97 7.00 1.19 6.90 7.00 1.14 -6.93 7.00 3.37 -6.24 7.00 7.00 0.00 TFO 0.00 104.27 0.00 0.00 90.00 -89.00 89.00 -85.00 80.00 -80.00 -60.00 0.00 Target 3/8/2019 2:40:43PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips BAKER ConocoPhillips Planning Report IGHES BAT GEmmpany Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1C-11 Company: ConocoPhillips Alaska Inc Kupawk TVD Reference: Mean Sea Level Project: Kupamk 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: IC -111.2 Design: 1 C-11 L2_wp03 (Draft A) Planned Survey T> XV r� Below Measured TVD 1' v+N/-S Vertical Dogleg Toolface Map Map Easting Depth Inclination Azimuth System +EI -W Section Rate Azimuth Northing (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100usft) (°) (usft) (usft) 10,495.50 42.24 346.93 6,292.50 7,704.65 -1,179.80 7,704.65 0.00 0.00 5,976,702.70 560,398.12 TIP 10,500.00 42.22 347.02 6,295.83 7,707.60 -1,180.48 7,707.60 1.44 104.27 5,976,705.64 560,397.42 10,600.00 41.89 349.11 6,370.08 7,773.13 -1,194.34 7,773.13 1.44 104.20 5,976,771.05 560,383.03 10,684.00 41.64 350.88 6,432.74 7,828.22 -1,204.06 7,828.22 1.44 102.65 5,976,826.06 560,372.85 KOP 10,700.00 43.88 350.68 6,444.48 7,838.95 -1,205.78 7,838.95 14.00 0.00 5,976,836.77 560,371.04 10,709.00 45.14 350.88 6,450.90 7,845.18 -1,206.78 7,845.18 14.00 0.00 5,976,842.99 560,369.99 End 14 DLS, Start 42 DLS 10,800.00 83.36 350.88 6,489.71 7,924.61 -1,219.53 7,924.61 42.00 0.00 5,976,922.31 560,356.59 10,811.05 88.00 350.88 6,490.54 7,935.49 -1,221.28 7,935.49 42.00 0.00 5,976,933.17 560,354.75 End 42 OILS, Start 7 DLS 10,900.00 88.01 357.11 6,493.64 8,023.85 -1,230.58 8,023.85 7.00 90.00 5,977,021.45 560,344.73 11,000.00 88.05 4.11 6,497.08 8,123.73 -1,229.51 8,123.73 7.00 89.78 5,977,121.32 560,344.98 11,100.00 88.12 11.12 6,500.42 8,222.73 -1,216.27 8,222.73 7.00 89.54 5,977,220.41 560,357.41 11,200.00 88.22 18.12 6,503.61 8,319.38 -1,191.06 8,319.38 7.00 89.31 5,977,317.26 560,381.82 5 11,300.00 88.36 11.12 6,506.60 8,416.04 -1,165.85 8,416.04 7.00 -89.00 5,977,414.12 560,406.23 11,375.00 88.47 5.87 6,508.67 8,490.16 -1,154.78 8,490.16 7.00 -88.79 5,977,488.32 560,416.69 6 11,400.00 88.51 7.62 6,509.33 8,514.98 -1,151.84 8,514.98 7.00 89.00 5,977,513.16 560,419.42 11,500.00 88.64 14.62 6,511.82 8,613.01 -1,132.57 8,613.01 7.00 88.95 5,977,611.33 560,437.88 11,600.00 88.80 21.62 6,514.05 8,707.97 -1,101.50 8,707.97 7.00 88.78 5,977,706.54 560,468.17 11,700.00 88.98 28.62 6,515.99 8,798.44 -1,059.09 8,798.44 7.00 88.62 5,977,797.34 560,509.84 11,775.00 89.12 33.87 6,517.23 8,862.53 -1,020.21 8,862.53 7.00 88.49 5,977,861.74 560,548.19 7 11,800.00 89.28 32.12 6,517.58 8,883.50 -1,006.59 8,883.50 7.00 -85.00 5,977,882.82 560,561.63 11,900.00 89.89 25.15 6,518.31 8,971.21 -958.70 8,971.21 7.00 -84.98 5,977,970.91 560,608.80 12,000.00 90.51 18.18 6,517.96 9,064.09 -921.80 9,064.09 7.00 -84.92 5,978,064.08 560,644.92 12,100.00 91.12 11.20 6,516.53 9,160.74 -896.46 9,160.74 7.00 -84.95 5,978,160.93 560,669.47 9 12,200.00 92.33 18.10 6,513.52 9,257.39 -871.19 9,257.39 7.00 80.00 5,978,257.78 560,693.94 12,275.00 93.21 23.28 6,509.90 9,327.44 -844.73 9,327.44 7.00 80.21 5,978,328.04 560,719.82 10 12,300.00 93.51 21.56 6,508.43 9,350.51 -835.21 9,350.51 7.00 -80.00 5,978,351.18 560,729.15 12,400.00 94.69 14.64 6,501.28 9,445.26 -804.24 9,445.26 7.00 -80.10 5,978,446.17 560,759.33 12,500.00 95.79 7.70 6,492.13 9,542.90 -784.96 9,542.90 7.00 -80.60 5,978,543.95 560,777.81 12,525.00 96.06 5.96 6,489.55 9,567.58 -782.01 9,567.58 7.00 -81.23 5,978,568.66 560,780.56 11 12,600.00 98.66 1.36 6,479.94 9,641.79 -777.25 9,641.79 7.00 -60.00 5,978,642.90 560,784.71 12,700.00 102.04 355.13 6,461.96 9,740.05 -780.23 9,740.05 7.00 -60.59 5,978,741.12 560,780.92 12,775.00 104.49 350.36 6,444.75 9,812.44 -789.44 9,812.44 7.00 -61.71 5,978,813.42 560,771.13 12 12,800.00 106.24 350.36 6,438.13 9,836.20 -793.47 9,836.20 7.00 0.00 5,978,837.15 560,766.89 12,900.00 113.24 350.36 6,404.38 9,928.94 -809.23 9,928.94 7.00 0.00 5,978,929.75 560,750.37 13,000.00 120.24 350.36 6,359.42 10,016.93 -824.19 10,016.93 7.00 0.00 5,979,017.60 560,734.70 Planned TD at 13000.00 318/2019 2:40:43PM Page 3 COMPASS 5000.14 Build 85D �. ConocoPhillips ConocoPhillips Planning Report Database: EDT 14 Alaska Production Local Co-ordlnate Reference: Company: ConocoPhillips Alaska Inc_Kuparuk TVD Reference: Project: Kupawk River Unit MD Reference: Site: Kuparuk 1C Pad North Reference: Well: 1C-11 Survey Calculation Method: Wellbore: IC -111.2 10,709.00 Design: 1C-11 L2_wp03 (Draft A) -1,206.78 Plan Annotations Measured Casing Points Local Coordinates Measured Vertical Depth Depth (usft) (usft) Name 13,000.00 6,359.42 2 3/8" Plan Annotations Measured Vertical Local Coordinates Depth Depth +N1S +E/ -W (usft) (usft) (usft) (usft) 10,495.50 6,292.50 7,704.65 -1,179.80 10,684.00 6,432.74 7,828.22 -1,204.06 10,709.00 6,450.90 7,845.18 -1,206.78 10,811.05 6,490.54 7,935.49 -1,221.28 11,200.00 6,503.61 8,319.38 -1,191.06 11,375.00 6,508.67 8,490.16 -1,154.78 11,775.00 6,517.23 8,862.53 -1,020.21 12,100.00 6,516.53 9,160.74 -896.46 12,275.00 6,509.90 9,327.44 -844.73 12,525.00 6,489.55 9,567.58 -782.01 12,775.00 6,444.75 9,812.44 -789.44 13,000.00 6,359.42 10,016.93 -824.19 Comment Well 1C-1 t Mean Sea Level IC -11 @ 102.00usft(1C-11) True Minimum Curvature TIP KOP End 14 DLS, Start 42 DLS End 42 DLS, Start 7 DLS 5 6 7 9 10 11 12 Planned TD at 13000.00 B F�UGHES a GE company Casing Hole Diameter Diameter (in) (in) 2.375 3.000 318/2019 2:40:43PM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips BA_ ICER ConocoPhillips Anticollision Report F� IGHES BAT GEcompany Company: ConocoPhillips Alaska Inc Kuparuk Project: Kuparuk River Unit -1 Reference Site: Kupamk 1C Pad Site Error: 0.00 usft Reference Well: 1C-11 Well Error: 0.00 usft Reference Wellbore 1C-111-2 Reference Design: 1 C-11 L2_wp03 (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 1C-11 @ 102.00usft(1 C-11) 1C-11 @ 102.00usft(1C-11) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Reference 1C-11L2_wpO3(Draft A) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering Criteria Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 10,495.50 to 13,000.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,495.84 usft Error Surface: Combined Pedal Curve Wareing Levels Evaluated at: 2.79 Sigma Casing Method: Added to Error Values Survey Tool Program Date 3/7/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description 121.00 10,495.50 1C-11 (1C-11) MWD MWD- Standard 10.495.50 13,000.00 1C-11 1-2_wpW(Dmft A)(1C-111-2) MWD MWD - Standard Summary Kuparuk 1C Pad - 1C-11 - 1C-11 - 1C-11 Reference Offset Distance Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well - Wellbore - Design (usftl (usft) lush) (usft) Dismnce Kuparuk 1C Pad Measuretl Venial Measured Venlcal 1C-11 - 1C-11 -1 C-11 10,800.72 10,825.00 49.01 46.92 23.450 CC, ES, SF 1C-11 - 1C-111-1 - 1C-1111 10,807.59 10,825.00 36.85 33.59 11.317 CC, ES 1C -11 -1C -1111-1C-111-1 10,887.32 10,925.00 70.45 59.16 6.239 SF 1C -11-1C-11 L1 -01-1C-111-1-01 10,807.59 10,825.00 36.85 33.59 11.317 CC, ES 1C -11-1C-11 L1 -01-1C-111-1-01 10,887.32 10,925.00 70.45 59.16 6.239 SF 1C -11-1C-11 L1-02-1C-11Ll-02 10,807.59 10,825.00 36.85 33.59 11.318 CC, ES 1C -11 -1C -111-1-02-1C-1111-02 10,887.32 10,925.00 70.45 59.16 6.239 SF 1C-11 - 1C-111-2-01 - 1C-111-2-01_wp02 (Draft A) 12,735.49 12,750.00 55.39 44.03 4.878 CC, ES, SF IC -11 - IC -111-2-02 - 1C-11 L2-02_wp02 (Draft A) 10.525.00 6,416.36 0.39 0.53 Out of range IC -151 - 1C-151 - 1 C-151 -1,184.18 0.00 -1.20 1.20 Out of range 1 C-152 - 1 C-152 - 1 C-152 6,434.91 10.55000 8,434.91 012 Out of range Offset Design Kuparuk 1C Pad - 1C-11 - 1C-11 - 1C-11 offset site Eirm, o.99veft survey Program: 121 -MWD Offset WellEnar: 0.00 vett Reference Onset Saml MalorAale Dismnce Measuretl Venial Measured Venlcal Reference Offset Atmuth Offset Wellbore Centre Between eetween Minimum Separation Waming Depth Depth Depth Depth tram NOM eN1S +EMV centres Ellipses Separation Factor fast) (ueft) lust) (usft) (van) lush) PI (usft) (usft) fusel /usft) )maxi 10,50000 6,397.83 10.500.00 6,397.83 0.05 008 -10984 7,707.60 -1,180.48 000 -0.47 047 0.000 STOP Dding 10,525.00 6,416.36 10.525.00 6,416.36 0.39 0.53 -120.97 7,723.97 -1,184.18 0.00 -1.20 1.20 0.000 STOP Dnlling 10,55000 6,434.91 10.55000 8,434.91 012 0.98 -128.43 7,740.35 -0,187]2 0.00 -1.85 1.85 0.001 STOP Drilling 10,57500 6,453.48 10,575.00 6,453.48 1.05 1.42 -133.02 7.756.74 -1,191.11 0.00 -2.46 2.46 0.001 STOP Odin, 10,600.00 6,472.08 10,600.00 6,47208 1.37 1.87 -136.07 7,A3.13 -1,194.34 Ow 4.03 3.03 0.001 STOP dieing 10,62500 6,490.70 10,625.00 6490.70 1.70 2.32 -130.22 7,789.52 -1,197.42 000 -3.59 3.59 0.001 STOP Dnlling 10,650.00 6,509.35 10,650.00 6,509.35 2.03 2.77 -139.79 7,805.92 -1,200.34 0.01 4.13 4.13 0.001 STOP Drilling 10,675.00 6,520.03 10,675.00 6,528.02 2.36 3.21 32.75 7,822.32 -1,203.11 0.02 -2.69 2.71 0.007 STOP Drilling 10,700.00 6.546.51 10,700.00 15,546.70 2.70 3.66 169.24 7,838.71 -1,205.74 0.28 -1.66 1.94 0.145 STOP billing 10,724.66 6,563.29 10,725.00 6,565.41 3.08 4.10 170.88 7,855.08 -1,208.37 2.71 0.75 1.95 1.386 Take Immediate Adion 10,747.81 6,57602 10,750.00 6,584.14 3,44 4.54 171.22 7,871.43 -1,211.05 9.24 7.18 2.06 4,493 10,768.43 6,584.48 10,77500 6,602.89 3.81 4.98 171.34 7,887.74 -1,213.77 19.59 17.48 2.11 9.285 10,786.12 8,589.40 %8W.00 8,621.68 4.15 5.42 171.41 7,904.01 -1,216.54 33.04 30.92 2.12 15.599 10,800]2 6,591.72 10,825.00 6,640.46 4.43 5.86 171.21 7,920.26 -1,219.34 49.01 46.92 2.09 23.450 CC, ES, SF 10,814.80 6,592.72 10,850.00 6,659.27 4.71 6.30 171.63 7.938.47 -1,222.19 66.61 64.50 2.10 31.646 10.831.55 6,593.25 10.875.00 6.678.11 504 6.74 173.14 7,952.66 -1.225.09 84.91 82.89 2.22 38.212 CC - Min centre to center distance or covergent point, SF- min separation factor, ES - min ellipse separation 3!72019 2:57:02PM Page 2 COMPASS 5000.14 Build 85D Conocg ;hillipS PM)DO: Kupauk Rha Unlit She: KupemklC Pad Azslablvxen a.erkxmm-rmr uyre+ee WELLBOREDUAILS: IC -111.2 RERERENLE BioRlmna IC -1 Parent Wel bora: 1C41 idl coal4kxk Mol Retammw: w.n tt-n,iMxom Welk 1C-11 a..y6s+anari T"I MD' 0 9err0wlReluoxa 1G11®1020NYIItGn1 siGla-1- WONW,:IC-111.2 AlCtl 1N®mt@x=(C-011 kNeNm: Pbn:1C-111.2_Wp0.(DraflA)(iC-11/1C-111.21 uoee.5uobm eOkublromR MmmwnCwaWe in-Imm-1. IIIimil-I 51.1 I9-IMB-10 B F UGHES GEmmpa,,v 14850 14900 13950- a 1 I 13950. In-IL111-I) - _ I IIIS-01 ; : .. I11 -11lJIIr 116 111-IIYln-113 1(:-11/IG a m i 12150-. g nulnu 1 o:.n nn vo I 111-)1/111 )IAI+LI - - ^� "Sao III-IW111 IOa1R1 g 11250- -- j VaWII�I, `rtr, uoluwnl-19x6 Q i, 1121/lll-ZIA1.± _ � e'1j t 10350'. .( M � $ Iii-IL111-1'S 6161 161Y/el.,> c-IamG 19 + 3516'. IL' I WIf O 945U- - IC mWw mxn IC-IIIIC 1111 : z AC4'1 "'Sa IL-uyll'tsf 9C00 ICU IC 152 IfSIAM8Y\ 9 8350- 1 I1- �— 369% , le9'+ Ir lsSr1.11 G ryat5 .nnc u u:-I+alaw4 arvlr„wx 101 BIOD 3+9Y — — /� 7650 1( 1NIrp Int 1 l5 ex 4*3 111 unc w w uml _ �- 67So- 1[. I+ncv µg VI[nnrr la-. .WyNI 6300Wk :'161 Vntl91 6i� �ICa"/lli-0Anm. _� In -Imran ion 1 �� ` ypp \, �• _ _ 5 _ \ arncor Ir lkalrm Ir lwlr l9 � 4950- -7650 -T200 fi750 N00 -5850 -5400 4950 4500 JO50 -3600 -3150 -T100 -2250 -1800 -1350 900 450 0 450 900 I350 ISM 2250 VW 3150 3600 4050 4500 4950 5400 5850 6300 67500 nM W1st(-1/R.est(+l.(450 aa0/inl Ice+nco+A 1611 ®102.00uaR (1C -t1) 1C -11L1, U-01, L1-02 Actual CTD Sidetrack V-� Update: 07/27109 ConocoPhillips Alaska 10,244'on top MD 7" 26# L-80 shoe 10,427'MD Csand pads (sgz'd) 10,660'- 10,716 MD :er 3.5"x5" TTWS at 10,747'MD set 15 deg LOHS-2.80" Window Fait Fish at 0,990' (failed IBP) 5", 18# L-80 liner at 10,271'- 11,300' MD ZXP liner -top packer at 10,271' Hole in 7" casing at 5466' MD (5/26108) = 1.71" Il packet 1.68" /8" liner segment at 10,884' ID = 1.00" Camco TRMAXX-5E SCSSV @ 2297' MD Minimum ID = 2.813"(X -profile) Camco KBMG gas lift mandrels Q 3194', 4217', 5118' 9.3# L-80 EUE 8rd Tubing to surface BO -40 seal assembly @ 5172' MD muleshoe at 5193' MD Scab Liner (5163'-10271'MD FHL Retdevable packer at 5203' MD Baker Premier packer at 10,149' MD D -nipple at 10,189' MD Milled out to 2.80" (4/4109) Behind 2.3/8" Liner& Linerfoo Packer 5.75" OD Locator at 10,259' MD Muleshoe Jnt at 10,260-10,266' MD, inside of 5.25" ID tieback ID=4,40",OD=5.2" Fish - 8040 Seal Assembly, 10266'- 10313'(5125/2008) Length = 46.55', ID = 3.00" Muleshoe at 10,313' MD IC -1111-1-02:11,407'- 13,031' MD 2-318"liner 10,248'-13,DW' slotted 11,386'- 12,992' / l(: -1l Ll-0l:ll,/JU"-1L,C/D'MU /�� 2-3/B"liner 11,407'-11,802' anchor billet at 71,40] MD q� 1C18"lin r11,75 - 13,386 1 2-3/8'linef 11,750'-13,369' aluminum billet at 11,750' MD 1C-11 Proposed CTD Schematic M/8"409 L-80 shoe 6943' MD 7" 26# L-80 shoe 10,427' MO FOP 10,684' MO c Baker3.5"x5"TTWS — : c C -sand peels (sgYd) sa 10,660'- 10,716' MD 1/8" R -Nipple at 10725' MD = 1.71" ter 3.5" x 5" TTWS at 10,747' MD set 15 deg LOHS - 2.80" W ndow Exit 5", 18# L-801iner at 10,271' -11,300' MD ZXP liner -top packer at 10,271' F—J Hole in 7" casing at WIT MD (5/26/08) Updated: 13 -Mar -2019 WRL -1/2" Camco TRMAXXSE SCSSV ® 2297' MD Minimum ID = 2.813" (X -profile) -1/2" Camoo KBMG gas lift mandrels 0 3194',4217'. 5118' -1/2" 9.3# L-80 EUE Brd Tubing to surface taker 80-00 seal assemblyY 5172' MD -1/2" muleshoe at 5193' M[� -1/2" Scab Line�163�'-10271' MDQ taker FHleva a Dahl clear x15203' MD taker Premier packer at 10,149' MD 1 -nipple at 10,189' MD Milled out to 2.80" (414/09) 1C -11L2 Plan TD: 13,000' MO Top of Billet: 12.490' MD , inside of 5.25" ID tieback sleeve 10313'(5/25/2008) 1C-PIL2-01 Plan TD: 15,600 MD Top of Billet 10,780' MD 1C-111.2-02 Plan TD: 15,600' MD Top of Liner: 10,600' MD 11,407' -13,031' 1C-111.1-01: 11,750'- 12.875'MD 2-3/8" liner 11.407' - 11,602' anchor billet at 11,407' MD 1C.11L1: 10,750' -13,385' MD 2-3/8" liner 11,750'- 13,369' aluminum billet at 11,750' MD Remark: AOGCC PTD No. 219-041 Coordinate Check 21 March 2019 INPUT Geographic, NAD27 KRU 1C-1 I L2 Latitude: 70 19 33.12800 Longitude: 149 30 00.51400 OUTPUT State Plane, NAD27 5004 -Alaska 4, U.S. Feet v1 NorthingfY: 5969008.776 Easting/X: 561641.064 Convergence: 0 28 14.44165 Scale Factor: 0.999904316 Corpscon v6.0.1, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: g.at / (�— / / L– Z PTD: .2-1? – b �// / Development _ Service _ Exploratory Stratigraphic Test _ Non -Conventional FIELD:nct.�, t.–s—c POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER / MULTI LATERAL The permit is for a new wellbore segment of existing well Permit No. 7Z , API No. 50-� %� -CaCi -L–D.(If last two digits Production should continue to be reported as'a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_- from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company–Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sam le intervals throw 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 l in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 PTD#. 2190410 Company CONOCOPHILLIPS ALASKA, INC. _ _ Initial Class/Type Well Name: KUPARUK RI_V UNIT 1C_11L2 Program DEV Well bore seg DEV/ PEND-- GeoArea 890 Unit 11M0._ On/Off Shore On _ Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31 05.0300.1.A),(j.2.A-D) NA. . . 1 Permit fee attached _ NA 2 Lease number appropriate. Yes Surface location in ADL025649; top prod interval & TD in ADL025638.. 3 Unique well name and number _ Yes 4 Well located in a defined pool Yes Kuparuk River Oil Pool, governed by Conservation Order No. 432D _ 5 Well located proper distance from drilling unit. boundary Yes Conservation Order No. 432D has no interwell.spacing restrictions. Wellbore will be more than 500' 6 Well located proper distance from other wells.. _ Yes from an external property line. where ownership or landownership changes. 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 114mile 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 known 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 open. hole_ 23 Casing designs adequate for C, T B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all wasteto approved disposal wells. 25 If a. re -drill, has. a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations_ _ NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is 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 112S gas probable Yes 112S 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 1 CA 1 measured 52 ppm. H28 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 coiled -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 NOTE: Chance of encountering free gas while drilling due to gas injection performed in this area. Commissioner: Date: Commissioner: Dat Commissioner Date
