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219-043
DATA SUBMITTAL COMPLIANCE REPORT 8/5/2019 Permit to Drill 2190430 Well Name/No. KUPARUK RIV UNIT 1C -11L2-02 Operator ConocoPhillips Alaska, Inc. API No. 50-029-22714-65-00 MD 15201 TVD 6579 Completion Date 4/2812019 Completion Status 1-0I1- CurrentStatus 1-0I1- UIC No REQUIRED INFORMATION Mud Log No,/ Samples No v Directional Survey Yes z 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/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 30794 Digital Data 5/17/2019 Electronic File: 1C -11L2-02 EOW - NAD27.pdf ED C 30794 Digital Data 5/17/2019 Electronic File: 1C-111-2-02 EOW - NAD27.txt ED C 30794 Digital Data 5/17/2019 Electronic File: 1C-111-2-02 EOW NAD83.pdf ED C 30794 Digital Data 5/17/2019 Electronic File: 1C-111-2-02 EOW NAD83.txt Log C 30794 Log Header Scans 0 0 2190430 KUPARUK RIV UNIT 1C-111-2-02 LOG HEADERS ED C 30800 Digital Data 10408 15188 5/20/2019 Electronic Data Set, Filename: 1C-111-2-02 GAMMA RES.Ias ED C 30800 Digital Data 5/20/2019 Electronic File: 1C-111-2-02_2MD Final.cgm ED C 30800 Digital Data 5/20/2019 Electronic File: 1C-111-2-02_51VID Final.cgm ED C 30800 Digital Data 5/20/2019 Electronic File: 1C-111-2-02_5TVD Final.cgm ED C 30800 Digital Data 5/20/2019 Electronic File: 1C-11L2-02_2MD Final.pdf ED C 30800 Digital Data 5/20/2019 Electronic File: 1C-111-2-02_5MD Final.pdf ED C 30800 Digital Data 5/20/2019 Electronic File: 1C-llL2-O2_5TVD Final.pdf ED C 30800 Digital Data 5/20/2019 Electronic File: 1C-111-2-02 EOW - NAD27.pdf ED C 30800 Digital Data 5/20/2019 Electronic File: 1C-111-2-02 EOW - NA027.txt ED C 30800 Digital Data 5/20/2019 Electronic File: 1C-111-2-02 Final Surveys TO 15201.csv ED C 30800 Digital Data 5/20/2019 Electronic File: 1C-111-2-02 Final Surveys TO 15201.xlsx ED C 30800 Digital Data 5/20/2019 Electronic File: 1C-111-2- 02_25_tapescan_BH I_CTK.txt AOGCC Pagel of 3 Monday, August 5, 2019 DATA SUBMITTAL COMPLIANCE REPORT 8/5/2019 Permit to Drill 2190430 Well Name/No. KUPARUK RIV UNIT 1C -11L2-02 Operator ConocoPhillips Alaska, Inc. MD 15201 TVD 6579 Completion Date 4/28/2019 ED C 30800 Digital Data ED C 30800 Digital Data ED C 30800 Digital Data ED C 30800 Digital Data ED C 30800 Digital Data Log C 30800 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report &Y Production Test Informatio&/ NA Geologic Markers/Tops (2 COMPLIANCE HISTORY Completion Date: 4/28/2019 Release Date: 3/27/2019 Description Interval Start Stop Directional / Inclination Data (2 Completion Status 1 -OIL Mechanical Integrity Test Information Y / NA Daily Operations Summary O Date Comments 0 0 API No. 50-029-22714-65-00 Current Status 1 -OIL UIC No 5/20/2019 Electronic File: 1C-11L2- 02_5_tapescan_BHI CTK.txt 5/20/2019 Electronic File: 1C-111-2-02_output.tap 5/20/2019 Electronic File: 1C-11 L2-O2_2MD Final.tif 5/20/2019 Electronic File: 1C-11 L2-02 5MD Final.tif 5/20/2019 Electronic File: 1C -11L2-02 5TVD Final.tif 2190430 KUPARUK RIV UNIT 1C-111-2-02 LOG HEADERS Sample Set Sent Received Number Comments Mud Logs, Image Files, Digital Data Y / CA Composite Logs, Image, Data Files D Cuttings Samples Y / FA Core Chips Y leg Core Photographs Y /6) Laboratory Analyses Y IQ Comments: Compliance Reviewed By: _ Date: AOGCC Page 2 of 3 Monday, August 5, 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED 14AY 2 8 2019 WELL COMPLETION OR RECOMPLETION REPORT AND 1a. Well Status: Oil ❑Q Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b. Well Class: 20MC 25.105 20AAC 25.110 Development Ej Exploratory ❑ GINJ❑ WINJ❑ WAGE] WDSPL❑ No. of Completions: Service❑ Stratigraphic Test El 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Abend.: 412812019 219-043 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 4/18/2019 50-029-22714.65.00 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 1225' FNL, 637' FWL, Sec 12, T71N, R10E, UM - 4/24/2019 KRU 1C-111-2-02 Top of Productive Interval: 9. Ref Elevations: KB:102 17. Field / Pool(s): 1365' FSL, 569' FEL, Sec 35, T12N, R10E, UM ' GL: 59 r BF: Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD1)VD: 18. Property Designation: 2164' FNL, 1999' FWL, Sec 36, T12N, R10E. UM N/A ADL 25638, ADL 25649 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 561641 y- 5969009 -' Zone -4 15201/6579 LONS 79-016 TPI: x- 560366 y- 5976868 Zone -4 12. SSSV Depth MO/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 562918 y- 5978639 Zone -4 2297/1994 1993/1802 5. Directional or Inclination Survey: Yes ❑Q (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 NIA (ft MSL) 1074216574 ' 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD HOLE SIZE CEMENTING RECORD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 41 121 41 121 24 257sx AS 1 9.625 40 L-80 42 6945 42 4440 12.25 775sx AS III, 710sx Class G, 7 26 L-80 28 10466 28 6372 8.5 112sx Class G 5 18 L-80 10279 11300 6566 6605 6,125 11 2s Class G 31/2 9.3 L-80 5163 10271 3496 6231 Scab Liner 23/8 4.6 L-80 10238 15188 6208 6582 3 Slotted Liner 24. Open to production or injection? Yes Ej No ❑ 25. TUBING RECORD SIZE DEPTH SET (MO) PACKER SET (MD/TVD) If Yes, list each interval open (MDRVD of Top and Bottom; Perforation Size and Number; Date Perfd): 3 112 5193 1 5203/3518 Slotted Liner@ 1 10141/6143 10239.15188 MD and 6208-6582 TVD.... 4/28/2019 COMPLETION DAT 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No Q 1 VRIFIE Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEP TH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED �/ D 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 51612019 GAS LIFT Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water-Bbl:Choke Size: Gas -Oil Ratio: 5/8/2018 5hrs Test Period 474.2 739 1 960 1 176 1 1559 Flow Tubing Press. 3139 SI Casino Press: 1350 Calculated 24 -Hour Rate Oil -Bbl: 2276 Gas -MCF: 3547 Water -Bbl: 1 4-- Oil Gravity- API (corr): 1 22.6 Form 10-407 Revised 5/2017 V7-16/�f//OG, CONTINUED ON PAGE 2 RBDMS.l.11=" MAY 3 0 209 Submit ORIGINAL only. /K 'tip( gs rwocr l/a 28. CORE DATA Conventional Core(s): Yes ❑ No ❑Q Sidewall Cores: Yes ❑ No ❑Q If Yes, list formations and intervals cored (MD/TVD, Fromlro), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑Q If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1993 1802 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk C 10742 6574 TD 15201 6579 Formation at total depth: 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, paleontolouical report, production or well test results. per 20 AAC 25,070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: William Lon Authorized Title: Staff CTD Engineer Contact Email: William.R.Long0cop.com Authorized„ //� Contact Phone: 263-4372 Signature: Date: /? INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item i 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 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only IC -11 Final CTD Schematic QM3'MD Fr-"- -L-3-0.7@1 L„ 110.42rMD l encM1or OtllN eltUOr MD 10,@&'MD Mg 2-:1-:0.6-M 3Sv Aa!f!B , caws W __ ______-� 10,@BJ'-1@,T1@ MD 0,71& M t 10,?;w MG wk at t0Jx5' MD r, 922E-xo llwrac+o,xn•-+>,3orc xw 2XP Ilwrlop vwxennn.nr Hok mT wtlry zt 61W'MD(5R&9d) mn+u . 1of &Ik[tt 2AW'MD 050'.0 To Updated: t-May-M19ML almal E avgr MD Mara. He=Z313V,.r C— KBMG gas MI IIMMrels Q 3194'. 4217'. 5110' 9U"0 EUE WTU g zurlaw for rmaka. MI i5,4ad TD:r TV MD user TOv @IIMt+o,341 MO gknx LMe[ m.mr-tx.ns M.[I n -Hoax m:+E.101'MD @OYam 01LL 10 95,9x@ MD Tp'oLka. 10.20@MD ® jErl"1at H,T5@-12,2 tt.0 2ST Ilm'+t90"tt, 0x' encM1or OtllN eltUOr MD FMM1 COAs __ ______-� +CJtL1'. 10,Ts0-txsx@Me 2.918'= 11.>5V -t3,%9 elmrinum WkbH1,T5V M0 CfmocoPhillips Alaska. Inn, WELLNAME 1C-11 WELLBORE IC -11 rcmu ig i2]83]PM Last Tag Vaeld e[hmetic(mani Annatemonnepin lRKB) 1 End Data WNI1pr¢ Last Mod By Last Tag:SLM it 0,9000 I.L. larpon, Last Rev Reason HANGER I X7 Annotation EM Oab Weothom Last Mad By ........................................................ .. ............... Rev Reason: Replaced OV 5/12019 1G-11 lzenuarej Casing Strings (WB) II.. Grade T.PT111W Deanna Description (in) nlanl TopmNBl 51, wplh(WBI SN De 10D CONDUCTOR 16 15.06 41.0 121.0 121.0 62.50 HJO WELDED CONOVCTOR; <IPI310 Doing wseriptWn OD find Ratio Top Mi So Depth hi ant Depth (100T-WtlLm 9.. Gmom TOp T11 Red SURFACE 9518 8.53 42.3 69452 4,439.9 4000 LA0 BT&C GaNg o"a"iWn Do(inl 10 M1 TOP hKal Sen Depth IKKEu get Dean LVLR. WbLen g... Grab Top Thrted PRODUCTION 7 6.28 282 104658 63726 26.00 L-80 BTCM casing DominanceOD(in) (in) Top RMIN set DepO(flke) ge[Dean rival W�Lan(L_(rNe TepTnwd 110 LINER 5 4.15 10,2794 11,3000 ],010] 1800 LA0 LTC I-Iner Details SAFETYVLV: 2.1i NOmmal m lop MB)Tov RVb)MKeI TOP ln[I IN Hem wB Ever lin) 10,09 .4 6,236.5 45. HAN ER BAKER 5"WY LINER HANGER & PACKER 5.003 GuuFT: Slips WIPACKER 1030321 6,253.4 1 4492 PBR BAKER PBR 4.000 LesNp DeFCllalon OB Ilnl I011n) TdpglHe) SN Dean lI1KB1 aM OanM (1001... WYlen 11... Glade Top Tn,esi Des uFT:4.zrz4 WINDOW LI A2 5 4.00 10,]50.0 10,]5].0 8,589.0 2fi.00 LA0 LnMg Davclipliwt 3.5"SCAB LINER 00(n) 3112 Ib9n) 2.99 Top 1X1061 5,1633 .wan IHKBI 10,01.0 BM DpM INO).. 8,230,6 WULen fi-frook 9.30 L-80 TOP In. EUESrdABM OR GABl1R;1.1175 Liner Details Nominal to Tap(XNB) Top( oBMIKB) TopinclM dem Den Com (In) 5,163.3 3,496.3 57.33 SLEEVE HE Liner Setting Sleeve 4420 LocnTOR; s.1mz 5,10.] 3,504.1 5].34 TO BUSHING XOver Bushing 4.250 5,1789 3,504.] 57.34 SBE 80-40 Seal Bore EkTenYOn 4.000 SEAL; 5.1725 5,14F2 3,515.1 57.35 NO BUSHING Xomr Bushing 2.990 52029 3,517.7 57.35 PACKER FHL Retrievable Packer 2.992 AL1409 6,142.8 4926 PACKER Baker Premier Peaducdon Packer 2.870 10,1890 6,174.5 48.06 NIPPLE 2750'Nipple - MILLED TO 2.80 4142009 2.800 102620 1 45.80 NIPPLE Fluted NGIGO 3.000 Tubing Strings mdmg De'inquiron shmg tri ud rop IND set DepM (d_ an, no in (NO) (-IM Dma¢ Top connection JID TUBING 3112 2.99 367 5,193.0 3512.3 930 LA0 EUE&IMMOD Completion Details TopjNDI Topind Nommen Tepeas.) aft ' P) INm on, Com SURFACE, 4zc M2 361 367 000 HANGER Tubing Hanger 6"x35""ISA"BPVG 2.992 $2974 1,9941 1 54.61 SAFETY VLV TRMAXX W/2813" X -Profile 2.812 5,1702 3.5000 5]34 LOCATOR BAKER LOCATOR val 106 space out 3.999 5,1725 3.5012 57 34 SEAL BAKER 8040 SEAL ASSEMBLY 3.999 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top(m(B) Top(NDI Minn 1, -; (') one corn Run Deft ID (in) LINER Ic-LL2pQ: 1aa].9- 'Ems.. 10,237,0 6.2070 4656 2 31 "CID CTO 2 31 ' Lirler, lined back up Into Ne parent Liner. QW019 LINER Too@10,23T MD 10268.0 6,20.1 4567 SEALASSY III SEALASSEMBLY, OAL 46,55 -sea parted 51252008 3000 Mom it was plugged into 5- liner (see punched dmxfng) -770- 10,01.0 6.2306 45.50 PBR Baker GBH -0 TUT= 6 GSSCABUNER:5n89.% 10,321.0 6,2662 4382 SHOE MULESHOE-has 4.4' ID, causing lip at the lop of FISH I 4.000 10,2]10 6 SEAL nSar. lo,MIO 10,684.0 6,534.] 4164 WHIPSTOCK Sed Baker Whipstock on Rig (CCRILI 2161. Set @ 41612019 D legs (high side) 10,]4].0 6,5819 4145 WHIPSTOCK IMAKERGEN II WNW, RI LEFT 5112009 2.5 OF HIGH SIDE, 173' DAL 10,]80.0 Qfi06.6 41.36 FISH Sed 216" Baker MR in 5.liner; rated 3600 psi; fishing 42012008 0.000 23e' CTO LINER: Mai PRODDCnM..M2-10.4 8 I 1 neck 1 375" OD; 5500r release pull- moved to 10780 CTMD 621108 Perforations & Slots snot Dann RPERF: 10.BJ pri0.a (PERF: 10.6]0.D1o.T10 .,.KZkOa0 Top(.) achroa) TOP(Nn) POKE) BIMIN3) fimta UnYq Zone DaN Isho ) Typ Com 10,660.0 10,6700 65168 6524.3 G41G11 61192008 6.0 RPERF .5"H D H Deg phage 10,670.0 10.716.0 6.524.3 6,5587 C4,C-3,1C-11 111411997 2.0 (PERF Zero tleg. Phasing', Ene0e1 Frac Summary SWI Daft Prappanlonigned(m) empgMln Farmtliondi LINER I0-111.102. IQTII6 1No-r0 6AXI2008 WWPsi0CK 10.]0.0 WINWWLI@tg7470 1oTn.O g y gmrtwN Tap CeahlhKe) IntoMO)Lln¢b FluMsnftm VoICImn(BMI Vd6Wrry@ng M 1 62012008 106609 10)180 Mandrel Inserts FIS1;IeMk0 st alt HTop (ND) VWe Latch PONIED& TRORun Tap ME) IM(B) Maine Model Dean) Sere Tate Than (n) and Mn INN Com Ot 1 .9 2,4721 Camco KBMG 1 Gas Lit GLV BK 0.188 1, JJ. YT]2019 4,217.4 2,992.9 Camm KBMG 1 Gas Lit JOV IBK 0250 Y177 019 3 5,117.5 3,471.6 Cameo KBMG 1 Gas Lit DMY BK D.DDO .0 5/12019 A Pkg NMas: General & Safety Ena we Mnodnwn 4/3/2008 NOTE: SWS LDL INDICATES IBP @ 10,385 LEAKING FROM BELOW LINER: 1a2fikNll30]0 KUP PROD WELLNAME 1C-11 WELLBORE 1C-11 ConocoPhiiiip5 Alaska. elc. & roti, E12N19191216WPM Notes: General d Safety vxmlxJ+mBc(cNll Ene Ozle AnnWlon ...............__.___.........................__............................... 51262008 NOTE: HOLE IN I- CASINO LO 5466' MD NPNGER; 3e] 6MI2008 NOTE: NEW 3.5"TBG INSERTED INTO 35' SCAB LINER @102]2' ...........---..... ""----"' 61162008 NOTE: VIEW SCHEMATI W Ala9ka S9h0m81ic9.0REV 11/520 NOTE: Recovered severely ¢masa OV p S11T, GLM likely damaged 7262009 NOTE: MULTI -LATERAL 1U-11. 11-1111, 1111I -VI. 1 Lt -02 (OFF MAIN WELLBORE) c9RowroR, anm o All I G96 LIFt:3 t93.9 OAS LIM ax? W6UFT:E11]5 LOCPTOR:EJM2 SFPL: SIRS SLeV` CE:423 9153 UNERIC-11UM;K,,M4 151839 3T SCAB LINER', 5.183.1 Rl aP . SE4L ASSY: 19.88.0 E a8 CTD LINER, 10 Wd MOWCTION.281-10i%B RPERF. 10WOd10.6M0 FRAC: 1099.9 (PERF: 108 0-0,1161 4VMPSTOC✓"10.6BB.0 LINER iFll LIM: 10M IN 13.Ob0 WNI L1M:LI M;:10,]<]0 WINDOW 10]A.O t0.)v/0 FI6N', 10]al0 LINER', 10,ZI9N1 ]{p0 KUP PROD WELLNAME 1C-11 WELLBORE 1C-11L2-02 a'� h," Well Attribub Maz Angle, TD ConocoPh'flies F.ld Name WNlbom PPIIURI WeIIMre Sblua ncll') PIN. ACL BIm(Mel Alaska, Im KUPARUK RIVER UNIT 5002922714'65 PROD 10144 11,09524 15,1880 LceLz.r¢. Erm'mLa rz'.Lm33 vM Last Tag vwo-ersnamecl+CeW1 Anndznnnoegn(Nltel End Oah MITI Un, Mae ay LWTag: 1C -11L2-02 jennall Last Rev Reason HANGER: J57 annoh5on End Dah wenbore vel Mae ey ............................... __.. _._ Rev Reason'. CTD MULTILAT 1G-11 L2-02 'Annan Casing strings cz:iny0e:mipLmn DID 0n1 moral ToplW s'd'"d luxe) seL Oegn INDI_wY/Len V-Oraa9 rnp rnreaa LINER IC-ttL2-02 23/8 1.99 10237.8 15,188.0 6,5818 4.60 L-80 STL Liner Details Nominal ID Top lhxel Top lrv0(MIN TOPlnaq°I Item Dee cam Od coNDUcroR:<>,Dam o 10,2378 6,207.6 46.55 eployment Sleeve Shots tleploymem sleeve 1.920 11.214.1 6,590.0 89.38 Deployment Shots tleploymem sleeve 1.920 SEE. I Frac Summary .".w PeoppanL Des,ned llnl PA,,Rvin Folmtlun (lb) 6120 008 &AFETYKV; 22n-4 S. Sae Date Top_dF lhN81 BLm IDM81 Lints biluN System Vd LWn lnbll Vol Slurry (bbl) 1 6202008 10,660.0 TWIN Notes: General & Safety End Dale ennouFon 5 /1412 01 9 NOTE: GPB DFT: J,1&i.9 GASUFPA21r4 GAS NFP, s1173 LOWTOF: EI"2 SEK;S.tr25 SURFACE; 43. S6,RAS 2� 23 M' CTO LINER. 102370 3S MAE LINER', 5,1931 o,nL 0 PRODUCTION'.M,. 10..a 8 II uNER tc-LlL2@Lin, 1s,LaeD ft. Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth swriime EndTime our (hr) Phase Op Code Activity Code rime P-T-X Opembon (W13) End Deplh(itKB) 3/26/2019 3/26/2019 1.50 MIRU MOVE MOB P Continue RD checklist, Trucks on 0.0 0.0 20:00 21:30 location, load shop, secure stairs and 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 3127/2019 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 changeout, 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 1 drop stairs 3/27/2019 3/27/2019 2.00 MIRU MOVE RURD P Begin RU checklist, get COMMS up, 0.0 0.0 13:00 15:00 set-down shop & lay mats, install scaffolding & platform around well 3/27/2019 3/27/2019 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 3/27/2019 3/27/2019 2.50 MIRU WHDBOP RURD P Complete dg 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 3/27/2019 3/27/2019 1.00 MIRU WHDBOP BOPE P PJSM, Fill stack and bleed afire out of 0.0 0.0 20:30 21:30 system. Shell lest BOPE, Swap out 0- Ring on riser 3/27/2019 3/28/2019 2.50 MIRU WHDBOP BOPE P Start full initial BOPE test, Test 0.0 0.0 21:30 00:00 witness waived by Adam Earl, AOGCC, No Fail pass through midnight test #9 3/28/2019 3/28/2019 2.50 MIRU WHDBOP BOPE P Continue full BOPE test, on test 9 0.0 0.0 00:00 02:30 3/28/2019 3/2812019 0.50 MIRU WHDBOP BOPE P Pull test joint, Makeup nozzle stab on 0.0 0.0 02:30 03:00 injector. Pressure test inner reel iron and pack offs, End BOPE test 3/28/2019 3/28/2019 1.00 SLOT WELLPR RURD P PJSM, Rig down BOPE test 0.0 0.0 03:00 04:00 equipment. PT PDL's TT line 3/28/2019 3/28/2019 0.75 SLOT WELLPR RURD P Normal up rig, Blow down TT line, 0.0 0.0 04:00 04:45 Open Tango valves. WHP=175 PSI 3/28/2019 3/28/2019 2.75 SLOT WELLPR PULD P M/U PD, BHA#1, fishing assembly 0.0 68.5 04:45 07:30 3/28/2019 3/28/2019 0.50 SLOT WELLPR PULD P Surface test Coil (good-test), Tag up 68.5 68.5 07:30 08:00 reset counters 3/28/2019 3/28/2019 2.00 SLOT WELLPR TRIP P RIH 68.5 9,745.0 08:00 10:00 3/28/2019 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 3/28/2019 3/28/2019 2.00 SLOT WELLPR CIRC P Continue RIH, park (0310,200', 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: 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 Achvity Code Time P -T -X Operation (WB) End DepN (MB) 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', hitjars x 25, jaring at 25k (57k), straight pull to 70 k, with no success 3128/2019 3/28/2019 1.75 SLOT WELLPR CIRC P Pump off fish, circulate 8.8 ppg drilling 10,245.0 10,200.0 14:33 16:18 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 3/28/2019 0.30 SLOT WELLPR TRIP P RBIH, pumping 0.46 bpm latch into 10,200.0 10,245.0 16:48 17:06 fish, pump 1.5 bpm at 3,451 psi, no returns 3/28/2019 3/28/2019 0.30 SLOT WELLPR JAR P Perform 5jar 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 3/2812019 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 12934, 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 1 1 Annular 2864, Bore 2923, WHP=41 3128/2019 3/28/2019 0.20 SLOT WELLPR OTHR P Pull fish harder, DHWOB=-7K, Annualr 10,245.0 10,245.0 19:24 19:36 12883, Bore 2924, WHP=41 3/28/2019 3/28/2019 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 19:64 21:12 from fish PUW=35K, PUH, Open EDC. Wail 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 Shutdown 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 whity 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 Report Printed: 5/312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Sort Time End Time our (hr) Phase Op Code Act,* Code Time P -T -X Operation (WB) 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 dg 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 3/2912019 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 out depth, looks to be clean. fire string shot 10,713'- 10,725'. 3/29/2019 3/29/2019 1.20 SLOT WELLPR ELNE P POOH, We -line 0.0 0.0 10:39 11:51 Note: Operator shut in well 1C-17 MI Injection well. 3/29/2019 3/29/2019 0.50 SLOT WELLPR ELNE P MU Jet cutter to a -line, stab on 0.0 0.0 11:51 12:21 lubricator PT, grease head small leak, add addtional grease, re -PT 3/29/2019 3/29/2019 1.00 SLOT WELLPR ELNE P RIH, w/Spectra2 Jet Cutter 1.68" OD, 0.0 0.0 12:21 13:21 3/29/2019 3/29/2019 0.40 SLOT WELLPR ELNE P Tie into K1 10,427.5', Log CCL while 0.0 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, temportly detained, RBIH, PUH w/increased speed, Pull free 3/29/2019 3/29/2019 1.00 SLOT WELLPR ELNE P POOH 0.0 0.0 13:45 14:45 329/2019 3/29/2019 1.00 SLOT WELLPR ELNE P PJSM, LD cutter and pressure 0.0 0.0 14:45 15:45 equipment, RD a -line unit and release 3/29/2019 3/29/2019 0.70 SLOT WELLPR CTOP P PJSM, move INJH cart forward, RIH 0.0 0.0 15:45 16:27 with coil into mouse hole inspecting coil, found flat spots at 10' and 15', Prep coil and cut 20 3/29/2019 3/29/2019 0.80 SLOT WELLPR CTOP P Prep CT, Install CT connector. Pull test 0.0 0.0 16:27 17:15 1 1 135K 329/2019 3/29/2019 1.00 SLOT WELLPR CTOP P Head up BHI UQC / test wire - Good. 0.0 0.0 17:15 18:15 Pressure test UQC CTC to 4400 PSI - Good 3/29/2019 3/29/2019 2.00 SLOT WELLPR PULD P M/U and PD BHA#2 Fishing BHAwith 0.0 81.3 18:15 20:15 Acceloralor, weight bars, Up down jars, and sealed GS spear 3/292019 329/2019 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 329/2019 3/29/2019 0.20 SLOT WELLPR DLOG P Log K1 for -2.5", Close EDC 9,760.0 9,798.0 22:03 22:15 3/29/2019 3/29/2019 0.30 SLOT WELLPR TRIP P Continue in hole, Pull weight check (off 9,798.0 10,248.0 22:15 22:33 10,200' PUW=36K 3/29/2019 3/292019 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. 3/2912019 329/2019 0.20 SLOT WELLPR CIRC P Start pumping to establish circulation. 10,248.0 10,248.0 23:15 23:27 Remain latched to fish. .5 BPM @ 3478, Annular 3096. Unable to move fluid to surface 3/29/2019 3/29/2019 0.45 SLOT WELLPR JAR P Go back to jarring up on 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 3/302019 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 3/35 Report Printed: 51312019 Operations Summary (with Timelog Depths) 1c-11 Cie Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth rt Start 7me End Time Dix(m) Phase Op Code ACENIy Code Time P -T-% Operatlan ft e) End Depth e) 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 BBL/Min 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 3/30/2019 1.50 SLOT WELLPR PULD P Tag up and space out, PJSM. PUD 72.0 0.0 03:54 05:24 1 1 1 BHA#2 3/30/2019 3/30/2019 1.50 SLOT WELLPR ELNE P Prep rig floor for eline ops, standby for 0.0 0.0 05:24 06:54 SLB eline travel to rig 3/30/2019 3/30/2019 0.75 SLOT WELLPR ELNE P SLB on location, PJSM, spot in unit 0.0 0.0 06:54 07:39 3/30/2019 3/30/2019 0.30 SLOT WELLPR ELNE P PJSM with rig crew and SLB 0.0 0.0 07:39 07:57 3/30/2019 3/30/2019 5.00 SLOT WELLPR ELNE P RU, SLB pressure equipment to the 0.0 0.0 07:57 12:57 rig floor 3/30/2019 3/30/2019 2.00 SLOT WELLPR ELNE P PT SLB e -line lubricator 0.0 0.0 12:57 14:57 3130/2019 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 e -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 e -line. PJSM to lay 0.0 0.0 20:45 21:51 down chem cutter. Swap out to 1 3/8" toolstring for logging ops 3/30/2019 3/30/2019 0.50 SLOT WELLPR ELNE P P/U Next 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 e -line unit with 13/8" 0.0 0.0 22:21 00:00 logging tools 3/31/2019 3/31/2019 1.30 SLOT WELLPR ELNE P Continue tripping out with a line 0.0 0.0 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 3131/2019 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 3131/2019 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 3/31/2019 0.25 SLOT WELLPR CTOP P PT re -head 4,500 psi 0.0 0.0 08:30 08:45 3/31/2019 3/31/2019 0.50 SLOT WELLPR CTOP P Stab into stump and pump 1 coil 0.0 0.0 08:45 09:15 volume forward @ 1.83 bpm at 3,299 psi, IA=110. OA=26, unstab INJH, park cart out of the way. 3/31/2019 3/31/2019 1.00 SLOT WELLPR PULD P PD fishing assembly 0.0 0.0 09:15 10:15 3/31/2019 3/31/2019 0.30 SLOT WELLPR PULD P Stab INJH, surface test BHI CoilTrak 0.0 81.3 10:15 10:33 1 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 Page 4135 Report Printed: 513/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Steil Tine End Time Da" Phase Op Code Activity Code Time P -T -X Operation (flKa) End Depth (MB) 3/31/2019 3/31/2019 0.20 SLOT WELLPR DLOG P Log formation correction of minus 4.0' 9,760.0 9,781.0 12:18 12:30 3/31/2019. 3/31/2019 0.30 SLOT WELLPR TRIP P Continue IH 9,781.0 10,200.0 12:30 12:48 3/31/2019 3/31/2019 0.50 SLOT WELLPR CIRC P Circulate bottoms up @ 1.5 bpm at 10,200.0 10,200.0 12:48 13:18 3,100 psi, Diff -16 psi, WHP=36, BHP 3,651, IA=114, OA=27 3/31/2019 3/31/2019 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 14:24 jar up on fish x 1, jar down on fish x2, jar up on fish x 4, Pull up to 64 it, pump 1.9 bpm -10 bbl, Could not establish returns 3131/2019 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 be 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+7.5' 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 Q 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 fatigue mgmt. Find e -line @ 38'. Trim 100'total 3/31/2019 3/31/2019 1.40 SLOT WELLPR CTOP P Test wire - good. Prep CT and install 0.0 0.0 22:30 23:54 connector. Pull test to 35K 3/31/2019 4/1/2019 0.10 SLOT WELLPR CTOP P Head up UQC 0.0 0.0 23:54 00:00 4/1/2019 4/1/2019 0.90 SLOT WELLPR CTOP P Complete reheading 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, WU and PD BHA #4 fishing 0.0 81.0 00:54 01:54 BHA. Check packoffs. Surface test BHA 4/1/2019 4/1/2019 2.00 SLOT WELLPR TRIP P RIH BHA#4, EDC open, pumping 1.5 81.0 9,760.0 01:54 03:54 BPM from surface 4/1/2019 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 411/2019 3.00 SLOT WELLPR JAR P Set down @ 10,220'. Did not latch up 10,220.0 10,220.0 04:06 07:06 first time. Bring pumps on . BPM and run in faster. Set down and latch. Jar up 3X. Paint red flag @ 51 K PU W. 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 BBI& down coil. No circulation. Jar 5X up and down 4/1/2019 4/1/2019 0.50 SLOT WELLPR PULL P Continue jaring total of 30 cycles QP 10,220.0 10,195.0 07:06 07:36 1 10,199', hold in tention 60 notice weight fall off slight Page 5135 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth start Time End TIM Dorm Phase op code Activity Code Time P -T -X Operation We) End Depth(lU(B) 4/1/2019 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 @ 3-5 fpm, notice weight change @ 10,145', continue pulling up to 9,975', 15-30 fpm, fish is pulling free 4/1/2019 41112019 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 411/2019 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 close EDC, slowly PUH circulating 0.25 bpm 2 bbls, shutdown open EDC, bullhead 1.4 bbl, WHIP increased to 1,500 psi, shutdown pump, bleed pressure off, pull up hole to confirm fish is free, fish is free, Close the EDC, 4/112019 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 WHIP 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 Attemptto RIH w11000 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 check, well still flowing, 4/1/2019 4/1/2019 0.30 SLOT WELLPR PULL P RBIH to tag @ 9,713' (Fish 9,693.0 9,713.0 14:54 15:12 depth=10,287') 4/1/2019 4/1/2019 1.50 SLOT WELLPR PULL P Circulate bottoms up, gas cut brine at 9,713.0 9,713.0 15:12 16:42 surface, take returns to tiger tank, bring back inside, 4/1/2019 4/1/2019 1.30 SLOT WELLPR OWFF P Perform flow check (no -flow) 9,713.0 9,713.0 16:42 18:00 4/1/2019 4/1/2019 2.00 SLOT WELLPR TRIP P Close EDC, pump 2 bills down the 9,713.0 557.2 18:00 20:00 coil, shutdown, open EDC, circlulale 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 2-318" solid liner no 444.9 0.0 21:51 23:03 centrilizers. 4/1/2019 4/2/2019 0.95 SLOT WELLPR PULD P PJSM, MU cleanout assembly, Stab 0.0 23:03 00:00 on well, Surface test tool 4/2/2019 4/2/2019 0.10 SLOT WELLPR PULD P Complete surface test tool 51.3 51.3 00:00 00:06 4/22019 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 412/2019 0.20 SLOT WELLPR DLOG P Log gamma lie 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 4/2/2019 4/2/2019 0.20 SLOT WELLPR TRIP P 10210', Wt check @ 35K, RIH min 10,210.0 10,276.0 03:42 03:54 rate. Tag dill @ 10,276 Page 6135 Report Printed: 51312019 - Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Stearns EM Time Our (hr) Phase op Corte Acd y Code Tans PJA opesabon (MB) End Depth (Po(a) 4/2/2019 4/2/2019 1.80 SLOT WELLPR OTHR P Bring pumps on 1.85 BPM @ 3629 10,276.0 10,442.0 03:54 05:42 PSI FS. Start clean out. Taking 25' bites. Paraftn coming across shaker of first bottoms up 4/212019 4/2/2019 0.50 SLOT WELLPR OTHR P Washing down set down @ 10442. 10,442.0 10,442.0 05:42 06:12 PUH slowly to 10356. RBIH and tag up 10442. DHWOB=2K. 4/2/2019 4/2/2019 0.90 SLOT WELLPR OTHR P Pump sweeps, PUH slowly circ 10,442.0 10,442.6 06:12 07:06 1 1 1 bottoms up 4/2/2019 4/2/2019 0.50 SLOT WELLPR MILL P Hole circulated clear, Bring pumps on 10,442.6 10,443.0 07:06 07:36 1.88 BPM @ 3635 PSI FS, BHP=3540, DHWOB=2K 4/212019 4/2/2019 0.30 SLOT WELLPR MILL P Pick up off bottom to reset. to hard to 10,443.0 10,443.0 07:36 07:54 be fill. Reset. Set back down 2.5K DHWOB, 1.88 BPM @ 3635 PSI FS. BHP=3540 4/2/2019 4/2/2019 0.50 SLOT WELLPR MILL P 10443, Metal on shaker, PUH consult 10,443.0 10,444.0 07:54 08:24 town eng. RBIH dry. Set down @ 10444 attempt to move down. Set 8K. 4/2/2019 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 4/2/2019 4/2/2019 1.30 SLOT WELLPR SLKL P Move in / spot up slickline unit 0.0 0.0 1224 13:42 4/2/2019 4/2/2019 2.40 SLOT WELLPR SLKL P PJSM, R/U slickline unit, full pressure 0.0 0.0 13:42 16:06 control equipment on rig floor 4/2/2019 4/2/2019 1.90 SLOT WELLPR SLKL P PT slick line lubricator to 2500 PSI - 0.0 0.0 16:06 18:00 RIH with 2.47 LIB, POOH after tagging @ 10,462' SL depth 4/22019 4/212019 0.50 SLOT WELLPR SLKL P PJSM, pop off lubricator, LD LIB, 0.0 0.0 18:00 18:30 Picutes on S: Drive, confer w/ SL supervisor & town, decision made to to run non-retrievable spear. 4/2/2019 4/2/2019 0.40 SLOT WELLPR SLKL P PU non-retrievable spear 0.0 0.0 18:30 18:54 4/2/2019 4/2/2019 2.10 SLOT WELLPR SLKL P RIH w/ spear, attempt to spear into 0.0 0.0 18:54 21:00 fish, spang down for-45 min, unable to latch into fish, POOH to inspect tool 4/2/2019 4/2/2019 0.60 SLOT WELLPR SLKL P LD tools, small scratches on face of 0.0 0.0 21:00 21:36 grapple, decision made to run 1-12" braided line brush "Test non-retrievable spear on 4' piece of liner at surface to ensure engagment is possible, engages as designed 4/2/2019 4/2/2019 0.70 SLOT WELLPR SLKL P MU braided line brush 0.0 0.0 21:36 22:18 4/2/2019 42/2019 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 4212019 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 42/2019 4/3/2019 0.30 SLOT WELLPR SLKL P Begin POOH (to PU non-retrievable 0.0 0.0 23:42 00:00 spear) 4/312019 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 on 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: 51312019 Operations Summary (with Timelog Depths) a 1c-11 • Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth SlaRTime End Time our (M Phase Op Code Activity Code Tim PJA Operation (ftKB) End Depth(flKB) 4/3/2019 4/3/2019 1.30 SLOT WELLPR SLKL P PU non -retrievable spear, PT, RIH, 0.0 0.0 00:18 01:36 latched into fish, jarred up -25 times, sheared off spear (GR), no movement of fish 4/3/2019 4/3/2019 0.60 SLOT WELLPR SLKL P POOH 0.0 0.0 01:36 02:12 4/3/2019 402019 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 413/2019 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 4/312019 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 4/3/2019 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 SK PSI. Work free down. PUH and hung up in SSSV. Cock jars down. PUH jars fire @ 43K continue out of hole 4/3/2019 4/3/2019 2.30 SLOT WELLPR PULD P At surface tag up and space out. PUD 59.0 0.0 12:18 14:36 BHA#6. Have fish. Length 20.38'. Jet cut end flared to 2.752. Overall fish recovered 465.28' 4/3/2019 4/3/2019 1.00 SLOT WELLPR PULD P PJSM, Complete HES slickline rig 0.0 0.0 14:36 15:36 down. Remove spear from fish 4/3/2019 4/3/2019 1.40 SLOT WELLPR PULD P PJSM. P/U BHA#7 FCO with straight 0.0 51.3 15:36 17:00 motor and D331 mill and PD. Chalk pack offs - Good 413/2019 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, WHIP = 20 psi, significant asphaltenes over shaker, pump 5x5 sweeps, taking bites & picking up, drop in MW out, begin taking returns to figer-tank (pinch in choke), cleans up, begin taking returns back inside Page 8135 Report Printed: 5/312019 Operations Summary (with Timelog Depths) IC -11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time End Tim Ox (no Phase Op Code Atl ty Code Time P -T -X Operatlon (WB) End DeMOW) 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 4/312019 0.30 SLOT WELLPR DLOG P Log K1 for 0' correction, RIH to bottom 10,425.0 10,690.0 21:54 22:12 413/2019 4/412019 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 414/2019 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 4/412019 4/4/2019 1.70 SLOT WELLPR TRIP P Close caliper fingers. Trip out of hole 10,121.0 22.0 07:24 09:06 4/4/2019 4/4/2019 0.70 SLOT WELLPR PULD P At surface, PJSM, Shut swab. Unstab 22.0 0.0 09:06 09:48 injector. Lay down caliper and camera adapter 4/4/2019 4/4/2019 2.20 SLOT WELLPR CTOP P Pull floats from LOC. 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 Herrera, 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 4/412019 0.10 SLOT WELLPR DLOG P Log K1 for 4correction, close EDC, 10,435.0 10,474.0 22:00 2206 1 PUW = 35K 4/4/2019 4/4/2019 0.20 SLOT WELLPR TRIP P Continue RIH, RIW = 12.2K 10,474.0 10,660.0 22:06 22:18 Page 9135 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) 1c-11 9. a, Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time Dur (hr) Phase Op Code ACYhrity Code Time PJA Operation (ttl(B) EM Depth(MKB) 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, dip = 1420 psi, annular = 3658 psi, pump =4610 psi, CWT = 11.5K, WOB = 0.6K, vibrations into red Stall at 10,679', PUW = 38K, out rate dropped (from 1,8 bpm to 1.64 bpm), rate out continues to drop to 1.36 bpm, stall at 10,681', PUW = 37K, annular increasing, packing off, significant cement over shakers 4/4/2019 4/5/2019 0.70 SLOT WELLPR UREM P Continue under -reaming, reduce 10,681.0 10,687.0 23:18 00:00 speed to .2 fpm, dp = 1313 psi, annular = 3973 psi, pump = 4781 psi, annular dropped & rate out increased back to 1.8 bpm 4/5/2019 4/5/2019 1.80 SLOT WELLPR UREM P Continue under -reaming from 10,687' 10,687.0 10,700.0 00:00 01:48 @ 0.2 fpm, dp = 1283 psi, 1.84 bpm in, 1.79 bpm out, annular= 3619 psi, pump = 4341 psi, CWT = 8.5K, WOB =1K Stall at 10,690', 10,694', 10,699', again at 10,698' getting to bottom, ream to 10,700' 4/5/2019 4/5/2019 0.40 SLOT WELLPR UREM P Back -ream up to 10,600'@ 5 fpm, 10,700.0 10,600.0 01:48 02:12 PUW = 39K 4/5/2019 4/5/2019 1.10 SLOT WELLPR UREM P Under -ream from 10,600', dp = 1275 10,600.0 10,660.0 02:12 03:18 psi, pump = 4387 psi, 98% returns, start at 0.2 fpm, walk up to 0.5 fpm, then 1 fpm, vibrations to 4, pump 5x5 sweeps 4/5/2019 415/2019 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 41512019 1.10 SLOT WELLPR PULD P PJSM, PUD BHA#9. All under reamer 66.0 0.0 05:54 07:00 blades intact 4/5/2019 41512019 0.90 SLOT WELLPR PULD P M/U HES caliper, Stab on and surface - 0.0 22.7 07:00 07:54 test. 4/5/2019 4/512019 2.10 SLOT WELLPR TRIP P RIH BHA#10 22.7 10,704.0 07:54 10:00 4/5/2019 4/5/2019 0.30 SLOT WELLPR DLOG P 10,704'. Open caliper arms. Log 10,704.0 10,148.0 10:00 10:18 uphole. Close caliper arms 4/5/2019 4/5/2019 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 12:00 12:30 4/5/2019 4/5/2019 1.20 SLOT WELLPR PULD P M/U Whipstock in pipe shed/ Plan 0.0 0.6- 12:30 13:42 change reset motor back to 0` and pick up under reamer 4/5/2019 4/512019 1.30 SLOT WELLPR PULD P PJSM, PD BHA #11 Under reamer on 0.0 66.0 13:42 15:00 straight motor, Make up injector and surface test. 4/5/2019 4/5/2019 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 11 1 415/2019 4/5/2019 0.30 SLOT WELLPR TRIP P Continue RIH to 10,600' 9,770.0 10,660.0 16:48 17:06 Page 10135 Report Printed: 5/312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Sort Time Ed Tima Dur(hr) phase Op Code Acumty Code Time P -T -X Operation (fll(a) End Depth(ftKB) 4/5/2019 4/5/2019 1.50 SLOT WELLPR UREM P Under -reaming, dp = 1249 psi, annular 10,660.0 10,700.0 17:06 18:36 = 3610 psi, pump =4368 psi, 1 fpm from 10,660'to 10,700', back -ream to 10,680', under -ream down to 10,700' @ 0.5 fpm " Cement over shakers (trace asphaltenes, very little metal) 4/5/2019 4/5/2019 0.30 SLOT WELLPR UREM P Back -ream up to 10,600'(5 fpm) 10,700.0 10,600.0 18:36 18:54 4/512019 4/512019 1.80 SLOT WELLPR UREM P Under -ream from 10,600'to 10,660'(1 10,600.0 10,680.0 18:54 20:42 fpm), slow to 0.5 fpm from 10,660'to 10,680' " Stall @ 10,668', PUW = 37K 4/5/2019 4/5/2019 0.30 SLOT WELLPR UREM P Back -ream 10,680'to 10,600'(5 fpm), 10,680.0 10,600.0 20:42 21:00 PUW = 37K 4/5/2019 4/5/2019 1.60 SLOT WELLPR UREM P Under -ream from 10,600' to 10,700'(1 10,600.0 10,700.0 21:00 22:36 fpm), pump 5x5 sweeps, open EDC 4/5/2019 4/6/2019 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 K1 for -3.5' correction 10,420.0 10,476.0 04:42 04:54 4/6/2019 4/6/2019 0.20 PROD? RPEQPT TRIP P Continue RIH, arrive at setting depth, 10,476.0 10,697.0 04:54 05:06 PUW = 35K, Gose EDC, RBIH, bring up pump, shear off at 3700 psi, set - down 5K WOB, TOWS -10,684' 4/6/2019 4/6/2019 1.80 PROD1 RPEQPT TRIP P POOH w/ BHA #12, PUW = 35K 10,697.0 69.0 05:06 06:54 4/6/2019 4/6/2019 1.10 PRODt RPEQPT PULD P Tag up and space out. PJSM PUD 69.0 0.0 06:54 08:00 1 1 1 BHA#12 Whipstock setting tools 4/612019 4/6/2019 1.30 PRODt WHPST WPST P M/U BHA#13 vdth.6'AKO motor, 0.0 74.7 08:00 09:18 2.80 DSM, 2.79 String reamer, and 10' pup. Pressure deploy. Make up to coil and surface test 4/6/2019 4/6/2019 1.90 PROD1 WHPST WPST P RIH BHA#13 74.7 10,440.0 09:18 11:12 4/6/2019 4/6/2019 0.20 PROD1 WHPST WPST P Log K1 for -0.5', Close EDC, 10,440.0 10,477.0 11:12 11:24 PUW=36K 4/6/2019 4/6/2019 0.20 PROD1 WHPST WPST P Continue in well, Dry lag @ 10688. 10,477.0 10,688.0 11:24 11:36 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. 4/612019 4/6/2019 2.20 PRODi 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 416/2019 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 = 1.31K, pump = 4114 psi, annular = 33722 psi, WHP = 18 psi Page 11135 - ReportPrinted: 513/2019 Operations Summary (with Timelog Depths) F. 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Slid Depth Start Time End Trcne our (hr) Phase Op Code Activity Code Time P -T -x Operation (ftKB) End Depth (ftKB) 4/6/2019 4/6/2019 1.80 PROD1 WHPST REAM P Dress window (HS, 30R, 30R, & 10,711.0 10,711.0 18:54 20:42 180*), 1 fpm, dry drift window up & down, clean, tag TO of rat -hole, pump sweeps, PUW = 36K 4/6/2019 4/6/2019 1.90 PROD1 WHPST TRIP P Open EDC, POOH w/ BHA#13, PJSM 10,711.0 75.0 20:42 22:36 4/6/2019 4/6/2019 1.00 PROD1 WHPST PULD P PUD BHA#13, mill came out 2.80" no- 75.0 0.0 22:36 23:36 go, string reamer came out 2.79" po- go 4/6/2019 4/7/2019 0.40 PROD1 DRILL PULD P Begin PD BHA#14 Build/Tum 0.0 72.0 23:36 00:00 Assembly (2.2" AKO motor, RB Dynamus bit) 4/7/2019 4/7/2019 0.70 PROD1 DRILL PULD P Complete PD BHA#14 Build/Tum 0.0 72.0 00:00 00:42 Assembly (2.2' AKO motor, RB Dynamus bit), slide in cart, check pack -offs, MU to coil, tag up, set counters 4/7/2019 4!712019 2.20 PROD1 DRILL TRIP P RIH w/ BHA #14 72.0 10,425.0 00:42 02:54 4/7/2019 4/7/2019 0.20 PROD1 DRILL DLOG P Log K1 for -4' correction, close EDC, 10,425.0 10,463.0 02:54 03:06 1 1 1 PUW = 35K 4/7/2019 4/7/2019 0.10 PROD1 DRILL TRIP P Cotninue RIH 10,463.0 10,711.0 03:06 03:12 4/7/2019 4/7/2019 1.20 PROD1 DRILL DRLG P Drilling, FS = 535 psi @ 1.9 bpm, 10,711.0 10,805.0 03:12 04:24 CWT = 10.5K, WOB = 2.31K, annular= 3788 psi, WHP = 79 psi, pump = 4161 psi, 98% returns, pump 5x5 sweeps, begin losing -0.1 bpm @ 10,799', drill to called TD of 10,805' 4/7/2019 4/7/2019 0.20 PROD1 DRILL TRIP P PUH to log K1 & RA, PUW = 38K 10,805.0 10,425.0 04:24 04:36 4/7/2019 4/7/2019 0.40 PROD1 DRILL DLOG P Log K1 for O' correction, log RA at 10,425.0 10,725.0 04:36 05:00 10,691' TOWS = 10,684', BOW = 10,692, RA = 10,691.5' 4/7/2019 4/7/2019 1.80 PROD1 DRILL TRIP P POOH, PUW=37K 10,725.0 67.0 05:00 06:48 4/7/2019 4/7/2019 1.30 PROD1 DRILL TRIP P At surface, Tag up and space out. 67.0 0.0 06:48 08:06 PJSM. PUD BHA#14 Build section BHA 4/7/2019 4/7/2019 0.80 PROD1 DRILL OTHR P M/U Nozzle. Stab on well. Jet stack. 0.0 0.0 08:06 08:54 Flush micro motion. Pull off well. Change out floats in UQC 4/7/2019 4/7/2019 1.20 PROD1 DRILL PULD P PJSM. M/U Mill, Motor, and FVS and 0.0 78.2 08:54 10:06 scribe. PD BHA#15 lateral BHA with .5° AKO motor, agitator, and RB HYC A3 bicemer. Make up to coil and surface test 4/7/2019 4/7/2019 2.10 PRODI DRILL TRIP P RIH, Shallow test agitator @ 300'. 78.2 10,445.0 10:06 12:12 lConfinue in well 4/7/2019 4/7/2019 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 4/7/2019 0.20 PROD1 DRILL TRIP P Continue in well, Clean pass through 10,464.0 10,803.0 12:18 12:30 1 window 4/7/2019 4/7/2019 0.80 PROD1 DRILL DRLG P 10803', Drill ahead, 1.9 BPM @ 5057 10,803.0 10,864.0 12:30 13:18 PSI FS, BHP=3833. New mud @ bit 10,844' 4/7/2019 4/7/2019 0.10 PROD1 DRILL WPRT P Pull BHA wiper, PUW=35K. 10,864.0 10,864.0 13:18 13:24 477/2019 4/7/2019 1.90 PROD1 DRILL DRLG P New mud around, 1.9 BPM @ 10,864.0 11,000.0 13:24 15:18 4634PSI FS, BHP=3807. RIW=IO.SK, DHWOB=I.5K Page 12/35 Report Printed: 51312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Sbrt Time End Time Dw (hr) Phase Op Code AdlWly Code Time P -T -x Operation (dKa) End Depth (M) 4/7/2019 4/7/2019 2.40 PROM DRILL DRLG P Start continuous rotating drilling 11,000.0 11,205.0 15:18 17:42 11,000' - 11,155', 1.9 BPM @ 4634 PSI FS, BHP=3840 4/7/2019 4/7/2019 0.20 FROM DRILL WPRT P Wiper up -hole, PUW =37K 11,205.0 10,813.0 17:42 17:54 4/7/2019 47/2019 0.20 PROD1 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 FROM DRILL DRLG P Drilling, FS = 1303 psi at 1.9 bpm, 11,205.0 11,290.0 18:06 19:48 CWT = 11.5K, 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 4/7/2019 1.50 FROM DRILL DRLG P Continue drilling from 11,290, CWT = 11,290.0 11,370.0 19:48 21:18 8.1 K, WOB = 2.85K, annular= 3855 psi, WHP = 119 psi, pumps 5x5 sweeps, 100'wiper from 11,357', PUW = 39K, PUW = 45K from 11,370', avg ROP = 53 fph Holding -87" Inc in allempt to acquire the C1 prior to Fault 1 crossing (per geology) 4/712019 4/7/2019 1.70 FROM DRILL DRLG P PUW = 45K from 11,370', pull heavy to 11,370.0 11,467.0 21:18 23:00 52K break -over Drilling, CWT = 10.81K, WOB = 1.9K, annular = 3851 psi, WHP = 78 psi, PU's as required, avg ROP = 71 fph 4/7/2019 4/8/2019 1.00 PROD1 DRILL DRLG P Continuous rotation drilling, CWT= 11,467.0 11,511.0 23:00 00:00 10K, WOB = 1.7K, annular = 3875 psi, WHP = 69 psi, avg ROP = 44 fph 4/8/2019 4/8/2019 1.50 PRODi 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, WHP = 66 psi, pump sweeps, avg ROP = 60 fph 4/82019 4/8/2019 0.30 FROM DRILL WPRT P Wiper up -hole, PUW =40K 11,600.0 10,800.0 01:30 01:48 4/82019 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 gel through & bring back up quickly, RIW = 9.9K 4/8/2019 4/8/2019 1.60 PROD1 DRILL DRLG P BOBD (non oscillating to acquire 11,600.0 11,697.0 02:24 04:00 targets) FS = 1190 psi @ 1.85 bpm, CWT = 10.2K, WOB = 1.3K, annular = 3892 psi, WHP = 20 psi Confer w/ town geology, decsion made drop to 84° Inc (target deeper in Ct prior to fault crossing) 4/8/2019 4/8/2019 0.60 FROM 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 = 8.7K 4/8/2019 4/8/2019 3.00 PRODi 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= 3664 psi, pump = 4764 psi, drilling break at -11,699', PUW = 41 K from 11,756' Page 13/35 Report Printed: 513/2019 ' I Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SW DWh SW Time EMTme Dur(hn Phase Op Code Activity Code Time P-T-X Operation (MB) End Depth(ItKB) 4/8/2019 4/8/2019 1.20 PROD1 DRILL WPRT P Wiper to window with tie into RA 12,000.0 12,006.0 07:36 08:48 marker for a +7' correction. Some slight overpulls coming up. RBIH stacking multiple times. Reduce rate to get lhroigh 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 08:48 12:18 FS, BHP=3930, RIW=7.2K, DHWOB=2K. 12059' start working rotation 4/8/2019 4/8/2019 0.30 PROD1 DRILL WPRT P 12,400', 800 foot wiper with 5 X 5 12,400.0 11,592.0 12:18 12:36 sweeps, PUW=44K 4/8/2019 4/8/2019 1.80 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 PRODt DRILL DRLG P 12450'. Increase inclination to 100° 12,450.0 12,628.0 14:54 1736 turn up to cross cut. 1.84 BPM @ 4722 PSI FS, BHP=3954, 4/8/2019 4/8/2019 0.70 PROD1 DRILL WPRT P Pull wiper to 12,400. Staking, 12,628.0 12,628.0 17:36 18:18 PUW=53K 4/8/2019 4/8/2019 3.20 PROD? DRILL DRLG P 126281, Drill, 1.89 BPM @ 4918 PSI 12,628.0 12,796.0 18:18 21:30 FS, BHP=3970, RIW-.8K, DHWOB=I.8K. Hard to get drilling 4/8/2019 4/8/2019 0.70 PROD1 DRILL WPRT P 12796', Wiper trip to 12,300'. 12,796.0 12,795.0 21:30 22:12 PUW=55K 4/8/2019 4/8/2019 0.60 PROD1 DRILL DRLG P 12795', Drill, 1.84 BPM @ 4810 PSI 12,795.0 12,822.0 22:12 22:48 FS, BHP=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 PRODt DRILL DRLG P Difficulty starting drilling, WOB w/ n0 12,860.0 12,880.0 00:00 00:36 motonvork, 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 injector 4/9/2019 4/9/2019 2.00 PROD2 STK PULD P PU/PD BHA#16 OH Anchored Billet, 0.0 72.0 04:30 06:30 failed checks, PUD, & redeploy, check pack-offs " Crew chage 4/9/2019 4/9/2019 2.10 PROD2 STK TRIP P RIH w/ BHA #16 72.0 10,445.0 06:30 08:36 I 4/9/2019 4/9/2019 0.40 PROD2 STK DLOG P Log Kt for +15' correction, clean 10,445.0 10,495.0 08:36 09:00 counter wheel, PUW = 37K Page 14/35 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) IC -11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan 7me End Time Dur (hr) Phase Op C e Activit/ Cole Time P -T-% Operation (Po®) EM Depth (WS) 4/9/2019 4/9/2019 0.80 PROD2 STK TRIP P Continue RIH, park at window, close 10,495.0 11,050.0 09:00 09:48 EDC, RIH & stack weight 10,744', PUW = 40K, dragging -3.71K WOB, RBIH, setdown at 10757'10760', 10762', continue working through 10,802' Arrive at setting depth, PU 36K, bring on pumps, shear off at 4200 psi, set down 4K WOB, TOB -11,050', oriented HS 4/9/2019 4/9/2019 1.80 PROD2 STK TRIP P POOH, open EDC, PJSM 11,050.0 78.0 09:48 11:36 4/9/2019 4/9/2019 1.00 PROD2 STK PULD P PUD BHA #16, bit came out a ... 78.0 0.5- 11:36 12:36 4/9/2019 4/9/2019 0.40 PROD2 STK BOPE P Suck out stack, PU test jnl, function 0.0 0.0 12:36 13:00 test BOP'S, LD test jnt 4/9/2019 4/912019 1.30 PROD2 STK PULD P PD BHA#17 KO/Drilling Assembly 0.0 78.0 13:00 14:18 (Agitator, 0.5° AKO motor, new HYC A3 bit), slide in cart, chaged out pack - offs, MU to coil, tag up, space out, set counters 4/9/2019 4/9/2019 2.20 PROD2 STK TRIP P RIH w/ BHA#17, test agitator, 1.9 78.0 10,435.0 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 18:11; 11242 psi @ 1.9 bpm, tfph 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 fl 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 it 4/9/1019 4/9/2019 0.40 PROD2 DRILL DRLG P Off billet drilling ahead -10 fl/hr, WOB 11,054.1 11,058.0 18:48 19:12 <1 k lbs. 4/9/1019 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. 4/9/2019 4/9/2019 0.10 PROD2 DRILL WPRT P RBIH, CT Wt 10 k lbs, billet clean. 11,003.0 11,149.0 20:36 20:42 4/9/2019 4/10/2019 3.30 PROD2 DRILL DRLG P CT 5027 psi @ 1.87 by in and 1.86 11,149.0 11,422.0 20:42 00:00 bpm out, free spin diff 1248 psi, BHP 3808 psi holding 11.1 ppg EMW, BOBD, 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 f1hr 4/10/2019 4/10/2019 0.30 PROD2 DRILL DRLG P OBD- 11,422.0 11,450.0 00:00 00:18 1 4/10/2019 4/10/2019 0.10 PROD2 DRILL WPRT P PU Wt 42 k lbs Wiper # 1 to just below 11,450.0 11,112.0 00:16 00:24 1 1 I I the billet Page 15135 Report Printed: 51312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Tine EM Time Dur nn ( Phew op cotle ACiidy Cotle rime P -T -X Operation (Nf0) End DepN X(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 Ibs, 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, clean up 11,850.0 11,100.0 06:06 06:24 to 11,100' 4/10/2019 4/1012019 0.30 PROD2 DRILL WPRT P Wiper in-hole, stack CWT at 11,267', 11,100.0 11,850.0 06:24 06:42 no WOB indication, PUW = 51 K, then got by, RIW = 10K 4/10/2019 4/10/2019 3.00 PROD2 DRILL DRLG P Drilling, FS=1336 psi, CWT =7.2K, 11,850.0 12,043.0' 06:42 09:42 WOB = 2K, annular = 3860 psi, WHP = 46 psi, pump = 5292 psi, pump 5x5 sweeps, avg ROP = 64 fph 4/10/2019 4/10/2019 2.00 PROD2 DRILL DRLG P Drilling, CWT =5.5K, WOB =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 fph 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 4/10/2019 4/10/2019 1.20 PROD2 DRILL WPRT P Wiper to tubing tail, PUW = 45K, pull 12,250.0 10,325.0.. 12:48 14:00 heavy at 10,915'(55K), RBIH, PUH, pull heavy at 10,795', RIBH, stack -9K WOB, pull -13K WOB, begin packing off, work free, PUH, RBIH to surge BHA prior to pulling through window 4/10/2019 4/10/2019 0.20 PROD2 DRILL DLOG P RBIH R 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' 411012019 4/10/2019 2.60 PROD2 DRILL DRLG P Drilling, FS = 1200 psi @ 1.9 bpm, 12,250.0 12,420.0 15:30 18:06 CWT = 1.5K, WOB = 1 K, annular = 4113 psi, WHP = 18 psi PUW = 47K from 12,350' Average ROP over section - 65 ft/hr 4/10/2019 4/10/2019 1.10 PROD2 DRILL DRLG P PU post crew change, CT Wt 62 k Jibs, 12,420.0 12,496.0 18:06 19:12 RBIH CT 5396 psi @ 1.90 bpm in and 1.86 bpm out, Free spin 1398 psi, BHP 3991 psi, open choke, WH 16 psi, IA 124 psi, OA 42 psi CT Wt k 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 stmt Depth Start Tme End Time Dur (hr) Phew op Code Activity Code Tone P -T -X Dpereden (71x8) End Depth XB) 4/10/2019 4/10/2019 0.40 PROD2 DRILL DRLG P Last PU 69 k lbs, 100' short BHA 12,496.0 12,526.0 19:12 19:36 wiper. RBIH, Drill ahead, start preparing for mud swap. Small short lived pack off event, 4/10/2019 4/10/2019 0.30 PROD2 DRILL WPRT P PU 52 k lbs, 100' BHA viper, pump 12,526.0 12,526.0 19:36 19:54 5x5, RBIH 4/10/2019 4/10/2019 0.80 PROD2 DRILL DRLG P PU 69 k lbs, 100'short BHAwiper. 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 50 k lbs - Wiper trip #1 12,738.0 11,940.0 21:42 22:12 Trouble turning around, reduced rate to 1.5 bpm, 4/10/2019 4/10/2019 0.80 PROD2 DRILL WPRT P Multiple set downs while RBIH, 11,940.0 12,738.0 22:12 23:00 11,965,11,984,11,989,11,982'- Hot gamma areas, - 140 API 0.4 bbls of cuttings returned per WW 4/10/2019 4/11/2019 1.00 PROD2 DRILL DRLG P CT 4785 psi @ 1.89 bpm in and 1.85 12,738.0 12,878.0 23:00 0000 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 5 to -5 k lbs, WOB 1.2 to 0.3 k lbs. Average ROP over section - 140 R/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, OA38 psi. CT Wt to-5klb5, 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 Ibs 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, WHP = 117 psi, slow drilling w/ siderite in samples 4/11/2019 4/11/2019 3.50 PROD2 DRILL DRLG P Drilling, CWT =6.3K, WOB =3.4K, 12,986.0 13,035.0 07:00 10:30 annular = 3948 psi, WHP = 125 psi, pump = 5271 psi, PUW = 43K from 13,012', Continued low ROP w/ Siderite in samples, avg ROP = 14 fph 4/11/2019 4/11/2019 2.30 PROD2 DRILL DRLG P Drilling, CWT =7.9K, WOB =2.5K, 13,035.0 13,050.0 10: I : I I I I annular = 3942 psi, WHP = 104 psi 4/11/2019 4/11/2019 0.30 PROD2 DRILL WPRT P Wiper up -hole, PUW = 43, dean 13,050.0 12,250.0 12:48 13:06 Page 17135 Report Printed: 51312019 . Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log De Start DepDepthSIa RTime End Time Dw (hd phase Op Code Activity Code Time P -T -X Operation (rt Ertl Depth (flKB) 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 4111/2019 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 4/11/2019 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 4/11/2019 4/11/2019 1.20 PROD2 DRILL WPRT P PU Wt 52 k lbs - Bit trip 13,310.0 10,650.0 18:30 19:42 13,137-13,048' light WOB tugs -300 Ibs 12,250-12,216 firm WOB tugs - 680 Ibs 11,962 - 11,934 heavy WOB tugs 2.5 - 3 k lbs 10,788'-6 k WOB tug, believe it was a tool orientation issue not a hole issue. Window clean -150 Ib WOB tug 4/11/2019 4/11/2019 2.00 PROD2 DRILL TRIP P Park, open EDC, Online @ 1.95 bpm, 10,650.0 65.0 19:42 21:42 POH Saw coil weight swing and a small pack off event when passing the Mule shoe @10,331'. Preloaded drillers side PDL in order to swap our Res tool per town request. 4/11/2019 4/11/2019 1.40 PROD2 DRILL PULD P PUD BHA 17 65.0 0.0 21:42 23:06 Lowest WH 690 psi, estimate BHP @ 10.8-10.9 ppg or lower. Inspected pipe, 0.174, 0.175, 0.109, 0.175" -low reading from long shallow gouge, sliding across the Window or something similar. 4/11/2019 4/11/2019 0.50 PROD2 DRILL PULD P PU/PD BHA 18 0.0 65.0 23:06 - 23:36 Re highside motor post resistivity tool swap, 4/11/2019 4/11/2019 0.30 PROD2 DRILL PULD T PHASE 3 called - no email from 65.0 0.0 23:36 23:54 security, radio announcement, CPF 1&2 Phase 3, CPF 3 Phase 2. Pulled BHA above swab closed same. Lined up on managed pressure 4/11/2019 4/12/2019 0.10 PROD2 DRILL WAIT T Wait on weather 0.0 0.0 23:54 00:00 1 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 4/1212019 12.00 PROD2 DRILL WAIT T Waiting on weather, pumping 0.0 0.0 06:00 18:00 mangaged pressure, -16 bbl lost to formation, Phase 3 'Weather prediction calls for decreasing winds by midnight tonight. Page 18135 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth StartTime Ertl Tore D z (hr) Phew Op CDde Activity Qxle Time P -T -X Operate (M(B) Entl Depth (M(B) 4/12/2019 4/1312019 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 4/1312019 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 4/1312019 2.10 PROD2 DRILL TRIP P RIH w/ BHA#18, shallow test agitator, 68.0 10,435.0 06:00 08:06 1.87 bpm, dp = 1265 psi, pump = 5181 psi Many various alarms on HMI, park at 9054', evaluate, VFD room door open, possibly cold conditions causing issue 4/13/2019 4/1312019 0.20 PROD2 DRILL DLOG P Log K1 for -5.5' correction, PUW = 10,435.0 10,473.0 08:06 08:18 37K 4/13/2019 4/13/2019 0.30 PROD2 DRILL DLOG P Confirm 11.1 ppg kills well, trap 3795 10,473.0 10,676.0 08:18 08:36 psi SBHP: MD = 10,676 psi, annular = 3677 psi, TVD -sensor = 6492, 10.9 ppg EMW (slopped once hitting 10.9 ppg) 4/13/2019 4/13/2019 1.20 PROD2 DRILL TRIP P Continue RIH, 2K WOB bobble at 10,676.0 13,310.0 08:36 09:48 10,685' (window) Stack WOB 11,805', PUW = 42K, -3K WOB, & 11,785' Stack CWT at 12044' (no WOB indication) Annular increasing, PU, stack CWT at 12,711' Stack CWT at 13,088' 4/13/2019 4/13/2019 1.20 PROD2 DRILL DRLG P Drilling, FS = 1275 psi @ 1.87 bpm, 13,310.0 13,426.0 09:48 11:00 CWT = 5K, WOB = 1.6K, annular = 4285 psi, annular higher than expected wl choke fully open (11.8 ppg at Window, dropping as mud shears, cheesing over shakers), 4/13/2019 4/1312019 1.00 PROD2 DRILL DRLG P PUW =42K from 13,426', stacking 13,426.0 13,520.0 11:00 12:00 CWT getting to bottom, annular= 4115 psi, pump = 5419 psi, pump 5x5 sweeps (1 % LoTorq 12% 776), -98% returns 4/13/2019 4/13/2019 0.60 PROD2 DRILL DRLG P Hard spot 13,5201, 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) 1 C-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log �eVN Slwtnme End T Tine InSiert (fid Plwse Op Code Mtivity Ca0e Time P -T -X Opealim (MI®) End Depth (fixe) 4/13/2019 4/1312019 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 4/13/2019 4/13/2019 0.30 PROD2 DRILL WPRT P Wiper up -hole, load LVT to rig & begin 13,558.0 12,753.0 13:00 13:18 warming 4/1312019 4/13/2019 0.30 PROD2 DRILL WPRT P Wiper in-hole, work a bit to gel 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 = 1.21K, 13,558.0 13,640.0 13:36 14:48 annular= 4000 psi, 1.87 bpm in, 1 bpm out, drilling ahead, rate out continues to drop (.85 bpm), 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 4/1312019 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, nuetral to snubbing CWT, returns climb to 1.4 bpm PUW = 50K from 13,711' Pt1W = 47K from 13,769' PUW = 48K from 13,827' 4/13/2019 4/13/2019 0.20 PROD2 DRILL WPRT P PU Wt 54 k lbs, wiper trip 13,894.0 1,349.0 18:48 19:00 4/13/2019 4/13/2019 0.20 PROD2 DRILL WPRT P RBIH 1,349.0 13,984.0 19:00 19:12 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 A k Is, WOB 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 R/hr 4/14/2019 4/14/2019 3.30 PROD2 DRILL DRLG P Gamma dropping below 160 API, ROP 14,070.0 14,208.0 00:36 03:54 increasing to - 80 ft/hr CT 5326 psi @ 1.88 bpm in and 1.69 bpm out, BHP 4069 psi, CT Wt -5.5 k Ib, WOB 600 lbs, ROP 80 ft/hr, pump 5x5 beaded tubed 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 0600 13,779' Baker surface read out gtitched, 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 20135 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) 110-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SM Dep h start Time End Time Dur(hr) Phase Op Code Activity Code Time P -T -X Operation (Po®) End cops,(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 rate to 0.6 bpm, bring rate up as soon a possible, stacking working to bottom, PUW = 44K, pump 5x5 sweeps, 4/14/2019 4/14/2019 1.50 PROD2 DRILL DRLG P Drilling, FS = 1260 psi @ 1.87 bpm, 14,208.0 14,288.0 07:42 09:12 CWT -6K, WOB=0.6K, annular= 4128 psi, pump 5440 psi, rate out 1.7 bpm Bring HiVis to 2 ppb beads with lubes, pump 13 bbl pill, no significant improvement, PUW = 47 from 14288', Avg ROP = 53 fph 4/14/2019 4/14/2019 1.80 PROD2 DRILL DRLG P Drilling, CWT= -8K, WOB=.6K, 14,288.0 14,352.0 09:12 11:00 annular = 4007 psi, pump = 5097 psi, pump 15 bbl, 2ppb pill to limited effect, 4/14/2019 4/14/2019 0.50 PROM 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 I 14,365.0 14,467.0 12:00 14:00 2% Screen Kleen pill to good effect, increased weight transfer & able to drill, continue pumping Drill Zone / Screen Kleen pills binging active to —1 %, avg ROP = 51 fph PUW = 65K from 14,375' PUW = 63K from 14,403' PUW = 52K from 14,412' 4/14/2019 4/14/2019 2.00 PROD2 DRILL DRLG P Drilling, CWT= -3K, WOB=0.8K, 14,467.0 14,565.0 14:00 16:00 annular = 4081 psi, pump = 5546 psi, 85% returns, continue to struggle w/ weight transfer, pumping pills to keep weight to the bit, avg ROP = 49 fph PUW = 54K from 14,565' 4/14/2019 4/14/2019 3.60 PROD2 DRILL DRLG P Drilling, CWT= -1.8K, WOB=0.5K, 14,565.0 14,734.0 16:00 1936 annular = 4117 psi, pump = 5620 psi, continue pumping pills as required PUW = 60K from 14,579', tum into BHAwiper Average ROP over interval drilled - 477hr Page 21135 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) IC -11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase op Code AGWiry Code Tune P -T -X Operation (MB) End Depth (Po®) 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 PROM 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 PROM 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 dif 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 wl -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 oft @ 14,945', sweeps not helping Average ROP over interval drilled - 37'/hr 4/15/2019 4/15/2019 2.20 PROM DRILL WPRT P PU Wt 47 k lbs, Wiper trip to the 14,980.0 10,430.0 02:06 04:18 window for tie in. CT weight stepped up from 37 k 143 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" 4/152019 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 = 0.71K, 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 4/152019 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' 4/152019 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 PROM 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) 110-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Siert Depth Start Time End rare Dur (hr) Phase Op Code Aotirdy Cade TMPTX Operation (MB) End DePM (fIKB) 4/15/2019 4/15/2019 0.60 PROD2 DRILL TRIP P Wiper in-hole, struggl to bottom, 14,555.0 15,380.0 15:06 15:42 squatting up to -10K CWT, PU, continue in-hole, reduce rate to .75 bpm to reach bottom 4/15/2019 4/15/2019 2.30 PROD2 DRILL DRLG P Drilling, FS = 1233 psi @ 1.9 bpm, 15,380.0 15,437.0 15:42 18:00 CWT = -8.5K, WOB = 0.6K, annular = 4070 psi, pump = 5542 psi PUW = 42K from 15,387' PUW = 53K from 15,426' 4/15/2019 4/15/2019 1.20 PROD2 DRILL DRLG P Drilling, CWT= -3K, WOB= 1.8K, 15,437.0 15,458.0 18:00 19:12 annular = 4078 psi, pump = 5557 psi, drill to called TO 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 1 0x1 0 sweeps timed for EOB, jog 5", park at 4861'& reboot Orion 4/16/2019 4/16/2019 0.20 PROD2 DRILL WPRT P Continue out of hole, tag up, reset 137.0 78.0 00:00 00:12 counters. 4/16/2019 4/16/2019 1.80 PROM DRILL TRIP P RBIH 78.0 10,430.0 00:12 02:00 4/16/2019 4/16/2019 0.20 PROM 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 l min 3748 11.13 2min 3695 10.98 3min 3634 10.79 5 min 3606 10.71 4/16/2019 4/16/2019 3.80 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. SID 14,204', PU 45 k lbs, continue in hole, reduce RIH speed to 25 Whim @ 14518, reduce running speed to 14 ft/min @ 14,740'. 8 iVmin @ 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, 12-01 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 23135 ReportPrinted: 51312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Lo® Sten Time End Time Dw(hr) Phew Op Code Activity Code Time P-T-X Operation Sten Depth (RKB) End Depth(flKB) 4/16/2019 4/15/2019 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 1-2-01 liner. Tie into flag for- 1,265.0 15,462.0 14:00 18:06 10.68'. PU Wt 38 kWOB -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 COMPZ2 CASING TRIP P POOH, while laying in beaded LRP 14,457.0 10,670.0 18:57 20:27 4/16/2019 4/16/2019 1.90 COMPZ2 CASING TRIP P Pull through the window, continue 10,670.0 44.2 20:27 22:21 POOH 4/16/2019 4/16/2019 0.50 COMPZ2 CASING OWFF P At surface, check well for flow, PJSM 44.2 44.2 22:21 22:51 4116/2019 4/1612019 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 1 1 loompletion. 4/17/2019 4/17/2019 0.90 COMPZ2 CASING PULD P PU BHA#20, Lower 1-2-01 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 12-01 competion. 3,497.0 10,599.0 05:42 07:12 4/17/2019 4117/2019 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 t0 -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 1554 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 1642 Losses 4 bbpVhr 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. 4117/2019. 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 P Start bi-weekly BOPE test, low 250 0.0 0.0 19:27 00:00 psi/High 3,500 psi, Annular 2,500 psi, 14118/2019 , witness waived by AOGCC (Adam Earl) Page 24135 ReportPrinted: 5/312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth rte) Start Time Erb Tana our (ho Phase Op Cade Aebi Code b Tme P-T-X operation End Depen (WS) 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 Earl), call out grease/valve 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 PRODS STK CTOP P Coil Mangement (flat spot Q 0.0 0.0 02:30 03:00 T (WT=0.120"), Slide cartforward, remove UQ, cuttremove 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 4/18/2019 0.80 PROD3 STK CTOP P Re-head BHI UQ, PT UQ to 4,500 psi 0.0 0.0 04:00 04:48 (good-test) 4/18/2019 4/18/2019 0.30 PROD3 STK CTOP P Install QTS, MU build assembly 0.0 0.0 04:48 05:06 4/18/2019 4/18/2019 1.20 PROD3 STK PULD P PU BHA#21, tum build assemble, 2.2 0.0 90.0 05:06 06:18 ° AKO motor over a rerun P14 BH bit with an agitator. 4/18/2019 4/18/2019 2.00 PROD3 STK TRIP P Bump up, set counters, RIH. 90.0 10,435.0 06:18 08:18 Shallow agitator test, 1.9 bpm diff 1451 psi, strong vibrations. Continue in hole, star turning the coil over to mud. 4/18/2019 4/18/2019 0.20 PROD3 STK DLOG P Tie into the K1 for a -3.5' 10,435.0 10,468.0 08:18 08:30 4118/2019 4/18/2019 1.10 PROD3 STK TRIP P Open EDC, circulate well to mud. 10,468.0 10,625.0 08:30 0936 Mud to surface, Cose EDC, PU Wt 35k lbs. 4/18/2019 4/18/2019 0.10 PROD3 STK TRIP P RIH, window dean, dry tag billet @ 10,625.0 10,706.0 09:36 09:42 10743' PU Wt 37 k lbs 4/18/2019 4/18/2019 0.20 PROD3 STK KOST P Set 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, 4/18/2019 4/18/2019 1.00 PROD3 STK KOST P Tag TOB start time milling Q 1 fVhr 10,742.4 10,743.6 0954 10:54 4/18/2019 4/18/2019 0.60 PRODS STK KOST P Increase ROP to 2 fUhr 10,742.4 10,744.6 10:54 11:30 4/18/2019 4/18/2019 0.10 PROD3 STK KOST P Increase ROP to 3 ft/hr 10,744.6 10,745.2 11:30 11:36 4/18/2019 4/18/2019 0.30 PRODS STK KOST P Gradually target 1 k lbs WOB 10,745.2 10,752.0 11:36 11:54 CT Wt 13 k lbs, WOB 0.8 k lbs - 50 ft/hr 4/18/2019 4/18/2019 0.60 PROD3 DRILL DRLG P Drilling ahead, 10,752.0 10,800.0 11:54 12:30 CT 4844 psi @ 1.88 bpm in and 1.83 bpm out BHP 3787 psi, 11.1 ppg EMW at the window. CT Wt 11.79 k lbs, WOB 1.61 k lbs ROP 62 ft/hr 4/18/2019 4/18/2019 0.20 PROD3 DRILL WPRT P PU Wt 39 k lbs, PUH for dry drift. 10,800.0 10,800.0 12:30 12:42 RBIH Window clean 4/18/2019 4/18/2019 4.20 PROD3 DRILL DRLG P Ct 4776 @ 1.88 bpm in and 1.84 bpm 10,800.0 11,018.0 12:42 16:54 out, free spin diff 837 psi, BHP 3823 psi, WH 16, IA 121 psi, OA 26 psi, OBD, CT Wt 11.7 k lbs, WOB 3.8 k lbs, ROP 50 Page 25/35 ReportPrinted: 5/3/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log I Stan Depth Start Time Ed Time Dw(hd Phase Op Code ACUOy Code Time P -T -X Operation (MB) End Depth MKe) 4/18/2019 4/18/2019 1.10 PROD3 DRILL DRLG P Ct 4776 @ 1.88 bpm in and 1.84 bpm 11,018.0 11,070.0 1654 18:00 out, free spin diff 837 psi, BHP 3823 psi, WH 16, IA 121 psi, OA 26 psi, OBD, CT Wt 11.7 k lbs, WOB 3.8 k lbs, ROP 50 4/18/2019 4/18/2019 0.20 FROM DRILL TRIP P Pull up hole allowing sweep to exit the 11,070.0 10,684.0 18:00 18:12 bit, PUW 39k, continue pulling to the window, jog the 5 inch. 4118/2019 4/18/2019 0.20 FROM DRILL TRIP P At the TOW, shut down pump, open 10,684.0 10,684.0 18:12 18:24 EDC 4/18/2019 4/18/2019 1.60 PROD3 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, Gearing 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 FROM DRILL PULD P PUD build section assembly 69.0 0.0 20:57 22:03 4/18/2019 4/18/2019 0.60 FROM DRILL PULD P Crew change (Nabors), Tools OOH, 0.0 0.0 22:03 22:39 LD motor and brake off agitator 4/18/2019 4/18/2019 0.75 PRODS DRILL CTOP P MU Noale and jet BOPE stack and 0.0 0.0 22:39 23:24 flush choke (B) 4/18/2019 4/19/2019 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 FROM 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 PROD3 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 (K1) for depth control 10,430.0 10,463.0 02:18 02:30 minus 2.0' 4/19/2019 4/19/2019 0.38 PRODS DRILL TRIP P Continue IH 10,463.0 11,070.0 02:30 02:52 4/19/2019 4/19/2019 3.00 FROM DRILL DRLG P OBD, 1.87 bpm at 4,057 psi, 11,070.0 11,470.0 02:52 05:52 Diff --1,250 psi, WHP=14, BHP=3,920, IA=120, OA=22, avg ROP 1331Umin, 4/19/2019 4/19/2019 0.10 PRODS DRILL WPRT P PU W135 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 PRODS DRILL WPRT P RBIH 11,070.0 11,470.0 05:58 06:10 4/19/2019 4/19/2019 8.20 FROM DRILL DRLG P 1.87 bpm at 5007 psi, Free spin diff 11,470.0 11,900.0 06:10 14:22 1080 psi, WHP=14, BHP=3885psi, IA=122, OA=28, OBD CT 6 k lbs, WOB 2.8 k lbs. Ran into siderite- 11,490-11,584' and many more stringers 11,601' PU 39 k lbs 11,777' PU 38 k lbs 11,890' PU 40 k lbs avg ROP 52 ft/mm, 4/19/2019 4/19/2019 0.30 PRODS DRILL WPRT P PU Wt 40 k lbs, Wiper #2 11,900.0 11,078.0 14:22 1440 Page 26/35 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) 1 C-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Tune End Time our(hr) Phese Op CDde Achwty Cole Time P -T -X Operzfion Mai End Depth(N(B) 4/19/2019 4/19/2019 0.20 FROM DRILL WPRT P RBIH 11,078.0 11,900.0 14:40 14:52 SID 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 FROM 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 Itis, WOB 2.11 k lbs. 11,935' PU 41 k Itis avg ROP 38 ft/min, 4/1912019 4/19/2019 1.50 FROM 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 FROM 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 PROD3 DRILL DLOG P Log formation (Kt), correction of plus 10,430.0 10,463.0 19:28 19:40 4.9 4/19/2019 4/19/2019 0.60 FROM DRILL WPRT P Continue wiper IH 10,463.0 12,057.0 19:40 20:16 4/19/2019 4/19/2019 2.15 FROM 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 FROM DRILL DRLG P PUH, obtain new pumping 12,156.0 12,156.0 22:25 22:37 paramaters, PUW 40 k 4/19/2019 4/19/2019 0.20 FROM DRILL DRLG P BOBD, 1.87 bpm at 4,078 psi, Diff --1, 12,156.0 12,173.0 22:37 22:49 psi, WHP=222, BHP=3,897, IA=122, OA=289 4/19/2019 4/19/2019 0.50 FROM DRILL DRLG P Hard spot, PUW 38 k, restart, BOBO, 12,173.0 12,184.0 22:49 23:19 1.87 bpm at 4,078 psi, Diff --1,060 psi, WHP=222, BHP=3,897, IA=122, OA=289 4/19/2019 4/19/2019 0.30 FROM DRILL WPRT P PUH, mud weight falling, MM out 0.00, 12,184.0 12,184.0 23:19 23:37 take returns outside (35 bbls), returns cleaned up, bring returns back inside. 4/19/2019 4119/2019 0.20 FROM DRILL DRLG P BOBO, 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 FROM 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 FROM 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 FROM 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 FROM DRILL WPRT T HOT has failed, circulate 5x5 sweep 12,198.0 10,684.0 00:45 01:51 and chase to the window 4/2012019 420/2019 0.25 FROM DRILL WPRT T Jog the 51nch x1, Open EDC, POOH 10,684.0 10,348.0 01:51 02:06 42012019 4120/2019 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 4/202019 4/2012019 1.50 FROM DRILL PULD T LD BHA#22 67.0 0.0 04:06 05:36 4/202019 4/20/2019 1.50 FROM DRILL PULD T PU BHA#23 0.0 72.0 05:36 07:06 4/20/2019 4/20/2019 1.20 FROM 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: 61312019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Dept Stan Time End Tire Dur(hr) Phase op cote Advay Cone Time P -T -x operation (fll®) EM Depth (fll®) 4/20/2019 4/20/2019 0.20 PRODS 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 PRODS DRILL TRIP T PU Weight 35 k lbs, continue to RIH. 10,464.4 12,198.0 08:30 09:00 Window and billet clean, 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 PRODS 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 Wt 0 k lbs, WOB 2.3 k lbs. ROP 90 ft/hr 4120/2019 4/20/2019 3.20 PROD3 DRILL DRLG P OBD, CT 4726 psi, @ 1.86 bpm in and 12,207.0 12,332.0 09:06 12:18 1.82 bpm out, BHP 3896 psi, CT Wt 0 k lbs, WOB 1.9 k lbs. " Faulted into the D, -180 API rock ROP 40 ff/h 12,327' PU 40 k Ibs 12,332' PU 40 k lbs Average ROP 39 f fhr 4/20/2019 4/20/2019 0.90 PRODS 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 -1k WOB tougs up to 12,147' RBIH SID @ 12,164' 2.6 k WOB. PUH, -6 k WOB 54k CT Wt, slight pack off event pump 54, 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 4/20/2019 1.30 PROD3 DRILL DRLG P CT 4573 psi, @ 1.86 bpm in and 1.85 12,332.0 12,361.0 13:36 14:54 bpm out, BHP 3899 psi, CT Wt -1.6 k lbs, WOB 2.6 k lbs. Diff pressure jumpingg, assuing plugged nozde(s) cleared. 12,339' PU 40 k lbs 12,355' PU 40 k lbs 12,355' PU 40 k lbs Average ROP 22 fUhr 4/20/2019 4/20/2019 0.60 PRODS DRILL DRLG P Required the sand 12,361.0 12,439.0 14:54 15:30 CT 4893 psi @ 1.85 bpm on bottom diff 1304 psi, BHP 3905 psi, WH 99 psi, IA 125 psi, OA 29 psi CT Wt 4 k lbs, WOB 1.8 k lbs, ROP 220 ft/hr in between siderite stringers. Average ROP ft/hr 4/20/2019 4/20/2019 0.40 PRODS DRILL WPRT P PU 41k Pull up above the fault, 12,439.0 12,439.0 15:30 15:54 12,151' RBIH, set down @ fault 3 times, tried reduclgn rate and orienting. Made it through by orienting TF to low side and droping the pump. 4/20/2019 4/20/2019 1.10 PRODS DRILL DRLG P CT 4633 psi, @ 1.85 bpm in and 1.83 12,439.0 12,581.0 15:54 17:00 bpm out, BHP 3896 psi, CT Wt -2 k lbs, WOB 2. k lbs. Average ROP fUhr 4120/2019 4/20/2019 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 PRODS DRILL WPRT P Wiper back in hole, RIW 10 k 11,700.0 12,183.0 18:21 18:33 Page 28135 Report Printed: 51312019 Operations Summary (with Timelog Depths) 1C-11ip Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depm Start Time End Ttrne Dwav) Phase op code Activity Code Time P -T -X Operation Ma) End Deph(We, 4/20/2019 4/20/2019 0.20 PRODS 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 PRODS DRILL WPRT P Continue IH 12,183.0 12,700.0 18:45 19:00 4/20/2019 4/20/2019 3.50 PRODS DRILL DRLG P OBD, 1.86 bpm at 4,050 psi, 12,700.0 13,115.0 19:00 22:30 Diff -1,049 psi, WHP=227, BHP=3,910, IA=122, OA=26 4/20/2019 4/20/2019 1.25 PRODS 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 4/212019 0.25 PRODS DRILL WPRT P RIH to log formation 10,324.0 10,361.0 23:45 00:00 4/21/2019 4/212019 0.10 PRODS DRILL WPRT P Continue IH 10,361.0 10,430.0 00:00 00:06 4/21/2019 4/21/2019 0.20 PRODS DRILL DLOG P Log formation (K1), correction of plus 10,430.0 10,458.0 00:06 00:18 8.0' 4/212019 4/212019 1.00 PRODS DRILL WPRT P Continue wiper back in hole, RIW 10,458.0 12,300.0 00:18 01:18 4212019_ 4/21/2019 0.50 PRODS DRILL WPRT P Work pipe through rough area 12,300.0 12,371.0 01:18 01:48 maniplulating pump rate, one pickup, PUW 43 k, continue IH 4/21/2019 4/21/2019 4.20 PROD3 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 PRODS 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 PROD3 DRILL WPRT P PU Wt 45 k lbs, Wiper #1 - 1000' 13,494.0 12,495.0 12:42 13:06 4/21/2019 4/21/2019 0.80 PRODS 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 4/212019 3.10 PRODS 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 ff/hr 13,632' PU Wt 53 k lbs 4/212019 4/21/2019 4.50 PROD3 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=46 421/2019 4/21/2019 0.40 PRODS 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 PRODS DRILL WPRT P Wiper back in hole, RIW 6 k 13,110.0 13,910.0 21:54 22:30 4/21/2019 4/22/2019 1.50 PROD3 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 4/222019 4/22/2019 4.50 PRODS 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, 0A=26 4/22/2019 4/22/2019 0.30 PRODS DRILL WPRT T Unable to achieve DLGS to stay within 14,045.0 14,045.0 04:30 04:48 i the polygon PUH, PUW 46 k, Circ beaded sweep 4/222019 4/222019 0.70 PRODS DRILL WPRT T POOH, laying 8.76 ppg beaded pill 14,045.0 12,543.0 04:48 05:30 1 Page 29/35 Report Printed: 6/3/2019 Operations Summary (with Timelog Depths) IC-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth steRTmre End rime Our (Iv) Phase Op code Activity Code Time PJA Operation (Me) End Depth (ftKB) 4/22/2019 4/2212019 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!2212019 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. Bit graded out 1-1 4/22/2019 4/22/2019 1.20 PROD3 DRILL PULD T PD BHA 24, 1.1 ° AKO, over a 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 4/2212019 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. S/D 3 K WOB @ 12,295', PUH, pulling -5 k WOB @ 12,215' Clean after 12,179' 4122/2019. 4/2212019 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. tum 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 RIGH. Struggling W poor 12,395.0 14,045.0 15:42 17:00 weight transfer, pump 20 bbl bead sweep, ride to bottom on beads. 4/22/2019 4/22/2019 1.80 PROD3 DRILL TRIP T On bottom drilling, rammped up 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 4/22/2019 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 lbs, ROP 15 ft/hr 14,106' PU Wt 47 k lbs 4/2212019 4/23/2019 3.50 PROD3 DRILL TRIP T Reaquired sand 14,100.0 14,285.0 20:30 00:00 OBD, CT 5294 psi, @ 1.86 bpm, BHP 4357 psi, CT-8.4 k Itis, WOB 1.64 k lbs, WH 357 psi, IA 124, OA 50 psi Page 30/35 ReportPrinted: 5/3/2019 . I Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log De 31ad0epih alert Time End Tm Dur(hr) (� Phase Op Cada Activtty Code Tvne P -T-% Operation (n End Ou7m (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 PROD3 DRILL WPRT P Wiper up hole to 13,447', PUW 47 k 14,447.0 13,647.0 04:00 04:30 4/2312019 4/2312019 0.40 PRODS DRILL WPRT P Wiper back in hole, RIW 04k CTSW 13,647.0 14,447.0 04:30 04:54 4/23/2019 4/23/2019 1.90 PRODS DRILL DRLG P OBD, 1.87 bpm at 5,446 psi, 14,447.0 14,577.0 04:54 06:48 Diff=1,150 psi, WHP=347, BHP=4,388, IA=133, OA=54 —Osculation 14,447'-14,574' 4/23/2019 4/23/2019 0.60 PRODS DRILL WPRT P 800' wiper up hole, 55 k 14,577.0 14,577.0 06:48 07:24 4/23/2019. 4/23/2019 6.00 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=4,386, IA=133, OA=54, (average DLGS 4° while osculating) Osculation 14,613'-14,644' 14,668'-14,717- 4/23t2019 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 4123/2019 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 -1,160 psi, WHP=347, BHP=4,388, IA=133, OA=54, (average DLGS 4' while osculating), Heavy PU @ 14,920- 4/23/2019 4/23/2019 0.20 PRODS DRILL WPRT P 14942, BHA wiper, PUW=62K 14,942.0 14,942.0 16:54 17:06 4/23/2019 4/24/2019 6.90 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 4/24/2019 4/24/2019 1.60 PRODS DRILL DRLG P Continue drilling, 1.8 BPM @ 5207 15,152.0 15,190.0 00:00 01:36 PSI FS, BHP=4417 PSI, RIW=-5.5, DHWOB=I.1 K, ROP=33 FPH 4/24/2019 4/24/2019 0.50 PRODS DRILL CIRC P Call TO @ 15190'. PUH for sweeps 10 15,190.0 15,190.0 01:36 02:06 low vis 50 Hi vis with beads. PUW=47K 4/24/2019 4/24/2019 2.30 PRODS DRILL WPRT P Start swab viper. 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 4/242019 0.10 PRODS DRILL DLOG P Log K1 for+17.5 10,437.0 10,455.0 04:24 04:30 424/2019 4/24/2019 2.00 PRODS DRILL WPRT P Continue swab wiper 10,455.0 78.3 04:30 06:30 4/24/2019 4/2412019 1.70 PRODS DRILL TRIP P Tag up reset counters, RBIH 78.3 10,435.0 06:30 08:12 4/24/2019 4/24/2019 0.20 PRODS DRILL DLOG P Log formation (K1), correction of plus 10,435.0 10,467.0 08:12 08:24 2.0' 4/24/2019 424/2019 0.20 PRODS DRILL TRIP P Continue IH 10,467.0 10,680.0 08:24 08:36 Page 31135 Report Printed: 5/3/2019 . Operations Summary (with Timelog Depths) 1c-11 • Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log S Start Time End Time Dw(m) Phase Op Cade Ac" Code Tune P-T-X Operabon M(B) End DepN(flKe) 4/24/2019 4/24/2019 0.50 FROM DRILL OWFF P Obtain static hole pressure @ 10,680', 10,680.0 10,680.0 08:36 09:06 6495.91' TVD, 11.806 ppg (3,984 psi AP), 973 WHIP, weight check 4/24/2019 4/2412019 1.50 PRODS DRILL TRIP P Continue IH through window exit, S/D 10,660.0 15,201.0 09:06 10:36 12,238', and 14,607', confine TD 15,201- 4124/2019 - 4/24/2019 0.50 PRODS DRILL TRIP P Circulate 12.1 ppg completion fluid, 15,201.0 15,201.0 10:36 11:06 PUH slowly 4/24/2019 4/24/2019 4.50 PRODS DRILL TRIP P POOH, laying in 12.1 ppg beaded liner 15,201.0 78.3 11:06 15:36 running pill, painting EOP flags 13,960' (yellow) 4/24/2019 4/24/2019 0.50 PROD3 DRILL OWFF P At surface, check well for flow, PJSM 78.3 78.3 15:36 16:06 4/24/2019 4/24/2019 0.50 FROM DRILL PULD P LD drilling assembly on a dead well. 78.3 0.0 16:06 16:36 4/24/2019 4124/2019 2.80 FROM 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. Retread E-line to LOC. Test wire +2000 / 75.6. Pressure test to 450OPSI 4/24/2019 4/24/2019 0.60 PRODS DRILL BOPE P Perform Bi weekly BOPE function test 0.0 0.0 19:24 20:00 4/24/2019 4/24/2019 2.20 COMPZ3 CASING PUTB P PJSM, Prep floor for liner pick up. P/U 0.0 1,223.1 20:00 22:12 1-2-02 lower liner segment with non ported bullnose, 41 joints 2 3/8" slotted liner, and shorty deployment sleeve 4/24/2019 4/24/2019 0.70 COMPZ3 CASING PULD P M/U coil trek to liner. M/U injector and 1,223.1 1,267.0 22:12 2254 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 12-02 7,450.0 10,567.0 00:00 00:36 lower liner segment, First pick up @ 10,490' start working liner in hole 4/2512019 4/25/2019 0.10 COMM 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 4125/2019 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 COMM CASING TRIP T Unable to get liner to bottom, POOH 12,185.0 1,267.0 07:06 09:24 4/25/2019 4/25/2019 0.50 COMPZ3 CASING OWFF T At surface, check well for flow (no- 1,267.0 1,267.0 09:24 09:54 flow), 5 bbl static losses 4/25/2019 4/25/2019 0.50 COMPZ3 CASING PULD T LD, CoilTrak tools 1,267.0 1,222.8 09:54 10:24 4/25/2019 4/25/2019 2.50 COMPZ3 CASING PULL T PJSM, lay down liner segment #1 1,222.8 0.0 10:24 12:54 4/25/2019 4125/2019 0.70 COMPZ3 CASING PULD T MU cleanout assembly 0.0 68.4 12:54 13:36 4/25/2019 4125/2019 1.80 COMPZ3 CASING TRIP T Tag up, reset counters, RIH with BHA 68.4 10,430.0 13:36 15:24 #26, surface lets agitator, 1.8 bpm at 1,050 psi, 4/25/2019 4/25/2019 0.20 COMM CASING DLOG T Log formation (K1) correction of minus 10,430.0 10,469.2 15:24 15:36 4.5' 4/2512019 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 rt De Start Depth StartTme i End Time Do(hn Phase Op code Acduity Code Tie P -T -X Operation End Depth (fiKB) 4/25/2019 4125/2019 0.60 COMPZ3 CASING TRIP T Set down @ 10,859', PUH, PUW 38 k, 10,859.0 12,193.0 15:54 16:30 adljusl TF RBIH, popped through, continue IH to next SD @ 12,193' 4/25/2019 4/25/2019 1.10 COMPZ3 CASING CIRC T PUH slowly displacing well to drilling 12,193.0 10,700.0 16:30 17:36 fluid 4/25/2019 4/25/2019 1.20 COMPZ3 CASING REAM T Clean out 10,700'to setdown @ 10,700.0 12,190.0 17:36 18:48 12,190 4/25/2019 4125/2019 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. 4125/2019 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 untill 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 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 4126/2019 0.10 COMPZ3 CASING DLOG T Log RA in for+13' 10,700.0 10,721.0 03:06 03:12 4/26/2019 4/26/2019 1.30 COMPZ3 CASING REAM T RBIH 50 FPM, 1.86 BPM. Set down 10,721.0 14,125.0 03:12 04:30 12,284, P/U went right through. Clean down to 12,354'. Pick up and went right through. Continue in. Set down 13034 No DHWOB. Pick up went right through 4/26/2019 4/26/2019 1.30 COMPZ3 CASING REAM T Lost surface weight, RIW=-6K, Slow 14,125.0 15,186.0 04:30 05:48 run in speed 4/26/2019 4126/2019 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) correction 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 1 circulating 12.1 ppg beaded completion fluid down coil. 4/2612019 4/26/2019 0.80 COMPZ3 CASING TRIP POOH, laying in beaded 12.1 ppg 10,900.0 7,640.0 12:51 13:39 LRP, encounter gas cut returns 8,670', IT send out to the tiger tank. Paint EOP flag 13,180' Page 33/35 ReportPrinted: 51312019 Operations Summary (with Timelog Depths) »w. ;. 1C-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log N De slan Depth start'nme End Time Our (N) Phase op Code Acdwty Code TiP-T-x me Opemtlon End Depth (fl(a) 4/26/2019 4/26/2019 0.50 COMPZ3 CASING TRIP T Stop moving OOH, continue 7,640.0 7,640.0 13:39 14:09 displacing well to completion fluid. 4/26/2019 4/26/2019 1.25 COMPZ3 CASING TRIP T Continue POOH, paint EOP flag 7,640.0 68.4 14:09 15:24 7,639.3' 4/26/2019 4/26/2019 0.50 COMPZ3 CASING PULD T Check well for flow (no -flow), PJSM 68.4 68.4 15:24 15:54 4/26/2019 4/26/2019 0.50 COMPZ3 CASING PULD T LD cleanout BHA on a dead well. 68.4 0.0 15:54 16:24 "• Note: 2.80 no-go 4/26/2019 4/26/2019 0.50 COMPZ3 CASING 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 PIU 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 SID pump. Continue to work liner 12,580.0 12,713.0 02:00 03:06 4/2712019 4127/2019 0.10 COMPZ3 CASING RUNL T Roll pump in compression, .5 BPM 12,713.0 12,713.0 03:06 03:12 4/27/2019 4/27/2019 0.60 COMPZ3 CASING RUNL T Work liner towards bottom 12,713.0 12,767.0 03:12 . 03:48 4/27/2019 4/27/2019 0.10 COMPZ3 CASING RUNL T Roll pump 12,767.0 12,767.0 03:48 03:54 4/27/2019 4/27/2019 1.20 COMPZ3 CASING RUNL T Continue Working liner, 12,878 tough 12,767.0 12,901.0 03:54 05:06 spot. Pump 1 BPM in compression. No returns. 4/27/2019 4/2712019 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 Gear annulus of mixed fluids, PUH laying in beaded 8.8 ppg LRP up to 10,900- 4/2712019 4/27/2019 0.25 COMPZ3 CASING TRIP P Continue POOH, laying in 12.1 ppg 10,900.0 10,420.0 10:42 10:57 beaded LRP 4/27/2019 4/27/2019 0.20 COMPZ3 CASING DLOG P Log formation (K1) for depth control 10,420.0 10,458.0 10:57 11:09 plus 11.0 4/27/2019 4/27/2019 2.00 COMPZ3 CASING TRIP P Continue POOH, laying in 12.1 ppg 10,458.0 44.2 11:09 13:09 beaded LRP 4/27/2019 4/27/2019 0.50 COMPZ3 CASING OWFF P Tag up, check well for flow (no -flow), 44.2 44.2 13:09 13:39 PJSM 4/27/2019 4/27/2019 0.75 COMPZ3 CASING PULD P LD setting tools 44.2 0.0 13:39 14:24. 4/27/2019 4/27/2019 0.50 COMPZ3 CASING PUTS P Prep RF for liner OPS 0.0 0.0 14:24 14:54 Page 34135 Report Printed: 5/3/2019 . Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stant Tim End Time Our (hr)Phase Op Cotle Activity Cods Time P -T -X Operation End Depth (Po(B) 4/27/2019 4/27/2019 4.40 COMPZ3 CASING PUTB P Start picking up liner segment #2 with 0.0 2,976.3 14:54 19:18 large ported, 1.25" bullnose, 99 jts slotted liner and shorty deployment sleeve 4/27/2019 4/27/2019 0.90 COMPZ3 CASING PULD P PJSM, P/U Coiltrak, M/U to liner and 2,976.3 3,020.6 19:18 20:12 hang in deployment rams. Change out floats in UCC. Inspect packoffs. M/U coil and surface test. Strip on. Tag up and set counters 4/27/2019 4/27/2019 1.60 COMPZ3 CASING TRIP P RIH BHA# 28, EDC closed pumping 3,020.6 10,628.0 20:12 21:48 min rate 412712019 4/27/2019 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 4/28/2019 4/28/2019 3.40 COMPZ3 CASING RUNL P Continue working 12-02 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 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 14/2812019 test. Sensor depth TVD 6184.98', Pressure stabilized @ 3882 PSI, EMW=12.07 25 Minute test 4/28/2019 4/28/2019 2.00 DEMOB WELLPR CIRC P Dispace well to seawater 10,2192 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 4/26/2019 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' whh 32 bbls of deisel 428/2019 428/2019 0.55 DEMOB WELLPR TRIP P Continue POOH 2,500.0 44.2 08:06 08:39 4/28/2019 4/28/2019 1.25 DEMOB WELLPR PULD P At surface, PUD and LD setting tools 44.2 0.0 08:39 09:54 FTP 1,200 psi 428/2019 4/28/2019 2.00 DEMOB WELLPR CTOP P MU Nozzle, stab onto stump, flush 0.0 0.0 09:54 11:54 stack and surface lines to tiger tank, vac truck on location remove returns from tank 4/28/2019 428/2019 6.10 DEMOB WELLPR RURD P RDMO 0.0 0.0 11:54 18:00 I Rig Release 18:00 hrs Page 35135 Report Printed: 5/3/2019 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1C Pad 1C -11L2-02 50-029-22714-65 Baker Hughes INTEQ Definitive Survey Report 15 May, 2019 BA. ICER UGHES GE.m,.,, Conocolahillips a Sit r, CAl1000P11llIF15 Definitive Survey Report ... Compaw. ConocoPhillips Alaska lnc_Kupamk Local Coordinate Reference: Well 10-11 Project: Kuparuk River Unit TVD Reference: 1C-11 sig 102.00uspt(1611) Site: Kupamk IC Pad MD Reference: 1C-118910200uspt(1611) Well: 1611 North Reference: Trus Wellbore: 1611!2-02 Survey Calculation Method: Minimum Curvature Doi 1C-11 L2-02 Database: EDT 14 Alaska Production Project Kupamk River Unit, North Sbpe Alaska, Untied States Map System: US State Plane 1927(Eeact solution) System Datum: Mean Sea Level Geo Date in NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 10.11 Well Position +14114 0.00 ..it Northing: 5S691003]4us0 Latitude: 70'19'33.128N +El -W 0.00 usfl Fasting: 561,641.06usft Longitude: 149' 30' 0.514 W Position DexMalMy 0.00 usfl Wellhead Elevation: daft Ground Level: 0.00 usfl Waltham ta11t2-02 Magnetics all wars. sample Daft Deolingski Dip Angle Fileid Strength PI Inn BGGM2019 411/2D19 16.71 80.88 57,423 Design 1C-1 1L2-02 Audit Notes: Version: 10 Phase: ACTUAL no On Depth: 10,712.99 Vertical Section: Depth From (TVD) ♦W4 aEwi Winston (usft) les) (da) (1) - 41 so coo 0.120 90.00 Survey Program Date From TO Supply Sunday leapt) Ni Survey(Wellbore) TOW wire Deacriplfon SftltoWe E1M Daft 121+00 10,495.53 1C-11(1611) MWD MWD -Standard 825/2000 10,684.00 10,712.99 1CAIL2 MWD -INC (1611!2) MW41NC ONLY MWD-INL ONLY FILLER 4/52019 4/52018 10742.00 10,769.67 1C-111.2-02 MkAr(1G11L2-02) MWS}INC ONLY MW61NG_ONLY FILLER 42312019 4232019 10,799.91 15,160.93 iC-11!2-02 MIND (1C.111.2-02) MWD MWD - Standard 424/2019 4242019 5n52of9 10:15'04AI6f gaga 2 COMPASS 5000. 14 Bngd 85D ConoeoPhillips Bi 0 CO11000PflIlllPS Definitive Surety Report Company. ConocePhAps Alaska Inc_Kupamk Local Oo,mi inate Reference: MI) 1C.11 Project: Kupamk River Unit TVD usher e: IC-11®102,OOusR(1C-11) Site: Kupemk lC Paid MD Reference: iC-11®102.00usn(1C-11) Well: IC -11 North Reference: True Wellbore: 1C-11 L292 Survey Calculation Method: Minimum Ou.ure Desigr,'. 1C -11L202 Database: EDT 14 Alaska Prorludion Survey Map Map Vertical MD Inc Act TVD TV096 WS +EI -W Northing Eacting DlS '1 Section Survey Tool Name Annotation(usnl I11 11I lusnl lusnl lura IManl Inl Inl hnl PnDID In) 10.712.99 45.37 351.00 6555.26 6,453]6 2,842.93 -1,20720 5,9168.74 56036955 1287 -1,20].20 M 11INC_ONLY(2) InteryOlateE PSimulh - TIP 10.24200 So. 35148 6,93.21 6421.21 7.870.38 -1,21965 5,82696916 56036591 43.56 -1,210.65 MAI ONLY (3) KOP 10289.82 65.22 368,30 6,58625 6,@4.26 7,884.62 -1,24.55 5,92689242 560 363M 32.52 -1213.55 MN0.1NC_ONLY (3) InteryOlateEAu imNh 10.29981 23.22 6.82 6,592.22 6495.22 7,922.95 -1,210.98 58268448 560,365.16 3536 -1,210.98 MND(4) 10,92922 81.60 15.14 680358 6,501.56 7.951.49 4205Ao 5826949.29 587,320.87 3L92 -1,205.44 MJUD(4) 10860.00 8646 X..35 660610 6544.18 2,929.20 -1194.69 5,92691 SWIkh 43.42 -1.194.69 MJN(4) 10,08954 9344 36.87 660560 6,50.68 8.00503 -1, MIT 5,901.40385 560.396.29 38.52 -1129.12 MIND (4) 10,920.01 97.11 4243 6,6UW 6,500.90 8.02230 -1 ISy08 5,922,02.5.49 560,416.19 32.50 -0,159.08 MAD(4) 10949.95 8981 6025 6,59625 6495.25 8,044.21 -1,135.28 5,922.043.00 560.439.65 42.92 -1,115.28 MND(4) 10,980.02 100.68 RAN 6,SW52 649162 8,056.63 -1,108.11 5822,05523 560,466.92 40,20 -1.108.11 MOD(4) 11008.91 101.11 85.28 6,507,96 6,486.95 8,062.30 -1,0]8.32 5.972,06113 SWAS.So 4230 -0.029.32 MAD (4) 11036.10 101.33 9A0 6.502&0 6 48D8 8,061.70 -1 553.24 5.922.060]4 661 45.40 -0.453]4 MAD (4) 11,065.50 101.19 109.20 6,92.02 6,42502 8.055.20 -1,025]0 5,922054.42 2.4.54932 3TM -1,M70 MND(4) 11, WI 101.44 11228 6521.24 6 HiS.24 8,044.88 498.44 5,9n.OM.36 560,526.5 13.42 F98.44 MWD(4) 1112545 10122 11648 6,55.30 6,487.30 8,03254 4021.51 5.972032.26 587,603.87 1209 -021.51 111 11.155.12 100.31 H99 6,559]5 .,45775 0,01996 4)45.62 5,922.01909 587,639.87 928 945.62 Niel 11,18509 9908 1.41.18 8,554.9 6452.92 8004.39 110.98 5.972(04.54 660,656 44 8.43 -919.99 MWD(4) 11215.87 542 122.16 6.5102 6,44907 2498958 ZB385 5,928,908.95 560.681.71 8.30 -873.85 MWD(4) 11,246.99 9552 119.06 6,54281 6445.81 2.9883 %2.23 5.976.97342 560,200.46 IDM 182.23 MWD(4) 11,277.32 9058 11901 6,545.12 6,443.12 7958.40 4140.69 5,976.958.21 550.73511 4.75 d4O.6B MWD(4) 11.305.78 9304 116.23 8,543M 6,441.03 2,845.35 115.47 5.926.94.5 55O.2W.43 5.19 41542 MAD (4) 11'..51 93M 114.17 6,54L01 6.43901 7,932.18 -78280 5,92693342 550.788.21 632 48280 MM (4) 11.36223 9541 113.56 653055 6436.55 7919.79 45929 5,944,93126 550,816.3, 5.85 -75979 MWD(4) 11,395.12 96.04 112.81 6.53558 6,433.58 7,a.,. -73426 5,928.91954 56,841113 5.22 -734.26 MAD (4) 11426.55 95]9 110.28 653213 6.430.13 7.88240 -00525 5,926.89932 560021.03 665 40525 MWD(4) 11,454.94 9523 10932 6,529.40 6.427.40 7,8&9.5 828.58 5,92689020 560.892.77 7.18 E7656 MWD(4) 11404.52 84.34 104.76 6.55.93 6,424.93 799.66 65033 5,92600204 580.926.09 1235 65033 MAD (4) N,510.73 94.55 10182 6,524.28 642128 7,9182 61214 5926024.48 550959.34 9.59 64.14 MAT) (4) 11544.82 9631 102.11 652185 6,418.85 7,887.46 SB1.88 5976.869.32 560,894.64 6.54 -59188 MIND (4) 1195.11 95.87 1M.24 6518.65 6,416.65 7,887.59 456219 5900.87168 51014.38 5.40 -56218 MWO(4) 54152201910:1(134.444 Page 3 COMPASS SN814 SUM 8539 ConocoPhillips O ConocoPhillips Definitive Survey Report Company: Co oncePhillips At Inc _Kupa uk Pmjecto Kupamk River Unit SIR: Kupamk 1C Pad Well: 1041 Wetmore: 1C 11 L202 Design, 10-11-202 Survey Local Coordinate Reference: 4Ve111C-11 Top Reference: 10-11 @ 102.00uan(1C 11) MO Reference: 10-11 ®102.00usn(1C-11) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Annotation 915201910: 15: 34AM cattle CCMAA555000.143udi Map Mep Vertical MD law,qtl TVD TVDSS eWi ♦wM No Ea( DLS Section tool Name Nary r) 19 (runt (.1111loalry (9Mr) (•noo9 Survey Ift) n) (ft) n) n) 1.1.,60924 600] HBSt 6,580 6,4126] ],855.30 529]3 59]4.652 68 561.046.8] 9.00 523.]3 MJJD (4) fldoli 9582 9568 6,511,19 644919 7und9 301]0 5,976.85549 561.074.93 tt85 501]0 0404.(41 fl YK.59 W79 WN 6,5MM 6,40]09 7,84994 47295 5,9]6.653.]] 561,102bB 16,01 473.95 HIM (4) 11895.07 92.95 9321 640)51 640.5,61 7IlWeM 44252 5,904,05131 561134/2 691 442.52 Mili 11124.51 M.M But 6,51 6,404,17 7Sulaw 414.12 59M.M,92 66116252 696 414.12 MMD 14) 11 ]5621 8997 WAt 658660 6403.50 ],051,1] 4181 5,8]6.855]6 561,194,15 10.63 N2.47 MWD (41 11]84]9 8660 83.M 6,58604 8 403A8 ],85].04 '154,02 5904,05065 561222.57 1050 -354.02 MMD(4) 11810.46 81.10 H2W 65C5.89 640209 ],056.90 42053 5,976,86192 561.248.03 950 4120.53 Ilii 11.31 93.57 8234 650488 640280 7,BWAI -28925 5,9]68656] 561,2]28 8.45 -299.25 MMD(4) 118]5.9] 93.87 87.81 6,502]5 6,400,35 7111 363.52 5,9173 56181298 12.45 -M.52 MMD(4) 11835.67 90.43 8080 6.50123 6393.04 7,88685 332]9 5,9M.&i 561342.70 1202 -233.79 MMD (4) 11.935,86 87.45 9384 6,501,78 639918 788635 -20480 5.9199 561.3'2.11 1156 -20480 MWD(41 11,964.71 BG,So 92.70 658624 6.40124 7,063.4 -174.81 5.H]G,B69.II 561.40186 784 -174.81 MMD(4) 11.upi Way 95.01 6.50415 6,4MO 7 c -14907 5,9M,860M 561,42]43 0.93 -148.07 MMD(4) 1.202055 8631 94.04 6,568.43 6,404.43 7,05833 -119.12 5,9M.MAG7 561,457.33 363 -119M MVrD(41 1205180 90,09 9301 6,507.18 640.5.10 7,85742 Aii 5,976,6104.42 561.9].99 ISM -86.54 0404.(4) 1288037 Mi 8981 6,50779 6.40.579 785621 59.50 5,904,86384 561,6VAM 10.13 58.50 11111 12,111.7 Not 81 659974 640].]4 7,057,43 368] 597686481 561547[5 7.05 -26.07 MWD(4) 12.131.45 8640 68.34 6,51974 6,408.]4 7,05916 4,53 5,904.86502 561 56]89 1243 853 MVVi 12,15741 0986 94.5] 6511.18 6,40910 7,851 1].3] 5,876.88]8] 561,58607 1531 1737 MWD(4) 12,10,13 88.59 8481 6,511.86 6,404.60 7,686.2 49.92 5,9M.871,16 %Ifs 39 269 4992 MM➢(41 12219.94 88.65 81.86 6,512]9 6410.39 7me74 79A9 5,976,07512 on65,92 788 79.49 MWD(41 12,250.04 8840 79.8 651317 6.41117 ],8]167 109.17 5,976.88629 56188556 729 10917 MWD(4) 12.29]3 87.11 80,09 6.51433 641233 7,81 138.37 5,976,Wnt 561]14]1 4.11 13837 hi 12,39985 8595 8187 6,51619 6,414,19 ],881.79 168.14 58]6,090.89 561]9 83 5.94 16014 MWDI41 12,34133 8383 B1.50 6,519W 641]06 7,886.44 199.3 5,976,09580 561,]7529 Try 19983 MM (4) '2,37186 83.86 BUM 6,52237 64,1187 7,89041 229.12 5,97698601 561,68634 6.59 22812 MAID (4) 12,21982 83.33 85.46 6,52845 642345 7,891,05 25658 5,976.=69 561,8327] ]25 256.50 MADI4) 12.31.13 8539 111 6,52054 642654 7,894.92 207.00 5904,905.1 66184486 660 28786 MWDI4) 1246329 8390 81 653154 642955 7,Me76 31.9.96 5976,986.12 86109686 6,56 31809 MAD(4) 12.1,. 8251 Brien 6534.92 6,432.92 ],01 34821 591.65 56192437 505 M021 MAD(4) Annotation 915201910: 15: 34AM cattle CCMAA555000.143udi ConocoPhillips %+ au Q COf1000Ml1p5 Survey Report ._. Definitive C."re: COnoWPMIk, Alaska lnc Kupamk Li Caardbua Referanu: Mil 1C41 %Preps; Kupamk River Unit TVO Reference: 1C-11®102.00usn (IC-11) Sea: Kupamk IC Pad MO Rein..: 1C-11®102.00usfl(M-11) j WA: 1C-11 None Reference: Tme Wobae: 1C-1182-02 Survey CalculaWn MetbOd: Minimum Curvature ;Dodge: 1C-1112-02 Database: EDT 14 Alaska Production Starkey Map Wetlial MO Inc Ad TVD WDSS ♦m.5 9am Naming E OLS Secnen! survey T9ol cram. Anrrolalun. ' lues) (1) V) ("sen) Met (usg) (-ft) (R) pry (./low) (R) t2,521X 8295 W14 6,538.65 6435.65 i,Ine 65 3TAi 5,976907.97 Sfit 9vi.5fi 5,14 37741 MWD(4) 12,5559] 83.10 "M 6.542.@1 6,44006 ],896]5 411.79 59]690985 56190]92 9.39 411.79 MrW(4) 1258639 0335 art ae 6,5$.45 644445 7,901.82 44f &5 5976,91316 5 ,111]134 455 "1.85 trim (a) 1261182 8366 0192 6.549.34 6,"].34 7,90504 467,01 5,976.916.59 562.0$.07 6.23 467.01 "D(4) 1264005 83.42 Mile 654.50 6450.50 7,909.44 494.61 5,976921M 5620]063 890 ,eA61 kevn(4) 1267059 85.39 790 6,555.40 6453.40 7,91496 52449 5,976,928.99 582.1W.47 7,05 52449 VAD (4) 12700.2] 84.68 ]6.01 6,558.05 6,456.05 ],92114 553.41 5,978,933.40 562.129.33 0.02 55341 KRAD)4) t2MA7 83.97 ]4.60 6.56110 6,459.10 7,928.60 5.43.13 5,9m,ml.11 56215699 6.35 583.13 klAU(4) ,2]6130 83.57 ]3.$ 6,564.30 6,46238 ],936]9 61204 5,$6949.53 54.10].02 5.36 612.04 kNAD (4) 1279159 62.33 71.0 6,569.10 6,466.10 ],945.9] 8$.67 5$6958$ 56221638 8.72 6$.97 ~(4) 12821.49 82.71 ]OW 6,571.99 640.99 7.955.65 66869 5976,968.85 54,24431 105 659.68 &VAD (4) j 1285418 84.84 70.0 6.575.60 6,4Tf.60 7.966.48 fi0.96 5876,97993 56,MAM 641 60.96 MN0(4) 12.80441 87.80 Me 6.577.40 6,4F.40 ],8]5.81 7MO1 5,9]6989.$ 5430.46 1114 88.01 MND (4) 12.919.95 88.87 71.29 5.578.49 6,476.48 7,8%.93 76115 5,W].OW.4 54,337.11 1. 761.75 MWD(4) ,2,950.41 88.19 ]1116 6,579.27 6,47].2] ],990.98 50 ]90. 5,97.011]8 562,355]7 433 ]BOW MAD (4) 129802] 87W 68.98 65$38 6,47838 8,007.40 91645 59]],4182 5439364 4.04 818.$ MWD (4) 13,01106 BTal 6].0] 6,58138 6,478.30 8,018.71 947,00 5,97.0333] 54,42216 3.60 847.0 MWD (4) 13.0"33 8716 66.41 6.54.52 64$.52 8.030'$ 87495 5,97.045.35 562"9.03 476 074.95 MD (4) 13,07D.91 W18 64.54 8,54.93 6481.93 604272 901.83 5.97,051'.83 W24M.71 7.13 BOf83 MWD (4) 13.10463 86.20 63.$ 6,5&5.99 64489 8,057,48 932.00 5,97,07263 02506,83 366 9320 MWD (4) 13.131.01 97.06 6232 660]54 6,485.54 8,09.48 95551 6,87,05.0 562,530.1] 5.38 955.51 MW0(4) 13,15964 9613 We 6,66914 6486.74 8.082.80 Wirt 5,8]I,00.Y` 54,555.3] 3)] 980.83 MWD (4) 13,19031 8674 62.10 6.509.50 6,487.58 8.097.13 1,007,93 5,07.113]0 54582.35 2.01 1,00].93 MWD (4) 13,2190 89.64 61.47 6,5.41.0 6.488.03 0.111,13 1.034.03 5,97,127.31 s62808.33 3" 1,04.03 "D (4) 13.250.59 91.56 0219 8,50.73 6,40].]3 8,126.60 1861.0 5.97.14201 562635.23 60 101M MWD (4) 13,27950 4.96 6206 6580.61 6405.61 8,138.15 1,00666 5,9]]155.]6 lass 4.51 1,086.66 MWD (4) 1331003 94.24 610 6500.73 6,484.73 8,153.61 1,11J39 5,97,170" 56268].33 5.54 1,113.39 MWD (4) 1334054 92.61 Was 6684.91 644.91 0.160.39 1.14002 5,97.195." 02713.83 5.$ 1,140.02 MWD (4) 13.3700 90.95 59.54 6,503.99 6.461.99 Mao. 1,16664 5,9"';sx, m 562739.34 7.13 1.165.64 "D(4) 13MD28 90.40 50.07 6,5463 640163 8,19653 1,191.57 5.97.218W 56276514 207 1,191.57 MWD (4) 1343099 0979 W60 6.50350 640158 8,214.07 1,217.46 597,232.% 562790.90 i0 1,217.46 MWD (4) &IW01910.15: 34AM Pelta 5 COMPASS 500014 Build 85D Survey ConocoPhillips� O COf1OCOPhIlllPS Definitive Survey Report u Com,"", Conow iNpa Alaska lnc Kupamk Local Coomhmete Reference: Mil 10.11 Peject: Kupamk River Unit TVD Reference: 1G11@ 102.00usg(1G11) She: Kupamk I Pad MD Reference: 1,7110102.00us6(1G11) Wall: 10.11 North Reference: Tee Wallace: 1C -11L2412 Survey Calculation Method Minimum Curvature Design: 10-11 U42 Database: EDT 14 Mesta Pmd.di0n Survey S 16 019 10: 153MM Pella 6 COMPASS 5 ,14 Budd 850 , Map Vadical MD Inc Aid TVD TVOSS ♦W4 eVJ NucMng Eastln DLS Sn eeOa Sunni, Tool Name Annotation (ugh) PI (1) inch) (-am (usNl (uri MI (glg Moor) (a) 13,460.26 89.85 5502 650367 6401.67 8,231.37 1,241,75 5,971,24925 56].61500 530 1,24175 MWD(4) 134%.21 9046 04.10 6503.59 6,481.59 8,248.61 1,2%24 5, n,1%.69 562.63936 2.30 1.266.24 MWD(4) 13,520.17 09.45 53.30 6583.82 6,481.62 8,266.22 1,290.48 5,811,284.49 562.8634/ Sib 1,29048 MWD(4) 13,552.23 Sh. 5107 6584.20 6,48220 8,29,87 131580 5,971.304.35 562.888.63 7.61 1,31580 MWD(4) 13,579.01 88.52 52.01 6,584.91 6,40291 8.30252 133676 5,977.321.17 56290945 352 1.3%76 MM (4) 13,610.33 89.14 51.34 adh.55 6.463.55 0,321.94 1,361.33 5.7.340]9 56.93385 281 1,361.33 MWD(4) 1364054 91.11 50]9 6,58548 6,46346 834093 1,38002 5,977.359% 562.857.18 677 1.384.82 MWD(4) 13,67024 90.71 MA3 6,585.01 6,483.01 0,35997 1,407,61 5,97/,376.19 562.979.82 4.77 1,407.61 MWD(4) 13,099.94 09. 40.07 6,584.92 6,48292 8,379.55 142084 5,977.39695 5..00198 5.86 1,428.64 MWD(4) 13,734.07 9092 4263 658415 6,48275 640295 145500 5977,422.55 561,027.72 370 1.455.88 MWD(4) 13758. 91.78 47.65 6584.16 6,48216 0.41977 1.474.39 5977.439.54 503.0..10 351 1,47039 MWD(4) 1378525 92.67 45.71 6,583.18 6,461.18 6437.15 149282 5977.457.06 583.054.39 830 1,492.82 MWD(4) 13,81980 92.06 45.79 6,58115 647915 8,46102 1,59.76 5,97).481.13 563,01190,3 3.56 1,517.76 MWD(4) 13.84l9.% 9261 43.30 6,500.53 6,478.53 8,48227 1.639.04 5,67750255 5[3.110.23 1i.73 1.539.04 MWD(4) 13,880.29 9216 4252 6579.26 6,477.26 8,563.. 1.65911 5,977,520,49 S6i.1M.72 290 1.559.71 MWD(4) 13.01019 9178 4182 6,578.2A 6,476.24 0,526.65 157978 5,977.54726 58,7.15058 260 1.9978 M (0) 13,639]6 9109 40.04 6,5750 6,47550 6540.80 1.698.14 5,97759915 563.169]7 6.47 1,596.14 MWD(4) 13,97645 9190 38.16 6576.55 647455 0.57745 1,622.27 590.598.40 569.162.67 559 1,62237 VNMi 14,010.37 9169 35.24 6575,46 647348 8604,45 1.60277 5.971.62557 501212.94 589 1.84217 MWD(4) 14,041.9 91.0 35.21 6,574.74 647274 0,629.45 1,66075 5,977650.71 563,23071 3.09 1,66015 MWD(4) 14,071.35 07.05 3222 6575.23 6.473.23 6854.54 167746 5,977.67594 50.24734 1663 1677.46 M (4) 14 ,20214 6635 28.14 6,97.01 6,475.01 8.681.10 169294 597710263 56320247 13.42 1682.64 MMD(4) 14,130.43 8797 2365 6.570.41 8.476.41 8,70652 170528 5,9Tp2B.14 563.274.60 taus 1,70528 MAD (4) 10162% 8985 20.18 6979.02 6.477.01 8.735.31 1,7926 5,977158.03 sw2 . 1228 1,717.26 M (4) 14,190.12 89,011 1497 657928 6,477.28 8.762.58 185.58 5,977.784.36 569,291.44 19.12 1725.58 ~r 4) 14,22026 8994 1167 6,579.55 6.477.55 8,791.90 17M..53 5,97!.81373 5.301,14 11.34 VMMJ (4) 14,X5.33 8978 963 6578.61 6.477.61 8,816.54 173716 5,977.83BA1 5..3..57 8.15 1]37.16 MM1N(4) 14,26801 8826 9.76 6579.82 6.477.82 0.04067 1,741.28 5.971.852.57 5833%5!1 219 1,741.28 M (4) 14.303.05 87.32 4.50 0,580.01 6,478.01 S.W3,62 1,745.10 5,977,09555 56331335 16.861 1,745.40 M (4) 14,33158 87]5 0.65 65020, 64..a4 8,90208 1145.68 6,977,92403 SM,314,38 1357 1,7M.68 MOiM(4) 14.36113 88.37 35731 6.503.0, 648104 8,931.61 1,746.16 5,977.953.54 509313.63 1149 1,746.16 MJ 14) S 16 019 10: 153MM Pella 6 COMPASS 5 ,14 Budd 850 Annotation �o A i uc"�s Sof Q 19 10: iS34AM Papel COMPASS 5000.14 e W 65D ConocoPhillips ConocoPhillips Definitive Survey Report Compary. ConocoPhillips Alaska lnc Kuparuk Local Coar6inate Reference: wolIC-11 Pmlen: Kupamk River Unit ND Reference: 10-11@ 102.00usn(1G11) She: Kuparuk 1C Pad MO Reference: 1C-11 @ 102.00usn (10-11) Well: 1C-11 North Reference: True Wellbore: 1C -11L2-02 Survey Calcula0on Method: Minimum Curvature Deaign: 1C-11 L2-02 Database: EDT 14 Alaska Pmduction Survey Map Map Vertical MD Mc 441 iVD TVOSS 1)N1 -S ♦37400 Noft) Easting OLS Section (-am r) 1°I luznl Insnl (.01lusR) ( In) In) I°1160) Survey TDbl Name (ft) 14,39117 SAX 36332 65333) 648137 6961 to 1,7"0 5,9]]983.51 563311.11 7,43 1,74449 MWD (4) 10430.23 L19.16 354.48 fi58382 6401.02 9,000.53 1741.38 5,928,023.41 563,30836 T36 1,24136 MWD(4) 14466.42 08.59 352.0 6584.90 6,40390 9.036,54 1,232.39 5,928.058.38 563.303.99 4.44 1,232.39 MW(4) 14495.54 68.13 352.93 6,58523 6483.23 9.06532 1]33.81 5978,002.18 563,300.18 150 1233.81 MfN(4) 14530.12 89.34 352.23 6,506.29 648650 9.09322 1,M" 5,076,121Atl 563,295.58 0.86 1229.49 MWD(4) 14555.31 BB.86 35231 6,58241 6.485.41 9,12464 TM.21 5,82&146.32 563,292.10 253 1,226.21 MAN(4) 14585.42 8813 39,95 6588.20 8.48520 9.154.42 1,22152 5.920.126.12 563,282.21 009 172152 MND(4) 14,616.53 8344 34fi,. 6583.48 6,488.40 &184.24 1215.29 5,928,297.38 563.280.86 10.59 171529 MW➢(4) 14E4739 8263 343.86 6594.7 6,492.9 9,214.37 1,202.40 5,920,235.94 563.222.63 9.03 1,20740 M (4) 14625.51 05.51 341.10 6,597 03 6,495.03 9,241.04 1563.06 5.920,28254 563,97359 1364 1,699.06 MW➢(4) 14,205.26 86.42 340.43 6.599.15 6,492.15 9.259,53 1689.12 5028.28094 .761,363.02 3.82 1,WMA2 MM (4) 14.235.25 84.16 332.35 6,601.97 6.499.60 9.292.41 1,620.38 5,92631&23 .761)4203 12.81 1,62&36 MND (4) 14,26529 82.20 332.62 6.fi05.03 6.50303 %o2445 1,65625 5,928,34566 563,230.01 18.22 1,97575 Mass (4) 14297,38 BS.ot 322.35 6.600.42 6.50.42 9,351.64 1,65606 5,928,36666 553.214.09 1822 1,55DM MWD(4) 1482538 82.24 323.50 fi6t635 6,50&35 8,325.15 1,63380 5.92&396.97 563,192.8 15.28 1,633.88 KIND (4) 1485&23 8&06 319.30 6,6115 6,509.55 9,392.38 1.615.62 5.928.411128 X3.12933 1409 1,61562 MID (4) 14,88550 85.91 316.96 661314 6,51114 9,420,49 1,59550 5.928.441.12 563,150.92 10.49 1595.50 MD (4) 14,915.31 83.13 310.M 6.816.0" 6,51404 9,44131 1,52369 5.928.46125 53,135.99 23.59 1.523.69 MD (4) 14950.83 6&b 30686 Also 6,51663 9,463.5 1,548]9 5,926,483.20 563109.91 15[3 1546.29 MAO (4) 1492611 9202 scam 6fi18m 6,516.34 9,429.48 1,52242 5,920,499.55 563,090.16 12.96 1527.12 MIND (4) 15.0065 9792 35.95 6615.45 6,51345 9496.12 1.53.38 5,926518.97 563,05.23 18,W 153,38 Mi D(4) 15103531 89.98 302.52 (610.97 6,509.00 94515.93 1.47piNi 5,928.53565 X3,042.64 6.97 1,429.94 MM (4) 15.06625 101.26 310.02 6605.26 6,503.28 &50042 145701 5,920,553.1)8 53,018.5 9.40 1,452.01 MND(4) 15.094.55 10126 309.29 6,599.26 6,49726 &552.14 1,435.65 5928.52143 52.998.06 2.70 1,435.5 Milli 15,12530 1012a 31023 Astia 3 6,491.23 9,52150 1,412.49 5,928,590.60 562,974.74 4.53 1412.40 1AJrD(4) 15160.83 100.82 311.21 6faksw 6464.90 9,594.45 13X.15 5,978.613.34 562,948.22 126 1386,15 MND(4) 15201.00 100.02 31131 699.35 6.427.5 9,6211.38 1395.54 5,978.639.01 562.91640 009 1,356.54 PROJECTED to TO Annotation �o A i uc"�s Sof Q 19 10: iS34AM Papel COMPASS 5000.14 e W 65D I BA ER0 PRINT DISTRIBUTION LIST F UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1C -11L2-02 FIELD Greater Kuparuk Area CD/DVD COUNTY North Slope Borough PRELIMLOGS BHI DISTRICT Alaska SURVEY I AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider(o2bakerhuohes.com STATUS Final Replacement: COMPANY ADDRESS rEDEX WILL tqT DELIVER TO P.O. BOX) PERSON ATTENTION V t BP North Slope. EOA. PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 Exxon Mobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AS 99503 State of Alaska -AOGCC Attn: Natural Resources Technician If 333 W. 7th Ave, Suite 100 .Anchorage, Alaska 99501 219045 3 0 a 3 0 :e sign and return one copy of this transmittal form to: DcoPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. 3orage, Alaska 99510 LOG TYPE GR - RES LOG DATE April 24, 2019 TODAYS DATE May 16, 2019 Revision Details: Rev. Requested by: --- FIELD I FINAL CD/DVD FINAL PRELIMLOGS (las, dlis, PDF, META, I SURVEY I REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES # OF COPIES 4 lu 1� 4 4 4 RECEIVE AOGCC 5DNR -Division ofOil&Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver o ur r.xpioranon (AIasIM) Inc. Petrotechnical Data Center, IR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 BA ER F IGHES BAT GE company Date: May 16, 2019 m: Abby Bell ACGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 799043 30794 Letter of Transmittal Harvey Finch Baker Hughes, a GE Company 795 East 94" 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 (1) Total print RECEIVE® 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 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1C Pad 1 C-11 L2-02 50-029-22714-65 Baker Hughes INTEQ Definitive Survey Report 15 May, 2019 BAER UGHES a GE company 219043 30 794 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConowPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Project: Kupamk River Unit TVD Reference: Site: Kupamk 1C Pad MD Reference: Well: 1C-11 North Reference: Wellbore: 1 C-11 L2-02 Survey Calculation Method: Design: 1C-11 L2.02 Database: Project Kupamk River Ung, North Slope Alaska, United States Date Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Survey (Wellbore) Map Zone: Alaska Zone 04 1C-11 (1C-11) Well 1C-11 1C-111-2 MWD -INC (1C -11L2) Well Position +N/ -S 0.00 usft Northing: 10,799.91 +El -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 1C-111-2-02 Magnetics Model Name Sample Dale BGGM2018 4/1/2019 Design 1C-111-2-02 Audit Notes: Well 1C-11 1C-11 @ 102.00usft (1C-11) 1C-11 LID 102.00usft (1C-11) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,969,008.74 usft Latitude: 561,641.06 usft Longitude: usft Ground Level: Declination Dip Angle 16.71 80.88 Version: 1.0 Phase: ACTUAL Tie On Depth: 10,712.99 Vertical Section: Depth From (TVD) (usft) 41 60 Survey Program Date From To Description (usft) (usft) Survey (Wellbore) 121.00 10,495.53 1C-11 (1C-11) 10,684.00 10,712.99 1C-111-2 MWD -INC (1C -11L2) 10,742.00 10,769.67 1C-111-2-02 MWD -INC (1C -11L2-02) 10,799.91 15,160.93 1C-1112-02 MWD (1C-1112-02) +N/ -S (usft) 0.00 +El -W (usft) 0.00 Direction V) 90.00 6n(ee UGHES 70° 19'33,128 N 149° 30'0,514 W 0.00 usft Field Strength (nn 57,423 Sr1&2019 10:15:34AM Page 2 COMPASS 5000.14 Build 85D Survey Survey Tool Name Description Start Date End Date MWD MWD -Standard 8/25/2000 MWD -INC ONLY MWD -INC ONLY FILLER 4/5/2019 4/5/2019 MWD-INC—ONLY MWD-INC—ONLY—FILLER 4/23/2019 4/23/2019 MWD MWD -Standard 4/24/2019 4/24/2019 Sr1&2019 10:15:34AM Page 2 COMPASS 5000.14 Build 85D Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well is -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-1112-02 Survey Calculation Method: Minimum Curvature Design: 1C-111-2-02 Database: EDT 14 Alaska Production Survey Annotation Interpolated Azimuth - TIP KOP Interpolated Azimuth 5/152019 10:15:34AM Page 3 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E1 -W DLS (usft) (q (•) (usft) (usft) (usft) (ueft) Northing Easting (end) Section Survey Tool Name (ft) (ft) (ft) 10,712.99 45.37 351.00 6,555.76 6,453.76 7,847.93 -1,207.20 5,976,845.74 56D,369.55 12.87 -1,207.20 MM -INC _ONLY (2) 10,742.W Woo 351.48 6,57371 6,47171 7,870.38 -1,21065 5,976,868.16 560,365.91 43.56 -1,21065 MWD -INC -ONLY (3) 10,769.67 65.77 369.30 6,58675 6,484.76 7,894.67 -1,212.55 5,976,892.42 560,363.82 37.52 -1,212.55 MWD -INC ONLy(3) 10,79991 73.77 6.87 6,597.22 6,495.22 7,922.95 -1,210.98 5,976,920.72 560,365.16 35.36 -1,210.98 MWD (4) 10,82972 81.68 15.14 6,603.56 6,501.56 7,951.49 -1,205.40 5,976,949.29 560,370.50 37.92 -1,205.40 MWD(4) 10,860.08 8846 26.35 6,605.18 6,504.18 7,979.70 -1,194.69 5,976,97760 550,380.98 43.02 -1,194.69 MM (4) 10,889.84 93.44 36.68 6,055.68 6,503.68 8,005.03 -1,179.17 5,977,003.05 560,396.29 38.52 -1,179.17 MWD (4) 10,920.01 97.11 47.43 6,602.90 6,800.90 8,027.30 -1,159.08 5,977,025.49 560,416.19 37.50 -1,159.08 MWD (4) 10,949.85 98.81 60.25 6,598.75 6,496.75 8,044.71 -1,135.28 5,977,043.08 560,439.85 42.92 -1,135.28 MM (4) 10,980.02 100.69 72.41 6,59362 6,491.62 8,056.63 -1,108.11 5,977,055.23 560,466.92 40.20 -1,105.11 MWD(4) 11,009.91 101.11 85.28 6,587.95 6,48595 8,062.30 -1,079.37 5,977,061.13 560,495.60 42.30 -1,079.37 MWD(4) 11,03610 10133 97.40 6,582.83 6,405.83 8,061.70 -1,053.74 5,977,060.74 560,521.23 45.40 -1,053.74 MWD(4) 11,065.50 101.19 108.70 6,577.07 6,47507 8,055.20 -1,025.70 5,977,054.47 560,549.32 37.70 -1,025.70 MWD (4) 11,095.23 101.44 112.76 6,57124 6,469.24 8,044.88 -998.44 5,977,044.38 560,576.66 13.42 -998.44 MWD (4) 11,12545 101.22 116.48 6,565.30 6,463.30 8,032.54 -971.51 5,977,032.26 560,603.69 12.09 -97151 MWD (4) 11,155.17 100.31 118.97 6,559.75 6,457.75 8,018.96 -945.67 5,977,018.89 560,629.64 8.78 -945.67 MWD(4) 11,18508 96.05 120.16 6,554.97 6,452.97 8,004.39 -919.99 5,977,004.54 560,655.44 8.43 -919.99 MWD (4) 11,215.88 96.47 122.16 6,55107 6,449.07 7,968.58 -893.85 5,976,988.95 560,681.71 8.30 -893.85 MWD (4) 11,246.99 95.57 119.05 6,547.81 6.44581 7,972.83 -867.23 5,976,973.42 560,708.46 10.32 -867.23 MM (4) 11,277.32 94.58 118.01 6,545.12 6,443.12 7,958.40 -640.69 5,976,959.21 560,735.11 4.75 -84069 MWD (4) 11,305.79 93.84 11673 6,54303 6,44103 7,945.35 -815.47 5,976,946.36 560,760.43 5.18 -815.47 MWD (4) 11,336.51 93.72 114.17 6,541.01 6,439.01 7,932.18 -787.80 5,976,933.42 560,788.21 8.32 -787.80 MWD (4) 11,357.23 9541 113.56 6,538.56 6,436.56 7,919.79 -759.79 5,976,921.26 560,816.31 585 -759.79 MWD (4) 11,395.17 96.84 112.81 6,535.58 6,433.58 7,908.85 -734.26 5,976,910.54 560,841.93 577 -734.26 MWD(4) 11,426.55 95.79 110.29 6,532.13 6,430.13 7,897.40 -705.25 5,976,899.32 560,871.03 865 -705.25 MWD(4) 11,454.94 95.23 108.32 6,529.40 6,42740 7,888.05 -678.58 5,976,890.20 560,89777 7.18 -678.58 MWD (4) 11,484.52 94.34 104.76 6,526.93 6,424.93 7,679.65 -65033 5,976,682.04 560,926.09 12.36 -650.33 MWD (4) 11,518.73 94.55 101.82 6,524.28 6,422.28 7,871.82 -61714 5,976,87448 560,959.34 8.59 -617.14 MWD (4) 11,544.67 96.21 102.17 6,521.85 6,419.85 7,866.46 591.88 5,976,869.32 560,984.64 6.54 -591.88 MWD (4) 11,575.11 95.87 100.24 6,51865 6,416.65 7,860.58 -562.19 5,976,863.68 561,014.38 6.40 -562.19 MWD (4) Annotation Interpolated Azimuth - TIP KOP Interpolated Azimuth 5/152019 10:15:34AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips In ConocoPhillips Definitive Survey Report BA��cER iu� Company: ConocoPhillips Alaska Inc_Kupamk Local Co-ordinate Reference: Well 1C-11 Project: Kupamk River Unit TVD Reference: 1C-11 @ 102.00usft (1C-11) Site: Kupamk 1C Pad MD Reference: 113-11 @ 102.00usft (1C-11) Well: lC-11 North Reference: True Wellbore: 1 C 11-2-02 Survey Calculation Method: Minimum Curvature Design: 1C-111-2-02 Database: EDT 14 Alaska Production Survey Map Map Vertical - MD Inc AN TVD TVDSS +NAS +E/ -W Northing Fatting DLS Section (uaft) (•) (°) (uaft) (uaft) (uaft) (1131t) (°1100') Survey Tool Name Annotation (ft) (ft) (ft) 11,608.24 98.07 98.21 6,514.63 6,412.63 7,855.30 -529.73 5,976,858.68 561,046.87 900 -529.73 MWD (4) 11,63669 95.82 95-68 6,511.19 6,409.19 7,851.89 -501.70 5,976,85549 561,074.93 11,85 -501.70 MWD (4) 11,654.59 92.79 92.39 6,50909 6,40709 7,849.94 A73.95 5,976,853.77 561,102.69 16.01 A73.95 MWD (4) 11,69807 92.95 9021 6,50751 6,40551 7849.22 <2.52 5,976,853.31 561,134.12 6.93 -042.52 MWD (4) 11,724.51 92.46 88.28 6,506.17 6,404.17 7,849.60 A14.12 5,976,853.92 561,162.52 899 A14.12 MWD (4) 11,756.21 89.97 8601 6,505.50 6,403.50 7,851.17 -382.47 5,976,855.76 561,194.15 1063 -382.47 MWD (4) 11,784.79 88.68 83.30 8505.84 6,403.84 7,853.84 -354.02 5,976,858.65 561,222.57 10.50 -354.02 MWD (4) 11,810.46 91.10 83.00 6,505.89 6,403.89 7,856.90 -328.53 5,976,861.92 561,248.03 9.50 -328.53 MND (4) 11,639.98 93.57 83.34 6,504.68 6,40268 7,860.41 -299.25 5,976,865.67 561,277.28 8.45 -29925 MWD (4) 11,875.90 93.87 8781 6,502.35 6,400.35 7,863.17 -26352 5,976,86873 561,312.98 12.45 -263.52 MWD (4) 11,905.67 90.43 88.80 6,501.23 6,399.24 7,864.05 -233.79 5,976,869.85 561,342.70 12.02 -233.79 MWD(4) 11,935.09 87.45 90.44 6.501.78 6,399.78 7,864.25 -204.38 5,976,87029 561,372.11 11.56 -204.38 MWD(4) 11,964.71 8690 92.70 6,503.24 6401.24 7,81KIA4 474.81 5,976,86972 561,401.68 7.84 -174.81 MWD (4) 11,990.55 8686 95.01 6,504.65 6,402.65 7,861.70 -149.07 5,976,868.20 561,427.43 8.93 -149.07 MWD(4) 12,020.55 86.31 94.08 6,506.43 6,404.43 7,85933 -119.22 5,976,856.07 561,457.30 3.60 -119.22 MWD (4) 12,051.30 Was 93.02 6,50].18 6,405.18 7,857.42 -88.54 5,976,864.42 561,487.99 15.29 -88.54 MWD (4) _ 12,080.37 86.71 89.81 6,507.79 6,405.79 7,856.71 -59.50 5,976,863.94 561,517.03 18.13 -59.50 MWD (4) 12,111.07 86.01 87.50 6,509.74 6,407.74 7,85743 -28.87 5,976,864.91 561,547.65 7.85 -28.87 MWD (4) 12,131.45 88.40 88.34 6,51014 6,40874 7,858.16 -8.53 5,976,865.82 561,567.98 12.43 41.53 MWD(4) 12,157.41 89.66 84.57 6,511.18 6409.18 7,859.77 17.37 5,976,86763 561,593.87 15.31 17.37 MWD (4) 12,190.13 88.59 84.01 6,51168 6,409.68 7,863.02 49.92 5,976,871.16 561,626.39 3.69 49.92 MWD (4) 12,2%94 88.65 81.65 6,512.39 6,410.39 7,866.74 7949 5,976,875.12 561,655.92 7,88 79.49 MVA) (4) 12,250.04 88.40 79.48 6,513.17 6,411.17 7,871.67 10917 5,976,880.29 561,685.56 7.29 109.17 MND (4) 12,279.73 87.11 80.09 6,514.33 6,412.33 7,876.93 138.37 5,976,885.79 561,71411 4.81 138.37 MWD (4) 12,309.95 8.5.85 81.37 6,516.19 6,414.19 7,88179 168.14 5,976,89D.89 561,744.43 5.94 168.14 MWD (4) 12,341.33 83.63 81.50 6,519.06 6,417.06 7,886.44 199.03 5,976,895.80 561,775.29 7.09 199.03 MWD (4) 12,37166 83.94 83.50 6,522.37 6,420.37 7,890.41 229.12 5,976,900.01 561,805.34 6.59 229.12 MM (4) 12,399.62 83.33 85.46 6,525.45 6,423.45 7,893.06 256.58 5,976,902.89 561,832.77 735 256.58 MWD (4) 12,431.13 85.39 8772 6,528.54 6,426.54 7.894.92 287.88 5,976,905.01 561,864.05 9.68 287.88 MWD (4) 12,463.29 8390 8922 6,531.54 6,429.55 7,895.78 319.89 5,976,906.12 551,896.05 6.56 319.89 MWD (4) 12,491.82 82.51 89.60 6,53492 6,432.92 7,896.07 348.21 5,976,906.65 561,924.37 5.05 348.21 MWD (4) 57152019 10.15:34AM Page 4 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 ND 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-1112-02 Survey Calculation Method: Minimum Curvature Design: 1 CA 1-2.02 Database: EDT 14 Alaska Production Survey Annotation BAtUGHFS 5/152019 10:15:34AM Page 5 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azl ND N DSS •Nl3 +E/-WNo •-W Eaagng DLS Section (usft) C) (1) (usft) (usft) (uaft) Wall) ('1100') Survey Tool Name (Itt)) (R) (ft) 12,521.26 82.95 88.14 6,538.65 6,436.65 7,896.65 377.41 5,976,907.46 561,953.56 5.14 377.41 MM (4) 12,555.97 83.10 84.86 6,542.86 6,440.86 7,898.75 41119 5,976,90985 561,987.92 9.39 411.79 MWD (4) 12,586.39 83.35 83.49 6,546.45 6,444.45 7,901.82 441.85 5,976,913.16 562,017.94 4.55 441.65 MWD(4) 12,611.92 83.65 81.92 6,549.34 6,447.34 7,905.04 41STol 5,976,916.59 562,043.07 6.23 467,01 MWD (4) 12,640.05 83.42 79.96 6,552.50 6,450.50 7,909.44 494.61 5,976,921.22 562,07063 6.98 494.61 MWD (4) 12,670.59 85.39 79.09 6,555.48 6,453.48 7,91496 524.49 5,976,926.99 562,100.47 7.05 524.49 MWD (4) 12,700.27 84.68 76.81 6,558.05 6,456.05 7,921.14 553.41 5,976,93340 562,129.33 8.02 553.41 MWD (4) 12,731.07 83.97 74.98 6,561.10 6,459.10 7,928.60 583.13 5,976,941.11 562,158.99 6.35 583.13 MWD (4) 12,761.29 83.57 73.40 6,564.38 6,462.38 7,936.79 612.04 5,976,949.53 552,187.82 5.36 612.04 MWD(4) 12,791.59 82.33 71.05 6,668.10 6,466.10 7,945.97 640.67 5,976,958.94 562,216.38 872 640.67 MWD(41 12,82149 82.71 70.84 6,571.99 6,469.99 7,955.65 668.69 5,976,968.85 562,244.31 1.45 668.69 MWD(4) 12,854.78 84.84 70.95 6,575.60 6,47360 7,966,48 699.96 5,976,979.93 562,275.49 6.41 699.96 MWD(4) 12,884.41 87.88 72.24 6,577.48 6,47548 7,975.81 728,01 5,976,989.50 562,303.46 11.14 728.01 MWD (4) 12,919.95 88.67 71.29 6,578.49 6,47649 7,986.93 761.75 5,977,000.89 562,337.11 3.86 761.75 MWD(4) 12,950.41 88.19 70.16 6,579.27 6,47727 7,996.98 790.50 5,977,011.18 562,365.77 4.33 790.50 MWD (4) 12,980.27 87.94 68.98 6,58028 6,478.28 8,007.40 818.46 5,977,021.82 562,393.64 404 818.46 MWD (4) 13,011.06 87.94 67.87 6,581.38 6,479.38 8,018.71 847.08 5,977,033.37 562.422.16 360 847.08 MWD(4) 13,041.33 87.76 66.41 6,582.52 6,480.52 8,030.46 874.95 5,977,045.35 562,449.93 4.86 874.95 MWD (4) 13,070.91 86.78 64.54 6,583.93 6,481.93 8,042.72 901.83 5,977,057.83 562,476.71 7.13 901.83 MWD (4) 13,104.63 86.20 63.45 6,585.99 6,483.99 8,057.46 932.08 5,977,072.83 562,505.83 366 932.08 MM (4) 13,131.01 87.06 62.32 6,587.54 6,485.54 8,069.48 95551 5,977,085.03 562,530.17 5.38 955.51 MWD (4) 13,159.64 88.13 62.18 6,588.74 6,486.74 8,082.80 980.83 5,977,09855 562,555.37 3.77 980.83 MWD (4) 13,190.31 8874 62.10 6,589.58 6,487.58 8,097.13 107.93 5,977,113.10 562,582.35 2.01 1,007.93 MWD (4) 13,219.93 89.59 6147 6,590.03 6,488.03 8,111.13 1,034.03 5,977,127.31 562,608.33 3.44 103463 MWD (4) 13,250.59 91.56 62.19 6,58973 6,487.73 8,125.60 1,061.06 5,977,142.01 562,635.23 6.99 1,05106 MWD(4) 13,279.58 92.65 62.06 6,588.61 6,486.61 8,139.15 1,086.66 5,977,155.76 562,660.73 4.51 1,086.66 MWD (4) 13,310.03 9,124 61.09 6,58673 6,484.73 8.153.61 1,113.39 5,977,170.44 562,687.33 5.54 1,113.39 MWD(4) 13,340.54 9261 60.84 6,584.91 6,482.91 8,168.39 114002 5,977,185.44 562,713.83 5.40 1,140.02 MWD (4) 13,370.09 90.95 59.54 6.583.99 6,48199 8,183.08 1,165.64 5,9T,200,33 562,739.34 7.13 1,165.64 MWD (4) 13,400.28 90.40 58.87 6,58363 6,48163 8,198.53 1,191.57 5,977,216.00 562,765.14 2.87 1,191.57 MWD (4) 13,430.89 89.79 56.60 6,583.58 6,481.58 8,214.87 1,217.46 5,977,232.55 562.790.88 7.68 1,2179 MWD (4) Annotation BAtUGHFS 5/152019 10:15:34AM Page 5 COMPASS 5000.14 Build 85D Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1C-11 Project Kuparuk River Unit TVD Reference: 1C-11 @ 102.00usft (1C-11) Site: Kuparuk 1C Pad MD Reference: 1C-11 @ 102.00usft (1C-11) Well: 1C-11 North Reference: True Wellbore: 1C-111-2-02 Survey Calculation Method: Minimum Curvature Design: 1C-1112-02 Database: EDT 14 Alaska Production Survey BA ER UGNES 5/15!2019 10:15:34AM Page 6 COMPASS 5000.14 Build 850 Map Map Vertical MD Inc AN TVD TVDSS •NI.3 +EI•W Northing Ea(ft) DLS Section (usft) (1) (1) (uaR) (usft) (usR) (-ft) (./100,) Survey Tool Name Annotation (ft) IRI IRI 13,460.26 89.85 55.02 6,583.67 6,481.67 8,231.37 1,241.75 5,977,249.25 562,815.04 5.38 1,241.75 MWD(4) 13,49021 90.46 54.70 6,583.59 6,481.59 8,248.61 1,266.24 5,977,266.69 562,839.38 2.30 1,266.24 MWD(4) 13,520.17 89.45 53.30 6,583.62 6,48162 8,266.22 1,290.48 5,977,284.49 562,863.47 5.76 1,290.48 MWD(4) 13,552.23 88.46 51.07 6,584.20 6,482.20 8,285.87 1,315.80 5,977,304.35 562,888.63 761 1,315.80 MWD (4) 13,579.01 88.52 52.01 6,584.91 6,482.91 8,302.52 1,336.76 5,977,321.17 562,909.45 3.52 1,336.76 MWD(4) 13,610.33 89.14 51.34 6,585.55 6,483.55 8,321.94 1,361.33 5,977,340.79 562,933.85 2.91 1,361.33 MWD (4) 13,640.54 91.11 50.79 6,58548 6,483.48 8,340.93 1,384.82 5,977,359.96 562,957.19 6.77 1,384.82 MWD (4) 13,670.24 90.71 49.43 6,585.01 6,483.01 8,359.97 1,407.61 5,977,379.19 562,979.82 477 1,407.61 MWD(4) 13,699.94 89.63 48.07 6,584.92 6,482.92 8,379.55 1,429.94 5,977,398.95 563,001.98 5.85 1429.94 MWD (4) 13,734.87 90.92 47.83 6,584.75 6,462.75 8,402.95 1,455.88 5,977,422.56 563,027.72 3.76 1,455.88 MWD(4) 13,759.90 91.78 47.65 6,584,16 6,462.16 8,419.77 1,474.39 5,977,439.54 563,046.10 3.51 1,474.39 MWD (4) 13,785.25 92.67 45.72 6,583,18 6,481.18 8,437.15 1,492.82 5,977,457.06 563,064.39 8.38 1,492.82 MWD(4) 13,819.80 92.06 46.79 6,581.75 6,479.75 8,461.02 1,517.76 5,977,481.13 563,089.13 3.56 1,517.76 MWD (4) 13,849.90 92.61 43.30 6,580.53 6,478.53 8,482.27 1,539.04 5,977,50255 563,11023 11.73 1,53904 MWD(4) 13,880.29 92.15 42.52 6,579.26 6,477.26 8,504.50 1,559.71 5,977,524.96 563,13072 2.98 1,559.71 MWD (4) 13,910.19 91.78 41.82 6,578.24 6,476.24 8,526.65 1,57978 5,977,547.26 563,150.59 2.65 1,579.78 MWD (4) 13,93976 91.08 40.04 6,577.50 6,475.50 8,548.98 1,599.14 5,977,569.75 563,18917 6.47 1,599.14 MM (4) 13,976.45 91.90 38.16 6,576.55 6,474.55 8,57745 1,622.27 5,977,598.40 563,19287 5.59 1,622.27 MWD (4) 14,010.37 91.69 36.24 6,575.48 6,473.48 8,604.45 1,642]7 5,977,62557 563,212.94 5.69 1,642.77 MWD (4) 14,041.17 9108 35.21 6,574.74 6,472.74 8,629.45 1,66075 5,977,650.71 563,230.71 3.89 1,65015 MWD (4) 14,071.35 87.05 32.22 6,575.23 6,473.23 8,654.54 1,677.49 5,977,675.94 563,247.24 16.63 1,677.49 MWD (4) 14,102.14 86.35 28.14 6,577.01 6,475.01 8,681.10 1,692.94 5,977,702.63 563,262.47 13.42 1,692.94 MWD (4) 14,130.43 87.97 23.65 6,578.41 6,476.41 8,706.52 1,705.28 5,977,728.14 563,274.60 1685 1,705.28 MWD (4) 14,162% 89.85 20.18 6,57902 6,47702 8,736.31 1,717.26 5,977,758.03 563,286.34 12.28 1,717.26 MWD(4) 14,190.12 89.05 14.97 6,57928 6,47728 8,762.58 1725.58 5,977,784.36 563,294A4 19.12 1,725.58 MWD (4) 14,22026 89.94 11.67 6,579.55 6,477.55 8,791.90 1,732.53 5,977,813.73 563,301.14 11.34 1,732.53 MWD(4) 14,245.33 8978 963 6,579.61 6477,61 8,816.54 1,737.16 5,977,838.41 563,305.57 8.16 1,737.16 MWD (4) 14,269.81 89.26 976 6.579,82 6,477.82 Q840.67 1,741.28 5,977,862.57 563,309.50 2.19 1,741.28 MWD(4) 14,303.05 87.32 4.50 6,580.81 6,478.81 8,873.62 1,745.40 5,977,89555 %3,313.35 16.86 1.745.40 MWD (4) 14,331.58 8715 065 6,%2.04 6,480.04 8,902.09 1,746.68 5,977,92403 563,314.39 13.57 1,746.68 MWD (4) 14.361.13 8637 357.31 6,583.04 6,481.04 8,931.61 1,746.16 5.977,953 54 563,31363 11.49 1,746.16 MWD (4) BA ER UGNES 5/15!2019 10:15:34AM Page 6 COMPASS 5000.14 Build 850 ConocoPhillips BA ER ConocoPhillips Definitive Survey Report uEs Company: ConocoPhillips Alaska Inc_Kuparuk Local Coordinate 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-111-2-02 Survey Calculation Method: Minimum Curvature Design: 1C -11L2-02 Database: EDT 14 Alaska Production Survey Annotation 5/15/2019 10:15:34AM Page 7 COMPASS 5000.14 Build 85D Map Map vertical MD Inc Azi TVD TVDSS +N/.S +E/ -W DLS (uaR) (°) (% (uaft) (uaft) (waft) (uaft) Northing Eaat)no (°/100') Se(it)on Survey Toot Name (ft) � (ft) 14,391.17 90.37 356.32 6,583.37 6,481.37 8,961.60 1,744.49 5.977,983.51 553,311.71 7.43 1,744.49 MWD(4) 14,430.23 88.16 354.48 6,583.87 6,481.87 9,000.53 1,741.36 5,978,02241 563,306.26 7.36 1741.36 MWD (4) 14,466.47 88.59 352.93 6,564.90 6,482.90 9,036.59 1,737.39 5,978,058.38 563,303.99 4.44 1,737.39 MWD(4) 14,495.54 88.13 352.93 6,585.73 6,483.73 9,065.37 1,733.81 5,978,087,18 563,300.18 1.58 1,733.81 MWD (4) 14,530.17 88.34 352.72 6,586.79 6,484.80 9,099.72 172949 5,978,121.49 563,295.58 0.86 1.729.49 MWD(4) 14,555.31 86.86 352.31 6,587.41 6,485.41 9,12464 1,726.21 5,978,146,37 563,292.10 2.63 1,726.21 MWD (4) 14,585.47 88.13 349.98 6,58820 6,485.20 9,154.42 1,721.57 5,978,176.12 563,287.21 8.09 1,721.57 MWO(4) 14,616.53 8344 346.60 6,590.48 6,48848 9,184.74 1,71529 5,978,206.38 563,280.68 18.59 1,715.29 MWD(4) 14,647.39 82.83 343.86 6,594.17 6,492.17 9,214.37 1,707.48 5,978,235.94 563,272.63 9.03 1,707.48 MWD (4) 14,675.51 85.51 341.10 6,597.03 5,495.03 9,241.04 1,699.06 5,978,262.54 563,263.99 13.64 1,699.06 MWD (4) 14,705.76 86.47 340.43 6599.15 6,497.15 9,269.53 1,689.12 5,978,290.94 563,253.82 3.87 1,689.12 MWD(4) 14,735.75 84.16 337.35 6,601.60 6,499.60 9,297.41 1,678.36 5,978,318.73 563,242.83 12.81 1,678.36 MWD (4) 14,765.79 82.70 332.67 6605.03 6,50303 9,324.45 1,665.75 5,978,345.66 563,230.01 16.22 1,665.75 MWD(4) 14,797.38 8501 327.35 6,808.42 6,506.42 9,351.64 1,650.06 5,978,372.72 563,214.09 18.27 1,650.06 MWD (4) 14,825.99 87.24 323.58 5,610,35 6,508.35 9,375.15 1,633.88 5,978,396.09 563,197.72 15.28 1,633.88 MWD (4) 14,855.23 88.06 319.30 6,611.55 6,509.55 9,397,99 1,615.67 5,978,41878 563,179.33 14.89 1,61567 MWD (4) 14,885.50 85.91 316.96 6,613,14 6,511.14 9,420.49 1,59550 5,978,441.12 563,158.97 10.49 1,595.50 MAID (4) 14,915.81 83.13 310.34 6,616.04 6,514.04 9,441.31 1,57369 5,978,461]5 563,136.99 23.59 1,57369 MWD (4) 14,950.83 8840 308.86 6,618.63 6,516.63 9,463.56 1,546.79 5,978,483.78 563,109.91 15.63 1,546.79 MWD(4) 14,976.11 92.92 309.30 6,618.34 6,516.34 9,479.49 1,527.17 5,978,499.55 563,090.16 17.96 1,527.17 MIND (4) 15,006.50 97.97 306.96 6,615.45 6,513.45 9,498.17 1,503.38 5,978,51803 563,086.23 18.30 1,503.38 MWD(4) 15,036.31 99.98 307.52 6,610.80 6,508.80 9,515.98 1,47994 5,978,53565 563,04264 6.99 1,479.94 MWD (4) 15,066.25 101.26 31007 6,605.28 6,503.28 9,53442 1,457.01 5,978,553,89 563,019.56 9.40 1,457.01 MAD (4) 15,094.55 101.26 30929 6,599.76 6,497.76 9,552.14 1,43565 5,978,57143 562998.06 2.70 1,43565 MAID (4) 15,125.38 101.28 31073 6,593.73 6,491.73 9,571.58 1,412.49 5,978,590.68 562,97414 4.58 1,412.49 MWD(4) 15,160.93 100.87 311.21 6586.90 6,484.90 9,594.45 1,386.15 5.978,613.34 562,948.22 1.76 1,386.15 MWD (4) 15,201.00 10067 31121 6,579.35 6,477.35 9,620.38 1,356.54 5,978,639.01 562,91840 0.00 1,356.54 PROJECTED to TD Annotation 5/15/2019 10:15:34AM Page 7 COMPASS 5000.14 Build 85D THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Od and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 C-11 L2-02 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-043 Surface Location: 1225' FNL, 637' FWL, SEC. 12, Tl 1N, R10E, UM Bottomhole Location: 1126' FNL, 2029' FWL, SEC. 36, T12N, RIOE, UM 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.aloska.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, 600*� Daniel T. Seamount, Jr. Commissioner DATED this2.7day of March, 2019. STATE OF ALASKA 1 ALASKA OIL AND GAS CONSERVATION COMMIAoiON PERMIT TO DRILL on nnc 25 005 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Dial) ❑ 1 c. Specify if well is proposed for: Drill ❑ Lateral 6 Stratigraphic Test ❑ Development - Oil ❑� • Service - Winj ❑ Single Zone E • Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑i • Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 KRU 1C -11L2-02 3. Address: 6. Proposed Depth:- (V;))Z 7� 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 15,600' TV 6169' Kuparuk River Pool / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1225' FNL, 637' FWL, Sec. 12, T11N, R10E, UM j7y'C, Z.SGfi ADL 25638 8. DNR Approval umber: 13. Approximate Spud Date: Top of Productive Horizon: 1401' FSL, 575' FEL, Sec. 35, T12N, R10E, UM LONS 79-016 3/27/2019 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 1126' FNL, 2029' FWL, Sec. 36, T12N, R10E, UM 2560 3425' 41b. 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: 36' (1 C-11 Li) 16. Deviated wells: Kickoff depth: 10,780 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 109 degrees Downhole: 3585 , Surface: 2955 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.6 L-80 ST -L 5000' 10,600'. 15,600' . Uncemented Slotted Liner 5, 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 III, 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' 1 6231' Perforation Depth MD (ft): 10,660 - 10,716 Perforation Depth TVD (ft): 6517-6559 Hydraulic Fracture planned? Yes El No ❑a 20. Attachments: Property Plat ❑ BOP Sketch ring Program E] DSeabed v. Depth ot ® Shallow Hazard ysis 20 AAC 25.050 Diverter Sketch E] Report Drilling FluidProgram L'] mquiremlenlsH 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 2 31"l9 Authorized Signature: Date: Commission Use Only Permit to Drill //} API Number: / 150_&A/' � 6Q Permit Approval See cover letter for other requirements. Number: / l �7/LI--� l0 Date: Conditions of approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane gas hydrates, or gas contained in shales: Ek' Other: .y . Samples req'd: Yes ❑ oL✓✓J Mud log req'd: Yes NoF ss �1 3 -6 D 5 / N2S Yes No Directional sv req'd: Yes No p measures: r❑, Y{ V1 q Y �J / G ✓On 1 -Yr ✓ �S '7�, Spacing exception req'd: Yes ❑ No� Inclination -only svy req'd: Yes ❑ No,L��I/ ,P/2',$, L1 r•G f ZJ 2-5-0 0 � 5, Post initial injection MIT req'd: Yes ❑ No L7 /`) !/'czriavyCc f>' 20 e9r9'C 2� O!S(6 � /:s G}I'R•nf�c� � a//ow 7ht !cv`ckcfj�poinfi 7b 6f✓✓4k7y pOtl? 4lo1-7 Q§117` Ll> APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: I ' r r/ZJ/L(O!/`1 /'� /� 1 ` owmit Form and Form 10-401 Revised 5/2017 This permit is valid fpr;4R Jhg 1(oM d Q approval per 20 AAC 25.005(g) AR hmaPts in Duplicate u v I L /�{(J7t 3.pa' ly ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 13, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits sundry application to set a whipstock and applications for permits to drill three laterals out of the KRU 1C-11 (PTD# 196-172) using the coiled tubing drilling rig, Nabors CDR3-AC. Also included in this submission is a sundry application to cut and remove liner from KRU 1 C-11 L1-02 (PTD# 209-078) to gain access to the kick off point in 1 C-11. CTD operations are scheduled to begin in late March 2019. The objective will be to drill thre laterals, KRU 1 C- 11 L2, 1C-111-2-01, and 1 C-111-2-02, targeting the Kuparuk C -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to the sundry applications are the following documents: - Sundry Application Forms (10-403) for 1C-11 and 1C-11 L1-02 - Operations Summary in support of the 10-403 Sundry Applications - Current Wellbore Schematic - Proposed CTD Schematic Attached to permit to drill applications are the following documents: - Permit to Drill Application Forms (10-401) for 1 C-1 1 L2, 1 C-1 11-2-01, and 1C-11 L2-02 - Detailed Summary of Operations - Directional Plans for 1C-11 L2, 1C-111-2-01, and 1C-11 L2-02 - Current Wellbore Schematic - Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-2634372. Sincerely, William R. Long Coiled Tubing Drilling Engineer ConocoPhillips Alaska �- Kuparuk CTD Laterals 1 C-11 1-21 1 C-11 1-2-01, & 1 C-11 1-2-02 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(f) 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 of20AAC25. 005(c)(4)) .. .............. ..._._....... ............... _.............. ._........ ................................ ....2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)) ... ...................... ............................ ... .................. .......... ......... _................. ... . _....2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(0)(6)) ..... .........._._........................ .......................... ... .. ..........._.. ... ........_..._ ....................3 7. Diverter System Information ..........................................................................................................3 (Requirements of 20 AAC 25.005(c)(7))... .... --- ................... _..... ........... .......... ..... _.... ........ _.......................... 3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8))... ............... _ _ ................ ...............3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9)) ... .................. ............. ..... _. _. _................... ............. ..... _.... .... ......... 4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))... .. ................. ............4 11. Seabed Condition Analysis............................................................................................................4 (Requirements of 20 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(6)) .......... ........... _....... ....................... ......................................... . _............ ..._..........6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 1C-1112, 1C-111-2-01, & 1C-111-2-02 laterals.........................................................6 Attachment 2: Current Well Schematic for 1C-1 1 ............................................................................................................6 Attachment 3: Proposed Well Schematic for 1C-111-2, 1C-1112-01, & 1C-1112-02 laterals...........................................6 Page 1 of 6 January 30, 2019 PTD Application: 1C-111-2, 1C-111-2-01, & 1C-111-2-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b)) The proposed laterals described in this document are 1C-111-2, 1 C-11 L2-01, & 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-111-2-02. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. Using the maximum formation pressure in the area of 3585 psi in 1C-06 (i.e. 10.9 ppg EMW), the maximum potential surface pressure in 1C-11, assuming a gas gradient of 0.1 psi/ft, would be 2955 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. - The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure�L�$: (Requirements of 20 AAC 25.005 (c)(4)) ✓ssl �ux Reservoir Pressure and Maximum Downhole Pressure (Kequiremeftts of 20 AAC 25.005 (c)(4)(a 3• zz Fy The formation pressure in KRU 1 C-11 was measured at the datum to be 2615 psi (8.0 ppg EMW) on 5/12/2015. The maximum downhole pressure in the 1 C-11 vicinity is to the south in the 1 C-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 of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 1 C-11 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 C-11 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 March 14, 2019 PTD Application: 1C-11 L2, 1C-111-2-01, & 1C-111-2-02 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 1C-111-2 62.5 H-40 Welded Surface Lateral is planned to be left unlined. Surface 121' 1640 670 Surface 2-3/8", 4.7#, L-80, ST -L slotted liner; 1C-111-2-01 10,780' 15,800' 6486' 6609' aluminum billet on to 4440' 5750 3090 Production 7" 2-3/8", 4.7#, L-80, ST -L slotted liner; 1C-111-2-02 10,600' ` 15,600' 6370' 6169' deployment sleeve on to Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top 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-11 L2-01, & 1C-11 L2-02 Pressure at the 1C-11 Window (10,684' MD, 6534' TVD) Usinq MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations KRU well 1 C-11 is a Kuparuk C -Sand producer equipped with 3-1/2" tubing and 5" production casing. The CTD sidetrack will utilize three laterals to target the C -sands to the north and north-east of 1C-11. The laterals will increase C -sand resource recovery and throughput. Prior to CTD rig up, the CTD liner landed in the 1C-11 L1-02 will be cut. CDR3-AC will pull the cut liner and set a mechanical thru tubing whipstock inside the 5" casing at the planned kick off point of 10,684' MD. The 1C-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 1C-11. The laterals will increase C -sand resource recovery and throughput. Prior to CTD rig up, the CTD liner landed in the 1C-11 L1-02 will be cut. CDR3-AC will pull the cut liner and set a mechanical thru tubing whipstock inside the 5" casing at the planned kick off point of 10,684' MD. The 1C-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-111-2, 1C -11L2-01, & 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. 1C -11L2 Lateral (C sand -North) a. Mill 2.80" window at 10,684' MD. b. Drill 3" bi-center lateral to TD of 13,000' MD. c. Run an aluminum billet with open hole anchor at 12,490' MD. 4. 1 C-11 L2-01 Lateral (C sand -North) a. Kickoff the aluminum billet at 12,490' MD. b. Drill 3" bi-center lateral to TD of 15,800' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 10,780' MD. 5. 1C-111-2-02 Lateral (C sand -North-East) a. Kickoff of the aluminum billet at 10,780' MD. b. Drill 3" bi-center lateral to TD of 15,600' MD. ' c. Run 2%" slotted liner with deployment sleeve from TD up to 10,600' MD. 6. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post -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 -11L2-02 - 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 1B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding woste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. ' - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance IC -111-2 5300' 1 C-111_2-01 3000' 1C-111_2-02 3425' ' Distance to Nearest Well within Pool Lateral Name Distance Well 1C -11L2 37' 1C-11 L1 1 C-11 L2-01 2784' IC -152 1C-11 L2-02 36' 1C-111_1 16.Attachments Attachment 1: Directional Plans for 1C -11L2, 1C -11L2-01, & 1C -11L2-02 laterals Attachment 2: Current Well Schematic for 1C-11 Attachment3: Proposed Well Schematic fork -11L2, 1C -11L2-01, &1C -11L2-02 laterals Page 6 of 6 March 14, 2019 ConocoPhillips Proleeb Kuparuk ICPaUnlLi Kuparuk lC Patl �menm.x.xm .exmxxn ,erg y�.xxvya VVELLBORE DETAILS: IC -111.2-02 NkTEFENCE x ORIORT" Parent Wellbore: 1C-111.2 0^^"kxka�El xearervv MIC 1,T - Vain; Well: 1C -1i so-xxm.yma.rt Tiem MD: 10790.W wnWnwlx.xmxe. Nywxwx Wallboro: IC4113-02 oa,w•:sxam e:Nrvsix.x.�x.: sw ryaox.GaDEI Pian:1C-IIU2 2__wpD2(D.ftA)(1C-1111C-IIU-02) m.'mer+,w^me 5969008.74 Nwwoegxwyema: icuB�ekaOxaticul 700 19'33.128 N 149° 30' 0.514 W ec M D Gkitlb�Nxxa Ni1010 e BAF�l1GHES .GE.." WnW-NfP.WN N1AM... A/i..\ ■■■■■■■■■■■■■■■■■■■■■■■■■■■ WELLDETAILS: 1 C-11 +Nl-S +ELW Northing Easting Latitude Longitude 0.00 0.00 5969008.74 561641.06 700 19'33.128 N 149° 30' 0.514 W ec M D Inc Azi TOS +N/ -S +FJ -W Dleg TFace VSect Annotation 1 10780.00 74.96 350.88 6485.95 7905.24 -1216.42 0.00 0.00 7682.46 TIP/K0P/Start42DLS 2 10850.00 89.67 16.64 6495.28 7973.68 -1211.75 42.00 60.00 7750.94 2 3 11025.00 108.65 88.91 6467.52 8072.49 -1084.78 42.00 75.00 7865.29 End42DLS,Stan7DL 4 11275.00 99.90 104.57 6405.93 8043.74 -845.21 7.00 120.00 7867.67 4 5 11450.00 95.71 116.19 6382.17 7983.43 -683.02 7.00 110.00 7828.77 5 6 11850.00 95.71 88.05 6342.37 7900.71 -297.77 7.00 -90.00 7796.40 6 7 11950.00 95.71 95.08 6332.42 7897.99 -198.37 7.00 90.00 7806.52 7 8 12300.00 92.30 70.76 6307.99 7940.79 145.46 7.00 -98.00 7893.28 8 9 12475.00 91.23 82.97 6302.61 7980.46 315.48 7.00 95.00 7954.54 9 10 12875.00 85.89 55.46 6312.67 8120.87 685.64 7.00 -101.00 8141.49 10 11 13275.00 89.30 27.64 6329.45 8417.01 948.05 7.00 -83.00 8469.00 11 12 13475.00 94.09 14.48 6323.54 8003.10 1019.73 7.00 -70.00 8662.77 12 13 13675.00 94.09 28.52 6309.28 8788.25 1092.65 7.00 90.00 8855.77 13 14 14025.00 97.50 4.13 6273.96 9119.82 1189.90 7.00 -82.00 9197.12 14 15 14250.00 93.42 19.41 6252.57 9338.38 1235.50 7.00 105.00 9419.73 15 16 14650.00 83.84 353.06 6262.12 9731.94 1278.63 7.00 -110.00 9815.57 16 17 15000.00 92.22 16.12 6274.12 1007795 1306.52 7.00 70.00 10162.29 17 18 15300.00 102.72 357.75 6235.16 10371.51 1342.60 7.00 10.00 10458.05 18 19 15600.00 102.72 19.28 6169.10 10659.22 1385.66 7.00 90.00 10748.91 Planned TD at 15600.00 BAF�l1GHES .GE.." WnW-NfP.WN N1AM... A/i..\ Vertical Section at 7.410(95 usfVin) u u U ■■■■■■■■■■■■■■■■■■■■■■■■■■■ ■■■■■ HEM ■!�■■■■■■■■■ ■■■■■■■■■■■■■■■■■■■!! ONE ■■■ ■■■■■■■■■■■■■■■■■■®■■■m■■■MNONE ■�■�NMI 1■■■ ■■s■■M■■!s■®■®■■■ ■■■■■■■■■■■■�__■� MEMMEMEMI Vertical Section at 7.410(95 usfVin) u u U ConocoPhillips ConocoPhillips Alaska lnc_Kuparuk Kuparuk River Unit Kuparuk 1C Pad IC -11 1C-111-2-02 Plan: 1 C-11 L2-02_wp02 (Draft A) Standard Planning Report 08 March, 2019 BT�a GHES GE company ConocoPhillips BA ER ConocoPhillips Planning Report F IGHES BAT GE company Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska lnc Kupawk Project: Kupawk River Unit Site: Kupauk 1C Pad Well: 1C-11 Wellbore: 1 C-11 1-2-02 Design: 1 C-11 L2-02_wp02 (Draft A) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1C-11 Mean Sea Level ° 1C-11 @ 102.00usft(1C-11) True Minimum Curvature 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-11L2-02_wp02(Draft A) — �— Site Position: Northing: 5,968,522.46 usft 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: 0.000 in Grid Convergence: 0.48 ° Well 1C-11 Well Position +N/ -S +E/.W Position Uncertainty 0.00 usft 0.00 usft 0.00 usft Northing: Easdng: Wellhead Elevation: Wellbore 1C-111-2-02 Magnetics Model Name Sample Date BGGM2018 4/1/2019 5,969,008.74 usft 561,641.06 usft usft Declination (°I 16.71 Latitude: 70° 19' 33.128 N Longitude: 149° 30'0.514 W Ground Level: 0.00 usft Dip Angie Field Strength I (nT) 80.88 57,423 Design 1C-11L2-02_wp02(Draft A) — �— Audit Notes: Version: Phase: PLAN Tie On Depth: 10,780.00 Vertical Section: Depth From (TVD) +NIS +EI -W Direction (usft) (usft) (usft) (I -60,40 0.00 0.00 7.41 31a12019 2:42:12PM Page 2 COMPASS 5000.14 Build 85D .. S;s,,. ConocoPhillips BA ER ..• t7S ConocoPhllllps Planning Report F�IGHES Plan Sections�� a GE comoany Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1C-11 Company: ConowPhillips Alaska Inc_Kupawk TVD Reference: Mean Sea Level Project: Kupawk River Unit MD Reference: 1C-11 @ 102.00usft (1C-11) Site: Kupawk 1C Pad North Reference: True Well: 1C-11 Survey Calculation Method: Minimum Curvature Wellbore: 1C-111-2-02 1 r_1 n o m ...02 m.ee e1 Turn .. S;s,,. .,...�_ _ . ..• t7S Plan Sections�� Measured TVD Below 4 Dogleg Build Turn Depth Inclination Azimuth System +NfS +E/ -W Rate Rate Rate TFO (usft) V) (") (usft) (usft) (usft) (°/100usft) (`I100usft) (°1100usft) (') Target 10,780.00 74.96 350.88 6,485.95 7,905.24 -1,216.42 0.00 0.00 0.00 0.00 10,850.00 89.67 16.64 6,495.28 7,973.68 -1,211.75 42.00 21.00 36.37 60.00 11,025.00 108.65 88.91 6,467.52 8,072.49 -1,084.78 42.00 10.87 42.82 75.00 11,275.00 99.90 104.57 6,405.93 8,043.74 -845.21 7.00 -3.50 6.15 120.00 11,450.00 95.71 116.19 6,382.17 7,983.43 -683.02 7.00 -2.39 6.61 110.00 11,850.00 95.71 88.05 6,342.37 7,900.71 -297.77 7.00 0.00 -7.03 -90.00 11,950.00 95.71 95.08 6,332.42 7,897.99 -198.37 7.00 0.00 7.03 90.00 12,300.00 92.30 70.76 6,307.99 7,940.79 145.46 7.00 -0.97 -6.94 -98.00 12,475.00 91.23 82.97 6,302.61 7,980.46 315.48 7.00 -0.61 6.97 95.00 12,875.00 85.89 55.46 6,312.67 8,120.87 685.64 7.00 -1.34 -6.89 -101.00 13,275.00 89.30 27.64 6,329.45 8,417.01 948.05 7.00 0.85 -6.95 -83.00 13,475.00 94.09 14.48 6,323.54 8,603.10 1,019.73 7.00 2.39 -6.59 -70.00 13,675.00 94.09 28.52 6,309.28 8,788.25 1,092.65 7.00 0.00 7.02 90.00 14,025.00 97.50 4.13 6,273.96 9,119.82 1,189.90 7.00 0.97 -6.99 -82.00 14,250.00 93.42 19.41 6,252.57 9,338.38 1,235.50 7.00 -1.81 6.77 105.00 14,650.00 83.84 353.06 6,262.12 9,731.94 1,278.63 7.00 -2.39 -6.62 -110.00 15,000.00 92.22 16.12 6,274.12 10,077.95 1,306.52 7.00 2.39 6.58 70.00 15,300.00 102.72 357.75 6,235.16 10,371.51 1,342.60 7.00 3.50 -6.21 -60.00 15,600.00 102.72 19.28 6,169.10 • 10,659.22 1,385.66 7.00 0.00 7.18 90.00 31WO19 2:42:12PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc Kuparuk Project: Kuparuk River Unit Site: Kuparuk 1C Pad Well: 1c-11 Wellbore: 1C-111.2-02 Design: 1C-11 L2-02_wp02 (Draft A) Planned Survey TVD Reference: Mean Sea Level MD Reference: 1C-11 @ 102.00usft (1C-11) Measured True Survey Calculation Method: Minimum Curvature 6,301.75 8,004.98 Depth Inclination Azimuth (usft) (_) 8,271.79 (°) 562,013.17 10,780.00 Vertical 74.96 Toolface 350.88 Map Map TIPIKOP1Start 42 DLS +El -W 10,800.00 Rate 79.17 8,417.01 358.34 Easting 10,850.00 (usft) 89.67 (usft) 16.64 (°) 685.64 2 (usft) 6,485.95 7,905.24 -1,216.42 10,900.00 0.00 95.10 36.95 560,359.86 11,000.00 7,924.63 105.95 7,701.46 78.29 60.84 11,025.00 5,976,922.33 108.65 6,495.28 88.91 -1,211.75 7,750.94 End 42 DLS, Start 7 DLS 5,976,971.43 11,100.00 6,493.20 106.03 -1,189.37 93.68 42.00 11,200.00 102.53 560,385.99 99.93 8,069.82 11,275.00 7,859.59 99.90 71.75 104.57 5,977,068.41 560,466.45 4 8,072.49 -1,084.78 7,865.29 41.99 11,300.00 99.30 560,490.11 106.24 8,070.86 11,400.00 7,872.90 96.91 119.28 112.88 5,977,070.23 11,450.00 6,420.51 95.71 -917.07 116.19 7.00 119.20 S 5,977,059.52 560,657.90 6,405.93 8,043.74 11,500.00 7,867.67 95.71 119.54 112.67 5,977,044.50 11,600.00 6,401.76 95.71 -821.44 105.64 7.00 11,700.00 95.71 560,753.70 98.60 8,004.07 11,800.00 7,843.41 95.71 109.51 91.57 5,977,005.79 11,850.00 6,382.17 95.71 -683.02 88.05 7.00 109.82 6 5,976,985.53 560,892.56 6,377.19 7,962.86 11,900.00 7,814.21 95.71 -89.83 91.57 5,976,965.33 11,950.00 6,367.24 95.71 -543.79 95.08 7.00 -89.65 7 5,976,933.48 561,032.20 6,357.29 7,909.36 12,000.00 7,785.79 95.22 -89.65 91.60 5,976,913.40 12,100.00 6,347.34 94.25 -347.51 84.65 7.00 12,200.00 93.27 561,228.69 77.70 7,900.71 12,300.00 7,796.40 92.30 -89.83 70.76 5,976,905.98 561,278.43 8 7,900.88 -248.03 7,802.98 7.00 12,400.00 91.69 561,328.17 77.74 7,897.99 12,475.00 7,806.52 91.23 89.83 82.97 5,976,904.08 561,377.84 9 7,895.09 -148.69 7,810.05 7.00 12,500.00 90.90 561,427.54 81.25 7,898.35 12,600.00 7,826.11 89.56 -97.71 74.38 5,976,905.67 12,700.00 6,312.85 88.22 49.40 67.51 7.00 12,800.00 86.89 561,625.45 60.63 7,940.79 12,875.00 7,893.28 85.89 -97.82 55.46 5,976,949.69 561,721.27 10 7,967.90 241.59 7,932.56 7.00 12,900.00 86.10 561,817.16 53.72 7,980.46 13,000.00 7,954.54 86.95 94.93 46.76 5,976,990.76 13,100.00 87.81 39.81 13,200.00 88.66 32.86 13,275.00 89.30 27.64 11 13,300.00 89.90 26.00 13,400.00 92.29 19.42 13,475.00 94.09 14.48 12 13,500.00 94.09 16.23 13,600.00 94.09 23.25 ConocoPhillips BAT Planning Report �j IGHES a GE company Local Coordinate Reference: Well 1C-11 TVD Reference: Mean Sea Level MD Reference: 1C-11 @ 102.00usft (1C-11) North Reference: True Survey Calculation Method: Minimum Curvature 6,302.14 7,983.89 340.23 8,158.44 7,961.13 7.00 -100.98 562,280.11 5,976,994.39 561,915.67 6,301.75 8,004.98 437.92 -83.22 7,994.64 7.00 -100.97 8,271.79 TVD Below '2i 562,013.17 6,303.68 Vertical Dogleg Toolface 8,039.17 Map Map System +N1S +El -W Section Rate Azimuth 8,417.01 Northing Easting (usft) (usft) (usft) (usft) (°HOOusft) (°) 685.64 (usft) (usft) 6,485.95 7,905.24 -1,216.42 7,682.46 0.00 0.00 5,976,902.96 560,359.86 6,490.43 7,924.63 -1,218.25 7,701.46 42.00 60.84 5,976,922.33 560,357.88 6,495.28 7,973.68 -1,211.75 7,750.94 42.00 61.16 5,976,971.43 560,363.97 6,493.20 8,018.03 -1,189.37 7,797.80 42.00 74.74 5,977,015.96 560,385.99 6,474.96 8,069.82 -1,108.46 7,859.59 41.97 71.75 5,977,068.41 560,466.45 6,467.52 8,072.49 -1,084.78 7,865.29 41.99 73.52 5,977,071.27 560,490.11 6,445.17 8,070.86 -1,013.24 7,872.90 7.00 119.28 5,977,070.23 560,561.66 6,420.51 8,059.36 -917.07 7,873.89 7.00 119.20 5,977,059.52 560,657.90 6,405.93 8,043.74 -845.21 7,867.67 7.00 119.54 5,977,044.50 560,729.89 6,401.76 8,037.20 -821.44 7,864.24 7.00 109.86 5,977,038.15 560,753.70 6,387.66 8,004.07 -728.22 7,843.41 7.00 109.51 5,977,005.79 560,847.19 6,382.17 7,983.43 -683.02 7,828.77 7.00 109.82 5,976,985.53 560,892.56 6,377.19 7,962.86 -637.73 7,814.21 7.00 -89.83 5,976,965.33 560,938.01 6,367.24 7,930.23 -543.79 7,793.96 7.00 -89.65 5,976,933.48 561,032.20 6,357.29 7,909.36 446.56 7,785.79 7.00 -89.65 5,976,913.40 561,129.58 6,347.34 7,900.54 -347.51 7,789.82 7.00 -89.65 5,976,905.41 561,228.69 6,342.37 7,900.71 -297.77 7,796.40 7.00 -89.83 5,976,905.98 561,278.43 6,337.40 7,900.88 -248.03 7,802.98 7.00 89.83 5,976,906.56 561,328.17 6,332.42 7,897.99 -198.37 7,806.52 7.00 89.83 5,976,904.08 561,377.84 6,327.66 7,895.09 -148.69 7,810.05 7.00 -97.83 5,976,901.59 561,427.54 6,319.41 7,898.35 -49.14 7,826.11 7.00 -97.71 5,976,905.67 561,527.04 6,312.85 7,913.66 49.40 7,853.99 7.00 -97.76 5,976,921.78 561,625.45 6,307.99 7,940.79 145.46 7,893.28 7.00 -97.82 5,976,949.69 561,721.27 6,304.52 7,967.90 241.59 7,932.56 7.00 94.87 5,976,977.59 561,817.16 6,302.61 7,980.46 315.48 7,954.54 7.00 94.93 5,976,990.76 561,890.94 6,302.14 7,983.89 340.23 8,158.44 7,961.13 7.00 -100.98 562,280.11 5,976,994.39 561,915.67 6,301.75 8,004.98 437.92 -83.22 7,994.64 7.00 -100.97 8,271.79 5,977,016.28 562,013.17 6,303.68 8,037.61 532.36 562,424.11 8,039.17 7.00 -101.05 8,399.91 5,977,049.68 562,107.33 6,307.94 8,081.27 622.16 8,417.01 8,094.04 7.00 -101.13 -83.05 5,977,094.07 562,196.75 6,312.67 8,120.87 685.64 8,141.49 7.00 -101.15 5,977,134.19 562,259.91 6,314.41 8,135.32 705.97 8,158.44 7.00 -83.06 5,977,148.80 562,280.11 6,320.47 8,199.11 782.66 8,231.59 7.00 -83.22 5,977,213.22 562,356.27 6,325.04 8,271.79 851.10 8,312.48 7.00 -83.17 5,977,286.45 562,424.11 6,328.12 8,352.26 910.28 8,399.91 7.00 -83.11 5,977,367.39 562,482.62 6,329.45 8,417.01 948.05 8,469.00 7.00 -83.05 5,977,432.45 562,519.85 6,329.63 8,439.32 959.33 8,492.57 7.00 -70.01 5,977,454.85 562,530.94 6,327.72 8,531.49 997.91 8,588.95 7.00 -69.96 5,977,547.33 562,568.76 6,323.54 8,603.10 1,019.73 8,662.77 7.00 -69.88 5,977,619.10 562,589.99 6,321.76 8,627.14 1,026.34 8,687.47 7.00 89.94 5,977,643.20 562,596.40 6,314.63 8,720.97 1,060.01 8,784.85 7.00 89.75 5,977,737.28 562,629.30 3/82019 2:42:12PM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips BA ER Conoc( Phillips Planning Report BAT a GE company Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc Kuparuk Project: Kuparuk River Unit Site: Kuparuk 1C Pad Well: IC -11 Wellbore: IC -111.2-02 Design: 1 C-11 L2-02_wp02 (Draft A) Planned Survey TVD Below 1+A�V System .'! +NI -S Measured (usft) 6,309.28 8,788.25 Depth Inclination 8,810.33 Azimuth (usft) (°) 8,997.20 (°) 13,675.00 94.09 9,119.82 28.52 13 6,255.95 9,290.87 6,252.57 13,700.00 94.33 9,385.93 26.78 13,800.00 95.31 9,582.68 19.82 13,900.00 96.28 9,731.94 12.85 14,000.00 97.25 9,881.21 5.87 14,025.00 97.50 10,077.95 4.13 14 6,254.19 10,273.41 6,235.16 14,100.00 96.14 10,468.97 9.23 14,200.00 94.33 10,659.22 16.02 14,250.00 93.42 19.41 1s 7.00 -109.91 14,300.00 92.22 7.00 16.12 14,400.00 89.83 9.54 14,500.00 87.43 5,978,600.72 2.96 14,600.00 85.04 356.37 14,650.00 83.84 -110.15 353.06 16 7.00 70.16 14,700.00 85.04 356.37 14,800.00 87.43 5,978,899.13 2.96 14,900.00 89.83 9.54 15,000.00 92.22 69.96 16.12 17 7.00 -59.82 15,100.00 95.72 10.04 15,200.00 99.22 5,979,291.84 3.92 15,300.00 102.72 357.75 18 7.00 89.22 15,400.00 102.72 7.00 4.92 15,500.00 102.72 12.10 15,600.00 102.72 5,979,677.97 19.28 Planned TD at 15600.00 ' 4 'P ( TVD Below 1+A�V System .'! +NI -S (usft) (usft) 6,309.28 8,788.25 6,307.45 8,810.33 6,299.05 8,901.79 6,288.96 8,997.20 6,277.17 9,095.12 6,273.96 9,119.82 6,265.06 9,193.76 6,255.95 9,290.87 6,252.57 9,338.38 6,250.11 9,385.93 6,248.32 9,483.36 6,250.71 9,582.68 6,257.27 9,682.40 6,262.12 9,731.94 6,266.96 9,781.49 6,273.52 9,881.21 6,275.91 9,980.52 6,274.12 10,077.95 6,267.19 10,175.06 6,254.19 10,273.41 6,235.16 10,371.51 6,213.14 10,468.97 6,191.12 10,565.37 6,169.10- 10,659.22 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1C -Ii Mean Sea Level 1C-11 Q 102.00usft (1C-11) True Minimum Curvature Dogleg Vertical +Bl -W Section (usft) (usft) 1,092.65 8,855.77 1,104.22 8,879.17 1,143.61 8,974.94 1,171.59 9,073.16 1,187.74 9,172.35 1,189.90 9,197.12 1,198.56 9,271.55 1,220.32 9,370.66 1,235.50 9,419.73 1,250.73 9,468.85 1,272.92 9,568.33 1,283.79 9,668.22 1,283.21 9,767.03 1,278.63 9,815.57 1,274.04 9,864.11 1,273.46 9,962.92 1,284.33 10,062.81 1,306.52 10,162.29 1,329.09 10,261.50 1,341.15 10,360.58 1,342.60 10,458.05 1,344.87 10,554.98 1,359.30 10,652.45 1,385.66 10,748.91 Well 1C -Ii Mean Sea Level 1C-11 Q 102.00usft (1C-11) True Minimum Curvature Dogleg Toolface Map Measured Rate Azimuth Hole Northing Depth (°1100usft) (°) (usft) (usft) (in) 7.00 89.81 6,169.10 23/6' 5,977,804.82 3.000 7.00 -81.94 5,977,827.00 7.00 -81.72 5,977,918.78 7.00 -81.66 5,978,014.40 7.00 -81.60 5,978,112.44 7.00 -81.89 5,978,137.15 7.00 104.69 5,978,211.15 7.00 104.68 5,978,308.43 7.00 104.88 5,978,356.06 7.00 -109.91 5,978,403.73 7.00 -109.92 5,978,501.33 7.00 -110.06 5,978,600.72 7.00 -110.19 5,978,700.42 7.00 -110.15 5,978,749.93 7.00 70.16 5,978,799.43 7.00 70.24 5,978,899.13 7.00 70.10 5,978,998.52 7.00 69.96 5,979,096.12 7.00 -59.82 5,979,193.40 7.00 -59.64 5,979,291.84 7.00 -59.45 5,979,389.94 7.00 89.22 5,979,487.40 7.00 89.22 5,979,583.91 7.00 89.22 5,979,677.97 Map Basting (usft) 562,661.39 562,672.77 562,711.41 562,738.59 562,753.93 562,755.89 562,763.94 562,784.90 562,799.69 562,814.53 562,835.91 562,845.97 562,844.57 562,839.58 562,834.59 562,833.19 562,843.25 562,864.63 562,886.39 562,897.64 562,898.29 562,899.76 562,913.40 562,938.98 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 15,600.00 6,169.10 23/6' 2.375 3.000 3/8!2019 2:42:12PM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips BA ER 0 ConocoPhillips Planning Report F IGHES a GE company Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1C-11 Company: ConocoPhillips Alaska Inc_Kuparuk TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1C-11 Q 102.00usft(1C-11) Site: Kuparuk 1C Pad North Reference: True Well: lC-11 Survey Calculation Method: Minimum Curvature Wellbore: IC -111-2-02 Comment 10,780.00 Design: 1 C-11 L2-02_wp02 (Draft A) -1,216.42 Plan Annotations Measured Vertical Local Coordinates Depth Depth +Nl-S +E/ -W (usft) (usft) (usft) lust[) Comment 10,780.00 6,485.95 7,905.24 -1,216.42 TIP/KOP/Start 42 DLS 10,850.00 6,495.28 7,973.68 -1,211.75 2 11,025.00 6,467.52 8,072.49 -1,084.78 End 42 DLS, Start 7 DLS 11,275.00 6,405.93 8,043.74 -845.21 4 11,450.00 6,382.17 7,983.43 -683.02 5 11,850.00 6,342.37 7,900.71 -297.77 6 11,950.00 6,332.42 7,897.99 -198.37 7 12,300.00 6,307.99 7,940.79 145.46 8 12,475.00 6,302.61 7,980.46 315.48 9 12,875.00 6,312.67 8,120.87 685.64 10 13,275.00 6,329.45 8,417.01 948-05 11 13,475.00 6,323.54 8,603.10 1,019.73 12 13,675.00 6,309.28 8,788.25 1,092.65 13 14,025.00 6,273.96 9,119.82 1,189.90 14 14,250.00 6,252.57 9,338.38 1,235.50 15 14,650.00 6,262.12 9,731.94 1,278.63 16 15,000.00 6,274.12 10,077.95 1,306.52 17 15,300.00 6,235.16 10,371.51 1,342.60 18 15,600.00 6,169.10 10,659.22 1,385.66 Planned TD at 15600.00 38!2019 2:42: 12PM Page 6 COMPASS 5000.14 Build 850 ConocoPhillips BAKER ConocoPhillips Anticollision Report IGHES a6Ew,,, any Company: ConocoPhillips Alaska Inc Kuparuk Project: Kuparuk River Unit_t Reference Site: Kuparuk 1C Pad Site Error: 0.00 usft Reference Well: 10-11 Well Error: 0.00 usft Reference Wellbore 1C -11L2-02 Reference Design: 1 C-11 L2-02_wp02 (Draft A) 1 C-11 L2-02_wp02 (Draft A) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output ernors are at Database: Offset TVD Reference: Fitter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: Depth Range: 10,780.00 to 15,600.00usft Scan Method: Results Limited by: Maximum ellipse separation of 3,000.00 usft Error Surface: Warning Levels Evaluated at: 2.79 Sigma Casing Method: Survey Tool Program Date 3/612019 From To (usft) (usft) Survey (Wellbore) 121.00 10,495.50 1C-11 (1C-11) 10,495.50 10,780.00 1C-111-2_wp03 (Draft A) (1C-111-2) 10,780.00 15,600.00 1C-11 L2-02_wp02 (Draft A) (1C-111-2-02) Summary Site Name Offset Well - Wellbore - Design Kuparuk 1C Pad 1 C-07 - 1 C-07 - 1 C-07 1 C-07 - 1 C-07 - 1 C-07 1C -07 -1C -07A- iC-07A 1 C-07 - 1 C -07A - 1 C -07A 1C-07 - IC-07AL7 - 1C-07AL1 1C-07 - IC-07ALl - 1C-07AL1 1 C-07 - i C-07AL7 PB1 - i C-07AL7 PB1 1C-07 - IC-07ALlPBI - IC-07ALiPB1 1C-07 - IC-07APB1 - 1C-07APB1 IC -08 - 1C-08 -1 C-08 I C-08 - 1 C-08 - 1 C-08 1C-08 -1 C-081-7 - 1C-0811 1C-08 -1 C-081-7 - 1C-0811 1C-08 -1 C-0811-01 - 1C-081-1-01 1C-08 -1 C-0817-01 - IC -080-01 1C-08 -1C-08L1 PB1 -1 C-081-1 PB7 1C-08 - 1 C -08L1 PB1 -1 C-081-1 PB7 1 C-09 - i C-09 - 1 C-09 IC -09 - 1C-09 - 1C-09 IC -102 - IC -102 - IC -102 1C-102 -1 C-102 - 1C-102 1C-102 -1 C-1021-1 - IC -1021-1 IC -102 -1 C-1021-1 - IC -1021-1 IC -104 -1 C-104 - 1C-104 1C-104 -1 C-104 - 1C-104 1 CA 04 - 1C-1040 -1 C-10417 1C -104 -1C -10411-1C-10411 1C-104 - 1C-104PB1-1C-104PB1 1C-104 - IC-104PB1-1C-104PB1 IC -11 -1C-11 - le -11 IC -l1 - 1C-111.1 -1C-1111 1C-11 - 1C-111-1 -1C-1111 IC -11 - IC -11L1-01 -1C-1111-01 Well IC -11 1C-11 @ 102.00usft(iC-11) 10-11 @ 102.00usft(1C-11) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum ISCWSA Tray. Cylinder North Combined Pedal Curve Added to Error Values Tool Name Description MWD MWD - Standard MWD MVuD- Standard MWD MVuD- Standard Reference Offset Distance Measured Measured Between Between Separation Warning Depth Depth Centres Ellipses Factor (usft) Waft) (usft) Wait) 11,792.82 10,525.00 2,639.44 2,540.37 12,117.75 11,321.00 2,885.45 2,768.87 11,705.00 10,150.00 2,767.39 2,654.36 10,805.00 10,808.52 10,839.69 10,808.52 10,825.00 48.05 45.76 10,825.00 36.22 32.33 10,875.00 55.31 47.54 10,825.00 36.22 32.33 Out of range Out of range 26.641 CC, ES 24.750 SF Out of range Out of range Out of range Out of range 24.482 CC, ES, SF Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 20.936 CC, ES, SF 9.296 CC, ES 7.116 SF 9.296 CC, ES CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 3WO19 10:11:26AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips BA ER ConocoPhillips Anticollision Report F IGHES BAT GE company Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kupawk River Unit -1 Reference Site: Kupawk 1C Pad Site Error: 0.00 usft Reference Well: lC-11 Well Error: 0.00 usft Reference Wellbore 1C-111-2-02 Reference Design: 1C-1112-02_wp02 (Draft A) Summary Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1C-11 1C-11 @ 102.00usft(1C-11) 1C-11 @ 102.00usft(1C-11) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Offset Design Reference Offset Distance 9745 -MWD OHsef Wetmore canine Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well - Wellbore - Design (usft) tusftl (usftl (usft) Depth Kuparuk 1 C Pad 2,749.79 2,639.23 from North 1u9a1 (esn) 1C -11 -1C -11L7 -02-1C-11 L1-02 10,808.52 10,825.00 36.22 32.33 9.297 CC, ES 1C -11 -1C -11L1 -02-1C-11 L1-02 10,839.69 10,875.00 55.31 47.54 7.117 SF 1C -11 -1C -111-2-1C-11 1-2_wp03(Draft A) 11,080.00 11,850.00 858.91 856.85 417.500 CC, ES 1C -11 -1C -111-2-1C-11 L2_wp03(Drafl A) 11,591.72 9,225.00 1,543.27 1,523.58 78.365 SF 1C -11 -1C -1112-01-1C-11 L2-01_wpO2(Draft A) 11,080.00 11,850.00 858.91 856.85 417.500 CC, ES 1C -11 -1C -1112-01-1C-11 L2-01_wp02(Draft A) 15,600.00 14,450.00 2,283.75 2,062.77 10.335 SF IC -12 -1 C-12 - 1C-12 212.11 75.33 -172.21 11,730.0 Out of range 1 C-12 -1 C-12 - 1CA2 6,509.59 212.11 75.35 -172.13 Out of range 1C-151 - 1C-151 - 1C-151 11,080.00 11,725.00 2,885.33 2,767.30 24.445 SF 1C-151 - 1C-151 - 1C-151 11,105.00 11,325.00 2,825.40 2,711.76 24.862 CC, ES 1C -152 -1C -152-1C-152 11,255.00 11,850.00 2,784.25 2,695.26 31.288 SF 1C -152 -1C -152-1C-152 11,491.23 10,900.00 2,648.50 2,567.06 32.521 CC 1C -152 -1C -152-1C-152 11,505.00 10,875.00 2,648.59 2,567.05 32.483 ES IC -17 - 1C-17 - IC -17 Out of range 1 C-17 - 1 C-17 - 1017 Out of range 1 C-172 - 1 C-172 - 1 C-172 Out of range 1 C-172 - 1 C-172 - 1 C-172 Out of range 1C -172 -1C -172-1C-172 Out of range 1 C-172 - 1 C -172A- 1 C-1 72A Out of range 1 C-172 - 1 C -172A-1 C-1 72A Out of range 1 C-172 - 1 C.172A-1 C-1 72A Out of range 1 C-172 - 1 C-172AL1 - 1 C-172ALl Out of range 1 C-172 -1 C-172AL1 - 1 C-172AL7 Out of range 1C-172-1C-172ALl - 1C-172AL7 Out of range 1C-172 -1 C-172AL2 - 1 CA 72AL2 Out of range 1 C-172 - 1 C-172AL2 -1 C-172AL2 Out of range 1 C-172 - 1 C-172AL2 -1 C-172AL2 Out of range 1C-172 - 1C-172AL2PB1-1C-172AL2PB1 Out of range 1C-172 - 1C-172AL2PB1-1C-172AL2PB1 Out of range 1C-172-1C-172AL2PB1-1C-172AL2PB1 Out of range 1C-172-1C-172AL2PB2-1C-172AL2PB2 Out of range 1C-172-1C-172AL2PB2-1C-172AL2PB2 Out of range 1 C-172 -1 C-172AL2PB2 - 1C-172AL2PB2 Out of range 1C-174 -1 C-174 -1 C-174 Out of range 1C-174 - 1 C-174 - 1 C-174 Out of range Offset Design Kuparuk 1C Pad - 1C-07 - 1C -07A- 1C -07A Survey program: 10POVD-CT- S, 892S -MWD, 9745 -MWD OHsef Wetmore canine BeMven Reference Offset Separation warring Semi Major Ails centres Measured Venleal Measured vertical Rehire.. Offset Azimuth Depth Depth Depth Depth 2,749.79 2,639.23 from North 1u9a1 (esn) (..ft) luan) leen) ivaft) r) 11,705.00 6,458.80 10,150.00 6,505.47 212.20 75.20 -170.55 11,716.62 6,457.64 10,175.00 6,505.81 212.16 75.24 -171.39 11,730.00 6,456.31 10,200.00 6,506.36 212.11 75.28 -172.36 11,730.00 6,466.31 10,225.0 6,507.33 212.11 75.31 -172.29 11,730.00 6,458.31 10,250.00 6,508.45 212.11 75.33 -172.21 11,730.0 6,456.31 10,275.00 6,509.59 212.11 75.35 -172.13 11,743.58 6,454.96 10,300.00 6,510.84 212.06 75.36 -173.10 11.755.00 6,453.82 10,325.00 6,51223 212.02 75.37 -173.91 11.755.00 6,453.82 10.350.00 6,513.62 212.02 75.37 -173.82 Onset Sim E.I. 0 00 usft offset Well Error. 0.W usft CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 3/6/2019 10:11:26AM Page 3 COMPASS 5000.14 Build 85D Distance OHsef Wetmore canine BeMven B.. Minimum Separation warring +NIS eEf-W centres Ellipses Separation Fedor (itan) (..it) (usft) (pion) (esff) 5,183.46 -804.73 2,749.79 2,639.23 110.56 24.821 5,183.94 -779]4 2,746.03 2,636.24 109.79 25.012 5,185.96 -754.83 2,741.00 2.631.79 109.21 25.098 $189.71 .730.14 2,734.35 2.626.69 107.67 25.3% 5,195.13 -705.76 2,726.31 2,620.11 10&21 25.6e) 5,201.92 -681.73 2,717.14 2.612.31 lNs3 25.919 5,210.24 -658.20 2,7116.55 2.602.00 104.55 25.887 5,219.87 -635.17 2,694.93 2,590.75 104.18 25.869 5,229.99 512.35 2,882.92 2,579.91 103.0 26.047 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 3/6/2019 10:11:26AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips ProKup"Unlit BM: KUPeruk lC ICP PW SM: ntnxxae Inm+xxeee lets• WELLSOREDUML& IG -1112 R6 FaiN EKBORMARM Parent Wellbore: 1C-11 cuwxw Mrc1891ewna wwtctl, tlwxom W.m 10.11 P.>.eonx snpnetere e..* T...MD: 10485.80 veaw OVDl Rates.. IF11g102.Wuonc Ill savemrysl Rebenw: au-ry9D1, 000E) Wa : 1C41L2 ao^'�°:BOAa tnenuva` 0Ut11 Plan:1C-IiL2_wpW(DnaKA)11C4IMC-1112) 11�aooxaw' � w--c. e FTUGHES GEcpmp,tw In-ImIl Im In-lo3/111-I .1 m IME -Ire nl.lmnn-119.1 In-I9/III-Ire13 uI-1Mnu.u9.z rnLYln-InslY-laLin-laf.5' IR-IONN-Ia srinovm-lov.3 1eia9i'w-lebe In-1nuulaou.l _ 14400 13950 -III IRIA 1110J1A Y llr-115/11 v 135110- n . II11]/111 113 n hllu-Ix IC-11AC-1113-01 �— — 111 IINI11 114 `I o B 1 I 1 6111 a I a In -I II/rn uI 12nry111-uN —_ . /� "Jam 11'-IW111-wel'r11 _ f ej IUAI/IC IIL2M_- J Iotl00- Q 111-2vV1-SIAL^. `4 $ lil-1 In -Il I 4111 r5. It'I)I/ICIfI 3532 37A6 -3401 9130- w, lnwlil lU9n ]CIVIC IMI k L- L /yam r Ic.uvmav 910()4) : p tLM IC -1 IC IR - _ -- I� d' •• 3 t ' 1 10150'11 LID , 16'8 8530 I.. p1 ' IC IIIIC II `� �!, b IC 15111(LI'14 411`. •X11 1 arm- 7650: IUO 9650'e�..- - ul-lin I I 3x25 II.10/I(. Il (b34 ',S II/ 0111.1 i � T wso r 3iYl 615t � I - 6Ve IR-lel/le l01 ey IcmnflP"tnnAl l:. (♦!m 1 �/ .. L _ .� ns6nnq 1 WA nlaomn IMn r 5830- - 1(•tllllG'aYl 1 IC aW1UM IC IwIC 19' - - j m fel S40o-. n amc liu,l 1 insg , p u' IGINIC-le 1 b IP / - -9766 R 50 -00 -fii50 430058" -5400 -1930 -0500 40M -3b00 -1130 -2ilp -2250 -1800 -1]SO -900 J50 '�. 0 450 900 1330 IB00 2250 4/00 3130 3600 4050 1500 1950 5100 5830 6300 6750 TL00 West(-)/East(+),(450asf1in) Icmncmn 1C-11 ® 1020WSR(1C-11) 1C-11 L1, L1-01, L1-02 Actual CTD Sidetrack ✓ Update: 07127109 Alaska Alaska Hole in 7" casing at 546V MD (5126108) 6943' MD IBaKer KB liner -top pacKer DU = 1. it, at 10,244' on top of 23/8" liner Camce TRMAXX-5E SCSSV @ 2297' MD Minimum ID = 2.813"(X -profile) Cameo KBMG gas lift mandrels @ 3194', 421 T. 5118' EUE 8rd Tubing to surface BD -40 seal assembly @ 51 72'MD muleshoe at 5193' MD Baker Premier packer at 10,149' MD D -nipple at 10,189' MD Milled out to 2.80" (4/4/09) 5.75" OD Locator at 10,259' MD ,Auleshoe Jnt at 10,260-10,266' MD, inside of 5.25" ID tieback ID=4,4O",OD=5.2" 9sh - 60-40 Seal Assembly, 102136- 10313'(5/2512008) Length = 46.55', ID = 3.00" Muleshoe at 10,313' MD 'MD �I I� '11,386'-12,992030' 7.26#1'MD 7" 288 L30 shoe slotted @ 12-'/8"R -Nipple at 10725' MD — — — — ID=1.71"— C-sand pads (sgz'd) 10,660' -10,716' MD Swell packer a1 70,758' MD set15 deg TfbVS 2.80- TMD set 15 deg LOHS - 2.80" Window Exit 10,990' Fish at 18#L301ineral1D,271'-11,300'MD (failed IBP) ZXP line( -top packer at 10,271' 2-3/8"liner sr liner 11,40T -11,802' billet at 11,40T MD N� J 1 0'-13,3 2-3/8"Iner 111750'-13,369' aluminum billet at 11,750' MD 95/8" 40# L-80 shoe 90 6943' MD 7" 26# L-80 shoe 10,42T MD KOP @ 10,884' MO Baker 3.5" z 5" TTWS C -sand Paris (sqz'd) 10,660' -10,716' MD 112 8" R- Ripple at 107' MD D =1.71' 25 Baker 3.5"z5" TTWS at 10,747MD WS set 15 deg LOHS - 2.80" Window EA 5', 18# L-80liner at 10,271'- 11,300' MD ;P liner -top packer a 10,271' 1 C-11 Proposed CTD Schematic Hole in 7" casing at 5466' MD (5/26/08) IC -111-2 Plan TD: 13,000' MD Top of Billet 12,490' MO Updated 13 -Mar -2019 WRL Camoo TRMPXX-5E SCSSV @ 2297' MD Minimum ID = 2.813" (X -profile) Camco KBMG gas lift mandrels @ 3194', 4217', 5118' 9.3# L -BO EUE 8rd Tubing to surface 80-40 seal assembN ® 5172' MD muleshoe at 5193' F1U Scab Liner (5163'-10271' MID FHL Retr.%uib packer at 2'MD ander packer at 10,149' MD it 10,189 MD out to 2.80" (414/09) w Swell packer at 10,758MD D = 1.68" Pi� 10,990' (failed IBP) -- ----------- IC-11L2.01 _._ MD, inside of 5.25" ID tieback sleeve 166' -10313' (5/25/2008) 1C-11L2-01 Plan TD: 15,800' MD Top of Billet: 10,780' MO iC-111-2-D2 -------------- Plan TD: 15,600' MD Top of Liner: 10,600' MD 11,407' MD 1C-1111: 10,750' -13,385'MD 2-W8" finer 11,750'-13,369' aluminum billet at 11,750' MD TRANSMITTAL LETTER CHECKLIST WELL NAME: &�ae 1r,'-11Z_2_—()i!— PTD: ( 11 Z_ 2 'Gi!— PTD: Z-19- OZ3 Development —Service —Exploratory _ Stratigraphic Test —Non -Conventional FIELD: POOL: /��c�c Gc (�y{�✓ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing yvell Permit / LATERAL No. / 9& "/ % API No. 50- aOj? z. 71el- ec- 4-e) ✓ (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' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be ran. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name KUPARUK 31V UNIT 1C-1112-02. _ _ _ __ Program DEV Well bore seg se PTD#:2190430 Company CONOCOPHILLIPS ALASKA, INC. Initial Class/Type DEV/PEND _GeoArea 890 Unit 1116.0_ On/Off Shore On Annular Disposal ❑ I Administration 17 Nonconven. gas conforms to AS31.05.0300.1.A),0.2.A-D) NA Well located in. a. defined pool... Yes 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in. a. defined pool... Yes 5 Well located proper distance from drilling unit. boundary Yes 6 Well located proper distance from other wells. Yes CMT will cover all known productive horizons 7 Sufficient acreage. available in drilling unit Yes Casing designs adequate for C,. T, B & permafrost 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 SFD 3/22/2019 12 Permit can be issued without administrative approval Yes If diverter required, does it meet regulations I13 Can permit be approved before 15 -day wait Yes Drilling fluid. program schematic & equip list adequate 14 Well located within area and strata authorized by Injection Order # (put 10# in. comments) (For NA 15 All wells. within 1/4 mile area of review identified (For service well only) NA. 16 Pre -produced injector: duration of pre production less than 3 months (For service well only) NA _ Surface location in ADL025649; top prod interval & TD in ADL025638. Kuparuk River Oil Pool, governed by Conservation Order No. 432D Conservation Order No. 432D has no interwell. spacing. restrictions. Wellbore will be more than 500' from an external property line where. ownership or. landownership. changes. As proposed, well will conform to spacing_ requirements. Conductor set for KRU 1C-11 Surface casing set for KRU 1C-11 Surface casing set and fully cemented Productive. interval will be completed with. uncemented slotted liner Rig has steel tanks; all wsste to approved disposal wells Anti -collision analysis complete; no major risk failures Max formation pressure is 3585 psig(10.0 ppg EMW); will drill w/ 8,6. ppg EMW and maintain overbal w/ MPD MPSP is 2955 psig; will test BOPS to 3500 psig 1-12S measures required Primary well 1C-11.measured 52 ppm 1-12S on. 1/25/19. H2S. measures required. Max. potential res. pressure is 10.9 ppg EMW;. expected res. pressure is 8.0 ppg EMW. Well will be drilled using 8.6 ppg mud, a coiled -tubing rig, and managed pressure drilling technique to control formation pressures and stabilize shale sections with. constant BHP of about 11.4 ppg EMW. 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: Date Commissioner Date Sri ir:�LL 3(_Z-7/Jq 18 Conductor string. provided ............ NA . Engineering 19 Surface casing protects all known USDWs NA 20 CMT vol adequate to circulate. on conductor & surf csg NA 21 CMT vol adequate to tie-in long string to.surf csg No 22 CMT will cover all known productive horizons No 23 Casing designs adequate for C,. T, B & permafrost Yes 24 Adequate tankage. or reserve pit _ _ Yes 25 If a_re-drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes 27 If diverter required, does it meet regulations NA Appr Date 28 Drilling fluid. program schematic & equip list adequate Yes VTL 3/26/2019 29 BOPEs, do they meet. regulation Yes 30 SOPE_press rating appropriate; test to (put psig in comments) Yes 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of 1-12S gas probable _ Yes 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Geology 36 Data presented on potential overpressure zones Yes Appr Date 37 Seismic analysis of shallow gas. zones NA SFD 3/22/2019 38 Seabed condition survey (if off -shore) _ NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Surface location in ADL025649; top prod interval & TD in ADL025638. Kuparuk River Oil Pool, governed by Conservation Order No. 432D Conservation Order No. 432D has no interwell. spacing. restrictions. Wellbore will be more than 500' from an external property line where. ownership or. landownership. changes. As proposed, well will conform to spacing_ requirements. Conductor set for KRU 1C-11 Surface casing set for KRU 1C-11 Surface casing set and fully cemented Productive. interval will be completed with. uncemented slotted liner Rig has steel tanks; all wsste to approved disposal wells Anti -collision analysis complete; no major risk failures Max formation pressure is 3585 psig(10.0 ppg EMW); will drill w/ 8,6. ppg EMW and maintain overbal w/ MPD MPSP is 2955 psig; will test BOPS to 3500 psig 1-12S measures required Primary well 1C-11.measured 52 ppm 1-12S on. 1/25/19. H2S. measures required. Max. potential res. pressure is 10.9 ppg EMW;. expected res. pressure is 8.0 ppg EMW. Well will be drilled using 8.6 ppg mud, a coiled -tubing rig, and managed pressure drilling technique to control formation pressures and stabilize shale sections with. constant BHP of about 11.4 ppg EMW. 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: Date Commissioner Date Sri ir:�LL 3(_Z-7/Jq
