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217-090
DATA SUBMITTAL COMPLIANCE REPORT 11/7/2017 Permit to Drill 2170900 Well Name/No. KUPARUK RIV UNIT 31-1-261-1-02 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20208-62-00 MD 10168 TVD 5972 Completion Date 8/5/2017 REQUIRED INFORMATION Mud Log No Completion Status 1 -OIL Samples No,/ DATA INFORMATION Types Electric or Other Logs Run: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No ED C 28511 Digital Data ED C 28511 Digital Data Log C 28511 Log Header Scans Log C 28546 Log Header Scans ED C 28547 Digital Data ED C 28547 Digital Data ED C 28547 Digital Data ED C 28547 Digital Data ED C 28547 Digital Data ED C 28547 Digital Data ED C 28547 Digital Data ED C 28547 Digital Data ED C 28547 Digital Data ED C 28547 Digital Data ED C 28547 Digital Data ED C 28547 Digital Data ED C 28547 Digital Data AOGC(Page I al ?__ Current Status 1 -OIL UIC No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) Interval OH/ Start Stop CH Received Comments 8/21/2017 Electronic File: 3H-2611-02 EOW - NAD27.pdf, 8/21/2017 Electronic File: 3H-2611-02 EOW - NAD27.txt 0 0 2170900 KUPARUK RIV UNIT 3H-2611-02 LOG HEADERS 0 0 2170900 KUPARUK RIV UNIT 3H-261-1-02 LOG HEADERS 6219 10168 8/28/2017 Electronic Data Set, Fi)ename: 31-1-261.1-02 GAMMA RES.Ias 8/28/2017 Electronic File: 3H-261_1-02 2MD Final Log.cgm - 8/28/2017 Electronic File: 3H-2611-02 5MD Final Log.cgm , 8/28/2017 Electronic File: 31-1-261-1-02 5TVDSS Final Log.cgm AD 8/28/2017 Electronic File: 3H-261-1-02 2MD Final Log.pdf P 8/28/2017 Electronic File: 3H-261-1-02 5MD Final Log.pdf 8/28/2017 Electronic File: 3H-261-1-02 5TVDSS Final Log.pdf 8/28/2017 Electronic File: 31-1-2611-02 EOW - NAD27.pdf 8/28/2017 Electronic File: 3H-261_1-02 EOW - NAD27.txt . 8/28/2017 Electronic File: 3H-261_1-02 Final surveys TO 10168.csv 8/28/2017 Electronic File: 3H-261-1-02 Final surveys TD 10168.xlsx 8/28/2017 Electronic File: 3H-261-1-02 Survey Listing.txt 8/28/2017 Electronic File: 3H-2611-02 Surveys.txt Tuesday, November 7, 2017 DATA SUBMITTAL COMPLIANCE REPORT 11/7/2017 Permit to Drill 2170900 Well Name/No. KUPARUK RIV UNIT 3H-261-1-02 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20208.62-00 MD 10168 TVD 5972 Completion Date 8/5/2017 Completion Status 1-0I1- Current Status 1 -OIL UIC No ED C 28547 Digital Data 8/28/2017 Electronic File: 31-1-261-1- 02_25_tapescan_BHI_CTK.txt ` ED C 28547 Digital Data 8/28/2017 Electronic File: 31-1-261-1- _ 02_5_tapescan_BHI CTK.txt ED C 28547 Digital Data 8/28/2017 Electronic File: 3H-261-1-02_outpuLtap - ED C 28547 Digital Data 8/28/2017 Electronic File: 3H-261-1-02 2MD Final Log.tif - ED C 28547 Digital Data 8/28/2017 Electronic File: 31-1-261-1-02 5MD Final Log.tif , ED C 28547 Digital Data 8/28/2017 Electronic File: 31-f-261-1-02 5TVDSS Final Log.tif Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED. Completion Report Y Production Test Informatio Y NA Geologic Markers/Tops Y COMPLIANCE HISTORY Completion Date: 8/5/2017 Release Date: 6/26/2017 Description Comments: Directional / Inclination Data!ice Mud Logs, Image Files, Digital Data Y NA Core Chips Y69 Mechanical Integrity Test InformationvYGt3A) Composite Logs, Image, Data File sr4l��1 Core Photographs Y _ Daily Operations Summary d rv,v Cuttings Samples YE) Laboratory Analyses Y Date Comments Compliance Reviewed Pa -e2 of 2 Date: _ C !/ k Tuesday, November 7, 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED AUG 312017 WELL COMPLETION OR RECOMPLETION REPORT AWbkft 1a. Well Status: OIIH Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ❑ WINJ❑ WAGE] WDSPL❑ No. of Completions: 1b. Well Class: Development[ Exploratory El Service ❑ Stratigraphic Test El 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 8/5/2017 14. Permit to Drill Number / Sundry: 217-090 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: *5&2w V.$g- 15. API Number: 50-103-20208-62-00 4a. Location of Well (Governmental Section): Surface: 1384' FNL, 281' FWL, Sec 12, T12N, R8E, UM Top of Productive Interval: 3669' FNL, 4997' FEL, Sec 12, T12N, RBE, UM Total Depth: 4950' FNL, 5268' FEL, Sec 12, T12N, R8E,UM 8. Date TD Reached: 8/3/2017 16. Well Name and Number: KRU 31-1-261.1-02 9. Ref Elevations: KB:80 GL:41 BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk Oil Pool . 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25531 , 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498655 y- 6000273 Zone- 4 TPI: x- 498658 y- 5997988 Zone- 4 Total Depth: x- 498388 y- 5996707 Zone- 4 11. Total Depth MD/TVD: 10168/5972 19. DNR Approval Number: ALK 2657 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1639/1638 5. Directional or Inclination Survey: Yes Q (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral TOp Window MD/TVD: -NA iL/o® '/!g$4 (� 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 Surface 121 Surface 121 24 200 sx CMT 7.625 29.7 L-80 Surface 3142 Surface 3140 9.875 550 sx ASIII, 300 sx Class G CMT 5 x 5 1/2 17 L-80 39 6643 39 5973 6.75 210 sx Class G CMT 2 318 4.6 L-80 6114 10168 5782 5972 3 Slotted Liner 24. Open to production or injection? Yes Q No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Slotted Liner @ 6133 - 8171 MD and 5800 - 5899 TVD :COMPLETION 8172 - 10168 MD and 5899 - 5972 TVD DPT -5 s1 \rERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 6127 1 6117/5785 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No Q Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) JAMOUNTAND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 8/8/2017 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 8/1212017 Hours Tested: 3.33 Production for Test Period Oil -Bbl: 32.68 Gas -MCF: 126.93 Water -Bbl: 1 1198.9 IChoke Size: 1 176 bean Gas -Oil Ratio: 1273 Flow Tubing Press. 250 lCasinq Press 1 1380 10alculated 24 -Hour Rate Oil -Bbl: 760 Gas -MCF: 967 Water -Bbl: 1 8026.5 Oil Gravity - API (corr): 1 24 Form 10-407 ?vis j/20 �� ? R �.2 0 / J'�- CONTINUED ON PAGE 2 RBDMS VV Sp - 5 26blubmit ORIGINIAL only /�-,.,1 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑A If Yes, list formations and intervals cored (MD/TVD, FromfTo), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1639 1638 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7408 5891 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk C TD 10168 5972 Formation at total depth: Ku aruk C 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematics Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report. production or wellresults. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: Mike Callahan A&d Authorized Title: §4ff CTD Engineer Contact Email: mike.callahan co.com Authorized p Contact Phone: 263-4180 7 Signature: Date: INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 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 10407 Revised 512017 Submit ORIGINAL Only �/ � . §E| ` KUP PROD CanoCAPFIiIIipS NellAttribu Alaska, Inc. Weflho�e APVDSo FMo NIPPLE 1 1901 12/412016 3H-26 Annotation MMe) Ene pah Mnda6on LssiMW ey Enar Edo Lan Tag:RKB 6,299.0 ]161201] Rev Reason: CTD SIDETRACK phnalt 829201] WA GER 17 a as ng Strings eesmo 0esn"Al.n 00 pni muni Tap(WEh Set Depth (ME)$"'D *11,n I... ..do "TMead CONDUCTOR 16 15.062 40.9 121.0 62.50 H4G WELDED OaelnB Deaniption —upon tI Set Dept. OND].. ou-np._.,1e Tap lTrtad OOpni 106ni Top IXK4e, SURFACE JSB 8.875 3,142.8 3,140.3 29.]0 L-80 LTC eaeing Descripton OD phi ID1bi Tap lfll(Depin MKBi Set Dep..IND.... Wf�Len p... Oraee TaPTESWI PRODUCTION 5112 4275 6.6431 6,290.9 17.00 L-80 LTC 5.5x5"@6552' Tubing Strings Tuomp Deaenptmn sennp Ma_. m Im Top MKeI bet Oepu IIL. set Dept. IND) L.. V/tpNM1i G,aae Top Conn-flon TUBING WO 3112 2992 3>8 61260 5,793.1 9.30L-80 IBT Completion Details CONDUCTOR;4J;_Ivo Within IS Top(WSJ Top(ND) MKOI Top nml fl 1bm Oea cold oni 3>8 HANGER FMC TUBING HANGER 3500 504.2 NIPPLE CAMCO BP -81 LANDING NIPPLE 28]5 dI Eo 6,108.2 5.7746 21.13 NIPPLE CAMCO ro8IN PPLE 2.812 6,1132 5,701.1 1 20.99 LOCATOR BAKER GBH22 LOCATOR 2.850 6,113.5 5,7814 2096 BEALASSY BAKER BUT GBH22SEAL ASSY 2.85"DRIFT 2.980 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top jND1 top ltd GASLIFT 3l65T Top MKBI r) DunCam Run Dats '300 8,229.0 5,890.1 1664 WHIPSTOCK BAKER WHIPSTOCK.OAL=4T, UAW 330 LBS, ]/12801] 0.000 MAX TOOL OR = 2.70, SET WHIPSTOCK 23,4° LEFT OF HIGH -SIDE, TOP OF WHIPSTOCK SET @ 6229'(2 RA TAGS) Perforations & Slots shut Dane Top DVD) atm IND1 Intend Top WO) Shum I MKs IRKa) IDne Date RI Type cem suRFACb, asa.t4za— 6,250.0 6,280.0 51910.0 5,9386 Cd, CJ, 3H- 6/1511998 4.0 RPERF 2 Me EnerJet, 0 Deo ph 26 6,250.0 8,2811.0 5,910.0 5,938.6 CA G3, 3H- Mh1997 40 (PERF 111116" PIVOTS. 180 26 Beg. ph u sort; a,lsa< 6,306.0 6,336.0 5.963.4 5,992.2 tk3,A2, 3H, 624/1994 40 (PERF 210 EnerJet, 90 de;. 26 ph Mandrel inserts St at GASUFr:d,�T6 on Top 0"1 Valle ratan N Top MKB1 MKB) Meka Model ODDS) 6av Type Int" Podaze IN) TRO Run Ipsq Run Oak Cmm 1 2,]65.] 2,763.5 CAMCO KBG2- 1 GASLIFT GLV BTM 0.188 1,253.0 8/]201] 9 2 4,124.4 4,096.2 CAMCO KBG-2- 1 GASLIFT OV BTM 0.250 0.0 &8201] 9 3 4,967.6 4,8363 CAMCO KBG2- 1 GASLIFT DMY BTM 0.000 0.0 1WO16 9 GAsuFr;SS 4 5,6309 5,351.9 CAMCO KBG2- 1 GASLIFT DMY I 0.000 BO MM005 9 5 60551 5,72]-0 CAMCO KBG2- 1 GASLIFT DMY I 0.000 0.0 KDQO05 9 Notes: General & Saw End Dale MnoOEN .n5 ua. c -,6m 4292005 NOTE: TREE: FMC 3-12""IGEN IV/WOO psi step 11I2fi2009 NOTE'. Vlew Schemeti<wl A18skaSMematic9.0 NIPPLEatob2 sEALAssv; e,nas WHIPSTOCK 6.ZLi0 RPERF;6]SOO.,.n IPERRa3FA06,3a10� (PERF; 4IDTOR6,33I PRODUCTI0N1EwTW551; 3a.T$6i3.t KUP PROD 3H -26L1 COnoc(N fillips weuaurlw. Ma><angle , To Nasky lr1r. wellmre gpuuwl F�eM Name welNoresGeus nc1 r1 MBlnnnl aet Blm lLLKeI 501032020860 NUPARUK RIVER UNIT PROD 10266 6.890.03 8.JJ IPiz /r-,1fIW.&IA , ee�.nom .xw Rnnohtion Ceptb (ttNB) EnE Oam Real Last Mad By Entl Gale ...................__......_....._..._...._.___ _...__. Lesrta9: Rev Rev Reason: CTO SIDETRACK lennall 8/29201) XPNOER: ae ng ngs C -Ir, nli-ilGon00(11 1011,) Top(nNB) 6m CapM(MR) t S 0 MM01... Wtll�,(L..Onde Tap Thread Li LINER 2 JIB 1.992 V70.7 8,MB 460 L-80 STL Liner Details Nominal l0 Top(flKB) Top BVO)(ItKB) I Top Incl rl Ilem Des Lom (In) 6.]70) 5,954.3 97.3) ALUMINUM Liner Top Billel 1920 BILLET I Neter: General 8 Safety End O ie Annotation CONDUCTOR; 1OA141� NOTE: NIPPLE; 001.4 GFB LIFP 27�.] SURFACE L6.BJ.ta20� G95 U1. a.Po]x ws -i S,=8 cur u14 eP5.1 NIPPI 6.106.2 6E9LA65Y:6t135 WXIPSTCCK B.iID.O RPERF; 6.2'AO Mio IPEREem".3W.o�—. (PERF: 8,366.0 B,SYO� PRODUCTION iS4®655T; 34.]9.80.9.1 Ll LINER; IrDO 7A,Tl3.0� ` KUP PROD Gonoc0Wlip5 Well At ,bu Aja" IIR wcllwm apuuwi Pae 3H -26L1-01 12IN2016 IIASTWO: 1 1 40.991 31611994 Annata Cepte(✓. Ene Oare pnnohtlon bat Matl BY Entl Baa Tag; Rev Reason: CTD SIDETRACK jenna0 812812017 w.NaER', aTs as ng ys Casing 0eanlp. OO pp IO lin) Tap WS) Set DepthBet D"'T p D)...Mt"`t IL.. Grad. Top ThrcaG L1-01 LINER 2318 1992. 740fi] MOOD 4.60 L-80 STL Notes: General & Safely End Dare i AnnOletron OTE; COHCIGTCP; N.ff1T 0 NIPPIE:dW.Y GAS LIR; 2.76S7 SURFACE;40Bat426� GPSUFTA1.1 GhS UEr. 4,8878 Gas uR; s.66o.6 GAS uR; S.I NIPPLE 6.1052 SE9L PSBY; Bitaa w pSTOCKGZBD RPFRF,. U...08.X0.0` PERF. SMO -6.0N00 IPERF; eSXS6,0660� PRODUCTION 696'®E662; X.]8E43.1 lI1^�'' 11 Li -01 LINER; 7,406TA.M 0� `, KUP PROD Cono4hiilips Well Aft bi Alaska.IIx, welmOre APuuvn Flew 3H -26L1-02 4H,.P(2.ddN1.I7]:14:5$Px 1 1 1901 lV4MI6 (LASTWO: 1 1 40,991 3/611994 1 m m.m Amolalion DeptN(WIR EMOdle ennoMlon Lasl Mad By End Dao ......____.._......................_...._.........................._.._...___. Lest Tag: Rev Reason: CTD SIDETRACK jennall 8f2912017 NPNGEB; �O casing Strings Casino Descreson OO NnI ntpnI TOP(NNB) SN D`md Im' SeIDePIN (NO)... VNLen (I... GreEe TOp TM1reatl L1-02LINER 2318 1992 6113.6 11168.0 5,9]1.6 4.61 L-80 STL Liner Details AMANomi-110 Top MRM) TOP Mind` B) T, Incl r) Nem Des Com (In) 6,113.6 5,]81.9 19.BJ DEPLOYMENT Shorty Deployment Sleeye 1.920 SLEEVE 8,1]1.2 5,899.5 INILI DEPLOYMENT SNDIty DeplWonembleeve 1.000 SLEEVE Notes: General & Safety End Dale n—EdIcn NOTE. CONDIlCT0.2: W.912�p NIPPLE, E 4.2 G44IlFT:2]B5.] WRFPCE: a�dl GAS LI! .11211 WS OFT: 4,9578 GRB DFT; 5.6]0.8 GAS LIFT: 40851 NIPPLE: B,IM2 PR=LdTION 556@.; .'] I, 01 i ) Ll -GR LINER. 41136-10100 uperations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Sled Tene End Time Dur (hr) Phase Op Code Activity Code Time P -T -X operation (fto) End DepM (O<13) 7/21/2017 7/21/2017 2.00 MIRU MOVE RURD P Trucks arrive at 1C -Pad at10:00 hrs, 0.0 0.0 10:00 12:00 PJSM with NES, dg sows up to modules 7/21/2017 7/21/2017 5.50 MIRU MOVE MOB P Move to 31 -1 -Pad 0.0 0.0 12:00 17:30 7/21/2017 7/21/2017 4.50 MIRU MOVE MOB P Sub spotted over 3H-26, service 0.0 0.0 17:30 22:00 module spotted 7/21/2017 7/22/2017 2.00 MIRU WHDBOP RURD P Halfway house &shop spotted 0.0 0.0 22:00 00:00 7/22/2017 7/22/2017 5.00 MIRU WHDBOP NUND P reconfigure well scaffoldiing, reinstall 0.0 0.0 00:00 05:00 mouse holes, TT line air tested, nipple up BOPE, fuseable link install, depressureize SSV, BOP shell test to 4200 psi, work past rig move checklist Rig Accept 5:00 him 7/22/17 7/22/2017 7/22/2017 5.00 SLOT WELLPR OTHR P Install CTC & pull test, various injector 0.0 0.0 05:00 10:00 tests, COMMS up, prep for BOPE test 7/22/2017 7/22/2017 0.80 MIRU WHDBOP BOPE T Begin ROPE test, witnessed by Brian 0.0 0.0 10:00 10:48 Bixby of AOGCC. Test #1, Swab 2 test, grease Rt & fluid pack above, fail/pass 7/22/2017 7/22/2017 2.20 MIRU WHDBOP BOPE P Continue with BOPE test 0.0 0.0 10:48 13:00 7/22/2017 7/22/2017 2.20 MIRU WHDBOP BOPE T Change out seals on both Lower 2- 0.0 0.0 13:00 15:12 318" ram doors due to leak, Test #6 fail/pass 7/22/2017 7/22/2017 0.70 MIRU WHDBOP BOPE P Continue with BOPE test 0.0 0.0 15:12 15:54 7/22/2017 7/22/2017 0.60 MIRU WHDBOP BOPE T Fail/Pass Test#9 0.0 0.0 15:54 16:30 7/22/2017 7/22/2017 2.50 MIRU WHDBOP BOPE P Continue with BOPE test 0.0 0.0 16:30 19:00 7/22/2017 7/22/2017 0.80 MIRU WHDBOP BOPE T Fail Pass test #15 Lower 2" pipe slips, 0.0 0.0 19:00 19:48 Function twice and pass 7/22/2017 7/22/2017 1.00 MIRU WELLPR BOPE T Fail pass test # 16 Upper 2 inch pipe 0.0 0.0 19:48 20:48 slips. Function. Relocate test joint 7122/2017 7/22/2017 0.20 MIRU WHDBOP BOPE T Perform draw down test - good End 0.0 0.0 20:48 21:00 BOPE test NAD 1 Hr NPT for 11 Hour test 7/2212017 7/22/2017 1.90 MIRU RIGMNT CTOP P Skid injector to floor, Head up E -line to 0.0 0.0 21:00 22:54 BHI upper quick connect, Good test on E -line 7/22/2017 7/23/2017 1.10 MIRU RIGMNT CTOP P Fill coil string. PT CTC to 4500 PSI 0.0 0.0 22:54 00:00 7/23/2017 7/23/2017 1.50 MIRU RIGMNT PRTS P Complete filling CT string, Test and 0.0 0.0 00:00 01:30 chart inner reel iron and packoffs, 4000 PSI 7/23/2017 7/23/2017 1.50 MIRU RIGMNT PRTS P Prep and pressure test PDL and tiger 0.0 0.0 01:30 03:00 tank line 7/23/2017 7/23/2017 1.50 MIRU WHDBOP OTHR P PJSM with valve crew, Rig up BPV 0.0 0.0 03:00 04:30 lubricator and pull BPV, RID BPV equipment. WHP after BPV removeal 2304 PSI Page 1113 Report Printed: 81812017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time DW(hr) Phase op Code Activity Code Tmie P-T-% opere6on ifum) End Depth otKS) 7/23/2017 7/23/2017 0.40 PROD1 WELLPR KLWL P Consult with town, PJSM Bull head 0.0 0.0 04:30 04:54 80 BBIs seawater down hole to reduce pressure, Initial pressures @ 3 BPM WHP=2304, IA=2225, 30 BBIs away, WHP= 1770 PSI, IA 2495 7/23/2017 7/23/2017 0.20 PROD1 WELLPR KLWL P 40 BBIs away, 3 BPM, WHP=1600, 0.0 0.0 04:54 05:06 IA=2500 , All gas will not bleed off, 60 BBIs away WHP=1440, @ 3.5 BPM, IA=2370 7/23/2017 7/23/2017 0.30 PROD1 WELLPR KLWL P 80 BBIs away, Shut down pump, 0.0 0.0 05:06 05:24 WHP=1100 PSI, monitor well 7/23/2017 7/23/2017 3.00 PRODt WHPST PULD P PJSM, crew change, another PJSM, 0.0 74.6- 05:24 08:24 PU & PD BHA #1 Window Milling Assembly, WHP climbs to 1459 psi 7/23/2017 7/23/2017 1.40 PROD1 WHPST EQRP T Begin RIH to -214', Baker & Nabors 74.0 74.0 08:24 09:48 depth counters not in agreement, troubleshoot depth counters, change out encoder, PUH & tag up, 7/23/2017 7/23/2017 2.20 PROD1 WHPST EQRP T RIH with BHA#1, stop at 2086 to 74.0 3,189.0 0948 12:00 check gooseneck alignment, continue to RIH, reel counter again does not agree with Baker depth counter after gooseneck alignment, trouble-shoot issue, observe that RIH speeds are not the same, swap back to old counter 7/23/2017 7/23/2017 0.60 PROD1 WHPST TRIP P Continue RIH 3,189.0 6,160.0 12:00 12:36 7/23/2017 7/23/2017 0.40 PRODt WHPST DLOG P Unable to tie into K1 , gamma is 6,160.0 6,213.0 12:36 13:00 reading coninuous -230 API, slop at TOWS 7/23/2017 7/23/2017 0.20 PROD1 WHPST TRIP P Confer with town, PUH to 6085'to 6,213.0 6,080.0 1300 13:12 perform CCL, PUW = 32K 7/23/2017 7/23/2017 1.00 PRODt WHPST CLOG P RIH to perfrom CCL from GLV #5 to 6,080.0 6,080.0 13:12 14:12 TOWS, correlate +20' correction to. CCL, swap to milling fluid, close EDC Note: Tagged WS pinch point at 6233', putting TOWS at 6230' (RA tag should be at 6237.35') 7/23/2017 7/23/2017 0.20 PROD1 WHPST TRIP P RIH, dry tag WS pinch point 6233', 6,080.0 6,233.0 14:12 14:24 PUH, PUW = 33K, RBIH to mill window 7/23/2017 7/23/2017 1.90 PRODi WHPST WPST P Begin milling window as per procedure 6,233.0 6,234.0 14:24 16:18 at 330° ROHS 7/23/2017 7/23/2017 5.40 PROD1 WHPST WPST P Milling @ 1FPH, 1.83 BPM @ 3090 6,234.0 6,237.5 16:18 21:42 PSI FS, BHP=3515 7/23/2017 7/23/2017 0.10 PROD1 WHPST WPST P 6237.5 Stall, PUH RBIH and stall 6,237.5 6,237.5 21:42 21:48 again. Get back on borttom and appear to have exit. 7/23/2017 7/24/2017 2.20 PROD1 WHPST WPST P Milling rathole, 1.8 BPM @ 3090 PSI 6,237.5 6,255.0 21:48 00:00 FS, BHP=3553 Page 2113 Report Printed; 8/8/2017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sort neem Sort Time End Time our(hr) Phew Op Cade Activity Code Toe P -T -X Operation (W) End Oepth(NKS) 7/24/2017 7/24/2017 2.50 PROD1 WHPST WPST P 6255 @ rathole TD, Start reaming 6,255.0 6,255.0 00:00 02:30 passes, as drilled, 330'ROHS, 30L of as drilled 300°, 30R of as drilled 0', 180° from as drilled 150° ROHS. - Maintained -100 PSI motorwork toward bottom of window. Repeal this pass and one more as drilled. Get dean dry drift 7/24/2017 7/24/2017 1.50 PROD1 WHPST TRIP P Trip out for lateral BHA #2, PUW=30K. 6,255.0 78.0 02:30 04:00 7/24/2017 7/24/2017 3.00 PROD1 WHPST PULD P On surface, PJSM, PUD BHA#1 78.0 0.0 04:00 07:00 window milling BHA, Mills out @ 2.79 No Go 7/24/2017 7/24/2017 2.00 PROD1 DRILL PULD P PJSM, M/U & PD BHA#2 Build 0.0 72.0 07:00 09:00 Drilling Assembly (2.45° motor and rebuilt Hughes bi center) 7/24/2017 7/24/2017 0.50 PROD1 DRILL EQRP T Begin RIH, observed depth counter 72.0 72.0 09:00 09:30 issues, PUH to surface, resolve 7/24/2017 7/24/2017 1.20 PROD1 DRILL TRIP P RIH 72.0 6,000.0 09:30 10:42 7/24/2017 7/24/2017 1.90 PROD1 DRILL EQRP P CCL from 5940' to TOWS (6000'- 6,000.0 6,200.0 10:42 12:36 6200 bit depth) @16 fpm, fie from CCL for+11' correction, allow Peter O'Brian time to install final software updates, upload caused circ pump reading issue, upload new update, dose EDC 7/24/2017 7/24/2017 0.20 PROD1 DRILL TRIP P Continue to RIH 6,200.0 6,255.0 12:36 12:48 7/24/2017 7/24/2017 2.70 PROD1 DRILL DRLG P OBD pumping 1.6 bpm, CWT = 15K, 6,255.0 6,334.0 12:48 15:30 WOB = 2.4K, annular = 3690 psi, WHP = 493 psi, IA = 1430 psi, FS = 379 psi, multiple PU's required drilling BHA length past window, observed Siderite over shakers, PUWs = -36K 7/24/2017 7/24/2017 1.50 PROD1 DRILL DRLG P Continue drilling build, pumping 1.6 6,334.0 6,386.0 15:30 17:00 bpm, rale out = 1.5 bpm, CWT = 15K, WOB = 2.5K, annular= 3680 psi. called EOB at 6386' 7/24/2017 7/24/2017 2.00 PROD1 DRILL TRIP P Pump sweeps, POOH, MAD pass 6,386.0 72.0 17:00 19:00 6300'-6200' for geology to determine suitable tie-in point, notice black mud and dark cutting coming over the shakers when close to surface, test mud, very little trace amounts of oil, suspect mud black due to fines observed over shakers., EOB Avg DLS=51' 7/24/2017 7/24/2017 2.20 PROD1 DRILL PULD P PJSM, PUD BHA#2, difificulty, pulling 72.0 0.0 19:00 21:12 BHA into PDL through tree, work wire -line, get through, tag up, motor was packed off with same black cuttings coming over the shakers. Bit out @ 2- 2 with chipped cutters on reamer faces 7/24/2017 7/24/2017 1.10 PROD1 DRILL PULD P PSJM, PD BHA #3 1_1 Lateral Drilling 0.0 78.0 21:12 22:18 Assembly (.5° AKO X-Treme motor, agitator, RB HYC B8 Edge), check' pack -offs, slide in cart, stab on WH, tag up Page 3113 ReportPrinted: 8/8/2017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Dep -Start Time End Time Dur(hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth(/tKB) 7/24/2017 7/24/2017 1.30 PROD1 DRILL TRIP P RIH 78.0 6,000.0 22:18 23:36 7/24/2017 7/25/2017 0.40 PROD1 DRILL DLOG P Perform CCL, tie-in for... 6,000.0 6,220.0 23:36 00:00 7/25/2017 7/25/2017 0.30 PRODi DRILL DLOG P Continue to review logs for tie in, Call 6,220.0 6,220.0 00:00 00:18 a +5' correction 7/25/2017 7/2512017 0.10 PROM DRILL TRIP P Close EDC, PUW=28K, trip in 6,220.0 6,260.0 00:18 00:24 7/25/2017 7/25/2017 0.20 PROM DRILL DLOG P Log Ra marker, Stacked out, Unable 6,260.0 6,280.0 00:24 00:36 to work through build at logging speed 7/25/2017 7/25/2017 0.20 PROD? DRILL TRIP P Trip in to drill 6,280.0 6,387.0 00:36 00:48 7/25/2017 7/25/2017 4.60 PROD1 DRILL DRLG P 6387', Drill, 1.8 BPM @ 4924 PSI FS, 6,387.0 6,810.0 00:48 05:24 BHP=3825 7/25/2017 7/25/2017 0.40 PROD1 DRILL WPRT P Wiper trip to 6390', PUW=27K 6,810.0 6,810.0 05:24 05:48 7/25/2017 725/2017 5.60 PRODt DRILL DRLG P 6810% Drill, 1.78 BPM @ 4924 PSI 6,810.0 7,125.0 05:48 11:24 FS, BHP=3760 7/25/2017 7/25/2017 0.50 PROM DRILL WPRT T PUH to cased hole, depth discrepancy 7,125.0 6,203.0 11:24 11:54 between BHI and Nabors, PUW=34K, Open EDC in cased hole 7/25/2017 7/25/2017 1.00 PROD1 DRILL RGRP T Change out Baker encoder, Shut • 6,203.0 6,000.0 11:54 12:54 EDC, Pull up hole to log CCL 7/25/2017 7/25/2017 0.30 PROM DRILL DLOG P Log CCL for -3 foot correction 6,000.0 6,205.0 12:54 13:12 7/25/2017 7/25/2017 0.10 PROD1 DRILL WPRT P Continue in hole 6,205.0 6,250.0 13:12 13:18 7/25/2017 7/25/2017 0.30 PROD1 DRILL DLOG P Log gamma points for future tie in - No 6,250.0 6,280.0 13:18 13:36 correction 7/25/2017 7/25/2017 2.50 PROD1 DRILL WPRT T Baker computer depth tracking side of 6,280.0 7,020.0 13:36 16:06 program became corrupt, Call Jeff and CDR2, Remove erronious data from data base generated by bad encoder, 2.5 Hrs BHI NPT 7/25/2017 7/25/2017 0.30 PRODt DRILL WPRT P Continue in hole to drill 7,020.0 7,123.0 16:06 16:24 7/25/2017 7/25/2017 4.00 PROM DRILL DRLG P 7123', Drill, 1.76 BPM @ 4822 PSI 7,123.0 7,525.0 16:24 20:24 FS, BHP=3740 7/25/2017 7/25/2017 0.50 PROM DRILL WPRT P Wiper up hole PUW38 k 7,525.0 6,500.0 20:24 20:54 7/25/2017 7/25/2017 0.50 PROD1 DRILL WPRT P Wiper back in hole RIW 14 k 6,500.0 7,525.0 20:54 21:24 7/25/2017 7/26/2017 2.60 PROD1 DRILL DRLG P BOBD, 1.8 bpm at 4,870 psi FS, BHP 7,525.0 7,830.0 21:24 00:00 3,908, WHIP 384, IA 1,290. OA 23 7/26/2017 7126/2017 0.75 PROD1 DRILL DRLG P OBD, 1.8 bpm at 5,028 psi, BHP 7,830.0 7,861.0 00:00 00:45 3768, WHIP 306, IA 1297, OA 24 7/26/2017 7/26/2017 1.50 PRODi DRILL TRIP T POOH, to inspect BHA, (lost 650psi 7,861.0 78.0 00:45 02:15 diff), leaving EDC closed 7/262017 7/26/2017 2.00 PROD1 DRILL PULD T PJSM, PUD Drilling BHA# 3, following 78.0 0.0 02:15 04:15 checklist w/closed EDC 7/26/2017 7/26/2017 2.60 PRODt DRILL PULD T PJSM, PU/MU/PD Drilling BHA# 4 0.0 78.0 04:15 06:51 7/26/2017 7/26/2017 1.40 PROD1 DRILL TRIP T Trip in hole, BHA #4 with .5° motor 78.0 6,001.0 06:51 08:15 and RS HYC bit with agitator, Test agitator @900' Page 4113 Report Printed: 8/8/2017 -;' Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Lo® Start nme End Tum our (hr). Phase Op Code ACGVHy Code Time P -T -X Operation start Depot (") End Depth (9K0) 7/26/2017 7/26/2017 0.40 PROD1 DRILL DLOG T Set tool to CCL mode. Log CCL tie in 6,001.0 6,215.0 08:15 08:39 for+7' 7/26/2017 7/26/2017 0.70 PROD1 DRILL TRIP T Close EDC and trip in to drill. Clean 6,215.0 7,857.0 08:39 09:21 pass through window. Slight stacking at bottom of build - 6370', 7 HRS BHI NPT 7/26/2017 7/26/2017 3.40 PROD1 DRILL DRLG P 785T, Drill, 1.8 BPM @ 5133 PSI FS, 7,857.0 8,250.0 09:21 12:45 BHP=3834, RIW=BK. DHWOB=I.1K 7/26/2017 7/26/2017 0.60 PROM DRILL WPRT P 8250, Wiper trip to 7395', PUW=33K 8,250.0 8,250.0 12:45 13:21 7/26/2017 7/26/2017 4.50 PROD1 DRILL DRLG P 8250', Drill, 1.78 BPM @ 4940 PSI 8,250.0 8,628.0 13:21 17:51 FS, BHP=3839 7/26/2017 7/26/2017 0.15 PROM DRILL WPRT P Wiper up to the window, PUW 35 k 8,628.0 7,535.0 17:51 18:00 7/26/2017 7/26/2017 0.50 PROD1 DRILL DLOG P Perform MADD PASS 7,535.0 7,325.0 18:00 18:30 7/26/2017 7/26/2017 0.50 PROD? DRILL WPRT P Continue wiper to the window 7,325.0 6,200.0 18:30 19:00 1 1 ' 7/26/2017 7/26/2017 0.25 PROD1 DRILL WPRT P Perform Static Pressure Survey 6,200.0 6,200.0 19:00 19:15 Sensor Depth=6,160' Annular Press =3,571 (11.74 ppg) MWI=8.7 ppg MWO=8.9 ppg TVD (RKB)=5,847' WHP=813 7/26/2017 7/26/2017 1.25 PROD1 DRILL WPRT P Wiper back in hole, RIW 11.3 k 6,200.0 8,628.0 19:15 20:30 7/26/2017 7/26/2017 3.00 PROD1 DRILL DRLG P BOBO, 1.8 bpm at 5,155 psi FS, BHP 8,628.0 8,762.0 20:30 23:30 3,850, WHP 364, IA 1,278, OA 26 8,629' rough drilling with stalls. 7/26/2017 7/27/2017 0.50 PROM DRILL WPRT P TO L1 lateral, PUW 35 k, send 10x10 8,762.0 8,762.0 23:30 00:00 sweep down hole 7/27/2017 7/27/2017 2.50 PROM DRILL WPRT P POOH, chasing 10x10 sweep, 6,187' 8,762.0 78.2 00:00 02:30 open EDC 7/27/2017 7/27/2017 0.25 PROM DRILL WPRT P Tag up at surface, reset counters, lube 78.2 78.2 02:30 02:45 CTES counters on horses head 7/27/2017 7/27/2017 1.00 PROM DRILL TRIP P RIH 78.2 6,000.0 02:45 03:45 7/27/2017 7/27/2017 0.25 PROD1 DRILL DLOG P Set tool to CCL mode. Log CCL tie in 6,000.0 6,199.0 03:45 04:00 for plus 6.0' 7/27/2017 7/27/2017 0.90 PROD? DRILL TRIP P Continue RIH, confirm TO 6,199.0 8,773.0 04:00 04:54 7/27/2017 7/27/2017 1.10 PRODi DRILL TRIP P POOH, laying in liner running pill with 8,773.0 6,926.0 04:54 06:00 1 1 beads. 7/27/2017 7/27/2017 0.50 PROM DRILL TRIP T 6926', Dragging weight 26K. 6K over 6,926.0 6,926.0 06:00 06:30 pull. Run back in hole. PUH overpull 10K - RBIH. PUH over pull 15K unable to run back in hole. Work pipe down. Unable to move. Orient freely. No weight changes on DHWOB. Start working pipe up. Pull free at 70K continue out 7/27/2017 7/27/2017 1.80 PROM DRILL TRIP P Continue up to 6202 above window. 5,926.0 6,202.0 06:30 08:18 Circ out small bubble and perform flow check - good Page 5113 Report Printed: 81812017 Uperations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Steil Time End Tine Dw" Phase Op cede Activity Cecile Time PJA Operatlon (ffKB) End Depth (@(B) 7/27/2017 7/27/2017 1.10 PROD1 DRILL TRIP P Continue out of well, Paint EOP flag 6,202.0 90.0 08:18 09:24 @ 4800' 7/27/2017 7/27/2017 2.20 PROD1 DRILL PULD P At surface, Flow check well, Lay down 90.0 0.0 09:24 11:36 BHA #4 7/27/2017 7/27/2017 1.00 PROD1 DRILL RURD P Rig up floor to run liner - inspect top 0.0 0.0 11:36 12:36 drive. Adjust wrapping on service loop 7/27/2017 7/27/2017 3.00 COMPZI CASING PUTS P PJSM, PIU BHA #5 Lt completion 0.0 1,993.3 12:36 15:36 with non ported bullnose, one joint solid liner, 49 joints slotted and anchor top billet. Perform safety joint drill at joint 15 -Good drill 7/27/2017 7/27/2017 1.20 COMPZI CASING PULD P PJSM, Make up coil trek to liner, 1,993.3 2,046.5 15:36 16:48 Secure coittrak in slips. Change out floats in UQC. Make up to coil and surface test. Strip on well. Change packoffs 7/27/2017 7/27/2017 1.50 COMPZ1 CASING RUNL P Trip in well with liner, Wt Chk at 6176' 2,046.5 6,842.0 16:48 18:18 34 k 7/27/2017 7/27/2017 0.00 COMPZ1 CASING RUNL P Saw flag on driveby @ 6842' plus 4.5', 6,842.0 7,507.0 18:18 18:18 didn't correct. continue IH 7/27/2017 7/27/2017 2.50 COMPZI CASING RUNL P Work pipe and attempt to run to 7,507.0 8,116.0 18:18 20:48 bottom, PUW's 40115 k, 7/27/2017 7/28/2017 3.20 COMPZI CASING RUNL T PUW 59 k, Weight cell faulted to 171 8,116.0 8,116.0 20:48 00:00 k. call electriciantmechanic, trouble shoot weight cell, service crew showed up at 21:16 7/28/2017 7/28/2017 0.50 COMPZI CASING RUNL T Install new weight cell, cleanup work 8,116.0 8,116.0 00:00 00:30 area "` Nabors NPT 3.5 hrs 7/28/2017 7/28/2017 0.20 COMPZ1 CASING RUNL P RIH 8,116.0 8,303.0 00:30 00:42 7/28/2017 7/28/2017 1.10 COMPZ1 CASING RUNL P Work pipe to bottom 8,303.0 8,773.0 00:42 01:48 7/28/2017 7/28/2017 0.30 COMPZI CASING RUNL P Liner on bottom, PUW 43 k, bring 8,773.0 8,773.0 01:48 02:06 pump up 1.6 bpm, 0.70 bpm returns, PUW 29 k, liner released, TOL (-6,7711 7/28/2017 7/28/2017 1.30 COMPZI CASING TRIP P POOH, pumping pipe displacement, 8,773.0 58.2 02:06 03:24 following trip sheet 7/28/2017 7/28/2017 0.50 COMPZ1 CASING OWFF P At surface, PJSM, Check well for flow 58.2 582 03:24 03:54 7/28/2017 7/28/2017 0.50 COMPZI CASING PULD P LD setting tools. on dead well 58.2 0.0 03:54 04:24 7/28/2017 7/28/2017 0.70 PROD2 STK PULD P PU/MU kickoff/drilling BHA# 5, surface 0.0 78.2 04:24 05:06 test CoilTrack tools, good test 7/28/2017 7/28/2017 1.20 PROD2 STK TRIP P Tag up, reset counters, RIH, 700' 78.2 6,060.0 05:06 06:18 shallow test agitator, 1.8 BPM @ 6200, Thinking this was due to 12PPG fluid. Same agitator as last run, Continue in well 7/28/2017 7/28/2017 0.20 PROD2 STK DLOG P Log CCL for+ 5.6correction 6,060.0 6,228.0 06:18 06:30 7/28/2017 7/28/2017 1.00 PROD2 STK CIRC P Displace well to 8.7PPG PwrPro from 6,228.0 6,234.0 06:30 07:30 12.OPPG Naar 7/28/2017 7/28/2017 0.50 PROD2 STK TRIP P Close EDC, PUW=28K, Trip in hole, 6,234.0 6,772.0 07:30 08:00 Dry tag billit @ 6772 Page 6113 Report Printed: 81812017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth SW Time End Time Dw(hr) Phase opcode Activity Coda Time P -T -X Operation (W13) End DePm(QKB) 7/2812017 7/28/2017 1.10 PROD2 STK MILL P Bring pumps on 1.8 BPM @ 5680 PSI 6,772.0 6,773.5 08:00 09:06 FS, BHP=3769, Call inital contact @ 6772.05, time mill @ 1 FPH 7/28/2017 7/28/2017 0.70 PROD2 STK MILL P Mill @ 2 FPH, 1.8 BPM @ 5680 PSI 6,773.5 6,774.0 09:06 09:48 FS, BHP=3769 7/28/2017 7/28/2017 0.30 PROD2 STK MILL P Stall, PUH Go to 3 FPH, 1.8 BPM @ 6,774.0 6,775.0 0948 10:06 1 5303 PSI FS 7/28/2017 7/28/2017 0.90 PROD2 DRILL DRLG P Time drill 2A FPH for 1 fool, Go to 6,775.0 6,782.0 10:06 11:00 control drilling 5-15 FPH, 1.8 BPM @ 5300 PSI FS, BHP=3768 7/28/2017 7/28/2017 0.40 PROD2 DRILL DRLG P Go to normal drilling ops, 1.8 BPM @ 6,782.0 6,825.0 11:00 11:24 5303 PSI FS, BHP=3768, On bottom pressure 6080 with fluctuations all through billit kick off 7128/2017 7/28/2017 0.10 PROD2 DRILL WPRT P PUH to drift billit area, PUW=30K. 6,825.0 6,825.0 11:24 11:30 Looks good 7/28/2017 7/28/2017 0.50 PROD2 DRILL DRLG P 6825', Drill, 1.8 BPM @ 5330 PSI FS, 6,825.0 6,874.0 11:30 12:00 BHP=3796 7/28/2017 7/28/2017 1.50 PROD2 DRILL TRIP T 6874, Pressures high and fluctuating. 6,874.0 84.0 12:00 13:30 Cannot drill on diff pressure. Trip out for agitator replacement 7/28/2017 7/28/2017 2.00 PROD2 DRILL PULD T Tag up and space out, PJSM PUD 84.0 0.0 13:30 15:30 BHA #6, Checks not holding. Close EDC. Continue PUD 7/28/2017 7/28/2017 1.50 PROD2 DRILL PULD T PD BHA #7 with .5° motor, agitator 0.0 78.2 15:30 17:00 and RR Hyc bit, surface test CoilTrak tools. 7/28/2017 7/28/2017 1.25 PROD2 DRILL TRIP T Tag up reset counters 78.2 6,060.0 17:00 18:15 7/28/2017 7/28/2017 0.25 PROD2 DRILL DLOG T Log CCL for+ 5.6correction 6,060.0 6,149.0 18:15 18:30 7/28/2017 7/26/2017 0.75 PROD2 DRILL TRIP T Continue RIH, work pipe to bottom. 6,149.0 6,875.0 18:30 19:15 from 6835' to 6875' 7/28/2017 7/28/2017 3.88 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 5,100 psi, BHP 6,875.0 7,275.0 19:15 23:07 3748, WHP 241, IA 1206, OA 17 7/28/2017 7/28/2017 0.50 PROD2 DRILL WPRT P Wiper up hole PUW 36 k 7,275.0 6,300.0 23:07 23:37 7/28/2017 7/29/2017 0.38 PROD2 DRILL WPRT P Wiper back in hole, RIW, gouge on 6,300.0 6,907.0 23:37 00:00 coil at (6382' f/EOP) 7/29/2017 7/29/2017 0.10 PROD2 DRILL WPRT P Continue wiper in hole 6,907.0 7,275.0 00:00 00:06 7/29/2017 7/29/2017 3.20 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 4,650 psi, BHP 7,275.0 7,675.0 00:06 03:18 - 3675, WHP 187, IA 1220, OA 20 7/29/2017 7/29/2017 0.50 PROD2 DRILL WPRT P Wiper up hole PUW 34 k 7,675.0 6,825.0 03:18 03:48 7/29/2017 7/29/2017 0.50 PROD2 DRILL WPRT P Wiper back in hole, RIW 14 k 6,825.0 7,675.0 03:48 04:18 7/29/2017 7129/2017 2.10 PROD2 DRILL DRLG P BOBO, 1.8 bpm at 5,074 psi, BHP 7,675.0 7,929.0 04:18 06:24 3,739, WHP 239, IA 1,235, OA 23 7/29/2017 7/29/2017 0.10 PROD2 DRILL WPRT P BHA Wiper, PUW=36K 7,929.0 7,929.0 06:24 06:30 7/292017 7/29/2017 2.50 PROD2 DRILL DRLG P 7929', Drill, 1.78 BPM @ 4805 PSI 7,929.0 8,075.0 06:30 09:00 FS, BHP=3790 7/29/2017 7/29/2017 1.20 PROD2 DRILL WPRT P 8075', Wiper to window with tie in, 8,075.0 6,060.0 09:00 10:12 7/29/2017 7/29/2017 0.40 PROD2 DRILL DLOG P Run CCL logging pass for+2' 6,060.0 6,203.0 10:12 10:36 Page 7113 Report Printed: 818/2017 Operations Summary (with Timelog Depths) t 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Time End Torre Ow hr) Phase Op cede AGiWry Cotle Time P -T -x Operation (fti(B) End Depth MS) 7/29/2017 7/29/2017 0.40 PROD2 DRILL RGRP P Tighten right angle drive coupler on 6,203.0 6,203.0 10:36 11:00 injector drive 7/29/2017 7/29/2017 0.75 PROD2 DRILL WPRT P Continue wiper back in hole 6,203.0 8,077.0 11:00 11:45 7/29/2017 7/29/2017 2.90 PROD2 DRILL DRLG P 8077', Drill, 1.78 BPM @ 5020 PSI 8,077.0 8,490.0 11:45 14:39 FS, BHP=3814 7/29/2017 7/29/2017 0.75 PROD2 DRILL WPRT P Wiper trip, 1000', PUW=36K, Clean 8,490.0 8,490.0 1439 15:24 trip up and down 7/29/2017 7/29/2017 2.87 PROD2 DRILL DRLG P 6490', Drill, 1.78 BPM @ 5030 PSI 8,490.0 8,629.0 15:24 18:16 FS, BHP=3856, RIW=10.2K, WHP=288 7/29/2017 7/29/2017 0.89 PROD2 DRILL WPRT P. Wiper trip up hole, PUW 35 k 8,629.0 8,300.0 18:16 19:09 7/29/2017 7/29/2017 0.85 PROD2 DRILL WPRT P Wiper back in hole, RIW 6 k 8,300.0 8,629.0 19:09 20:00 7/29/2017 7/29/2017 3.50 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 5,400 psi, BHP 8,629.0 8,894.0 20:00 23:30 3,891, WHP 286, IA 1,267, OA 38 7/29/2017 7/30/2017 0.50 PROD2 DRILL WPRT P TD well, pump 10x10 sweep, perform 8,894.0 7,711.0 23:30 00:00 swab wiper. PUW 33 k 7/30/2017 7/30/2017 1.90 PROD2 DRILL WPRT P Continue Swab Wiper 7,711.0 78.2 00:00 01:54 7/3012017 7/30/2017 1.10 PROD2 DRILL TRIP P Tag up reset counters, RIH 78.2 6,060.0 01:54 03:00 7/30/2017 7/30/2017 0.20 PROD2 DRILL DLOG P Log CCL correction of plus 5.5', PUW 6,060.0 6,225.0 03:00 03:12 31 Is 7/3012017 7130/2017 0.90 PROD2 DRILL TRIP P Continue in hole, RIW 18 k 6,225.0 8,890.0 03:12 04:06 7/30/2017 7/30/2017 1.30 PROD2 DRILL DISP P Pump 12 PPG pill 8,890.0 8,890.0 04:06 05:24 7/30/2017 7/30/2017 1.70 PROD2 DRILL TRIP P POOH laying in 12 PPG liner running 8,890.0 101.0 05:24 07:06 pill followed by 12PPG completion fluid, Paint EDP flags @ 7300 and 4700. 7/30/2017 7/30/2017 1.30 PROD2 DRILL PULD P Tag up, Flow check well. Lay down 101.0 0.0 07:06 08:24 BHA # 7 on dead well 7/30/2017 7/30/2017 0.50 PROD2 DRILL BOPE P Perform Bi Weekly BOPE function test 0.0 0.0 08:24 08:54 7/30/2017 7/30/2017 3.10 COMPZ2 CASING PUTB P Prep floor and pick up L1-01 0.0 1,424.4 08:54 12:00 completion with non ported bullnose, 1 A blank liner, 35 Jts slotted liner, and liner top billet 7/30/2017 7/30/2017 0.90 COMPZ2 CASING PULD P Make up coil track to liner, set in 1,424.4 1,477.7 12:00 12:54 deployment rams. Check pack offs, C/O UQC checks, M/U to coil and surface test. Strip on well 7/30/2017 7/30/2017 1.00 COMPZ2 CASING PULD T Change of liner configuration, Tag up 1,477.7 1,477.7 12:54 13:54 and space out. Strip off and lay down coil track 7/3012017 7/30/2017 0.10 COMPZ2 CASING PUTB T PIU one joint slotted, Add 8'solid pup 1,477.7 1,473.9 13:54 14:00 7/30/2017 7130/2017 0.80 COMPZ2 CASING PULD T PIU coil trek and make up to liner, Set 1,473.9 1,527.5 14:00 14:48 in slips and strip on well. Surface test tool. Tag up and set depths 7/30/2017 7/30/2017 0.90 COMPZ2 CASING RUNL P RIH, BHA#8 1,527.5 6,220.1 14:48 15:42 7/30/2017 7/302017 0.10 COMPZ2 CASING DLOG P Correct +7,38'at flag 6,220.1 6,227.5 15:42 15:48 7/30/2017 7/30/2017 1.75 COMPZ2 CASING RUNL P Continue in well. Set down and start 6,227.5 8,890.0 15:48 17:33 working pipe from - 8400 to bottom Page 8113 Report Printed: 8/812017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start oeplh Stan Time Emi Time ourQr) Phase Op Cade Activity Cade Time P -T-% Operation MKS) End OpO (rlKe) 7/30/2017 7/30/2017 0.25 COMP72 CASING RUNL P Liner on bottom, bring pump up to 1.5 8,890.0 7,406.7 17:33 17:48 bpm, 0.7 bpm returns, PUW 29 k, subtract liner BHA from counter 7/30/2017 7/30/2017 1.00 COMPZ2 CASING TRIP P POOH, following trip sheet, pumping 7,406.7 44.3 17:48 18:48 pipe displacement 7/30/2017 7/30/2017 0.50 COMPZ2 CASING OWFF P. Check well for flow, PJSM 44.3 0.0 18:48 19:18 7/30/2017 7/30/2017 0.50 COMPZ2 CASING PULD P LD setting tools, inspect coil and CTC, 0.0 0.0 19:18 19:48 visually inspect setting tools, everything looks normal 7/30/2017 7/30/2017 1.00 PROD3 STK CTOP P Gap and marks noticed above CTC, 0.0 0.0 19:48 20:48 perform pipe maintenance, cut off connector and marks, prep and install New CTC, Pull test CTC 35 k, PT 4000 psi, " Trim 16' of coil 7/30/2017 7/30/2017 0.75 PROD3 STK CTOP P Meg a -line, > 2000 mohms 187 ohms 0.0 0.0 20:48 21:33 Rehead UQ sub, 7/30/2017 7/30/2017 1.00 PROD3 STK PULD P PJSM, PU/MU Build section BHA# 9, 0.0 72.2 21:33 22:33 surface test tools (good test) 7/30/2017 7/30/2017 1.25 PROD3 STK TRIP P Tag up, reset counters, RIH w/ build 72.2 6,060.0 22:33 23:48 section BHA# 9 ' 7/30/2017 7/31/2017 0.20 PROD3 STK DLOG P Log CCL corrrection of plus 8.0', 6,060.0 6,199.0 23:48 00:00 PUW 7/31/2017 7/31/2017 0.50 PROD3 STK TRIP P PUW 31 k, continue RIH 6,199.0 7,409.0 00:00 00:30 7/31/2017 7/31/2017 1.00 PROD3 STK DISP P Dry tag TOB, PUW 31 k, bring pump 7,409.0 7,409.0 00:30 01:30 on to displace well to drilling fluid. 7/31/2017 7/31/2017 1.20 PROD3 STK KOST P Kickoff billet at 7,409', 1.8 bpm at 7,409.0 7,437.0 01:30 02:42 4,300 psi, BHP 3,807, WHP 259, IA 1250, OA 8, dry drift billet area clean. 7/31/2017 7/31/2017 2.30 PROD3 DRILL DRLG P Drill ahead, 1.8 bpm at 4,294 psi, BHP 7,437.0 7,546.0 02:42 05:00 3,753, WHP 247, IA 1,257, OA 10 7/3112017 7/31/2017 0.60 PROD3 DRILL WPRT P Wiper trip, PUW=35K 7,546.0 7,546.0 05:00 05:36 7/31/2017 7/31/2017 4.60 PROD3 DRILL DRLG P 7546', Drill, 1.81 BPM @ 4210 PSI 7,546.0 7,708.0 05:36 10:12 FS, BHP=3760, Several pick ups - Ratty drilling 7/31/2017 7/31/2017 0.50 PROD3 DRILL WPRT P 7708', Wiper to billet, 7000', 7,708.0 7,708.0 10:12 10:42 PUW=39K 7/31/2017 7/31/2017 1.10 PROD3 DRILL DRLG P 7708', drill, 1.78 BPM @ 4238 PSI FS, 7,708.0 7,728.0 10:42 11:48 BHP=3802 7/31/2017 7/31/2017 1.90 PROD3 DRILL TRIP P Call end of tum / build, trip out, AVG 7,728.0 84.3 11:48 13:42 DLS=39.7°, Perform 200' jog at surface 7/31/2017 7131/2017 1.80 PROD3 DRILL PULD P Tag up and space out. PJSM, PUD 84.3 0.0 13:42 15:30 BHA #9, Floats not holding, Power up tool and close EDC. Follow procedure for PUD with EDC shut 7/31/2017 7/31/2017 1.70 PROD3 DRILL PULD P PD BHA # 10 with .6' motor, agitator, 0.0 78.2 15:30 17:12 and RS Hyc bit, Make up to coil and surface test. Strip on well. Tag up and set counters 7/31/2017 7/31/2017 1.20 PROD3 DRILL TRIP P Trip in well, EDC open, shut EDC 78.2 6,060.0 17:12 16:24 shallow test agitator- Good Continue in well Page 9113 Report Printed: 81812017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stag Depth Start Time End Time Our hr ( ) Phase Op Code Adivhy Code Time P -T -X Operation (flKe) End Depth (tlKa) 7/31/2017 7/31/2017 0.20 PRODS DRILL DLOG P Log CCL for+5' correction, PUW=29K 6,060.0 6,214.0 18:24 18:36 7/312017 7/31/2017 1.00 PRODS DRILL TRIP P Continue in well, Stack at 7710 P/U 6,214.0 7,723.0 18:36 19:36 continue in 7/312017 811/2017 4.40 PRODS DRILL DRLG P 7723', drill, 1.79 BPM (a3 5050 PSI FS, 7,723.0 8,041.0 19:36 00:00 BHP=3745, RIW=9.6K 8/1/2017 8/1/2017 1.25 PRODS DRILL DRLG P OBD, 1.5 bpm at 3,960 psi, BHP 8,041.0 8,120.0 00:00 01:15 3,736, WHP 327, IA 1,343, OA 24, CTSW=2k, DHWOB=2 k, ROP 48 fph 8/1/2017 8112017 0.50 PRODS DRILL WPRT P 400'wiper up hole, PUW 33 k 8,120.0 8,120.0 01:15 01:45 8/1/2017 8/1/2017 5.75 PROD3 DRILL DRLG P OBD, 1.8 bpm at 5,108 psi, BHP 8,120.0 8,520.0 01:45 07:30 3,783, WHP 299, IA 1,343, OA 25, ROP ranging from 20FPH to 115 FPH. 8/1/2017 8/1/2017 1.00 PRODS DRILL WPRT P 400' wiper up hole to 7515', PUW 36K, 8,520.0 8,520.0 07:30 08:30 8/1/2017 8/1/2017 4.50 PROD3 DRILL DRLG P OBD, 1.8 bpm at 5314 psi, 1360 psi 8,520.0 8,715.0 08:30 13:00 DP, ROP from 20 to 115 FPM, pump hi vis sweeps w/ 2.5% DZone w/ limited improvement, try 5x5 sweeps. 8/1/2017 8/1/2017 0.20 PRODS DRILL WPRT P 1 00'wiper up hole, 42K PUW, had to 8,715.0 8,715.0 13:00 13:12 work to get RIH 8/1/2017 8/12017 2.50 PRODS DRILL DRLG P OBD, 1.8 bpm, 5134 psi, 3912 psi 8,715.0 8,920.0 13:12 15:42 SHE, 1220 psi dip, 6K CW, 1k WOB, 135 FPH, ROP improved, pumped 5x5 sweep w/ 2.5% Mone 8/1/2017 8/1/2017 1.10 PRODS DRILL WPRT P Wiper trip to window, 34K PUW, 8,920.0 6,060.0 15:42 16:48 8/1/2017 8/1/2017 0.20 PRODS DRILL DLOG P Tie-in to CCL, 1.5' correction 6,060.0 6,195.0 16:48 17:00 8/1/2017 8/1/2017 0.20 PRODS DRILL SVRG P Injector maintenance, tighten Love 6,195.0 6,195.0 17:00 17:12 Joys 8/1/2017 8/1/2017 0.25 PRODS DRILL TRIP P Trip in, pressure cal, 6,195.0 6,197.0 17:12 17:27 Pressure Survey MD 6,225', TVD 5,850', Ann 3,600 psi, 11.83ppg 8/1/2017 8/1/2017 1.50 PRODS DRILL WPRT P Wiper back in hole, RIW 0 k 6,197.0 8,920.0 17:27 18:57 8/1/2017 8/1/2017 3.50 PRODS DRILL DRLG P BOBD, 1.77 bpm at 4,933 psi FS, 8,920.0 9,158.0 18:57 22:27 BHP 3,889, WHIP 257, IA 1,321, OA 30 8/1/2017 8/2/2017 1.55 PRODS DRILL DRLG P By pass high pressure screens, pump 9,158.0 9,191.5 22:27 00:00 20 bbl beaded pill, continue drill ahead, 1.77 bpm at 5,233 psi, BHP 3,884, WHP 277, IA 1,321, OW 30 8/2/2017 8/2/2017 1.00 PRODS DRILL DRLG P OBD, 1.78 bpm at 5,242 psi, BHP 9,191.5 9,255.0 00:00 01:00 3,880, IA 1,342, OA 30, CTWS= minus 4 k, DHWOB=1.5 k, ROP 35 fph 8/2/2017 8/2/2017 2.50 PRODS DRILL DRLG P Pump 20 bbl beaded pill, continue 9,255.0 9,319.0 01:00 03:30 drilling ahead, 1.77 bpm at 5,372 psi, BHP 3,889, WHP 266, IA 1,330, OA 30 8/2/2017 8/2/2017 0.50 PRODS DRILL WPRT P wiper up hole, PUW 33 k 9,319.0 8,300.0 03:30 04:00 Page 10113 Report Printed: 81812017 ARMOperations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our mr) Phase Op Cade Arbviry Code Time P -T -X Operation (flKB) End Depth (WS) 8/2/2017 8/2/2017 0.40 PRODS DRILL WPRT P Wiper back in hole, TIW 4 k, lowering 8,300.0 9,319.0 04:00 04:24 pump rate to 0.9 bpm to get back to bottom. 8/2/2017 8/2/2017 1.90 PRODS DRILL DRLG P BOBD, 1.8 bpm at 5,400 psi, BHP 9,319.0 9,372.0 04:24 06:18 3,969, WHP 258, IA 1,323, OA 28, CTSW= 0 k, DHWOB=1.5 k, ROP= 55 fph 8/2/2017 8/2/2017 0.20 PRODS DRILL WPRT P Wiper up hole, PUW 34K 9,372.0 9,372.0 06:18 06:30 8/2/2017 8/2/2017 3.50 PRODS DRILL DRLG P OBD, 1.8 bpm at 5420 psi, BHP 3976 9,372.0 9,505.0 06:30 10:00 psi, WHP 268 psi, -31K CTW, WOB=1.6K, Pump 20 bbl beaded pill, swap to new mud at.9486'. 8/212017 8/2/2017 3.10 PRODS DRILL DRLG P OBD, new mud at bit, 1.8 bpm, 5121 9,505.0 9,590.0 10:00 13:06 psi, BHP 3983, WHP 279, CTW= _ -.2K, WOB=1.2K, ROP 15 to 30 FPH 8/2/2017 8/2/2017 1.40 PROD3 DRILL WPRT P Wiper to window, PUW 40K, jet 5-1/2" 9,590.0 6,060.0 13:06 14:30 8/2/2017 8/2/2017 0.30 PRODS DRILL CLOG P Tie-in to CCL, +1.5' correction, 31K 6,060.0 6,206.0 14:30 14:48 PUW 8/2/2017 8/2/2017 1.30 PRODS DRILL WPRT P Wiper in hole, weight swings at 8710' 6,206.0 9,590.0 14:48 16:06 and 8900' to 9000', -2 to +51K. 8/2/2017 812/2017 2.75 PRODS DRILL DRLG P BOBD, 1.8 bpm at 5433 psi, BHP 9,590.0 9,681.0 16:06 18:51 3981, WHP 333, CTW=-4K to -1.2K, WOB= O.BK, ROP 25 to 45 FPH. 8/2/2017 8/212017 2.00 PRODS DRILL WPRT P BHA wiper up hole, PUW 35 k 9,681.0 9,681.0 18:51 20:51 8/2/2017 8/3/2017 3.15 PRODS DRILL DRLG P BOBD, 1.52 bpm at 4,297 psi, BHP 9,681.0 9,819.0 20:51 00:00 3,942, WHP 596, IA 1,455 psi, OA 22 psi, pumping 10 bbl mud x 10 bbl beads x 10 bbl mud 8/3/2017 8/312017 0.50 PRODS DRILL WPRT P Wiper up hole, PUW 50 k, 9,819.0 8,819.0 00:00 00:30 8/3/2017 8/3/2017 0.50 PRODS DRILL WPRT P Wiper back in hole, RIW minus 4 k 8,819.0 9,819.0 00:30 01:00 8/3/2017 8/3/2017 3.25 PRODS DRILL DRLG P BOBD, 1.82 bpm at 5,100 psi, BHP 9,819.0 9,925.0 01:00 04:15 4,034, WHP 363, IA 1,398, OA 21,• CTWS=O k, DHWOB=1.4 k, ROP30- 60 fph, pumping low -vis and high -vis beaded sweeps 8/3/2017 8/3/2017 0.50 PRODS DRILL WPRT P 200' Wiper up hole, PUW 32 k 9,925.0 9,925.0 04:15 04:45 8/3/2017 8/3/2017 5.00 PRODS DRILL DRLG P BOBD, 1.8 bpm at 5,100 psi, BHP 9,925.0 10,065.0 04:45 09:45 3,890, WHP 598, IA 1437, OA 22 8/3/2017 8/3/2017 1.10 PROD3 DRILL WPRT P Wiper up hole 500', PUW= 38K 10,065.0 10,065.0 09:45 10:51 8/3/2017 8/3/2017 3.30 PRODS DRILL DRLG P BOBD, 1.8 bpm at 5500 psi, BHP 10,065.0 10,168.0 10:51 14:09 4081, WHP 500, IA 1426, OA 19. 8/3/2017 8/3/2017 2.80 PRODS DRILL WPRT P TD called, pump 10 x 10 sweep, 10,168.0 78.2 14:09 16:57 1 1 1 perform swab wiper 8/3/2017 8/3/2017 1.25 PRODS DRILL TRIP P Tag up, reset counters, RIH 78.2 6,060.0 16:57 18:12 8/3/2017 8/3/2017 0.25 PRODS DRILL DLOG P Log CCL Correction of plus 6.0' 6,060.0 6,190.0 18:12 18:27 8/3/2017 8/3/2017 1.50 PRODS DRILL TRIP P Continue IH 6,190.0 10,168.0. 18:27 19:57 8/3/2017 8/3/2017 0.50 PRODS DRILL TRIP P Confirm TD 10,168', PUW 40 k, line 10,168.0 10,168.0 19:57 20:27 up to liner running pill Page 11113 Report Printed: 81812017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Suri Dapih Start Time End rime Dur (hrj Phase Op Cade ActivMy Code Time RT -X Operetian (flKB) End 0eplh (fixe) 8/3/2017 8/3/2017 1.50 PROD3 DRILL DISP P POOH, laying liner running pill 10,168.0 6,230.0 20:27 21:57 8/3/2017 8/3/2017 1.25 PRODS DRILL DISP P At the window, displace well to 6,230.0 78.2 21:57 23:12 oompetion fluid while POOH, filling trip sheet. 8/3/2017 8/4/2017 0.81 PRODS DRILL OWFF P Check well for flow, flow seen at V 78.2 78.2 23:12 00:00 haliburton valve, shut in and monitor well, WHIP 28 psi, open choke bleed off pressure to the pits, continue to monitor well, observed flow, close 1 pressure build of 27 psi 8/4/2017 8/4/2017 0.25 PRODS DRILL OWFF P Check well for flow, flow seen at 1" 78.2 78.2 00:00 00:15 haliburton valve, shut in and monitor well, WHIP 28 psi, open choke bleed off pressure to the pits, continue to monitor well, observed flow, close 1", pressure build to 27 psi, Discuss with DE, reset counters. 8/4/2017 8/4/2017 1.20 PROD3 DRILL TRIP T RIH, pumping 0.3 bpm at 319 psi, 78.2 6,060.0 00:15 01:27 WHP=44 psi 8/4/2017 814/2017 0.50 PROD3 DRILL DLOG T Log CCL correction of plus 6.0' 6,060.0 6,208.0 0127 01:57 8/4/2017 8/4/2017 1.25 PRODS DRILL DISP T Continue RIH to 6200', displace well to 6,208.0 6,208.0 01:57 03:12 12.2 ppg completion fluid. 130 bbls returned 8/4/2017 8/4/2017 0.75 PRODS DRILL OWFF T Check well for flow, Gas Cut fliud at 6,208.0 6,208.0 03:12 03:57 surface 8/4/2017 8/4/2017 1.00 PROD3 DRILL CIRC T Circulate bottoms up 6,208.0 6,208.0 03:57 04:57 8/4/2017 8/4/2017 0.50 PRODS DRILL OWFF T Check well for flow, no flow observed 6,208.0 6,208.0 04:57 05:27 8/4/2017 8/4/2017 0.90 PROD3 DRILL TRIP T POOH pumping pipe displacement; 6,208.0 78.2 05:27 06:21 with 40% returns 8/4/2017 8/4/2017 1.40 PRODS DRILL PULD T Flow check well, no flow observed. 78.2 0.0 06:21 07:45 Laydown BHA#10 over dead well. 8/4/2017 8/42017 2.70 COMPZ3 CASING PUTS P Prep rig floor, PJSM, pick-up Li -02 0.0 0.0 07:45 10:27 lower liner segment; non -ported bullnose, 50 jts of 2-3/8" slotted liner, and shorty deployment sleeve. Fill hole every 10 jnts. 8/4/2017 8/4/2017 0.60 COMPZ3 CASING PULD P - Make up coil track BHA, set in 2,041.1 2,041.1 10:27 11:03 deployment rams, Change checks in UCC, MU to coil, surface test, strip on well, set counters 8/412017 8/4/2017 5.00 COMPZ3 CASING RUNL P RIH w/ BHA #11, 0.8' correction at 2,041.1 10,168.0 11:03 16:03 window flag, continue in well, sat down at 7904', begin working liner to 9600', gain 6K wieght back, able to RIH 30 to 40 FPM. 8/4/2017 8/4/2017 0.40 COMPZ3 CASING RUNL P Liner on bottom, bring pump to 1.5 10,168.0 8,171.2 16:03 16:27 bpm, 4800 psi, PUW 31 K, subtract liner BHA from counter 8/4/2017 8/4/2017 1.50 COMPZ3 CASING TRIP P POOH, slow while making beaded 8,171.2 8,171.0 16:27 17:57 - liner pill. 8/4/2017 8/4/2017 1.70 COMPZ3 CASING TRIP P POOH, laying in 12.2 ppg beaded liner 8,171.0 6,009.0 17:57 19:39 running pill. 8/4/2017 8/4/2017 0.25 COMPZ3 CASING OWFF P Check well for flow 6,009.0 6,009.0 19:39 19:54 8/4/2017 8/4/2017 1.15 COMPZ3 CASING TRIP P POOH 6,009.0 44.3 19:54 21:03 Page 12/13 Report Printed: 8/812017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Stan Time End Time Dur (no Phase Op Code Activity Code Time P -T -X Operation (RKB) End DepN (WB) 8/4/2017 8/4/2017 0.50 COMPZ3 CASING OWFF P At surface, check well for flow, PJSM 44.3 44.3 21:03 21:33 8/4/2017 8/4/2017 0.50 COMPZ3 CASING PULD P LD settting tools 44.3 0.0 21:33 22:03 8/4/2017 8/4/2017 0.35 COMPZ3 CASING PUTB P Prep rig floor for liner ops, PJSM 0.0 0.0 22:03 22:24 8/4/2017 8/5/2017 1.60 COMM CASING PUTB P. PU/MU upper liner segment with 51 its 0.0 1,161.8 22:24 00:00 of slotted liner 8/5/2017 8/5/2017 1.25 COMPZ3 CASING PUTB P Continue PU upper liner segment 1,161.8 2,058.0 00:00 01:15 8/5/2017 8/5/2017 0.75 COMPZ3 CASING PULD P PJSM, PU/MU CoilTrak tools, surface 2,058.0 2,107.9- 01:15 02:00 lest, (good test), strip down onto stump 8/5/2017 8/5/2017 1.25 COMPZ3 CASING RUNL P RIH, pumping min rate 0.3 bpm 2,107.8 6,093.0 02:00 03:15 8/5/2017 8/5/2017 0.75 COMPZ3 CASING RUNL P Correct to the 4,000' EOP flag plus 6,093.0 7,808.0 03:15 04:00 1 1 8.3', puw 30 K, continue IH 8/5/2017 8/5/2017 0.70 COMPZ3 CASING RUNL P Tag up at 7808, work pipe down to 7,808.0 8,177.0 04:00 04:42 bottom 8/5/2017 8/5/2017 0.20 COMPZ3 CASING RUNL P Release from liner, bring pump to 1.5 8,177.0 6,110.0 04:42 04:54 bpm, 4350 psi, 30K PU, reset counter 8/5/2017 8/5/2017 1.10 COMM CASING DISP P Displace out KWF, roll well over to SW 6,110.0 6,110.0 04:54 06:00 8/5/2017 8/5/2017 2.20 COMPZ3 CASING TRIP P PUH to 2500', LRS pushed 30 bola. 6,110.0 44.2 06:00 08:12 diesel to coil, continue OOH, lay in diesel FP. 8/5/2017 8/5/2017 1.80 COMM CASING PULD P PUD and laydown BHA #12. 44.21 0.0 08:12 10:00 8/5/2017 8/5/2017 1.70 DEMOB WHDBOP MPSP P PJSM, RU, lubricate and set BPV, 0.0 0.0 10:00 11:42 perform negative test, RD valve crew 8/5/2017 8/5/2017 1.30 DEMOB WHDBOP NUND P MU 2" nozzle, slide injector cart over, 0.0 0.0 11:42 13:00 stab on, jet BOP stack, move injector off 8/5/2017 8/5/2017 0.50 DEMOB WHDBOP NUND P Borescope inspection on BOP stack 0.0 0.0 13:00 13:30 8/5/2017 8/5/2017 2.50 DEMOB WHOBOP NUND P Blowdown lines, suck out stack, pour 0.0 0.0 13:30 16:00 in MEOH on top swab, disconnect Putz, off high line power, 15:00 8/5/2017 8/5/2017 2.00 DEMOB WHDBOP NUND P ND BOPE 0.0 0.0 16:00 18:00 Rig Released 18:00 hours 8/5/2017 Page 13113 Report Printed: 61812017 sI ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H -26L1-02 60-103-20208-62 Baker Hughes INTEQ Definitive Survey Report 11 August, 2017 BAKER '1 �cUGHES y , 8412017 4.34:3" Page 2 COMFASS SOW.. 14 BuiM 65 ConoeoPhillips R E.RdEl ES ConoeoPhillips Definitive Survey Report Company: Con0wPhvii,s,(Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 31326 project: Kuparuk River Unit WO Reference: 311-26®80.00usfi(311-26) Sea: Kupamk 3H Pad MD Remmnco: 3H -26C 80.00 1311-26) Wall: 3H-26 North Reference: True Wellbore: 3H -26L1 Survey Calculadon Method: Minimum CurvaWrs Design: 3H-2611 Database: EDT Alaska Sandbox Project Kupamk River Unit, North Slope Alaska, United Slates Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NACCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using 9e0dele scale factor Well 3H-26 Well Position -NI-S 0.00 usfl Northing: 6,000,2M 70usft Latitude: 70.24 43,124 N ♦EbW 000 usfi Fasting: 498654.81 usfl Longitude: 150°0'39435W Position Uncertainty 000 usfi Wellhead Elevation: usfi Ground Level: 0.00 usfl Wellbore 311-261-1-02 Magnetics Model Name Semple Date O¢ctbMgon Dip Mgle Field 8lfert (1) (°) ufn SGGM2017 91112017 17.42 80.95 57,487.12 Design 3H-26L1-02_�-- Audit Notes: Version: 1.0 Phase: ACTUAL Te On Depth: 7,402.05 Vertical section: Depth Prom(WD) MUS •FNY Dkeeddn (uart) (-M (uW C) 8000 000 000 0.00 8412017 4.34:3" Page 2 COMFASS SOW.. 14 BuiM 65 Conocc Phillips eryc � a C0nocoPhillips Definitive Survey Report '1.87.... Company. ConomPhillips(Alaska) Inc .-Kup2 Lout Co-obdaade RMemnes: VJe11311-26 projectKupamk River Unit TVO Rehrence: 311-26@80 OOusn(3&26) Sim: Kupamk 3H Pad MO Reference: 311-26®80.00ush(3H-26) Well: 311-28 Norm Reference: hue Wellbom: 3H-2611 Survey Calculation Medved: Minimum Curvature Oeal9n'. 3H -26L1 Dambaso: EDT Alaska Sandbox Survey Pro9rem Wm WV2017 From 7o Survey Survey ( (um0 (-am Summy(Wmllmre) Taol Name description Smrt Data End Dam 121.00 5,9]4]0 311-26(311-26) MWD MM-SmndeM 1112/2001 6,229.65 6,32045 3H -26L1 MW41NC(3M-2611) Mill ONLY MW41NC_ONLY _MILLER 7232017 71242017 6,350.41 6,769.74 311-2811 MWD(311-261-1) MWD MWD -Startled! ]24@01] 7272017 6]12.0 6,880.12 311-281-1-01 MW41NC(311-2611-01) MWD-INC_ONLY MWAINC_ONLY _FILLER ]28201] ]291201] 6.88959 7,402.05 311-2811.01 MM(31-1-2611-01)MWD MWD-StandaN ]2&201] 7302017 7,400.0 7,441.31 311-261142 MWS-INC(3H-261.1-02) MN INC ONLY MWD-INC_ONLY _FILLER 71312017 ]91201] 147051 10,134.09 311Q61142 MM(314-2611-02)MWD MWD-6tandaN 71312017 &42017 Survey I MO Inc Abd NO NDSS aNIS .0 -WW Map Map DlS Vemcal (.an) 1°I 1°I (ush) (ectt) Paan) (awl No N) Easun9 (.Mw) (to Survey Tool Name Annotation U 7,40305 0.01 18319 5,88167 5,811 67 -4,2]9.56 181 5,98],9933] 499,fi66.21 2095 8.2]9.55 MWD(5) TIP ],4880] 92.80 16379 5y09JI�] 5,81137 -2,285.25 150 5,99790767 49865790 1052 -2.2&`.25 "WNC CNLY(6) NOP 7,44131 10351 153.70 5885.63 5.809.63 -2,315.91 1530 5,997,99A2 490,659]] 43.87 831591 MWOINC_ONLY (6) mmryalamd AvmuN I ],4]051 96.03 144.73 580187 5.801.67 -2,340.50 MAD 5987,932.35 498,604 49 39.01 -2,340.59 MWD(]) First Clean Survey i 7.49903 86.50 13398 5.80102 5.80102 -2362.76 4915 5,997,910.17 495703.53 48.96 -2,362.76 MWD(7) 7,530.39 83M 123.20 5,883.80 5,893.80 -2,301.]1 7389 5,99],89122 498,72728 36.80 -2,38171 MW0(7) ! 7.559.82 82.39 11104 5.807 54 5.807.54 -2395.00 90.83 5597,877.92 498,]53.20 41.04 -2,395.00 MWO(7) 1.t ],59021 W44 10361 5.85050 5.81050 -$40199 127.68 5,90.&893 498,76204 2774 -2,403.99 MVO(]) i ],620.21 &.07 9132 5,892.78 5.81378 Q408T 157.28 5,50,887.04 495811.61 4110 -2,40.0 MWD(T) 7,849W W 7962 5,89535 5,81535 -24W 55 186.62 5%!,86738 493,840.97 3941 -2405.55 MrW(7) ],8]9.64 87W 030 5,89715 5,81715 3,39729 21539 568707561 495&5.75 38M -239729 kill (7) 7.71069 88.0 51.93 5899.09 5,018.09 Q381.99 242.04 5,99],090.93 498,MM 5311 -2361.99 MWD(]) j 7,] 01 W0 16.78 5,898.1] 5.016.1] -287587 261.24 599],90$ 498,915.59 22.M -23%50 MJVO(7) ],]6544 8735 H.W SAN 09 5,01009 -2,34199 '202.34 5,997,82].09 498.536.]0 845 234499 MNp(7) 7,,70,01 90.43 11.95 5,898.15 5,818.1S -2,322.53 304.63 5,997,95024 490,959.99 343 -2,32263 NIM (7) 7M87 Sam 45.95 5,897.93 5,61793 -2,293.87 M8.0 59979]3.29 498,982.41 387 -22WW MND(7) S/If201] 4:34:86PM Pal COMPASS SOW. 14 Sixe 85 ConocoPhillips �i�iH[s 9 ConocoPhillips Definitive survey Report Campany: ConocoP0llllps(Maska) Inc.-Kup2 L9ol CG.orCmate RNerence: We113H-26 Pro3ea: Kupamk River Unit TVD Reference: 311-26 C 80 ODo88(3H-26) Site: Kupamk 3H Pad MO Relemirm 31-1-26 Q 80.00ush(31186) Wall 311-26 NORB Reference: hue Wa110om. 3H-2811 Survey Calculation Method: Minimum Ounatum Demgn'. 3H -26L1 Database: EDT Alaska Sandbox but ay Map Map VaNcal MD Inc Axi TVD TVD55 +NIS .0m NOnnin 9 East10 98uttey OLS. S iOn (ush) 11I (°I (um) lusnl Iu5h1 luahl Ihl Ilp f°n9D Tool Name IN MODtffiI0D ]864.51 90.fi8 47 589].62 5,81762 -237583 353.26 599].99]00 49900762 447 -2,27583 MWD(]) 709369 1.4.40 4933 5,89].35 5,017M -2.25645 VS 07 5,16,01610 489,0'tl" 648 -2,25545 MWD(]) ],925.]3 11 46.2] 5,811 5,8161 -2,230.94 mw 5,99903].91 499,053.17 966 -2,230.94 MWD(]) ],954.]9 89.85 43.43 5,81.01 5,816.81 -2,22434 419.M 5,11 410]36] 10.37 -2,22434 MWO(7) 7,91.55 Me 39.62 5,89].18 5,017.10 -2,191.14 43948 5,19081]0 499,0185 16.03 -2,19114 MD(7) 5.014.71 1.T] 35.33 5.897.30 5.017,30 -2,167N 45].D1 5.959100.1 499.111.39 13.A -2,167.05 MWD (]) 8.405.07 N71 33.24 5,09)40 5.017.44 -2,142.40 4]356 5999130.43 499,127,93 16.0 -2, 142AO MWD(]) 8,0]5]3 SO 5 M.67 5,17,72 5,81772 -211577 48974 5.91157 .00 499.14312 8.35 -2115.77 MhD(]) 91947 88.1 25.1 5,89615 5.81915 -2,08579 50420 5.91,87 .1 499.15059 10.10 -2,085.79 Ml I 8,140.43 89.83 51 5,18.93 5,81993 -20071 51751 5,91,21497 499,1711 332 -205785 MPoD(]) j 8,17035 1.11 23,70 5,891) 47 5,81947 -2030.59 529.84 5,9134221 ane'la 24 L51 -2030.59 NnnA ) 8.111 88.09 22.23 5,01.1 5.81998 -20U9.40 541.37 5,998269.40 11,11.]8 50 -2014D MJA(7) 8,233.24 180 Y1.51 5900.38 5.820.38 -197541 55309 5.91.297.39 41,2%.48 3.96 -197541 MND(]) 8.54.47 840 10.70 5902.1 582203 -1,943.50 56531 5,9131 .30 41,21971 1900 -1.9431 MNO(7) 8,55.10 62.38 16.01 5,9142 5,82542 -1,91445 5]439 5,18.31.34 41,25.79 11.1 {92445 IRM (7) 935.42 144 1233 6909 16 5,029.16 -1.885.28 59175 5,938.38.50 499235 16 12.54 -1,685.5 MWD (7) 1 ! 9355.01 8535 689 5,91208 5.032.08 -1.815 50866 5,91,4,6.52 49924100 1940 -1.855.5 MWD(7) 0,395.35 SIM 271 5,914.71 5,8u.7, -1,M14 51.19 581p46.63 499,243.61 1393 -1, 614 MWO(7) 0,41529 anm 081 5,9178 5,8W 07 -17131 10 11 5,81476.46 499,24453 955 -171.31 MWD(]) f 0.445.81 09.1 358.1 5.91908 5,838.46 -1765.1 51.1 5491,500.95 499.244.0 13.15 -171.82 1(7) 3 0,474.35 930 35733 5,91720 5175 -1]3]31 51.10 5,9153546 499,24354 102] -1,M,31 MMJ(]) 8,501.16 955 354.91 5,91480 50341 -1]0]5 1]1 5,9156540 499.24152 953 -178.1 MWD(]) i 0.534.37 938 11.]4 5.91271 5,832.]t -1,8].7 583.36 5999594.1 499,237.81 15.76 -1,6777 MWD(7) 0.5FN.t2 9132 31].13 5.911 5] 58 315] -1818.1 5]].66 51914624.16 41.233.11 1318 -1.610.60 NI8,591.14 Sam 341.95 5,9it 61 5,83161 -1,6,9 aa, 5691 5,998,6108 41,M12 1961. -1,61960 MND(]) 0.82465 92. an 3398 5,9115 5,03125 -151.1 55943 5.998.60161 41.21390 17.36 -1590.95 MWD(]) 8,654.13 1.10 34056 5,1-1.91 5,8'e9.91 -1,51.33 51922 5,1199.709 43 41,203.70 591 -1,5133 MND(]) B,685.8 1.10 34520 5,91 5,85.42 -1,533.80 54015 519]39.1 4111.1 1540 -153380 MND(]) 971479 167 34700 5,900.1 5.85.89 -1.504.98 53306 5.19]878 4saiia 9 913 -1,50498 MND(7) 9714.19 9190 35113 5905.1 5.1569 -1,0614 5751 5.91.]1.62 41,182.00 1410 -1.0614 MW(7) 8]]436 8631 35335 590563 5,8563 -1416.25 52344 5,91,85.1 41,177.1 131 A.K625 MND(]) BH Ud017 4 34: 35PM Page 4 COMNSS 14 B"86 COnOcOPhllllps dgI.Pp65 a COIIOCOPhIIIIIDs Definitive Survey Report company: ConocoPhillips(Alaska) Inc.-Kup2 Local Co<7dinate Reference: Well 3H-26 Project: Kupamk River Unit TVD Reference: 31126@8000usff(3H-26) Aso: Kupamk 3H Pad MD Resonance: 311-26 a 80.00usfl(311-26) WeII 3H-26 Norm Reference: Tme Wellbore: 3H -26L1 Survey Calculation Malmoi: Minimum Curvature Design: 3H-25Lt Database: EDTAlaska Sandbox Survey 87114017 4,34:3" Pape 5 COMPASS 5000.14 BuIIC 85 Map Map Will MD Inc A41 TVD WOSS ANIS ♦Et -W NOMing Eaafing OLS Section Survey Tool Name AnnaWbmn Ivrnl 19 I'1 loan) lusnl loan: lural (n) (ft)1 Nao') Irtl 8 W 15 8].30 355.95 5.906.96 5.826.96 -1,41164 52019 5.998.%1.11 x9917470 8.01 -1"164 MWD (]) 8.836.01 07.42 357.10 5.908.20 5.82830 -133466 51857 5,90,807.% 4.°9,1]3-08 4.30 -1384 Be MWD (7) 8864.90 Min 35728 5,90933 5829.33 -1,3560 517.15 5,998.918.72 a%,17167 2.43 -1,356.02 MWD (]) Base 35 910 357.83 Swee0 5,029.40 -1.32461 51576 5,990.940.13 499,17020 1137 -1,3X61 MAD (T) 8,9X.85 0 B 017 5,90034 encu -1,296.14 51521 5.99B9660 499.169.73 9.47 -1,20.14 MWD I71 895].13 91.% 343 5.9070 582]09 -1283.90 516M 5,9g%owBi 499,170.75 ion -1,263.90 Maim (7) 8.9&5.40 92.49 7.30 5.906.01 882501 -1,23578 51608 5,999,03595 499,173.40 13.05 -1.23578 MWD (]) 9.01485 9t 91 1110 5,%4.% 58X0 -1,20.74 523.57 5.9%.05.% 499.178.11 1304 -1,20674 MWD (]) 90W.Be 93.01 1494 Son SO 5,89:.'20 -1,1]55] 53078 5,999.07.15 499.18532 1745 -1,9557 MND (]) 9,07620 0M 19.10 59p19t 5,021.91 -1.14758 weaA 5,999.125.14 499,19389 14.19 -1,147,50 MWD(7) 9,104.5D 92.81 2391 5,900 45 5.82045 -112123 54954 586,15148 499,204.10 1467 -1,12123 MWD (]) 9.13492 in 77.05 5¢99.20 5.81920 -10372 02.45 5,88,9699 499,217.01 12.75 -1093.72 MWD (7) 9.16121 90.0 29.71 5,893.47 5,018.47 -107.0 5]8.3] 5,9%,204.74 4992300 992 -1,06798 MWD(7) 9,194.80 06.23 32.35 SUBA4 5,Bt64I -1,041.75 591.13 5,999.230.% 4%.246.]0 1014 -1,04175 NWD(7) 922506 8004 33.35 5.999.18 501910 -101581, &19.86 59%,20.81 4%,263.40 5.05 -101508 MWD(7) 9.25559 876( 28.94 5,8034 5,820.34 -%0.24 82433 5,999282.45 4%,2]8.0 148] -880.24 MWD(]) 928019 8714 25.0 5,80149 5,821,49 .%8.41 63560 59%,304.27 4%,2%.17 1340 -08.41 li 9,310.% 88.47 21.% esiv65 582265 AAO 70 84781 5,890,33198 4%,snag 13.10 510.]0 MWDI]) 9,340.34 8].0 9.0 590.81 5.823.81 MZ67 0772 5,999,36(1 499,31230 1691 5120 MWD(7) 8370.31 8585 1,147 5.90.0 BMW -89301 0588 "99358 Be 49go046 9.50 -8&101 MAD(7) 9,403.39 0588 11.07 5,90783 5.82!83 4854.55 67249 5.999.410.11 49,932700 1127 -05455 MWDI]) ( 9,43330 87M 6.81 5909 So 5,829 So 4824.98 677,14 59%.44].06 499,33174 15.47 M4,98 MWD (]) j 9,45.23 070 4.15 5,91063 5.833.63 -0002] 67951 5,9%p72.% 4%,3X.11 11.M -00027 NOV) (7) 94023 0.5 0.0 591231 5.832.31 -]]035 M85 5,8%,502.% AROMAS 10.74 -77036 MWO(]) 9,51033 as in M7 97 5,914.13 5,834.13 445.32 68062 59%,5,29.33 499.33522 13.21 -74532 MWDI]) 9,54031 a23 2.20 5,91665 5,838.85 -71546 WON 5990,55719 499,33627 140 -71546 MWD (]) 9,57038 091 35811 591890 5.838.98 -685 48 69074 5,90.58716 49933535 1375 -695,48 Bell (7) 96W 29 85.73 340.52 5921.9 Seel 1] 555.9] 6]6]6 5.999.616.67 499,311.30 %.5 -6597 MWD (7) 9.633.60 582 &2.0 5923.38 5.843.30 482].1] ON Be 5,999,645.47 4%,323.20 14.M 62717 MWD (7) - 9.9N33 M93 X538 592528 5,845.20 -598.41 00.34 5,999,674.23 499,31488 1173 -59041 MWD (]) 9.N,O2A 8.05 34962 5926.85 5846.85 559.26 853.]5 5,9%.]0.38 499,30.40 1363 5926 MWD)]) 87114017 4,34:3" Pape 5 COMPASS 5000.14 BuIIC 85 �- ConocoPhillips i Co71oCo'Phil Ips 9�� Definitive Survey Report Co.": ConocoPhllips(Alaska) Inc. Kup2 Local Co4r4inate Reseal vital 31+213 Profen: Kupamk River Unit NO Relenance: 3H-26(g 280.00usft(3H-26) St.: Kupwk 3H Pad MD Resorence: 3H-26@8000usft(314-26) Well: 311-26 North Resonance: True Wellbore: 311-2611 Survey Calculation Model Minimum CurvaWas Design: 3H-26L1 Database: EDT Alaska Sandbox Survey MD Inc NJ TVD MSS +073 3 -w Northing Eaalfn g OLS SMbn Tool Noma latent 1"I 11) (uaR) (daft) Nan) luau) (Sim) $unry Mnotation 011 (M III) 972039 5.5 35318 5928.BT S.Bd8.67 -$39.51 61923 5,999.433.12 499,30388 12.58 -53951 MWD(]) 9,]50.13 W53 35335 5,930.60 5,851 -`50998 618.52 5R99,762 .8] 499.801.18 1077 -5996 MW01]) 9783.09 0571 35982 5. MM 5,&52.38 J5A8 845.52 5,939]92.56 493.3M t0 1150 J 0,08 MWO(7) 9,01092 8519 3.28 5,934.27 5.054.27 M9.32 646.35 5,%9,023.31 49930101 11.26 04932 all (]) { 9,041,49 MW 748 5,935.26 5858.28 418.% 649.20 5,999,853 an 499,303.87 1379 418.M MWD(]) 9,070.23 85.91 10.12 Sam 19 Sam 19 -350.62 65.5 5,gag,85.W 499,30938 931 x.62 MWD(]) 9.95.19 89.56 14.22 5.95.16 5.85.16 36140 65989 5,95,911.21 499,314.57 13.83 38140 MWD(7) 9,93392 8711 17.5 5,94183 5,851.83 332.38 838.15 5,999.940.24 499.322.8t 1115 r 30 betel 9.95.49 111 19.55 5.94344 5.53.44 3(X91 67770 5,999,968.]0 499,332.39 375 303.91 MMD(]) 9989 79 Us SO 21.80 5.94540 5.86540 -2]656 69902 5,9gages ad 499,3428 859 -27655 MND(]) 10,02139 0107 22.1] 5,949.05 5,858505 -24256 59.73 6.05,025.01 499,361.43 1446 -24]5 MND(]) 10,med 5.5 25.13 5,95.8] 5,0]3.8] 421.27 ]fl 35 6.000.051.32 499,345.94 10.13 -22127 MND(]) 10081.17 8125 28.91 5,959.50 5.87650 -194.17 M507 6,003,07642 499,379.]0 1235 -194.17 MWD (7) 10,19089 8162 32.5 5.962.93 5,892.93 -18691 74008 8,003,15.67 499,39479 1191 48691 MWD(]) 10.134.09 80.08 34.40 5,85.46 5896.46 -14970 75272 60091mad 499,40]43 B.]3 -14878 MND(]) 10,16600 W 34.40 5,971.05 5,891.05 -122.16 7184 6,950,150.42 493,426.35 OW -122.16 PROJECTED to TO 8,112017 4,34:3" Pepe a COMPASS 500014 Bald 85 C_Q v14 0-t' T ( BA ER 0 PRINT DISTRIBUTION LIST F UGHES a GE company COMPANY ConocoPhillips Alaska, AEGEI E WELL NAME 3H -26L1-02 FIELD Greater Kuparuk Area AUG � 2 8 2017 COUNTY North Slope Borough AnrCC BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(a bakerhughes.corn STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V t 'IBP North Slope. 'EOA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 1900 E. Benson Blvd. !Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Tom Osterkamp ATO 3-344 700 G Street iAnchorage, AK 99510 3 Exxonsdobil,Alasle Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC Atm: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 I, - Z i 7090 28547 :e sign and return one copy of this transmittal form to: DcoPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. DATA LOGGED 9 / % /2011 forage. Alaska 99510 K. BENDER LOG TYPE GR - RES LOG DATE August 4, 2017 TODAYS DATE August 24, 2017 Revision Details: Rev. Requested by: --- FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, I SURVEY I REPORT LOGS CGM, Final Surve)s) (Compass) # OF PRINTS9 ur rKIN # OF COPIES I# OF COPIES I# OF COPIES 4 4 � 4 0 0 0 0 0 0 0 0 0 0 5 DNR -Division ofOil & Gas *** 0 0 1 i 0 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR 6! BP Exploration (Alaska) Inc. Petrotechnical Data Center, IR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 ConocoPhillips RECEIVED AUG 2 8 2017 AOGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H -26L1-02 50-103-20208-62 Baker Hughes INTEQ Definitive Survey Report 11 August, 2017 BA ER F�UGHES a GE company 21 70g0 2854 7 6. ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 31-1-26 Project: Kupamk River Unit TVD Reference: 3H-26 @ 80.00usft (3H-26) Site: Kuparuk 3H Pad MD Reference: 311-26 @ 80.00usft (3H-26) Well: 3H-26 North Reference: True Well 311-261-1 Survey Calculation Method: Minimum Curvature Design: 31H-2611 Database: EDT Alaska Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 3H-26 Well Position +N/S 0.00 usft Northing: 6,000,272.70usft Latitude: +E/ -W 0.00 usft Easting: 498,654.81 usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: Wellbore 31-1-2611-02 Magnetics Model Name Sample Date BGGM2017 9/1/2017 Design 31-1-261-1-02 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 80.00 Declination (I 17.42 Tie On Depth: 7.402.05 +N/S (usft) 0.00 +E/ -W (usft) 0.00 Dip Angle V) 80.95 Direction (1) 0.00 8V%9 0 70° 24'43.124 N 150° 0'39,435 W 0.00 usft Field Strength (nT) 57,48712 8/112017 4:34:35PM Wage 2 COMPASS 5000.14 Build 85 Survey Program Date 8/4/2017 From ConocoPhillips 7/24/2017 ConocoPhillips Definitive Survey Report (usft) Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference Well 3H-26 Project: Kuparuk River Unit TVD Reference: 3H-26 @ 80.00usft (311-26) Site: Kuparuk 3H Pad MD Reference: 3H-26 Q 80.00usft (31-1-26) Well: 311-26 North Reference True Wellbore: 311-261.1 Survey Calculation Method: Minimum Curvature Design: 311-26Li Database: EDT Alaska Sandbox Survey Program Date 8/4/2017 From To 7/24/2017 7/27/2017 7/28/2017 (usft) (usft) Survey (Wellbore) Toot Name Description 121.00 5,974.70 31 (31-1-26) MWD MWD- Standard 6,229.65 6,320.45 311-261-7 MWD -INC (31H-2811) MWD -INC -ONLY MWD -INC -ONLY FILLER 6,350.41 6,769.74 3H -26L1 MWD (31H-26111) MWD MWD -Standard 6,772.00 6,660-12 3H-2611-01 MWD -INC (3H-261-1-01) MWD -INC -ONLY MWD -INC -ONLY -FILLER 6,889.59 7,402.05 31-1-2617-01 MWD(31-1-261-1-01)MWD MWD -Standard 7,408.00 7,441.31 31-1-261-7-02 MWD -INC (3H-2611-02) MWD -INC -ONLY MWD -INC -ONLY -FILLER 7,470.51 10,134.09 31-1-261-7-02 MWD(3H-2611-02) MWD MWD -Standard Survey Survey Start Date 1/12/2001 OAd( UGERH[5 Survey End Date 7/23/2017 7/24/2017 7/24/2017 7/27/2017 7/28/2017 7/29/2017 7/28/2017 7/30/2017 7/31/2017 7/31/2017 7/31/2017 8/4/2017 Annotation TIP KOP Interpolated Azimuth First Clean Survey 8/1112017 4: 34 35P Page 3 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc TVD TVDSS -iiE/-W DLS (usft) ) (°) (1 ) (°) (usft) (usft) (usft) (usft) Northing Easting ("/100') Section Survey Tool Name (ftl (ft) tft) 7,402.05 93.01 163.19 5,891.67 5,811.67 -2,279.56 1.81 5,997993.37 498,656.21 24.95 -2,279.56 MWD(5) 7,408.00 92.83 163.79 5,891.37 5,811.37 -2,285.25 3.50 5,997,987.67 498,657.90 10.52 -2,285.25 MWD -INC _ONLY (6) 7,441.31 103.51 153.70 5,886.63 5,806.63 -2,315.91 15.38 5,997,957.02 498,669.77 43.87 -2,315.91 MWD -INC _ONLY (6) 7,470.51 96.03 144.73 5,681.67 5.801.67 -2,340.58 30.10 5,997,932.35 498,684,49 39.64 -2.340.58 MWD (7) 7,499.83 86.50 133.98 5,881.02 5,801.02 -2,362.76 49.15 5.997,910.17 498,703.53 48.96 -2.362.76 MWD (7) 7,530.38 83.08 123.20 5,883.80 5,803.80 -2,381.71 72.89 5,997,891.22 498,727.26 36.88 -2,381.71 MWD 17) 7.559.82 82.39 111.04 5,887.54 5,807.54 -2,395.00 98.83 5,997,877.92 498,753.20 41.04 -2,395.00 MWD (7) 7,590.21 1 103.61 5,890.50 5,810.50 -2,403.99 127.68 5,997,868.93 498,782.04 27.74 -2,403.99 MWD (7) 7,620.21 84.87 91.32 5,892.78 5,812.78 -2,407.87 157.28 5,997,865.04 498,811.64 41.18 -2,407.87 MWD (7) 7,649.80 85.20 79.62 5,895.35 5,815.35 -2,405.55 166.62 5,997,867.36 498,840.97 39.41 -2,405.55 MWD (7) 7,679.84 87.94 68.38 5,897.15 5,817.15 -2,397.29 215.39 5,997,875.61 498,869.75 38.44 -2.397.29 MWD (7) 7,710.69 88.62 51.90 5,898.09 5,818.09 -2,381.99 242.04 5,997,890.90 498,896.40 53.44 -2,381.99 MWD (7) 7,736.01 90.98 46.76 5,898.17 5,818.17 -2.365.50 261.24 5,997,907.39 498.915.59 22.34 -2,365.50 MWD (7) 7,765.44 89.35 44.88 5,89809 5,818.09 -2,344.99 282,34 5,997,927.89 498,936.70 8.45 -2,344.99 MWD (7) 7,797.01 90.43 44.95 5,898.15 5,818.15 -2,322.63 304.63 5,997,950.24 498958.99 3.43 -2,322.63 MWD (7) 7,829.87 90.34 4595 5.897.93 5,817.93 -2,299.58 328.05 5,997,973.29 498,98241 3.06 -2.299.58 MWD (7) Annotation TIP KOP Interpolated Azimuth First Clean Survey 8/1112017 4: 34 35P Page 3 COMPASS 5000.14 Build 85 Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 3H-26 Project: Kupamk River Unit TVD Reference: 3H-26 @ 80.00usft (31-1-26) Site: Kuparuk 3H Pad MD Reference: 311-26 @ 80.00usft (3H-26) Well: 3H-26 North Reference: True Wellbore: 3H -26L7 Survey Calculation Method: Minimum Curvature Design: 3H -26L1 Database: EDT Alaska Sandbox Survey Annotation BA (ER BA 8/112017 4:34:35PM Page 4 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS *NIS +El -W Northing Easting DLS Section Survey Tool Name (waft) (1 (1) (usft) (usft) (usft) (usft) (ft) (ft) (.1100') (ft) 7,864.51 90.68 4746 5,897.62 5,817.62 -2,275.83 353.26 5,997,997.04 499,007.62 4.47 -2,275.83 MVVD(7) 7,893.69 90.40 49.33 5,897.35 5,817.35 -2,256.45 375.07 5,998,016.40 499,029.44 6.48 -2,256.45 MWD(7) 7925.73 90.86 46.27 5,896.99 5,816.99 -2,234.94 398.80 5,998.037.91 499,053.17 9.66 -2.234.94 MWD (7) 7,954.79 89.85 43.43 5,896.81 5,816.81 -2,214.34 419.30 5,998,058.51 499,073.67 10.37 -2,214.34 MWD(7) 7,985.55 86.77 38.62 5,897.18 5,817.18 -2,191.14 439.48 5998,081]0 499,093.85 16.03 -2,191.14 MWD (7) 8,014.71 90.77 35.33 5,897.30 5,817.30 -2.167.85 457.01 5,998,104.99 499,111.39 13.20 -2,167.85 MWD(7) 8,045.07 88.71 30.72 5,897.44 5,81244 -2,142.40 473.56 5.998,130.43 499,127.93 16.63 -2,142,40 MWD (7) 8,075.73 90.25 28.67 5,897.72 5,817.72 -2,115.77 488.74 5,998,157.05 499.143.12 8.36 -2,115.77 MWD (7) 8,109.47 88.28 25.89 5,898.15 5,818.15 -2,085.79 504.20 5,998,187.03 499.158.59 10.10 -2,085.79 MWD(7) 8,140.43 88.83 25.02 5,898.93 5,818.93 -2,057.85 51251 5,998,214.97 499,171.89 3.32 -2,057.85 MWD (7) 8,170.35 89.11 23.70 5,899.47 5.819.47 -2,030.59 529.84 5,998,242.21 499,184.24 4.51 -2,030.59 MWD(7) 8,199.89 88.89 22.23 5,899.98 5,819.98 -2,003.40 541.37 5,998.269.40 499,195.76 5.03 -2,03.40 MWD (7) 8,230.24 89.60 23.20 5.900.38 5,820.38 -1,975.41 553.09 5,998,297.39 499,207.48 3.96 -1,975.41 MWD(7) 8,269.47 84.90 18.70 5,902.03 5,822.03 -1943.50 565.31 5.998,329.30 499,219.71 19.00 -1.943.50 MWD (7) 8,295.10 82.38 16.01 5,905.42 5825.42 -1,914.45 574.39 5,998,358.34 499,228.79 11.99 -1,914.45 MWD (7) 8,325.42 83.44 12.33 5,909.16 5,829.16 -1,885.28 561.75 5,998,38250 499,236.16 12.54 -1,885.28 MWD (7) 8,355.01 85.35 6.89 5,912.06 5,832.06 -1,856.26 586.66 5,998,416.52 499,241.08 19.40 -1,856.26 MWD (7) 8,385.35 84.62 2.71 5,914.71 5,834.71 -1,826.14 589.19 5,998,446.63 499,243.61 13.93 -1,826.14 MWD (7) 8.415.29 86.34 0.81 5,917.07 5,837.07 -1,796.31 590.11 5,998,476.46 499,244.53 8.55 -1,796.31 MWD (7) 8,445.81 89.88 358.92 5,918.08 5,838.08 -1,765.82 590.03 5,998,506.95 499,244.47 13.15 -1,765.82 MWD(7) 8,474.35 93.63 357.33 5,917.20 5,837.20 -1,737.31 589.10 5,938,53546 499.243.64 14.27 -1,737.31 MWD (7) 8,504.46 95.23 354.94 5,914.88 5,834.88 -1,707.36 587.08 5,998,565.40 499,241.52 9.53 -1,707.36 MWD (7) 8,534.37 93.07 350.74 5,912.71 5,832.71 -1,677.77 583.36 5,998,594.99 499,237.81 15.76 -1,677.77 MWD (7) 8.564.12 91.32 347,13 5,911.57 5,831.57 -1,648.60 577.66 5,998,624.16 499,232.11 13.48 -1,648.60 MWD (7) 8,594.14 88.52 341.95 5,911.61 5,831.61 -1,619.68 569.66 5,998,653.08 499,224.12 19.61 -1619.68 MWD 17) 8,624.65 92.83 338.87 5,911.25 5,831.25 -1,590.95 55943 5,998,681.81 499,213,90 17.36 -1.590.95 MWD (7) 8,654.13 92.40 340.56 5,909.91 5,829.91 -1563.33 549.22 5,998,709.43 499,203.70 5.91 -1,563.33 MWD(7) 8,685.07 93.10 345.28 5,908.42 5,828.42 -1,533.80 540.15 5,998,738.96 499,194.63 15.40 -1,533.80 MWD (7) 8,714.79 92.80 347.08 5.906.89 5.826.89 -1,504.98 533.06 5,998767.78 499,187.54 6.13 -1,504.98 MWD(7) 8,744.19 91.90 351.13 5,905.69 5,825.69 -1,476.14 527.51 5,998,796.62 499.18200 14.10 -1,476.14 MWD (7) 8,774.36 88.31 35335 5.90563 5,82563 -1,446.25 523.44 5,998,826.50 499,177.93 13.99 -1446.25 MWD (7) Annotation BA (ER BA 8/112017 4:34:35PM Page 4 COMPASS 5000.14 Build 85 s ConocoPhillips ER ConocoPhillips p Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 311-26 Protect Kuparuk River Unit TVD Reference: 311-26 @ 80.00usft (31-1-26) Site: Kuparuk 3H Pad MD Reference: 311-26 @ 80.00usR (3H-26) Well: 311-26 North Reference: True Wetlbore: 3H-2617 Survey Calculation Method: Minimum Curvature Design: 3H-2611 Database: EDT Alaska Sandbox Survey 8/11/2017 4:34: 35PM Page 5 COMPASS 5000 14 Build 85 Map Map Vertical MD Inc Azi ND NDSS -NI-S .E) -W (usft) (1) (1) (usft) (usft) Instill (usft) Northing ting Ea (0 1100 ) Section Survey Tool Name Annotation (it) (ft) (k) 8.809.15 8730 355.95 5,906.96 5,826.96 -1.411.64 520.19 5,998,861.11 499,174.70 8.01 -1,411.64 MWD(7) 8,635.01 87.42 357.10 5,908.20 5,828.20 -1,384.86 518.57 5,998,887.89 499.173.08 4.30 -1,384.86 MWD (7) 8,864.90 88.10 357.28 5,909.33 5,829.33 -1,356.02 517.15 5,998,916.72 499,171.67 2.43 -1,356.02 MWD (7) 8.896.35 91.66 357.63 5,909.40 5,829.40 -1,324.61 515.76 5,998.948.13 499,170.28 11.37 4,324.61 MVD (7) 8,924.85 92.58 0.17 5,908.34 5,828.34 -1,296.14 515.21 5,998,976.60 499.169.73 9.47 -1,296.14 MM (7) 8,957.13 91.88 3.43 5,907.09 5,827.09 -1,263.90 516.22 5,999,008.83 499,170.75 10.32 -1.263.90 MWD (7) 8,985.40 92.49 7.30 5,906.01 5,626.01 -1,235.78 518.86 5,999,036.95 499,173.40 13.85 -1,235.78 MWD (7) 9,014.85 91.91 11.10 5.904.88 5,824.88 -1,206.74 523.57 5,999,065.99 499,178.11 13.04 -1;206.74 MWD (7) 9,046.88 93.01 14.94 5,903.50 5.823.50 -1,175.57 530.78 5,999,097.15 499,185.32 12.46 -1,175.57 MM (7) 9,076.20 93.22 19.10 5,901.91 5,821.91 -1,147.58 539.34 5,999,125.14 499,193.89 14.19 -1,147.58 MWD (7) 9,104.50 92.67 23.22 5,900.45 5,820.45 -1,121.23 549.54 5,999,151.48 499.204.10 14.67 -1,121.23 MM (7) 9,134.92 92.03 27.05 6,899.20 5,819.20 -1693.72 562.45 5,999,178.99 499,217.01 12.75 -1,093.72 MM (7) 9,164.21 90.85 29.71 5,898.47 5,818.47 -1.067.96 576.37 5,999,204.74 499,230.93 9.92 -1,067.96 MWD(7) 9,194.80 89.23 32.35 5,898.44 5,818.44 -1,041.75 592.13 5.999,230.95 499,246.70 10.14 -1,041.75 MM (7) 9,225.60 88.04 33.35 5.899.18 5,819.18 -1,015.88 608.84 5.939.256.81 499,263.40 5.05 -1.015.88 MWD (7) 9,255.59 87.51 28.94 5.900.34 5,820.34 -990.24 624.33 5,999,292.45 499,278.90 14.80 -990.24 MM (7) 9,280.19 87.14 25.66 5,901.49 5,821.49 568.41 635.60 5,999,304.27 499,290.17 13.40 -968.41 MWD (7) 9,310.50 88.47 21.89 5,902.65 5,822.65 -940.70 647.81 5,999,331.98 499,302.38 13.18 -940.70 MWD (7) 9,340.26 87.08 17.05 5,903.81 5,823.81 512.67 657.72 5,999,360.00 499,312.30 16.91 -912.67 MWD (7) 9,370.31 85.85 14.47 5,905.66 5,825.66 -883.81 665.85 5,999,388.86 499,320.45 9.50 -683.81 MWD (7) 9,400.39 85.88 11.07 5,907.83 5,827.83 -854.55 672.49 5.999,418.11 499,327.08 11.27 -854.55 MM (7) 9,430.38 87.73 6.81 5,909.50 5,829.50 -824.98 677.14 5,999,447.68 499,331.74 15.47 .824.98 MWD (7) 9.455.23 87.05 4.15 5,910.63 5,830.63 -800.27 679.51 5,999,472.39 499.334.11 11.04 -800.27 MWD (7) 9.485.23 86.55 0.96 5,912.31 5,832.31 -770.35 680.85 5,999,502.30 499,335.45 10.74 -770.35 MWD (7) 9,510.33 85.11 357.97 5,914.13 5.634.13 -745.32 680.62 5,999,527.33 499,335.22 13.21 -745.32 MWD (7) 9,540.31 85.23 2.20 5,916.65 5,836.65 -715.46 680.66 5,999,557.19 499,335.27 14.06 -715.46 MWD (7) 9,570.38 85.91 358.11 5,918.98 5,838.98 -685.48 680.74 5,999,587.16 499.335.36 13.75 -685.48 MWD (7) 9600.29 85.73 346.52 5,921.17 5,841.17 -655.97 676.76 5,999,616.67 499,331.38 38.65 -655.97 MWD (7) 9,630.30 85.82 342.03 5,923.38 5,843.38 -627.17 668.65 5,999,645.47 499,323.28 14.92 -627.17 MWD (7) 9,660.33 86.93 345.38 5,925.28 5,845.28 -598.41 650.24 5,999,674.23 499,314.88 11.73 598.41 MWD(7) 9,690.24 87.05 349.52 5,926.85 5,846.85 -569.26 653.75 5,999,703.38 499,308.40 13.83 -569.26 MWD (7) 8/11/2017 4:34: 35PM Page 5 COMPASS 5000 14 Build 85 ER ConocoPhillips BA UGHES ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 31-1-26 Wellbore: 31-1-2611 Design: 3H-2611 Survey MD Inc Azi TVD TVDSS (usft) 0 1*) (usft) (usft) 9,720.39 86.03 353.18 5,928.67 5,846.67 9,750.13 86.53 356.35 5,930.60 5,850.60 9,780.09 86.71 359.82 5,932.36 5,852.36 9,810.92 86.19 3.26 5,934.27 5,854.27 9,841.49 86.38 7.48 5,935.26 5,856.26 9,870.23 85.91 10.12 5,938.19 5,858.19 9,900.19 86.56 14.22 5,940.16 5,860.16 9,930.42 87.11 17.55 5,941.83 5,861.83 9960.49 86.74 19.55 5,943.44 5.863.44 9,989.79 85.60 21.80 5,945.40 5,865.40 10,021.29 81.06 22.17 5,949.05 5,869.05 10.050.36 80.69 25.13 5.953.67 5,873.67 10,081.17 81.25 28.94 5,958.50 5,878.50 10,110.89 81.62 32.50 5,%2.93 5,882.93 10,134.09 80.86 34.40 5,966.46 5,886.46 10,168.00 80.86 34.40 5.971.85 5,891.85 Local Coordinate Reference: Well 31-1-26 TVD Reference: 31-1-26 @ 80.06usft (3H-26) MD Reference: 31-1-26 @ 80.00usft (31-1-26) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT Alaska Sandbox Annotation SO 112017 4:34:35PM Page 6 COMPASS 5000.14 Build 85 Map Map Vertical *N/S *El -W Northing 9 Eastin DLS Section Survey Tool Name (usft) (usft) (ft) (ft) (0100•) (R) -539.51 649.23 5,999,733.12 499,303.88 12.58 539.51 MWD (7) -509.96 646.52 5.999,762.67 499,301.18 10.77 509.96 MWD (7) 480.08 645.52 5,999,792,56 499,300.18 _ 11.58 480.08 mm (7) 449.32 646.35 5,939,823.31 499,301.01 11.26 449.32 MWD (7) 418.% 649.20 5,999,853.67 499.303.87 13.79 418.% MWD (7) 4190.62 653.59 5,999,882.00 499,308.26 9.31 390.62 MWD (7) 361.40 659.89 5,999,911.21 499,314.57 13.83 -361.40 MWD (7) 332.38 668.15 5,999,940.24 499,322.84 11.15 -332.38 MM (7) -303.91 677.70 5,999,%8.70 499,332.39 6.75 303.91 MWD (7) -276.56 688.02 5,999,996.04 499,342.72 8.59 -276.56 MM (7) -247.56 699.73 6,000,025.04 499,354.43 14.46 -247.56 MWD (7) -221.27 711.25 6,000,051.32 499,365.94 10.13 -221.27 MM (7) -194.17 725.07 6,000,078.42 499,379.78 12.35 -194.17 MWD (7) -168.91 740.08 6,000,103.67 499,394.79 1191 -168.91 MWD (7) -149.78 752.72 6.000122.80 499,407.43 8.73 -149.78 MWD (7) -122.16 771.64 6,000,150.42 499,426.35 0.00 -122.16 PROJECTED to TD Annotation SO 112017 4:34:35PM Page 6 COMPASS 5000.14 Build 85 RECEIVr "J AUG 2 1 2017 Letter of Transmittal AOGCC BA ER (IT.'tcT: Date. DATA LOGGED AT( �' `` August 18, 2017 , 6 BE R a GE company To: Makana Bender AOGCC 333 West 711 Ave, Suite 100 Anchorage, Alaska 99501 From: Yosha Ragbirsingh / Michael Soper Baker Hughes, a GE Company 795 East 9411 Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3H-261-1 2 1 7 0 8 7 Q 3H-261-1-01 21 7 0 8 8 I�� tl O 3H -26L1-02 2 1 7 ago 28 5 1 1 (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BHGE.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ra birsin h@BHGE.com ConocoPhillips RECEIVED AUG 2 1 2011 AOGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H -26L1-02 50-103-20208-62 Baker Hughes INTEQ Definitive Survey Report 11 August, 2017 BA ER F�UGHES a GE company 21 7090 2851 1 ConocoPhillips RAER L? ConocoPhillips Definitive Survey Report tutEs Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 31-1-26 Project: Kuparuk River Unit TVD Reference: 31-1-26 @ 80.00usft (31-1-26) Site: Kuparuk 3H Pad MD Reference: 31-1-26 @ 80.00usft (31-1-26) Well: 31-1-26 North Reference: True Wellborn: 31-1-2611 Survey Calculation Method: Minimum Curvature Design: 31-1-2611 Database: EDT Alaska Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 3H-26 Well Position +N/ -S 0.00 usft Northing: 6,000,272.70usft Latitude: +EI -W 0.00 usft Easting: 498,654.81 usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: Wellbore 3H-26L1-02,�F� Magnetics Model Name Sample Date Declination 0 Dip Angle (1) BGGM2017 9/1/2017 1742 80.95 Design 3H-2611-02 Audit Notes: Version: 1.0 Phase: ACTUAL The On Depth: 7,402.05 Vertical Section: Depth From (TVD) -NAS +E/ -W Direction (usft) (usft) (usft) (I 80.00 0.00 0.00 0.00 ....vii 70° 24'43.124 N 150° 0'39,435 W 0.00 usft Field Strength (nT) 57,487 12 8/112017 4:34.'35PM Page 2 COMPASS 5000.14 Build 85 s ConocoPhillips BA R.H� ESC mcoPhIIII S Definitive Survey Report G d Company: Project: Site: Well: Wellbore: Design: Survey Program ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Kupamk River Unit TVD Reference: Kupamk 3H Pad MD Reference: 311-26 North Reference: 31H-2611 Survey Calculation Method: 3H-2611 Database: ��.._..� Date 8/4/2017 Well 3H-26 311-26 Q 80.00usft (31-1-26) 3H-26 (o] 80.00usft (3H-26) True Minimum Curvature EDT Alaska Sandbox From To Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date 121.00 5,974.70 3H-26 (311-26) MWD MWD -Standard 1/12/2001 6,229.65 6,320.45 3H-2611 MWD-INC(31-1-261-1) MWD -INC -ONLY MWD -INC -ONLY -FILLER 7/23/2017 6,350.41 6,769.74 3H-2611 MWD(3H-2131-1)MWD (usft) MWD -Standard 7/24/2017 6,772.00 6,860.12 3H-261-1-01 MWD -INC (31-1-2611-01) MWD -INC ONLY MWD -INC -ONLY -FILLER 7/28/2017 6,889.59 7,402.05 3H-2611-01 MWD(3H-2611-Ot) MWD MWD -Standard 7/28/2017 7,408.00 7,441.31 311-2611-02 MWD-INC(3H-26L1-02) MWD -INC ONLY MWD -INC -ONLY -FILLER 7/31/2017 7,470.51 10,134.09 3H-2611-02 MWD(3H-26L1-02) MWD MWD- Standard 7/31/2017 „ Survey Survey End Date 7/24/2017 7/27/2017 7/29/2017 7/30/2017 7/31/2017 8/4/2017 Annotation TIP KOP Interpolated Azimuth First Clean Survey 8/112017 4:34.'35PM Page 3 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +FJ -W DLS (usft) P) (°) (usft) (usft) (usft) Wait) Northing Easting (°/100•) Section Survey Tool Name (ft) (ft) (ft) 7,402.05 93.01 163.19 5,891.67 5,81167 -2,279.56 1.81 5,997,993.37 498,656.21 24.95 -2,279.56 MWD(5) 7,408.00 92.83 163.79 5,891.37 5,811.37 -2,285.25 3.50 5,997,987.67 498,657.90 10.52 -2,285.25 MM -INC _ONLY (6) 7,441.31 103.51 153.70 5,886.63 5,806.63 -2,315.91 15.38 5,997,957.02 498,669.77 43.87 -2,315.91 MWD -INC _ONLY (6) 7,470.51 96.03 144.73 5,881,67 5,801.67 -2,340.58 30.10 5,997,932.35 498,684.49 39.64 -2,340.58 MWD(7) 7,499.83 86.50 133.98 5,881.02 5,801.02 -2,362.76 49.15 5,997,910.17 498,703.53 48.96 -2,362.76 MWD(7) 7,530.38 83.08 123.20 5,883.80 5,803.80 -2,381.71 72.89 5,997,891.22 498,727.26 36.88 -2,381.71 MAD (7) 7,559.82 82.39 111.04 5,887.54 5,807.54 -2,39500 98.83 5,997,877.92 498,753.20 41.04 -2,395.00 MAD (7) 7,590.21 86.44 103.61 5,890.50 5,810.50 -2,403.99 127.68 5,997,868.93 498,782.04 27.74 -2,403.99 MAD (7) 7,620.21 84.87 91.32 5,892.78 5,812.78 -2,407.87 157.28 5,997,865.04 498,811.64 41.18 -2,407.87 MWD(7) 7,649.80 85.20 79.62 5,895.35 5,815.35 -2,405.55 18662 5,997,867.36 498,840.97 39.41 -2,405.55 MWD (7) 7.679.84 87.94 68.38 5,897.15 5,817.15 -2,397.29 215.39 5997,875.61 498,869.75 38.44 -2,39729 MWD (7) j 7,710.69 88.62 51.90 5,898.09 5,81809 -2,381.99 242.04 5,997,890.90 498,896.40 53.49 -ZW1.99 MVV (7) 7,736.01 90.98 46.76 5,898.17 5,818.17 -2,365.50 26124 5,997,907.39 498,915.59 22.34 -2,365.50 MWD (7) 7,765.44 89.35 49.88 5,89899 5,818.09 -2,344.99 282.34 5,997,927.89 498,936]0 8,45 -2,344.99 MM (7) 7,797.01 90.43 94.95 5,898.15 5,818.15 -2,322.63 304.63 5,997,950.24 498,958.99 3.43 -2,322.63 MWD (7) { f 7,829.87 90.34 4595 5,897.93 5,817.93 -2,299.58 328.05 5,997,973.29 498,982.41 3.06 -2,299.58 MWD (7) Survey End Date 7/24/2017 7/27/2017 7/29/2017 7/30/2017 7/31/2017 8/4/2017 Annotation TIP KOP Interpolated Azimuth First Clean Survey 8/112017 4:34.'35PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 3H-26 Project: Kuparuk River Unit TVD Reference: 3H-26 @ 80.00usft (31-1-26) Site: Kupamk 3H Pad MD Reference: 31-4-26 @ 80,00usft (311-26) Well: 3H-26 North Reference: True Wellbore: 3H-261-1 Survey Calculation Method: Minimum Curvature Design: 3H-261-7 Database: EDT Alaska Sandbox BA ER Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Eastin g (°/100') Section Survey Tool Name AnnOfafi00 ) Iftl Ift1 (ft) 7864.51 90.68 47.46 5,697.62 5,817.62 -2,275.83 353.26 5,997,997N 499,007.62 4.47 -2,275.83 MWD(7) 7,893.69 90.40 49.33 5,897.35 5,817.35 -2,256.45 375.07 5,998,01640 499,029.44 6,48 -2,256.45 MM (7) 7,925.73 90.86 46.27 5,896.99 5,816.99 -2,234.99 396.80 5,998,03791 499,053.17 966 -2,234.94 MM (7) 7,954.79 89.85 4343 5,896.81 5,816.81 -2,214.34 419.30 5,998,058.51 499,07367 10.37 -2,214.34 MWD (7) 7,985.55 88.77 38.62 5,897.18 5,817.18 -2,191.14 439.48 5,998,08170 499,093.85 1663 -2,191.14 MWD (7) 8,014.71 90.77 35.33 5,897.30 5,817.30 -2,167.85 457.01 5,998,104.99 499,111.39 13.20 -2,167.85 MWD (7) I 8,04507 88.71 30.72 5,897.44 5,817.44 -2,142.40 473.56 5,998,13043 499,127.93 16.63 -2,142.40 MWD (7) 8,075.73 9025 28.67 5,897.72 5,817.72 -2,115.77 488.74 5,998,157.05 499,143.12 8.36 -2,115.77 MWD (7) 8,10947 88.28 25.89 5,898.15 5,818.15 -2,08579 504.20 5,998,187.03 499,158.59 10.10 -2,085.79 MWD (7) j 8,14843 88.83 25.02 5,898.93 5,818.93 -2,057.85 517.51 5,998,214.97 499,171.89 3.32 -2,057.85 MWD (7) 8,170.35 89.11 23.70 5,899.47 5,819.47 -2,030.59 529.84 5,998,242.21 499,184.24 4.51 -2,030.59 MWD (7) 8,199.89 88.89 22.23 5,899.98 5,819.98 -2,003.40 541.37 5,998,269.40 499,195.76 5.03 -2,003.40 MWD (7) 8,230.24 8960 23.20 5,900.38 5,820.38 -1,975.41 553.09 5,998,297.39 499,207.48 3.96 -1,975.41 MM (7) i 8,264.47 84.90 18.70 5,902.03 5,822.03 -1,943.50 565.31 5,998,329.30 499,219.71 19.00 -1,943.50 MWD(7) ( 8,29510 82.38 16.01 5,905.42 5,825.42 -1,914.45 574.39 5,998,358.34 499,228.79 11.99 -1,914.45 MWD(7) i 8,325.42 8344 12.33 5,909.16 5,829.16 -1,885.28 581.75 5,998,387.50 499,236.16 12.54 -1,885.28 MWD (7) 8,35561 85.35 6.89 5,912.06 5,832.06 -1,856.26 586.66 5,998,416.52 499,24168 19.40 -1,856.26 MWD (7) 8,385.35 8462 2.71 5,914.71 5,834.71 -1,826.14 589.19 5,998,446.63 499,243.61 13.93 -1,826.14 MWD(7) 8,415.29 86.34 0.81 5,917.07 5,837.07 -1,796.31 59011 5,998,476.46 499,244.53 8.55 -1,796.31 MWD (7) 8,445.81 8988 358.92 5,918.08 5,838.08 -1,765.82 590.03 5,998,506.95 499,244.47 13.15 -1,765.82 MWD (7) 8,474.35 9363 357M 5,917.20 5,837.20 -1,737.31 589.10 5,998,535.46 499,243.54 14.27 -1,737.31 MWD (7) i8,504.46 95.23 354.94 5,914.88 5,834.88 -1,707.36 587.08 5,998,56540 499,241.52 9.53 -1,707.36 MM (7) 8,534,37 93.07 350.74 5,912.71 5,832.71 -1,677.77 583.36 5,998,594.99 499,237.81 15.76 -1,677.77 MWD (7) 1 8,564.12 91.32 347.13 5,911.57 5,831.57 -1,69860 577.66 5,998,624.16 499,232.11 13.48 -1,64860 MWD (7) 3 8,594.14 88.52 341.95 5,911.61 5,831.61 -1,61968 569.65 5,998,653.08 499,224.12 19.61 -1,61968 MM (7) ( 8,624.65 92.83 338.87 5,911.25 5,831.25 -1,590.95 55943 5,998,681.81 499,213.90 17.36 -1,590.95 MWD(7) 8,654.13 92.40 340.56 5,909.91 5,829.91 -1,563.33 549.22 5,998,709.43 499,203.70 5.91 -1,563.33 MVV (7) 8,685.07 93.10 345.28 5,908.42 5,82842 -1,533.80 540.15 5,998,738.96 499,194.63 15.40 -1,533.80 MM (7) (kt( 8,714.79 92.80 347.08 5,90689 5,826.89 -1,504.98 53366 5,998,767.78 499,187.54 6.13 -1,504.98 MWD (7) ' 8,744.19 91.90 351.13 5,90569 5,825.69 -1,476.14 527.51 5,998,796.62 499,182.00 14.10 -1,476.14 MWD (7) 8.774.36 8831 353.35 5,905.63 5,825.63 -1446.25 52344 5,998,826.50 499,177.93 1399 -1.446.25 MM (7) 87112017 4:34:35PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips . Company: ConowPhillips (Alaska) Inc. -Kup2 Project Kuparuk River Unit Site: Kupamk 3H Pad Well: 3H-26 :. Wellbore: 311-2611 j Design: 31H-261.1 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3H-26 311-26 Q 80.00usft (31-1-26) 31H-26 Q 80.00usft (3H-26) True Minimum Curvature EDT Alaska Sandbox aA ER 5 Survey Map Map Vertical MD Inc Azi TVD TVDSS -N/-S -El-W OLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°1100' Section Survey Tool Name Annotation i 8,809.15 87.30 355.95 5,906.96 5,826.96 -1,411.64 520.19 5,998,861.11 499,17470 8.01 -1,41164 MWD (7) 8,836.01 I 87.42 357.10 5,908.20 5,826.20 -1,384.86 518.57 5,998,88].89 499,173.08 4.30 -1,384.86 MWD(]) 8,864.90 88.10 357.28 5,909.33 5,829.33 -7,356.02 517.15 5,998,916.72 499,171.67 2.43 -1,356.02 MWD (7) I 8,896.35 91.66 357.63 5,909.40 5,829.40 -7,324.61 515.76 5,998,948.13 499,170.28 11.37 -1,324.61 MWD(]) I 8,924.85 92.58 0.17 5,908.34 5,828.34 4,296.14 515.21 5,998,976.60 499,169.73 9.47 -1,296.14 MVD (7) 8,957.13 91.88 3.43 5,907.09 5,827.09 -1,263.90 516.22 5,999,008.83 499,170.75 10.32 -1,263.90 MWD(7) 8,985.40 92.49 7.30 5,906.01 5.826.01 -7,235.78 518.86 5,999,036.95 499,173.40 13.85 -1,23518 MWD (7) 9,014.85 91.91 11.10 5,904.88 5,824.88 -1,206.74 523.57 5,999,065.99 499,178.11 13.04 -1,206.74 MM (7) 9,046.88 93.01 14.99 5,903.50 5,823.50 -1,175.57 530.78 5,999,097.15 499,185.32 12.46 -1,175.57 MWD (7) 9,076.20 93.22 19.10 5,901.91 5,821.91 -1,14].58 539.34 5,999,125.14 499.193.89 14.19 -1,147.58 MWD(]) 9,104.50 92.67 2322 5,900.45 5,820.45 -1,12123 549.54 5,999,151.48 499,204.10 14.67 -1,121.23 MWD (7) 9,134.92 92.03 27.05 5,899.20 5,819.20 -1,093.72 56245 5,999,178.99 499,217.01 12.75 -1,093.72 MM (7) 9,164.21 90.86 29.71 5,898.47 5,818.47 -1,067.96 576.37 5,999,209.74 499,230.93 9.92 -1,067.96 MWD(7) 9,194.80 89.23 32.35 5,898.44 5,818.44 -1,041.75 592.13 5,999,230.95 499,246.70 10.14 -1,041.75 MWD(7) I 9,225.60 88.04 33.35 5,899.18 5,819,18 -1,015.88 608.84 5,999,256.81 499,263.40 5.05 -1,015.88 MWD(7) i 9,255.59 87.51 28.94 5,900.34 5,820.34 -990.24 624.33 5,999,262.45 499,278.90 14.80 -990.24 MM (7) 9,280.19 87.14 25.65 5,90149 5,821.49 -968.41 63560 5,999,309.27 499,290.77 13.10 -968.41 WO (7) 9,310.50 86.47 21.89 5,902.65 5,822.65 -94070 647.81 5,999,331.98 499,302.38 13.18 -940.70 MM (7) 9,340.26 87.08 17.05 5,903.81 5,823.81 -912.67 657.72 5,999,360.00 499,312.30 16.91 -912.67 MWD (7) 9,370.31 85.85 14.47 5,90566 5,825.66 -883.81 665.86 5,999,388.86 499,320.45 9.50 -883.81 MWD (7) 9,400.39 85.88 11.07 5,907.63 5,827.83 -854.55 672.49 5,999418.11 499,327.08 11.27 -854.55 MWD (7) 9,430.38 87.73 6.81 5,909.50 5,829.50 -824.98 677.14 5,999,447,68 499,331.74 15.47 -524.98 MWD (7) 9,455.23 8705 4.75 5,91063 5,830.63 -800.27 67951 5,999,472.39 499,334.11 11.04 -800.2] MM (7) 9,485.23 86.56 0.96 5,912.31 5,832.31 -770.35 680.85 5,999,502.30 499,335.45 1074 -T70.35 MM (7) 9,510.33 85.11 357.97 5,914.13 5,834.13 -745.32 680.62 5,999,527.33 499,335.22 13.21 -745.32 MWD (7) 9,540.31 85.23 2.20 5,91665 5,836.65 -715.46 680.66 5,999,557.19 499,335.27 1406 -715.46 MM (7) 9,570.38 85.91 356.11 5,918.98 5,838.98 685.48 680.74 5,999,587 16 499,335.36 13.75 885.48 MWD (7) 9,600.29 85.]3 346.52 5,921.17 5,841.17 855.97 67616 5,999,61667 499,331.38 38.65 655.97 MWD (7) 9,630.30 85.82 392.03 5,923.38 5,843.38 827.17 66865 5,999,64547 499,323.28 14.92 627.17 MWD(7) 9,660.33 86.93 345.38 5,92528 5,845.28 -598.41 660.24 5,999,67423 499,314.88 11.73 -598.41 MWD (7) 9,690.24 8].05 349.52 5,926.85 5,846.85 -569.26 65375 5,999,703.36 499,308.40 13.83 -56926 MWD (7) &112017 4:34:35PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Well 3H-26 TVD Reference: 3H-26 @ 80.00usft (3H-26) . Company: ConocoPhillips (Alaska) Inc. -Kup2 North Reference: Project: Kuparuk River Unit Minimum Curvature Database: Site: Kuparuk 3H Pad _ (usft) Well: 31 Easting (°/too) Section $ Wellbore: 31H-2611 (ft) (ft) y Design: 3H-2611 -539.51 649.23 Survey 499,303.88 12.58 -539.51 MWD (7) I MD Inc Azi TVD TVDSS (usft) (°) (°) (use) (usft) 9,720.39 86.03 353.18 5,928.67 5,848.67 9,750.13 86.53 356.35 5,930.60 5,850.60 9,780.09 86.71 359.82 5,932.36 5,852.36 9,810.92 86.19 3.26 5,934.27 5,854.27 9,841.49 86.38 7.48 5,936.26 5,656.26 9,870.23 85.91 10.12 5,938.19 5,858.19 9,900.19 86.56 14.22 5,940.16 5860.16 9,930.42 87.11 17.55 5,941.83 5,861.83 9,960.49 86.74 19.55 5,943.44 5,863.44 9,969.79 8560 21.80 5,945.40 5,855.40 10,021.29 8105 22.17 5,949.05 5,86905 10,050.36 80.69 25.13 5,953.67 5,873.67 10,061.17 81.25 28.94 5,958.50 5,878.50 10,110.89 81.62 32.50 5,962.93 5,88293 I 10,134.09 e0.E6 34.40 5,966.46 5886.46 10,168.00 80.86 3440 5,97185 5,891.85 ConocoPhillips BA ER @11 Definitive Survey Report Local Co-ordinate Reference: Well 3H-26 TVD Reference: 3H-26 @ 80.00usft (3H-26) MO Reference: 3H-26 @ 80.00usft (31-1-26) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT Alaska Sandbox 8%1/2017 4:34:35PM Page 6 COMPASS 5000.14 Build 85 Map Map Vertical +N/5 +E/ -W Di _ (usft) (usft) Northing Easting (°/too) Section rvY Sue Tool Name Annotation (ft) (ft) (ft) -539.51 649.23 5,999,733.12 499,303.88 12.58 -539.51 MWD (7) 509.96 646.52 5.999,76267 499,301.18 10.77 -509.96 MWD (7) A80.08 64552 5,999,792.56 499,300.18 11.58 480.08 MM (7) -449.32 646.35 5,999,823.31 499,301.01 11.26 -449.32 MWD (7) 418.96 649.20 5,999,853.67 499,303.87 1319 418.96 MWD (7) -390.62 653.59 5,999,882.00 499,308.26 9.31 -390.62 MWD (7) -361.40 659.89 5,999,91121 499,314.57 13,83 -361.40 MWD (7) -332.38 668.15 5,999,940.24 499,322.84 11.15 -332.38 MWD (7) 503.91 677.70 5,999,968.70 499,332.39 6.75 -303.91 MM (7) -276.56 688.02 5,999,996.04 499,34272 8.59 -276.56 MWD (7) -247.56 699.73 6,000,02504 499,354.43 1446 -247.56 MWD (7) -221.27 711.25 6,000,05132 499,365.94 10.13 -221.27 MWD (7) / -194.17 72507 6,000,078.42 499,379.78 12.35 -194.17 MWD (7) -168.91 740.08 6,000,10367 499,394.79 11.91 -168.91 MWD (7) -149.78 752.72 6,000,12280 499,40743 8.73 -149.78 MM (7) -122.16 77164 5,00015042 499,426.35 0.00 -122.16 PROJECTED to TO 8%1/2017 4:34:35PM Page 6 COMPASS 5000.14 Build 85 THE STATE °fALASKA GOVERNOR BILL WALKER James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alosko.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3H -26L1-02 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-090 Surface Location: 1384' FNL, 281' FWL, Sec. 12, T12N, R8E, UM Bottomhole Location: 1867' FNL, 4300' FEL, Sec. 12, TI 2N, R8E, UM Dear Mr. Ohlinger: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 194-029, API No. 50-103- 20208-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this a day of June, 2017. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMk otON PERMIT TO DRILL 20 AAC 25.005 RECEIVED JUN 12 2017 1 a. Type of Work: Drill ❑ Lateral, ❑� Redrill ❑ Reentry ❑ 1 b. Proposed Well Class: Exploratory - Gas ❑ Stratigraphic Test ❑ Development - Oil R] Exploratory - Oil ❑ Development - Gas ❑ Service - WAG ❑ Service - Disp ❑ • Service - Winj ❑ Single Zone ❑ Service - Supply ❑ Multiple Zone ❑' 1c. Speci o d for: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska Inc 5. Bond: Blanket Q. Single Well ❑ Bond No. 5952180 11. Well Name and Number: KRU 3H -26L1-02 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 9725 TVD: 15 5838 12. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool 4a. Location of Well (Governmental Section): Surface: 1384' FNL, 281' FWL, Sec. 12, T12N, R8E, UM Top of Productive Horizon: 3621' FNL, 5081' FEL, Sec 12, T12N, R8E, UM Total Depth: 1867' FNL, 4300' FEL, Sec 12, T12N, R8E, UM 7. Property Designation: ADL 25531 . 8. DNR Approval Number: ALK 2657 13. Approximate Spud Date: 6/21/2017 9. Acres in Property: 2560 . 14. Distance to Nearest Property: 5470' 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 498655 y- 6000273 Zone- 4 10. KB Elevation above MSL (ft): 80 GL / BF Elevation above MSL (ft): 41 15. Distance to Nearest Well Open to Same Pool: 1050'(3H-09) 16. Deviated wells: Kickoff depth: 7400 feet r Maximum Hole Angle: 97 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 3990 - Surface: 3405 ' 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7 ppf L-80 ST -L 3625' 6100' 5768' 9725' 5838' NIA 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): 6660' 6306' N/A Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 6643' 6291' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 121' 16" 200 sx CMT 121' 121' Surface 3143' 7-5/8" 550 sx ASIII, 300 sx Class G 3143' 3140' Intermediate Production 6643' 5" x 5-1/2" 210 sx Class G 6643' 6291' Liner Perforation Depth MD (ft): 6250-6280, 6306-6336 Perforation Depth TVD (ft): 5910-5939, 5963-5992 Hydraulic Fracture planned? Yes❑ No ❑a P Sketch 20. Attachments: Property Plat ❑ DiveOer Sketch e DSeling Program abed Report B Drilling Fluid Program av. Depth l m e 20 AAC 25.050 requ ements 4 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: Mike Callahan Authorized Name: James Ohlinger Contact Email: mike.callahan@conocophillips.com Authorized Title: Staff CTD Engineer Contact Phone: 263-4180 Authorized Signature: Date: Commission Use Only Permit to Drill © Number: �o9'D API Number: Q 50- 0,2j— CO— —M Permit Approval Date: ft -2(e -1-T See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: [3D D f l5 f w rCSSt 11_e � � �"5�.i�, $- lrq� Samples req'd: Yes ❑ No Lr� Mud log req'd: Yes ❑ N& >4 n vt v 1 u ✓ L' I C✓l t 1 moi✓ �t$ t I Zl �(gS.cmeasuas: Yes V No,❑( Directional svy req'd: Yes 2' No E] a Q ' 4Js, i /.J -ebk Vat rr� n Q C Spacing ex 1p11 n req'd: Yes ❑ NoL+J Inclination -only svy req'd: Yes ❑ Nog Post initial ' —kfCkaFie 1C)i qn 1 n0f"I f aj0-"CI Y�AVInt 1crFeraryectionMIT req'd:Yes❑ NOLO APPROVED BY Approved by: COMMISSIONER THE COMMISSION Dale: 'o'rmat0 10401 Re 5/2017 O5 pe�y�t 5�yaljd fpr ori monthsO�f//��n/t¢e date of approval per 20 AAC 25.005 Submit Form and 4 ' r, ORINA rv- I N A L( 7 pP p (g) Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 9, 2017 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: RECEIVE® JUN 12 2011 AGGGG ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill three laterals out of the Kuparuk well 31-1-26 using the coiled tubing drilling rig, Nabors CDR3-AC. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. The work is scheduled to begin June 21st, 2017. The objective will be to drill laterals KRU 31-1-261-1, 3H-261-1-01, and 31-1-261-1-02 targeting the Kuparuk C -sands. Attached to this application are the following documents: - 10-401 Applications for 31-1-261-1, 31-1-261-1-01, and 3H-261-1-02 - Detailed Summary of Operations - Directional Plans for 31-1-261-1, 31-1-261-1-01, and 31-1-261-1-02 - Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4180. Sincerely, Mike Callahan ConocoPhillips Alaska Coiled Tubing Drilling Engineer Kuparuk CTD Laterals 3H-261-1, 3H-261-1-01, & 3H -26L1-02 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005M and 20 AAC 25.005(b)). ................................... .... ... . ................................................................. 2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005 (c)(3))............... ................................................................................ ...................... ........................... 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 7. Diverter System Information ..........................................................................................................3 (Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9))................................................... ................. -........... .................... ..... -...................................... 4 10. Seismic Analysis.............................................................................................................................4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4 11. Seabed Condition Analysis............................................................................................................4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................. 4 12. Evidence of Bonding......................................................................................................................4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4 13. Proposed Drilling Program............................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................6 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 7 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 7 16. Attachments....................................................................................................................................7 Attachment 1: Directional Plans for 31-1-261-1, 31-1-261-1-01 and 31-1-261-1-02 laterals......................................................7 Attachment 2: Current Well Schematic for 3H-26............................................................................................................7 Attachment 3: Proposed Well Schematic for 31-1-261-1, 31-1-261-1-01 and 3H -26L1-02 laterals........................................7 Page 1 of 7 June 9, 2017 PTD Application: 3H -26L1, 3H-261-1-01, & 3H -26L1-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 3H -26L1, 3H-261-1-01, and 31-1-261-1-02. All laterals will be classified as "Development -Oil' wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the C sand package in the Kuparuk reservoir. See attached 10-401 forms for surface and subsurface coordinates of each of the laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,750 psi. Using the maximum formation pressure in the area of 3990 psi in 3H-09 (i.e. 12.7 ppg EMW), the maximum potential surface pressure in 3H-26, assuming a gas gradient of 0.1 psifft, would be 3,405 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 31-1-26 was measured to be 3472 psi (11.4 ppg EMW) on 5/20/2017. The maximum downhole pressure in the 31-1-26 vicinity is the 3H-09 at 3990 psi or 12.7 ppg EMW. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed in this area, so there is a chance of encountering gas while drilling the 3H-26 laterals. If significant gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 31-1-26 laterals will be shale stability. MPD will be used to maintain a constant BHP on the shales for hole stability, in addition to stability additives in the drilling mud. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 31-1-26 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 7 June 9, 2017 PTD Application: 31-1-261-1, 3H-261-1-01, & 31-1-261-1-02 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 3H -26L1 7,500' 8,900' 5,815' 5,823' 2%", 4.7#, L-80, ST -L slotted liner; 0' 121' 1640 670 Surface aluminum billet on to 3H-261-1-01 7,400' 8,900' 5,827' 5,812' 2%", 4.7#, L-80, ST -L slotted liner; 3140' 6890 4790 Production 5-1/2" aluminum billet on to 31-1-261-1-02 6,100' 9,725' 5,768' 5,838' 2%", 4.7#, L-80, ST -L slotted liner; 7740 6290 Production 5" 18 Liner top packer Existing Casing/Liner Information Category OD Weight ppf) Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded 0' 121' 0' 121' 1640 670 Surface 7-5/8"" 29.7 L-80 LTC 0' 3143' 0' 3140' 6890 4790 Production 5-1/2" 17 L-80 LTC 0' 6151' 0' 5816' 7740 6290 Production 5" 18 L-80 LTC 6151' 6643' 5816' 6291' 10140 10490 Tubing 3-1/2" 9.3 L-80 ELIE IBT 0' 6126' 0' 5793' 10160 10540 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 Power -Vis milling fluid (8.6 ppg) — Drilling operations: Water based Flo -Pro drilling 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: BHA's will be deployed using standard pressure deployments and the well will be loaded with 13.0 ppg potassium formate completion fluid in order to provide formation over -balance and maintain wellbore 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 5000 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 3H-26 laterals we will use MPD to maintain formation overbalance. We will target an EMW at the window of whatever formation pressure we see while drilling, with 12.7 ppg as the maximum expected. 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 7 June 9, 2017 PTD Application: 31-1-261-1, 3H -26L1-01, & 31-1-261-1-02 Pressure at the 31-1-26 Window (6277' MD, 5856' TVD) Using MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConoccPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background The 3H-26 CTD producer project targets the C4 and C3 sands to increase throughput and recovery in the parent well pattern and regain production from the long-term shut-in (LTSI) 3H-05 producer. Three laterals will be drilled from the 31-1-26 parent well in the C -sand, two to the south and one to the north. The 3H-26 CTD well will be supported by the offset 3H-07 and 3H-06 injectors to the west. Nabors CDR3 will mill a 2.80" window off of a whipstock at 6,277'. Three laterals will be drilled targeting the Kuparuk C sands. All laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the 3-1/2" tubing tail. Page 4 of 7 June 9, 2017 Pumps On 1.5 bpm) Pumps Off C -sand Formation Pressure 11.4 3472 psi 3472 psi Mud Hydrostatic 8.6 2619 psi 2619 psi Annular friction i.e. ECD 0.080psi/ft) 502 psi 0 psi Mud + ECD Combined no chokepressure) 3121 psi underbalanced -350psi) 2619 psi underbalanced -850psi) Target BHP at Window 12.7 3870 psi 3870 psi Choke Pressure Required to Maintain Target BHP 750 psi 1250 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 ConoccPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background The 3H-26 CTD producer project targets the C4 and C3 sands to increase throughput and recovery in the parent well pattern and regain production from the long-term shut-in (LTSI) 3H-05 producer. Three laterals will be drilled from the 31-1-26 parent well in the C -sand, two to the south and one to the north. The 3H-26 CTD well will be supported by the offset 3H-07 and 3H-06 injectors to the west. Nabors CDR3 will mill a 2.80" window off of a whipstock at 6,277'. Three laterals will be drilled targeting the Kuparuk C sands. All laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the 3-1/2" tubing tail. Page 4 of 7 June 9, 2017 PTD Application: 3H -26L1, 3H -26L1-01, & 3H -26L1-02 Pre -CTD Work 1. Set whipstock in 5" production casing at 6277'. 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. 3H -26L1 Lateral (C3/C4 sand - South) a. Mill 2.80" window at 6277' MD. b. Drill 3" bi-center lateral to TD of 8900' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 7500' MD. 3. 3H -26L1-01 Lateral (C3/C4 sand- South) a. Kickoff of the aluminum billet at 7500' MD. b. Drill 3" bi-center lateral to TD of 8900' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 7400' MD. 4. 3H -26L1-02 Lateral (C3/C4 sand -North) a. Kickoff of the aluminum billet at 7400' MD. b. Drill 3" bi-center lateral to TD of 9725' MD. c. Run 23%" slotted liner with seal bore from TD up to 6100' MD. 5. Freeze protect, ND BOPS, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Run KB liner top packer 2. Obtain SBHP. 3. Install GLV's . 4. Return to production. Page 5 of 7 June 9, 2017 PTD Application: 3H -26L1, 3H-261-1-01, & 3H -26L1-02 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. - 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 - 3H-26 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. - While running 2%" slotted liner, a joint of 2%" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 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 (1 R-18 or 1 B disposal facilities) or Prudhoe DS4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6 of 7 June 9, 2017 PTD Application: 3H-261-1, 3H-261-1-01, & 3H-261-1-02 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 3H -26L1 5215' 3H-261-1-01 5340' 3H-261-1-02 5470' Distance to Nearest Well within Pool Lateral Name Distance Well 3H-261-1 1328' 31-1-09 3H-261-1-01 1350' 3H-09 3H-261-1-02 1050' 31-1-09 16. Attachments Attachment 1: Directional Plans for 3H -26L1, 3H -26L1-01 and 3H -26L1-02 laterals. Attachment 2: Current Well Schematic for 3H-26 Attachment 3: Proposed Well Schematic for 3H -26L1, 3H -26L1-01 and 3H -26L1-02 laterals. Page 7 of 7 June 9, 2017 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-26 3H-261-1 Plan: 31-1-261-1_wp02 Standard Planning Report 01 June, 2017 WEaI BAKER HUGHES - ConocoPhillips FSA aI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc.-Kup2 Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 31-1-26 Wellbore: 31-1-261-7 Design: 3H-26L1_#p02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-26 Mean Sea Level 3H-26 @ 80.00usft (31-1-26) True Minimum Curvature Project Kupamk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kupamk 3H Pad 3H-26 TVD Below Site Position: Northing: 6,000,110.73 usft Latitude: 70"24'41.531N From: Map Easting: 498,655.44usft Longitude: 150° 0'39,416 W Position Uncertainty: 0.00 usft Slot Radius: O.D00in Grid Convergence: -0.01 ° Well 3H-26 TVD Below Audit Notes: Well Position -NIS 0.00 usft Northing: 6,000,272.70 usft Latitude: 70° 24'43124 N PLAN +E/ -W 0.00 usft Easting: 498,654.81 usft Longitude: 150° 0'39.435 W Position Uncertainty Direction 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft (°) (usft) 0.00 0.00 0.00 180.00 Wellbore 31-1-261-1 Magnetics Model Name Semple Date Declination Dip Angle Field Strength BGGM2016 9/1/2017 17.39 80.96 57,536 Design 31-1-261-1_wp02 TVD Below Audit Notes: Dogleg Build Turn Version: Phase: PLAN Tie On Depth: 5,974.70 Vertical Section: Depth From (TVD) +N/ -S +EI -W Direction (usft) (usft) (usft) (usft) (°) (usft) 0.00 0.00 0.00 180.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/•s +E/ -W Rate Rate Rate TFO (usft) I°) (I (usft) (usft) (usft) (-/100ft) (°1100ft) (°1100ft) (°) 5,974.70 23.80 182.70 5,573.02 -1,144.12 -308.86 0.00 0.00 0.00 0.00 6,277.00 17.52 187.55 5,855.76 -1,250.27 -317.72 2.15 -2.08 1.60 167.01 6,302.00 21.02 187.55 5,879.36 -1,258.45 -318.80 14.00 14.00 0.00 0.00 6,455.29 90.00 187.55 5,961.01 -1,376.27 -334.42 45.00 45.00 0.00 0.00 6,525.00 90.00 182.67 5,961.01 -1,445.68 -340.63 7.00 0.00 -7.00 270.00 6,700.00 102.06 180.51 5,942.66 -1,619.32 -345.48 7.00 6.89 -1.23 350.00 6,800.00 103.18 173.43 5,920.78 -1,716.69 -340.34 7.00 1.12 -7.08 280.00 6,900.00 103.08 166.24 5,898.03 -1,812.48 -323.17 7.00 -0.10 -7.19 270.00 7,175.00 95.96 148.09 5,852.18 -2,061.00 -218.05 7.00 -2.59 -6.60 250.00 7,325.00 96.77 137.56 5,835.49 -2,179.62 -128.12 7.00 0.54 -7.02 275.00 7,550.00 96.52 153.41 5,809.28 -2,363.18 -1.91 7.00 -0.11 7.05 90.00 7,975.00 89.29 182.33 5,787.28 -2,773.55 85.91 7.00 -1.70 6.80 103.OD 8,450.00 87.22 215.53 5,802.17 -3,216.38 -65.90 7.00 -0.44 6.99 94.00 8,900.00 87.63 184.00 5,822.94 -3,634.09 -216.01 7.00 0.09 -7.01 270.00 Target 6/112017 3:54:59PM Page 2 COMPASS 5000.1 Build 74 , I ConocoPhillips WAkI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 311-26 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-26 @ 80.00usft (3H-26) Site: Kuparuk 3H Pad North Reference: True Well: 3H-26 Survey Calculation Method: Minimum Curvature Wellbore: 311-2611 Depth Inclination Design: 3H-26L1_wp02 +N/ -S +E/ -W Planned Survey Measured TVD Below Vertical Dogleg TooHace Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (_) (_) (usft) (usft) (usft) (usft) (°1100ft) (°) (usft) (usft) 5,974.70 23.80 182.70 5,573.02 -1,144.12 -308.86 1,144.12 0.00 0.00 5,999,128.75 498,345.78 TIP 6,000.00 23.27 183.01 5,596.22 -1,154.21 -309.36 1,154.21 2.15 167.01 5,999,118.66 498,345.27 6,100.00 21.18 184.38 5,688.78 -1,191.96 -311.78 1,191.96 2.15 166.73 5,999,080.92 498,342.85 6,200.00 19.11 186.03 5,782.66 -1,226.25 -314.87 1,226.25 2.15 165.47 5,999,046.63 498,339.75 6,277.00 17.52 187.55 5,855.76 -1,250.27 -317.72 1,250.27 2.15 163.92 5,999,022.61 498,336.90 KOP 6,300.00 20.74 187.55 5,877.49 -1,257.74 318.71 1,257.74 14.00 0.00 5,999,015.14 498,335.91 6,302.00 21.02 187.55 5,879.36 -1,258.45 -318.80 1,258.45 14.00 0.00 5,999,014.43 498,335.81 End 14 dls, Start 45 die 6,400.00 65.12 187.55 5,949.19 -1,323.17 -327.38 1,323.17 45.00 0.00 5,998,949.72 498,327.22 6,455.29 90.00 187.55 5,961.01 -1,376.27 -334.42 1,376.27 45.00 0.00 5,998,896.63 498,320.18 End 45 dls, Start 7 die 6,500.00 90.00 184.42 5,961.01 -1,420.73 -339.08 1,420.73 7.00 -90.00 5,998,852.17 498,315.51 6,525.00 90.00 182.67 5,961.01 -1,445.68 -340.63 1,445.68 7.00 -90.00 5,998,827.22 498,313.96 5 6,600.00 95.17 181.76 5,957.63 -1,520.53 -343.52 1,520.53 7.00 -10.00 5,998,752.39 498,311.05 6,700.00 102.06 180.51 5,942.66 -1,619.32 -345.48 1,619.32 7.00 -10.04 5,998,653.61 498,309.07 6 6,800.00 103.18 173.43 5,920.78 -1,716.69 -340.34 1,716.69 7.00 -80.00 5,998,556.24 496,314.19 7 6,900.00 103.08 166.24 5,898.03 -1,812.48 -323.17 1,812.48 7.00 -90.00 5,998,460.46 498,331.34 8 7,000.00 100.61 159.55 5,877.48 -1,905.95 -294.38 1,905.95 7.00 -110.00 5,998,366.99 498,360.11 7,100.00 97.99 152.97 5,861.30 -1,996.22 -254.66 1,996.22 7.00 -111.38 5,998,276.73 496,399.81 7,175.00 95.96 148.09 5,852.18 -2,061.00 -218.05 2,061.00 7.00 -112.44 5,998,211.94 498,436.41 9 7,200.00 96.11 146.34 5,849.55 -2,081.90 -204.59 2,081.90 7.00 -85,00 5,998,191.04 498,449.87 7,300.00 96.65 139.32 5,838.42 -2,161.04 -144.59 2,161.04 7.00 -85.18 5,998,111.90 498,509.85 7,325.00 96.77 137.56 5,835.49 -2,179.62 -128.12 2,179.62 7.00 -85.97 5,998,093.32 498,526.31 10 7,400.00 96.75 142.85 5,826.66 -2,236.82 -80.46 2,236.82 7.00 90.00 5,998,036.11 498,573.95 7,500.00 96.62 149.89 5,815.01 -2,319.47 -25.49 2,319.47 7.00 90.62 5,997,953.47 498,628.90 7,550.00 96.52 153.41 5,809.28 -2,363.18 -1.91 2,363.18 7.00 9144 5,997,909.76 498,652.47 11 7,600.00 95.72 156.84 5,803.95 -2,408.27 18.99 2,408.27 7.00 103.00 5,997,864.66 498,673.37 7,700.00 94.07 163.67 5,795.41 -2,502.00 52.63 2,502.00 7.00 103.37 5,997,770.94 498,706.98 7,800.00 92.35 170.47 5,789.81 -2,599.25 74.95 2,599.25 7.00 103.95 5,997,673.70 498,729.29 7,900.00 90.61 177.25 5,787.22 -2,698.58 85.64 2,698.58 7.00 104.33 5,997,574.38 498,739.95 7,975.00 89.29 182.33 5,787.28 -2,773.55 85.91 2,773.55 7.00 104.51 5,997,499.41 498,740.21 12 8,000.00 89.17 184.08 5,787.62 -2,798.51 84.52 2,798.51 7.00 94.00 5,997,474.46 498,738.81 8,100.00 88.69 191.06 5,789.49 -2,897.56 71.35 2,897.56 7.00 93.98 5,997,375.42 498,725.63 8,200.00 88.23 198.05 5,792.17 -2,994.25 46.25 2,994.25 7.00 93.85 5,997,278.74 498,700.51 8,300.00 87.80 205.04 5,795.63 -3,087.15 9.57 3,087.15 7.00 93.66 5,997,185.85 498,663.82 8,400.00 87.40 212.04 5,799.82 -3,174.87 -38.13 3,174.87 7.00 93.42 5,997,098.15 498,616.11 8,450.00 87.22 215.53 5,802.17 -3,216.38 -65.90 3,216.38 7.00 93.12 5,997,056.66 498,588.34 13 8,500.00 87.22 212.03 5,804.59 -3,257.88 -93.67 3,257.88 7.00 -90.00 5,997,015.16 498,560.57 8,600.00 87.26 205.02 5,809.41 -3,345.58 -141.34 3,345.58 7.00 -89.83 5,996,927.48 498,512.88 8,700.00 87.35 198.01 5,814.12 -3,438.45 -177.95 3,438.45 7.00 -89.49 5,996,834.62 498,476.26 6,800.00 87.47 191.01 5,818.65 -3,535.10 -202.97 3,535.10 7.00 -89.16_ 5,996,737,99 498,451.22 6112017 3:54:59PM Page 3 COMPASS 5000.1 Build 74 �.- ConocoPhillips WE &I ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 3H-26 Wellbore: 31-1-2611 Design: 3H-26Ll_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-26 Mean Sea Level 31-1-26 Q 80.00usft (31-1-26) Tme Minimum Curvature Planned Survey 0.00 0.00 0.00 -1,126.551,139,681.38 5,998,941.00 - plan misses target center by 1139611.35usft at 7975.00usft MD (5787.28 TVD, -2773.55 N, 85.91 E) - Polygon Measured TVD Below Depth Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N7 -S +E/ -W Section Rate Azimuth Northing Easting (usft) (e) (o) (usft) (usft) (usft) (usft) (.1100hl V) (usft) (usft) 8,900.00 87.63 184.00 5,822.94 -3,634.09 -216.01 3,634.09 7.00 -88.84 5,996,639.01 498,438.17 Planned TD at 8900.00 Point 0.00 -3,146.27 201.75 5,995,795.01 Point Targets Target Name -hit/miss target Dlppngle Dip Dir. TVD +NbS +E1 -W Northing Easting -Shape (1) (q (usft) (usft) (usft) (usft) (usft) 3H -2611_T03 0.00 0.00 5,823.00 -3,677.761,139,929.86 5,996,390.00 - plan misses target center by 1139844.31 usft at 7975.00usft MD (5787.28 TVD, -2773.55 N, 85.91 E) - Point 31-1-26 CTD Polygon Soy 0.00 0.00 0.00 -1,126.551,139,681.38 5,998,941.00 - plan misses target center by 1139611.35usft at 7975.00usft MD (5787.28 TVD, -2773.55 N, 85.91 E) - Polygon Hole - Polygon Depth Diameter Point 0.00 0.00 0.00 5,998,941.00 Point 0.00 -813.08 -6.81 5,998,128.00 Point 0.00 -1,278.06 277.32 5,997,663.02 Point 0.00 -1,674.08 396.43 5,997,267.02 Point 0.00 -3,028.34 -145.31 5,995,912.99 Point 0.00 -3,146.27 201.75 5,995,795.01 Point 0.00 -1,813.00 764.50 5,997,128.04 Point 0.00 -1,353.98 687.38 5,997,587.03 Point 0.00 -785.00 340.22 5,998,156.02 Point 10 0.00 14.07 291.03 5,998,955.02 Point 11 0.00 0.00 0.00 5,998,941.00 1,638,470.00 1,638,222.00 1,638,222.00 1,638,215.04 1,638,499.06 1,638,618.09 1,638,076.16 1,638,423.16 1,638,986.10 1,638,909.07 1,638,562.04 1,838,513.00 1,638,222.00 3H-2611_701 0.00 0.00 5,961.00 -1,419.551,139,811.44 5,998,648.00 1,638,352.00 - plan misses target center by 1139726.35usft at 7975.00usft MD (5787.28 TVD, -2773.55 N, 85.91 E) - Point 31-1-26 CTD Polygon Nor 0.00 0.00 0.00 -2,008.561,140,063.57 5,998,059.00 1,638,604.00 - plan misses target center by 1139992.61 usft at 7975.00usft MD (5787.28 TVD, -2773.55 N, 85.91 E) Hole - Polygon Depth Diameter Diameter (usft) (usft) Name Point 0.00 0.00 0.00 5,998,059.00 1,638,604.00 Point 0.00 -173.96 236.06 5,997,885.01 1,638,840.01 Point 0.00 2,007.38 769.61 6,000,066.04 1,639,373.89 Point 0.00 1,944.45 1,096.66 6,000,003.06 1,639,700.90 Point 0.00 -367.90 597.14 5,997,691.03 1,639,201.01 Point 0.00 -617.99 312.17 5,997,441.02 1,638,916.03 Point 0.00 -424.07 -138.92 5,997,635.00 1,638,465.02 Point 0.00 -174.07 -242.98 5,997,884.99 1,638,361.01 Point 0.00 0.00 0.00 5,998,059.00 1,638,604.00 Latitude Longitude 70° 9'57.835 N 140'48'32.529 W 70° 10'22.971 N 140-48- 70' 40°48' 70° 10'19.934 N 140'48'26.074 W I 70' 10' 13.842 N 140° 48'21.431 W I 31-1-261-1_702 0.00 0.00 5,787.00 -2,793.611,140,232.73 5,997,274.00 1,638,773.00 70° 10'5.970 N 140° 48'20,016 W - plan misses target center by 1140146.82usft at 7975.00usft MD (5787.28 TVD, -2773.55 N, 85.91 E) - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 8,900.00 5,822.94 2318" 2.375 3.000 6/1!2017 3:54:59PM Page 4 COMPASS 5000.1 Build 74 Plan Annotations ConocoPhillips Ord.. ConocoPhillips Planning Report Vertical BAKER Depth Depth HUGHES Database: EDM Alaska ASK Sandbox Local Co-ordinate Reference: Well 311-26 (usft) Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level 5,974.70 Project Kupawk River Unit MD Reference: 31-1-26 @ 80.00usil (311-26) TIP Site: Kuparuk 311 Pad North Reference: True -317.72 Well; 311-28 Survey Calculation Method: Minimum Curvature -1,258.45 Wellbore: 311-281-1 End 14 dls, Start 45 dls 6,455.29 5,961.01 Design: 311-2611_wp02 -334.42 End 45 dls, Start 7 dls 6,525.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-5 +E/ -W (usft) (usft) lush) (usft) Comment 5,974.70 5,573.02 -1,144.12 -308.86 TIP 6,277.00 5,855.76 -1,250.27 -317.72 KOP 6,302.00 5,879.36 -1,258.45 -318.80 End 14 dls, Start 45 dls 6,455.29 5,961.01 -1,376.27 -334.42 End 45 dls, Start 7 dls 6,525.00 5,961.01 -1,445.68 -340.63 5 6,700.00 5,942.66 -1,619.32 -345.48 6 6,800.00 5,920.78 -1,716.69 -340.34 7 6,900.00 5,898.03 -1,812.48 -323.17 8 7,175.00 5,852.18 -2,061.00 -218.05 9 7,325.00 5,835.49 -2,179.62 -128.12 10 7,550.00 5,809.28 -2,363.18 -1.91 11 7,975.00 5,787.28 -2,773.55 85.91 12 8,450.00 5,802.17 3,216.38 -65.90 13 8,900.00 5,822.94 -3,634.09 -216.01 Planned TD at 6900.00 6/12017 3.54:59PM Page 5 COMPASS 5000.1 Build 74 ConocoPhillips Company: ConomPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 3H Pad Site Error: 0.00 usft Reference Well: 3H-26 Well Error: 0.00 usft Reference Wellbore 311-261-1 Reference Design: 3H-26L1_wp02 Baker Hughes INTEQ r�.. Travelling Cylinder Report BAKER HUGHES Local Co-ordinate Reference: Well 31-1-26 TVD Reference: 311-26 @ 80.00usft (314-26) MD Reference: 31-1-26 @ 80.00usft (3H-26) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: OAKEDMP2 Offset TVD Reference: Offset Datum Reference 311-261-1_wp02 Filter type: GLOBAL FILTER APPLIED: All wellpalhs within 200'+ 100/1000 of reference Depth Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 5,974.70 to 8,900.00usft Scan Method: Tmv. Cylinder North Results Limited by: Maximum center -center distance of 1,082.00 usft Error Surface: Elliptical Conic Survey Tool Program Date 5/24/2017 From To (usR) (usft) Survey (Wellbore) Toot Name Description 121.00 5,974.70 31-1-26 (31-1-20) MWD MWD -Standard 5,974.70 8,900.00 31-1-261-1_wp02(3H-26L7) MWD MWD -Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 121.00 121.00 16" 16 26 3,142.80 3,140.36 7 5/8" 7-518 9-7/8 8,900.00 5,902.94 2318" 2-3/8 3 Summary Kuparuk 3H Pad- 3H -26 -3H -26-3H-26 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) Reference OHss, (usft) Offsetwel]boreCemre iNlS -0-W Kuparuk 3H Pad Centre to Centre No Go Distance Allowffik Warning Devotion (nasi Idsftl (usft) (deft) 31-1-01 - 31-1-01 - 31-1-01 1°I (pen) (deh) f9 local Out of range 3H-02 - 31-1-02 - 311-02 5.97500 5,653.30 5.97500 5,653.30 0.00 000 -177.30 Out of range 31-1-03 - 31-1-03 - 31-1-03 4-114 0.00 007 -0A5 FAIL Major Risk, CC 6.00.00 5.67622 Out of range 3H-04 - 31-1-04 - 3W04 0.12 0.09 -175.95 -1.154.21 -309.36 4114 Out of range 31-1-05 - 311-05 - 3H-05 -0.83 FAIL - Major Risk 6,025.00 5,699.23 6,025.00 5,699.23 0.21 0.17 Out of range 3H-06 - 31-1-06 - 311-06 -309.90 4-1/4 00o 2.36 -1.18 FAIL -Major Risk Out of range 3H-07 - 311-07 - 3H-07 Out of range 31-1-09 - 31-1-09 - 311-09 Out of range 311-10 - 3H-10 - 3H-10 Out of range 31-1-10 - 311-10C - 3H-1 DC Out of range 31-1-10 - 3H-10CL1 - 3H-10CLi Out of range 3H-11 -311-11 -314-11 Out of range 3H -26 -3H -26-3H-26 6,275.00 6,275.00 0.01 9.38 -4.75 FAIL - Major Risk 311-26-311-2611-07-31-1-261-1-01_wp01 7,524.99 7,525.00 0.40 1.24 -0.51 FAIL - Minor 1/10 31-1-26-3H-2611-02-31-1-261-1-02_wp01 7,400.00 7,400.00 0.00 0.29 -0.22 FAIL - Minor 1/10 Offset Design Kuparuk 3H Pad- 3H -26 -3H -26-3H-26 Offsetsfte E. 0.00 usft Survey Program: 121 -MWD Rule Assigned: Major Risk Offset Well Enor. 0.00 usft Reference Oases Sam]hlaj.'Aak, Measured Vertical Depth Depth Measured Depth VeNcal Depth Reference OHss, T Ifac, Aarroh Offsetwel]boreCemre iNlS -0-W Casing- 1hoosce Centre to Centre No Go Distance Allowffik Warning Devotion (nasi Idsftl (usft) (deft) (usft) (--in 1°I (pen) (deh) f9 local (usft) )usft) 5.97500 5,653.30 5.97500 5,653.30 0.00 000 -177.30 -1.144.24 -308.88 4-114 0.00 007 -0A5 FAIL Major Risk, CC 6.00.00 5.67622 6.000.00 5,87822 0.12 0.09 -175.95 -1.154.21 -309.36 4114 0.00 165 -0.83 FAIL - Major Risk 6,025.00 5,699.23 6,025.00 5,699.23 0.21 0.17 -17807 -1,163.97 -309.90 4-1/4 00o 2.36 -1.18 FAIL -Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 5242017 10:53:27AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips Project: Kupamk River Unit Site: Kuparuk311 Pad '^eb u.prno conn: n n/npnelk rue WELLBORE DETAILS: 311-261.1 REFERENCE INROR"TION i r�.. Parent Wellbore: 311-26 Coaabale INO Relnnve: We6K26,Tne NOM Well: 911-26 Wallbore: 311-261.1 seegiNs1. aR Wgle. ores• Tie on MD: 5974.70 va rrvDlRenetie: AensenL-r snw rvsl Refaerce: Bbl-p.wN.cWEt rrroaaleca�rami BAKER Plan: 3H -26L1 wpO2(36-261911.261.1) Northing Easling uaea,m OroW Rereraee: swn(2 ea.auanpnzfit Latitude Longitude 0.00 caoeesen ueuon M. LUN& HIl6HES c Mean E 0 -350 -700 -1050 -1400 c -nso 7 o-zloa w, -2J50 -2800 0 �'-3159 3-3500 ■ -3850 a20a -45501OMEN ■■■■■■■■1/M11®1■i�rii�i' MEMO ■■■■■■�ifi�l�WINN ��//!�■■■OMEN MEMO ON I�■■■■■■■■► ������■■■mom ■� ,i■■■■■■■■��r�■■■mom ��■■■■■®��®���11�■■■■ENE II■■■■■■■■„�I■■■■■■■■, II■■■■��■��/, . ■■■■, _38501 4200i WELL DETAILS: 3H-26 +N/ -S +E/ -W Northing Easling Latitude Longitude 0.00 0.00 6000272.70 498654.81 70° 24'43,124 N 150' 0'39A35 W Sec MD Inc Azi TVDSS +N/ -S +E/ --W Dleg TFace VSecl Annotation 1 5974.70 23.80 182.70 5573.02 -1144.12 -306.86 0.00 0.00 1144.12 TIP 2 6277.00 17.52 187.55 5855.76 -1250.27 -317.72 2.15 167.01 1250.27 KOP 3 6302.00 21.02 187.55 5879.36 -1258.45 -318.80 14.00 0.00 1258.45 End 14 cls, Start 45 dls 4 6455.29 90,00 187.55 5961.01 -1376.27 -334.42 45.00 0.00 1376.27 End 45 cls, Start 7 dls 5 6525.00 90.00 182.67 5961.01 -1445.68 -340.63 7.00 270.00 1445.68 5 6 6700.00 102.06 180.51 5942.66 -1619.32 -345.48 7.00 350.00 1619.32 6 7 6800.00 103.18 173.43 5920.78 -1716.69 -340.34 7.00 280.00 1716.69 7 8 6900.00 103.08 166.24 5898.03 -1812.48 -323.17 7.00 270.00 1812.48 8 9 7175.00 95.96 148.09 5852.18 -2061.00 -218.05 7.00 250.00 2061.00 9 10 7325.00 96.77 137.56 5835.49 -2179.62 -128.12 TDO 275.00 2179.62 10 11 7550.00 96.52 153.41 5809.28 -2363.18 -1.91 7.00 90.00 2363.18 11 12 7975.00 89.29 182.33 5787.28 -2773.55 85.91 7.00 103.00 2773.55 12 13 8450.00 87.22 215.53 5802.17 -3216.38 -65.90 7.00 94.00 3216.36 13 14 8900.00 87.63 164.00 5822.94 -3634.09 -216.01 7.00 270.00 3634.09 Planned TD at 8900.00 c Mean E 0 -350 -700 -1050 -1400 c -nso 7 o-zloa w, -2J50 -2800 0 �'-3159 3-3500 ■ -3850 a20a -45501OMEN ■■■■■■■■1/M11®1■i�rii�i' MEMO ■■■■■■�ifi�l�WINN ��//!�■■■OMEN MEMO ON I�■■■■■■■■► ������■■■mom ■� ,i■■■■■■■■��r�■■■mom ��■■■■■®��®���11�■■■■ENE II■■■■■■■■„�I■■■■■■■■, II■■■■��■��/, . ■■■■, _38501 4200i West( -)/East(+) (350 usft/in) Vertical Section at 180.00° (85 usft/in) ME ;i■■■■■■■■■■■tea■■■■■� ...............��., West( -)/East(+) (350 usft/in) Vertical Section at 180.00° (85 usft/in) ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-26 31-1-261-1-01 Plan: 31-1-261-1-01_wp01 Standard Planning Report 01 June, 2017 ri"Fl- I BAKER HUGHES ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-26 Mean Sea Level 3H-26 @ 80.00usft (31,11-26) 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 AN BAKER HUGHES Site Kuparuk 3H Pad 3H-26 Conor Phillips Database: EDM Alaska NSK Sandbox Company: ConowPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kuparuk 3H Pad Well: 3H-26 Wellborn: 3H-261-1-01 Design: 3H-26L7-01_wp01 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-26 Mean Sea Level 3H-26 @ 80.00usft (31,11-26) 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 AN BAKER HUGHES Site Kuparuk 3H Pad 3H-26 Site Position: Northing: 6,000,110.73 usft Latitude: 70°24'41.531N From: Map Easting: 498,655.44 usft Longitude: 150° 0'39,416 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: -0.01 ° Well 3H-26 Well Position +N/ -S 0.00 usft Northing: 6,000,272.70 usft Latitude: 70° 24'43.124 N Dogleg +E/ -W 0.00 usft Easting: 498,654.81 usft Longitude; 150° 0'39.435 W Position Uncertainty +E/ -W 0.00 usft Wellhead Elevation: usft Ground Level: 0.00usft Wellbore 31-1-261-1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) (1) (nT) BGGM2016 9/1/2017 17.39 80.96 57,536 Design Audit Notes: Version: Vertical Section: 31-1-261-1-01_wp01 Phase: PLAN Tie On Depth: 7,500.00 Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) 11 0.00 0.00 0.00 180.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System -NI-S +E/ -W Rate Rate Rate TFO (usft) (') C) (usft) (usft) (usft) (°1100ft) (°/t00ft) (°/t00ft) (% Target 7,500.00 96.62 149.89 5,815.01 -2,319.47 -25.49 0.00 0.00 0.00 0.00 7,675.00 85.51 155.05 5,811.76 -2,474.34 55.21 7.00 -6.35 2.95 155.00 7,850.00 87.72 167.12 5,822.15 -2,639.30 111.70 7.00 1.26 6.90 80.00 8,000.00 89.57 177.46 5,825.72 -2,787.69 131.77 7.00 1.23 6.89 80.00 8,200.00 93.87 190.80 5,819.70 -2,986.59 117.44 7.00 2.15 6.67 72.00 8,600.00 93.41 218.85 5,793.80 -3,345.25 48.49 7.00 -0.11 7.01 90.00 8,900.00 93.19 197.82 5,776.34 -3,607.39 -189.83 7.00 -0.08 -7.01 270.00 611/2017 3:57:55PM Page 2 COMPASS 5000.1 Build 74 I I ConocoPhillips ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 31-1-26 Company: ConowPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-26 @ 80.00usft (31-1-26) Site: Kupamk 3H Pad North Reference: True Well: 3H-26 Survey Calculation Method: Minimum Curvature Wellbore: 31-1-261-1-01 Depth Inclination Design: 3H-261-1-01_wp01 +NIS +E/ -W Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NIS +E/ -W Section Rate Azimuth Northing Easting (usft) (1) (e) (usft) (usft) (usft) (usft) (-1100ft) V) (usft) (usft) 7,500.00 96.62 149.89 5,815.01 -2,31947 -25.49 2,319.47 0.00 0.00 5,997,953.47 498,628.90 TIP/KOP 7,600.00 90.27 152.85 5,809.00 -2,497.03 22.30 2,407.03 7.00 155.00 5,997,865.90 498,676.68 7,675.00 85.51 155.05 5,811.76 -2,474.34 55.21 2,474.34 7.00 155.18 5,997,798.59 498,709.57 Start 7 dis 7,700.00 85.81 156.78 5,813.66 -2,497.10 65.38 2,497.10 7.00 80.00 5,997,775.84 498,719.73 7,800.00 87.07 163.68 5,819.87 -2,590.97 99.11 2,590.97 7.00 79.87 5,997,681.97 498,753.44 7,850.00 87.72 167.12 5,822.15 -2,639.30 111.70 2,639.30 7.00 79.44 5,997,633.65 498,766.02 3 7,900.00 88.33 170.57 5,823.88 -2,688.31 121.36 2,688.31 7.00 80.00 5,997,584.63 498,775.67 8,000.00 89.57 177.46 5,825.72 -2,787.69 131.77 2,787.69 7.00 79.88 5,997,485.26 498,786.07 4 8,100.00 91.73 184.12 5,824.58 -2,887.61 130.39 2,BB7.61 7.00 72.00 5,997,385.35 498,784.67 8,200.00 93.87 190.80 5,819.70 -2,986.59 117.44 2,986.59 7.00 72.08 5,997,286.39 498,771.70 5 8,300.00 93.84 197.81 5,812.98 -3,083.21 92.80 3,083.21 7.00 9000 5,997,189.78 498,747.05 8,400.00 93.75 204.83 5,806.35 -3,176.10 56.54 3,176.10 7.00 90.47 5,997,096.90 498,710.78 8,500.00 93.61 211.84 5,799.93 -3,263.89 9.21 3,263.89 7.00 90.94 5,997,009.14 498,663.43 8,600.00 93.41 218.85 5,793.80 -3,345.25 48.49 3,345.25 7.00 91.39 5,996,927.79 498,605.72 6 8,700.00 93.39 211.84 5,787.86 -3,426.62 -106.20 3,426.62 7.00 -90.00 5,996,846.44 498,548.00 8,800.00 93.31 204.83 5,782.01 -3,514.44 -153.55 3,514.44 7.00 -90.42 5,996,758.64 498,500.64 8,900.00 93.19 197.82 5,776.34 -3,607.39 -189.83 3,607.39 7.00 -90.83 5,996,665.71 498,464.35 Planned TD at 8900.00 6112017 3:57:55PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips IeAUsI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project Kuparuk River Unit Site: Kuparuk 3H Pad Well: 31-1-26 Wellbore: 3H-2611-01 Design: 3H-261.1-01_wp01 Targets Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-26 Mean Sea Level 31-1-26 @ 80.00usft (3H-26) True Minimum Curvature Target Name -hitimiss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting -Shape V) (") (usft) (usft) (usft) (usft) (usft) 31-1-26 CTD Polygon SOL 0.00 0.00 0.00 -1,126.551,139,681.38 5,998,941.00 - plan misses target center by 1139565.71 usft at 8000.00usft MD (5825.72 TVD, -2787.69 N, 131.77 E) - Polygon Depth Depth Point 0.00 0.00 0.00 5,998,941.00 Point 0.00 -813.08 -6.81 5,998,128.00 Point 0.00 -1,278.06 277.32 5,997,863.02 Point 0.00 -1,674.08 396.43 5,997,267.02 Point 0.00 -3,028.34 -145.31 5,995,912.99 Point6 0.00 -3,146.27 201.75 5,995,795.01 Point 0.00 -1,813.00 764.50 5,997,128.04 Point 0.00 -1,353.98 687.38 5,997,587.03 Point 0.00 -785.00 340.22 5,998,156.02 Point 10 0.00 14.07 291.03 5,998,955.02 Point 11 0.00 0.00 0.00 5,998,941.00 3H-2611-07_ 702 0 .00 0.00 5,776.00 -3,650.751,139,955.86 5,996,417.00 - plan misses target center by 1139824.42usft at SDO0.00usft MD (5825.72 TVD, -2787.69 N, 131.77 E) - Point 311-261-1-01T01 0.00 0.00 5,825.00 -2,808.611,140,275.74 5,997,259.00 - plan misses target center by 1140143.97usft at 8000.00usft MD (5825.72 TVD, -2787.69 N, 131.77 E) - Point 3H-26 CTD Polygon Nor 0.00 0.00 0.00 -2,008.561,140,063.57 5,998,059.00 - plan misses target center by 1139946.96usft at 8000.00usft MD (5825.72 TVD, -2787.69 N, 131.77 E) - Polygon Depth Depth -NAS Point 1 0.00 0.00 0.00 5,998,059.00 Point 0.00 -173.96 236.06 5,997,885.01 Point 0.00 2,007.38 769.61 6,000,066.04 Point4 0.00 1,944.45 1,096.66 6,000,003.06 Point 0.00 -367.90 597.14 5,997,691.03 Point 0.00 -617.99 312.17 5,997,441.02 Point 0.00 -424.07 -138.92 5,997,635.00 Point 0.00 -174.07 -242.98 5,997,884.99 Point 0.00 0.00 0.00 5,998,059.00 1,638,222.00 1,638,222.00 1,638,215.04 1,638,499.06 1,638,618.09 1,638,076.16 1,638,423.16 1,638,986.10 1,638,909.07 1,638,562.04 1,638,513.00 1,638,222.00 1,638,496.00 1,638,816.00 1,638,604.00 1,638,604.00 1,638,840.01 1,639,373.89 1,639,700.90 1,639,201.01 1,638,916.03 1,638,465.02 1,638,361.01 1,638,604.00 Latitude Longitude 70° 10'22.971 N 140" 48'2B.517 W 70'9'58.058 N 140" 48'31.668 W 70" 10'5.761 N 140" 48' 70° 10' 13.842 N 140° 48'21 .431 W Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 8,900.00 5,776.34 23/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth -NAS +E/ -W (usft) (usft) (usft) (usft) Comment 7,500.00 5,815.01 -2,319.47 -25.49 TIP/KOP 7,675.00 5,811.76 -2,474.34 55.21 Start7 dls 7,850.00 5,822.15 -2,639.30 111.70 3 8,000.00 5,825.72 -2,787.69 131.77 4 8,200.00 5,819.70 -2,986.59 117.44 5 8,600.00 5,793.80 -3,345.25 -48.49 6 8,900.00 5,776.34 -3,607.39 -189.83 Planned TD at 8900.00 6/1/2017 3:57'55PM Page 4 COMPASS 5000.1 Build 74 I Baker Hughes INTEQ MINConocoPhiilips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 3H-26 Project: Kupamk River Unit TVD Reference: 3H-26 @ 80.00usft (3H-26) Reference Site: Kuparuk 3H Pad MD Reference: 311-26 @ 80.00usft (311-26) Site Error: 0.00 usft North Reference: True Reference Well: 311-26 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 3H-261.7-01 Database: OAKEDMP2 Reference Design: 311-2611-01_wp01 Offset TVD Reference: Offset Datum Reference 311-261-1-01 wp01 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference To Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,500.00 to 8,900.00usft Scan Method: Trev. Cylinder North Results Limited by: Maximum center -center distance of 1,082.00 usft Error Surface: Elliptical Conic Survey Tool Program Date 5/24/2017 Measured From To Depth Depth (usft) (usft) Survey (Wellbore) Tool Name Description 121.00 5,974.70 311-26(3H-26) MWD MWD - Standard 5,974.70 7,500.00 3H-261_1 wp02(3H-26L7) MWD MWD -Standard 7,500.00 8,900.00 3H-26L1-01_wp01 (3H -26L1-01) MWD MWD - Standard Casing Points Kuparuk 3H Pad- 3H -26 -311 -2617 -3H -26L1 wp02 Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 121.00 121.00 16" 16 26 3,142.60 3,140.36 7 5/8" 7-5/8 9-7/8 8,900.00 5,856.34 2 3/8" 2-3/8 3 Summary Kuparuk 3H Pad- 3H -26 -311 -2617 -3H -26L1 wp02 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore- Design (usft) (usft) (usft) (usft) Measured Kupamk 3H Pad Measored Vertical Reererue Offset Toolface+ 3H-01 - 3H-01 - 3H-01 call,- Centre to No Go Allowable Out of range 3H-02 - 3H-02 - 311-02 Depth Depth Out of range 3H-03 - 3H-03 - 3H-03 +E/.W Was $&a Carers Malars Out of range 311-04 - 311-04 - 311-04 lush) ("aft) (rant tum) Out of range 3H-05 - 311-05 - 311-05 (ren) ("an) f'1 teaft) Out of range 311-09 - 311-09 - 311-09 ).50000 5,09501 7,500.00 5,895.01 Out of range 311-26-311-2611-3H-26L1_wp02 7,524.99 7,525.00 0.40 1.25 -0.48 FAIL - Minor 1/10 3H-26-311-261-1-02-311-2617-02_wp01 7,518.19 7,525.00 33.54 1.34 33.25 Pass - Minor 1/10 Offset Design Kuparuk 3H Pad- 3H -26 -311 -2617 -3H -26L1 wp02 osaetsdaisror. 0.00 pat' survey Program: 121 -MM, 5975 -MWD Rule Asslgne4: Minor too Offset Well Error. 0.00 use' Peters.. Offset semi Major Axis Measured vesical Measored Vertical Reererue Offset Toolface+ Oaset Weutionecohe call,- Centre to No Go Allowable Depth Depth Depth Depth Azimuth .ryes +E/.W Was $&a Carers Malars Wareng oeven.. lawn) lush) ("aft) (rant tum) (usft) (9 (ren) ("an) f'1 teaft) loan) loan) ).50000 5,09501 7,500.00 5,895.01 0.00 GW 149.89 -2,319.47 -25.49 2-11/16 0.00 029 -0,22 FAIL. Minor 1/10, CC 7,524.99 5092.47 7,525.00 5,892.13 0.49 003 -176.06 -2,341.14 -13.37 241/16 0.40 1.25 -0.48 FAIL - Minor 1/10, ES, 6F 7,549.95 5.090.62 7.55000 5,889.20 0.97 1.27 -175.23 .2,363.18 -1.91 2-11116 1.01 1.37 039 Pass - Minor 1110 7,574.03 5,889.47 7,575.00 5.886.53 1,40 1.76 -17387 -2.385.56 8.88 2-11116 3.55 1.38 2.24 Pass - Mina, 1110 7,59962 5,889.00 7.600.00 5,863.95 1.83 2.25 -172.36 -2,400.27 10.99 2-11115 6.15 1.30 5.13 Paas � Minor 1110 7,62429 5,88921 7,825.00 5,881.55 2.23 2.67 -170.97 -2,43130 28.44 2-11/16 9.41 1.37 9.19 Pass - ether 1/10 7.648.01 5,690.09 7.850.00 5,879.32 2.62 3.09 -169.70 -2,454.00 3720 2-11/16 13.33 1.32 13.10 Pass - Miner 1110 7,673.17 5,891.62 7167500 5,87728 2.99 3.45 -168.53 -2,478.18 45M 2-11116 1789 1.35 17.67 Pass - Minor 1110 CC - Min centre to Center distance or covergent point, SF - min separation factor, ES - min ellipse separation 5242017 11:03.24AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips Project: KUParuk River Unit Site: Kuparuk 3H Pad Wall: 3H-26 wrawm m Tm Nans Mapnele xmn: nes• MsrrM�=a.N WELLBORE DETAILS: 3H-261-1-01 NEFENENDE INFONMAnON a� WE as Parent Wellbore: 3H -26L1 coaNrek(iWa Ranee.. Wal 3H-25, Toe Norm Wellbore: 3H-2611-01 se.,em.5ieseaml Isaft. t� Te on MD: ]500.00 Ve i.IMo)Nalearm: Mean see level SeN,n(JS)Fak. SM-Ionox,O.WE) BAKER Plan: 3H-261-1-01 wp01(3H-2613X-2611.01) Me eer eeenaots Easting Meennatl Deem Refeence 3635®WWwtlPMG) Latitude Longitude 0.00 0.00 madHY6HEs 6000272.70 Mean West( -)/East(+) (350 usft/in) W 5355 WELL DETAILS: 3H-26 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 6000272.70 498654.81 70' 24'43.124 N 150° 0'39.435 W Sec MD Inc Azi TVDSS +NI -S +E/ -W Dleg TFace VSect Annotation 1 7500.00 96.62 149.89 5815.01 -2319.47 -25.49 0.00 0.00 2319,47 TIP/KOP 2 7675.00 85.51 155.05 5811.76 -2474,34 55.21 7.00 155.00 2474.34 Start 7 dls 3 7850.00 87.72 167.12 5822.15 -2639.30 111.70 7.00 80.00 2639.30 3 4 8000.00 89.57 177.46 5825.72 -2787.69 131.77 7.00 80.00 2787.69 4 5 8200.00 93,87 190.80 5819,70 -2986.59 117.44 7.00 72.00 2986.59 5 6 8600.00 93.41 218.85 5793.80 -3345.25 -48.49 7.00 90.00 3345.25 6 7 8900.00 93.19 197.82 5776.34 -3607.39 -189.83 7.00 270.00 3607.39 Planned TD at 8900.00 Mean West( -)/East(+) (350 usft/in) W 5355 5440 ~_I 5535 .l 5610 5695P m Innel T, at 8 40.0) 3H- 314-26 1-mJH-2 /3H-2 LI -01 5790 865 TIP OP Stan &3 5 6 5950 3H-2 314- Ll 6035 6120 6205 H-26/ H-2fi eeILei '" o .. o „r o u o � o „ o u o .•. .,� $ ,,, o N o .,. o u o .,, 'o ,,. a ,.. Vertical Section at 180.000 (85 usft/in) 1 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-26 311-261-1-02 Plan: 3 H-261-1-02_wp01 Standard Planning Report 01 June, 2017 'Ails BAKER HUGHES ConocoPhillips .E.. ConocoPhiilips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConomPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kupamk 3H Pad Well: 31-1-26 Wellbore: 311-2611-02 Design: 31-1-281-1-132_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-26 Mean Sea Level 31-1-26 @ 80.O0usft (31-11-26) 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 Weil Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor site Kuparuk 3H Pad Site Position: Northing: 6,000,110.73 usft Latitude: 70'24'41.531N From: Map Easing: 498,655.44 usft Longitude: 150° 0'39.416 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.01 ` Well 3H-26 Well Position +N/S 0.00 usft Northing: 6,000,272.70 usft Latitude: 70" 24'43.124 N +E/ -W 0.00 usft Easting: 498,654.81 usft Longitude: 150° 0'39.435 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 31-1-261-1-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 0 P) K) BGGM2016 9/1/2017 17.39 80.96 57,536 Design 31-1-261-1-02_w1301 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,400.00 Vertical Section: Depth From (TVD) +N/ -S +Ef-W Direction (usft) (usft) (usft) (I 0.00 0.00 0.00 0.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (`) (1) (usft) (usft) (usft) (-1100ft) ("1100ft) (°1100ft) V) Target 7,400.00 96.75 142.85 5,826.66 -2,236.82 -80.46 0.00 om 0.00 0.00 7,470.00 82.38 132.83 5,827.19 -2,288.51 -33.66 25.00 -20.52 -14.32 215.00 7,540.00 94.84 120.50 5,828.89 -2,330.12 22.27 25.00 17.79 -17.60 315.00 7,800.00 92.04 55.43 5,811.39 -2,321.17 267.76 25.00 -1.07 -25.03 270.00 7,900.00 91.85 30.41 5,807.93 -2,248.56 335.28 25.00 -0.19 -25.01 270.00 8,050.00 91.82 19.91 5,803.12 -2,113.05 398.92 7.00 -0.02 -7.00 270.00 8,250.00 87.94 9.96 5,814.02 -1,920.59 450.33 7.00 -4.94 -4.97 225.00 8,375.00 82.04 1.12 5,831.47 -1,797.51 462.27 7.00 0.08 -7.07 270.00 8,750.00 90.64 26.00 5,855.79 -1,437.01 549.62 7.00 2.29 6.63 72.00 9,125.00 91.01 359.75 5,850.30 -1,074.67 632.44 7.00 0.10 -7.00 271.00 9,375-00 91.27 17.25 5,845.29 -828.42 669.23 7.00 0.10 7.00 89.00 9,725.00 91.15 352.74 5,837.78 -482.49 699.48 7.00 -0.03 -7.00 270.00 61112017 3.58:35PM Page 2 COMPASS 5000.1 Build 74 r ConocoPhillips MCA aI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 3H-26 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 31-1-26 @ 80.00usft (31-1-26) Site: Kuparuk 3H Pad North Reference: True Well: 3H-26 Survey Calculation Method: Minimum Curvature Wellborn: 31-1-261-1-02 / Depth Inclination Azimuth Design: 3H-261-1-02_wp01 +E/ -W Section Planned Survey _ Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°AOOft) (°) (usft) (usft) 7,400.00 96.75 142.85 5,826.66 -2,236.82 -80.46 -2,236.82 0.00 0.00 5,998,036.11 498,573.95 TIP/KOP 7,470.00 82.38 132.83 5,827.19 -2,288.51 -33.66 -2,288.51 25.00 -145.00 5,997,984.42 498,620.74 Start 26 the 7,500.00 87.71 127.53 5,829.78 -2,307.77 -10.84 -2,307.77 25.00 -45.00 5,997,965.16 498,643.56 7,540.00 94.84 120.50 5,828.89 -2,330.12 22.27 -2,330.12 25.00 44.54 5,997,942.81 498,676.65 3 7,600.00 94.67 105.45 5,823.89 -2,353.39 77.16 -2,353.39 25.00 -90.00 5,997,919.53 498,731.53 7,700.00 93.70 80.40 5,816.48 -2,358.43 175.96 -2,358.43 25.00 -91.25 5,997,914.47 498,830.33 7,800.00 92.04 55.43 5,811.39 -2,321.17 267.76 -2,321.17 25.00 -93.11 5,997,951.72 498,922.13 4 7,900.00 91.85 30.41 5,807.93 -2,248.56 335.28 -2,248.56 25.00 -90.00 5,998,024.31 498,989.65 End 26 dls, Start 7 dls 8,000.00 91.64 23.41 5,804.71 -2,159.49 380.48 -2,159.49 7.00 -90.00 5,998,113.36 499,034.87 8,050.00 91.82 19.91 5,803.12 -2,113.05 398.92 -2,113.05 7.00 -90.23 5,998,159.79 499,053.31 6 8,100.00 89.34 17.43 5,802.61 -2,065.69 414.93 -2,065.69 7.00 -135.00 5,998,207.14 499,069.32 8,200.00 84.40 12.47 5,808.07 -1,969.28 440.68 -1,969.28 7.00 -135.03 5,998,303.54 499,095.09 8,250.00 81.94 9.96 5,814.02 -1,920.59 450.33 -1,920.59 7.00 -134.75 5,998,352.22 499,104.75 7 8,300.00 81.96 6.42 5,821.02 -1,871.60 457.38 -1,871.60 7.00 -90.00 5,998,401.21 499,111.81 8,375.00 82.04 1.12 5,831.47 -1,797.51 462.27 -1,797.51 7.00 -89.50 5,998,475.28 499,116.71 8 8,400.00 82.58 2.80 5,834.82 -1,772.75 463.12 -1,772.75 7.00 72.00 5,998,500.04 499,117.56 8,500.00 84.81 9.47 5,845.80 -1,673.99 473.75 -1,673.99 7.00 71.78 5,998,598.79 499,128.21 8,600.00 87.12 16.10 5,852.85 -1,576.78 495.82 -1,576.78 7.00 71.04 5,998,695.99 499,150.30 8,700.00 89.46 22.70 5,855.83 -1,482.56 529.01 -1,482.56 7.00 70.57 5,998,790.19 499,183.50 8,750.00 90.64 26.00 5,855.79 -1,437.01 549.62 -1,437.01 7.00 70.38 5,998,835.73 499,204.12 9 8,800.00 90.70 22.50 5,855.21 -1,391.44 570.15 -1,391.44 7.00 -89.00 5,998,881.30 499,224.65 8,900.00 90.81 15.50 5,853.90 -1,296.95 602.68 -1,296.95 7.00 -89.04 5,998,975.77 499,257.20 9,000.00 90.91 8.50 5,852.40 -1,199.21 623.46 -1,199.21 7.00 -89.13 5,999,073.50 499,277.99 9,100.00 90.99 1.50 5,850.74 -1,099.66 632.16 -1,099.66 7.00 -89.24 5,999,173.03 499,286.71 9,125.00 91.01 359.75 5,850.30 -1,074.67 632.44 -1,074.67 7.00 -89.35 5,999,198.02 499,286.99 10 9,200.00 91.10 5.00 5,848.92 -999.77 635.54 -999.77 7.00 69.00 5,999,272.91 499,290.11 9,300.00 91.20 12.00 5,846.90 -900.95 650.31 -900.95 7.00 89.10 5,999,371.72 499,304.89 9,375.00 91.27 17.25 5,845.29 -828.42 669.23 -828.42 7.00 89.24 5,999,444.24 499,323.83 11 9,400.00 91.27 15.50 5,844.73 -804.45 676.28 -804.45 7.00 -90.00 5,999,468.21 499,330.88 9,500.00 91.25 8.50 5,642.54 -706.71 697.05 -706.71 7.00 -90.04 5,999,565.93 499,351.66 9,600.00 91.22 1.50 5,840.38 -607.18 705.75 -607.18 7.00 -90.19 5,999,665.45 499,360.38 9,700.00 91.17 354.49 5,838.29 -507.32 702.26 -507.32 7.00 -90.34 5,999,765.30 499,356.91 9,725.00 91.15 352.74 5,837.78 -482.49 699.48 -482.49 7.00 -90.49 5,999,790.14 499,354.13 Planned TD at 9726.00 6/12017 3.58:35PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project Kuparuk River Unit Site: Kupamk 3H Pad Well: 31-1-26 Wellbore: 3H -26L1-02 Design: 31-1-2611-02_vvp01 Targets ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-26 Mean Sea Level 31-1-26 @ 80.00usft(31-1-26) True Minimum Curvature Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting -Shape V) (_) (usft) (usft) (usft) (usft) (usft) 3H-26 CTD Polygon SOL 0.00 0.00 0.00 -1,126.551,139,681.38 5,998,941.00 1,638,222.00 - plan misses target center by 1138990.72usft at 9600.00usft MD (5840.38 TVD, -607.18 N, 705.75 E) Hole Polygon Depth Point 1 0.00 0.00 0.00 Point 1 0.00 0.00 0.00 5,998,941.00 1,638,222.00 Point 0.00 -813.08 -6.81 5,998,128.00 1,638,215.04 Point 0.00 -1,278.06 277.32 5,997,663.02 1,638,499.06 Point4 0.00 -1,674.08 396.43 5,997,267.02 1,638,618.09 Points 0.00 -3,028.34 -145.31 5,995,912.99 1,638,076.16 Point 0.00 -3,146.27 201.75 5,995,795.01 1,638,423.16 Point 0.00 -1,813.00 764.50 5,997,128.04 1,638,986.10 Point 0.00 -1,353.98 687.38 5,997,587.03 1,638,909.07 Point 0.00 -785.00 340.22 5,998,15602 1,638,562.04 Point 10 0.00 14.07 291.03 5,998,955.02 1,638,513.00 Point 11 0.00 0.00 0.00 5,998,941.00 1,638,222.00 3H -2611-02_T01 0.00 0.00 5,803.00 -2,106.491,140,560.64 5,997,959.00 1,639,101.00 - plan misses target center by 1139855.88usft at 9600.00usft MD (5840.38 TVD, -607:18 N, 705.75 E) - Point 3H -261-7-02_T02 0.00 0.00 5,856.00 -1,535.411,140,671.55 5,998,532.00 1,639,212.00 - plan misses target center by 1139966.18usft at 9600.00usft MD (5640.38 TVD, -607.18 N, 705.75 E) - Point UGrI BAKER HUGHES Latitude Longitude 70' 10'22.971 N 140° 48'28.517 W 70° 10' 12.136 N 140° 48'7.652 W 70° 10'17.536 N 140° 48' 1.981 31H -2611-02T03 0.00 0.00 5,638.00 -526.281,140,845.39 5,999,541.00 1,639,386.00 70° 10'2T075 N 140° 47'52.606 W - plan misses target center by 1140139.64usft at 9600.00usft MD (5840.38 TVD, -607.18 N, 705.75 E) - Point 3H-26 CTD Polygon Nor 0.00 0.00 0.00 -2,008.561,140,063.57 5,998,059.00 - plan misses target center by 1139373.65usft at 9600.00usft MD (5640.38 TVD, -607.18 N, 705.75 E) - Polygon Casing Hole Depth Depth Point 1 0.00 0.00 0.00 5,998,059.00 Point 0.00 -173.96 236.06 5,997,885.01 Point 0.00 2,007.38 769.61 6,000,066.04 Point 0.00 1,944.45 1,096.66 6,000,003.06 Points 0.00 -367.90 597.14 5,997,691.03 Point 0.00 -617.99 312.17 5,997,441.02 Point 0.00 -424.07 -138.92 5,997,635.00 Point 0.00 -174.07 -242.98 5,997,884.99 Point 0.00 0.00 0.00 5,998,059.00 1,638,604.00 70° 10' 13.842 N 140° 48'21.431 W 1,638,604.00 1,638,840.01 1,639,373.89 1,639,700.90 1,639,201.01 1,638,916.03 1,638,465.02 1,638,361.01 1,638,604.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,725.00 5,837.78 23/8" 2.375 3.000 6/12017 3:58:35PM Page 4 COMPASS 5000.1 Build 74 Plan Annotations ConocoPhillips FORM ConocoPhillips Measured Vertical Local Coordinates Planning Report Depth BAKER +E/ -W (usft) HUGHES Database: EDM Alaska NSK Sandbox Local Cc -ordinate Reference: Well 31-1-26 7,400.00 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level TIP/KOP Project: Kupamk River Unit MD Reference: 311-26 aQ 80.00usft (3H-26) -33.66 Site: Kupamk 31A Pad North Reference: True -2,330.12 Well: 31-1-26 Survey Calculation Method: Minimum Curvature 5,811.39 Wellbore: 3H -26L1-02 267.76 4 7,900.00 Design: 311-26L1-02_wp01 -2,248.56 335.28 End 25 cls, Start 7 dls Plan Annotations Measured Vertical Local Coordinates Depth Depth -NIS +E/ -W (usft) (usft) (usft) (usft) Comment 7,400.00 5,826.66 -2,238.82 -80.46 TIP/KOP 7,470.00 5,827.19 -2,288.51 -33.66 Start 25 dls 7,540.00 5,828.89 -2,330.12 22.27 3 7,800.00 5,811.39 -2,321.17 267.76 4 7,900.00 5,807.93 -2,248.56 335.28 End 25 cls, Start 7 dls 8,050.00 5,603.12 -2,113.05 398.92 6 8,250.00 5,814.02 -1,920.59 450.33 7 8,375.00 5,831.47 -1,797.51 462.27 8 8,750.00 5,855.79 -1,437.01 549.62 9 9,125.00 5,850.30 -1,074.67 632.44 10 9,375.00 5,845.29 -828.42 669.23 11 9,725.00 5,837.78 -482.49 699.48 Planned TD at 9725.00 6112017 3..58:35PM Page 5 COMPASS 5000.1 Build 74 >,. Baker Hughes INTEQ ��R. ConocoPllillips Travelling Cylinder Report BAKER HUGHES Company: ConomPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 3H Pad Site Error: 0.00 usft Reference Well: 3H-26 Well Error: 0.00 usft Reference Wellbore 31-1-2611-02 Reference Design: 3H-26L7-02_wp01 Local Co-ordinate Reference: Well 31-1-26 TVD Reference: 3H-26 @ 80.00usft (311-26) MD Reference: 3H-26 (03 80.00usft (31-1-26) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: OAKEDMP2 Offset TVD Reference: Offset Datum Reference 31-4-261-1-02_wp01 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,400.00 to 9,725.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,164.50 usft Error Surface: Elliptical Conic Survey Toot Program Date 5/24/2017 From To Vertical (usft) (usft) Survey (Wellbore) Tool Name Description 121.00 5,974.7031-1-26(31-1-26) MWD MWD - Standard 5,974.70 7,400.003H-26L1_wp02(3H-26L1) MWD MWD - Standard 7,400.00 9,725.00 3H-26L1-02wp01 (31-1-2611-02) MWD MWD -Standard Casing Points Kuparuk 3H Pad Measured Vertical Casing Hole Depth Depth Allowable Diameter Diameter (nett) (usft) Name Distance Deviation 121.00 121.00 16" 16 26 3,142.80 3,140.36 75/8" 7-5/8 9-7/8 9,725.00 5,917.78 23/8" 2-3/e 3 Summary Kuparuk 3H Pad Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance Neff) from Plan Offset Well - Wellborn - Design inert) (usft) (usft) (usft) Kuparuk 3H Pad 3H-01 - 31-1-01 - 31-1-01 Measured Vertical Reference Offset Teolha+ Mast Wellbore Out of range 3H-02 - 3H-02 - 3H-02 Desire to Na Go Allowable Depth Depth Depth Out of range 3H-03 - 31-1-03 - 3H-03 Azimuth +1,1/4 +U -w No%Size Out of range 31-4-04 - 31-1-04 - 311-04 Wmreng Oeriell. (-aft) (daffl (usft) (rift) (usft) Out of range 3H-05 - 31-1-05 - 31-1-05 Iuanl (.it) f'1 Ineft) (nen) Out of range 31-1-07 - 31-1-07 - 31-1-07 7,20000 8.27367 2761 3586 12929 Out of range 3H -09 -3H -09-3H-09 8,067.07 6,675.00 1,050.35 180.20 871.62 Pass - Major Risk 3H-10 - 3H -10C - 3H-1 OC 27.61 35.83 128.14 .2.458.18 1,43645 Out of range 3H-10 - 3H-tOCL1 - 3H-10CL1 181.39 979.93 Pass - Major Risk 8,060.56 5,882.83 7,150.00 6,223.88 Out of range 3H -26 -3H -26-3H-26 8,650.00 6,325.00 873.25 63.59 809.80 Pass - Major Risk 3H-26-31-1-2611-3H-26L7_wp02 7,400.00 7,400.00 0.00 0.29 -0.22 FAIL - Minor 1/10 3H-26-3H-26L1-01-3H-261.1-01_wp01 7,400.00 7,400.00 0.00 0.29 -0.22 FAIL - Minor t/10 Offset Design Kuparuk 3H Pad -3H -09 -3H -09-3H-09 offsetsae Emm: 0.09 Usti Survey Program: 100.90s6 -GYRO Rule Assigned: Major Risk ONZN Waq FJran 0.00 use RNemnce 011se1 Semi MajorAzis Measured Vernon Measured Vertical Reference Offset Teolha+ Mast Wellbore Centre casing- Desire to Na Go Allowable Depth Depth Depth Depth Azimuth +1,1/4 +U -w No%Size Centre DISMr1ce Wmreng Oeriell. (-aft) (daffl (usft) (rift) (usft) (.it) r) Iuanl (.it) f'1 Ineft) (nen) (nen) 8059.55 588285 7,20000 8.27367 2761 3586 12929 2,459.12 1,436.37 211/15 1.16258 18143 990.89 Pan -Major Risk 8,060.06 5882.84 7,175.00 8.24837 27.61 35.83 128.14 .2.458.18 1,43645 2-11/16 1.15235 181.39 979.93 Pass - Major Risk 8,060.56 5,882.83 7,150.00 6,223.88 27.60 35.79 126.98 -2457.24 1,432.52 2-11/16 1,142.53 181.32 969.46 Pass - Major Risk affilD3 5,882.82 7.125.00 6,198.95 27.60 35.75 125.77 2.456.31 1,430.58 2.11/16 1,133.24 181.27 959.47 Pass -Major Risk 0061.48 5,882.81 7,100.00 6.174.05 27.59 3572 124.68 -2,45541 1,428.60 2-11/16 1,124.37 181.21 949.%Pam -Major Risk CC - Min centre to center distance or mvergent point, SF - min separation factor, ES - min ellipse separation 5242017 11:09:44AM Page 2 COMPASS 5000.1 Build 74 Project. Nuparuk River Unit Site: Hupamk 3H Pad Well: 3H-26 Wellbore: 3H -26L1-02 Plan: 3H-261.1.02 wP01 (3H -2613H-2611-02) I Mean S C_ ACE INFOWOVR ad"..II<m nYa xoom Mpre"o NnIF 1].3Y M.a"MK rlda WELLBORE DETAILS: 311-261.1-02 Parent Wellbore: 3H -26L1 WELL SLina'" n33a>" Te on MD: 7400.00 HUGHES oM.. nvmn MoaeI: BGGIROt +E/ -W I Mean S C_ ACE INFOWOVR E)RO E) Rele.: Wer3N-]6, T Noem ,T FA.. WELL DETAILS: 9. MW:3xa6023000mnpx261 Nlen NZIFW: A4rvmYm Curvalue HUGHES 3H-26 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 5525 6000272.70 498654.81 70° 24'43.124 N 150° 0'39.435 W Sec MD Inc Azi TOSS +N/ -S +E/ -W Dleg TFace VSect Annotation 1 7400.00 96.75 142.85 5826.66 -2236.82 -80.46 0.00 0.00 -2236.82 TIP/KOP 2 7470.00 82.38 132.83 5827.19 -2288.51 -33.66 25.00 215.00 -2288.51 Start 25 dls 3 7540.00 94.84 120.50 5828.89 -2330.12 22.27 25.00 315,00 -2330.12 3 4 7800.00 92.04 55.43 5811.39 -2321.17 267.76 25.00 270.00 -2321.17 4 5 7900.00 91.85 30.41 5807.93 -2248.56 335.28 25.00 270.00 -2248.56 End 25 d1s, Start 7 cls 6 8050.00 91.82 19.91 5803.12 -2113.05 398.92 7.00 270.00 -2113.05 6 7 8250.00 81.94 9.96 5814.02 -1920.59 450.33 7.00 225.00 -1920.59 7 8 8375.00 82.04 1.12 5831.47 -1797.51 462.27 7.00 270.00 -1797.51 8 9 8750.00 90.64 26.00 5855.79 -1437.01 549.62 7.00 72.00 -1437.01 ■■■■■■ 9 10 9125.00 91.01 359.75 5850.30 -1074.67 632.44 7.00 271.00 -1074.67 10 11 9375.00 91.27 17.25 5845.29 -828.42 669.23 7.00 89.00 -828.42 11 12 9725.00 91.15 352.74 5837.78 482.49 699.48 7.00 270.00 -482.49 Planned TD at 9725.00 I Mean S C_ ACE INFOWOVR E)RO E) Rele.: Wer3N-]6, T Noem ,T FA.. d n)Fbf.m, a: Sbf-A LaH 6)Relmence: Sbl-IemN,6ro0 BAKER 9. MW:3xa6023000mnpx261 Nlen NZIFW: A4rvmYm Curvalue HUGHES West( -)/East(+) (350 usfr/in) 5440 - 5525 4 0 5610 695 H-26/ 11-26 1 End 2 dls. S1 at] dl n n 3 `2613 -26L1 DI q 6 .fel■■■■■■■fly �■����■■■■ 8 ■� ■■■■■■ wli�®■■■■■■� g ■■■■■■■111 X10 Ignn. ■■ ON 5865 ■■■■ ■®.�■®■■■■� 5950 P/KO 10 11 ■■■■■■■�\lh�l!■■■■■■ SV 125 d1 5035 ■■■■■■■■%://■■■■■■MEN 5120 " 5205 I I ■■■■■■■I/ f�■■m■■■■Sol J", - 3H6/3 H- 6 ea ■■■■■■■LFII ■■■■■■■■■M 05 z West( -)/East(+) (350 usfr/in) 5440 - 5525 4 0 5610 695 H-26/ 11-26 1 End 2 dls. S1 at] dl n n 3 `2613 -26L1 DI q 6 8 g Ignn. 3Da19725. 5865 5950 P/KO 10 11 SV 125 d1 5035 5120 5205 I J", - 3H6/3 H- 6 ea 05 z Vertical Section at 0.001 (85 usft/in) 1 ConocoPhillips Project: Kuparuk River Unit Site: Kuparuk 3H Pad aimum u rm. xum _,e TN' v.as• M,euu<Biga WELLBORE DETAILS: 3H-281-1 REFERENOEINF6RManox Parent Wellbore: 3H-26 ooarNnA IN�E)Rawme: WM13+26, True Nmb Well: 3X-28 sn.rern 5I536.bn TI on MD: 5974.70 Ve:lill, 1N Relceree: 3+26@O.XWA(3H 2M Wellbore: 3H-261-1 .0_ eose section l.7 Rek.. 9q-(O.WN, 0.00E) Plan: 3W26L7 vp02(3H-2613H-26L1) Moe.�eooMmiT MrmuetlD th W...: 3+26®e0.01urX l3+267 C,kWalion MAA: Mmimum G.W. West( -)/East(+) (200 usft/in) 3H-26 @ 80.00usR (3H-26) ri.2 RAKER HUGHES KUP PROD 3H-26 v: = --- Lonocopnimps ON Attributes M" Angla III Mb TU Alaska Inc wnmomppuuwl FF:m Name wenenreslaae na Pl mDInKBI Aal.-SINBI 501032p20600 KUPARUK RIVER UNIT PROD 39.20 5,149.90 L. COMnMINL4(ppm)D.N.pnnolallon SSSV: NIPPLE 120 1ROO16 Fna One KBCr4 (In RIB RVIene Gale LasI WO: 4292005 40.99 3161IM4 aHM, irzvmlfisaeasqu emcelnlvmeec xDal AnnMnlon pepih lflNo' En40ale gnnomtion WH1Mod 6y Fna Ga@ Lasf Tag: SLM 6,3230 3/22/2015 Rev ReasonH2S,GLV CIO ppmven 5252016 HANGER ]9 unswiligivings Casing Description OO lnl nl (in) Tvp II1KBI Fal OeplF (NNO) &el OeplF (IVOI... WULen (I... Gratle Top TFreatl CONDUCTOR 16 15062 40.9 121 0 121.0 62.50 H40 WELDED Casing Description OD (a) ID(n) Top(CK8) Sol DnplF (NK9) Set GepN (TVGI... WULen (I.,.Ei Top Tnmaa SURFACE 7W8 6.675 409 3,tA2.6 3,140.3 2990 LAO LTC Casing 0escnpllon 0D (In ID(in) iop (XKBI $pi DepIF(RK 81 SN Cepin (NO)... WVLen (I.. Gnae Top TMna PRODUCTION 5112 4.2]6 387 6,643.1 6,2909 1]00 LBp LTC 5 6x5"@6552' Tubing Strings T1,mna wacNpaon smn9 ma_. ID '2rop OINB) sm Depm (N_ se! U1111(1Dl F.. wymn1) emae mp eennemmn TUBING WO 3112 2.992 3] 8 6,1260 5.)93.1 830 L-80 EUE ST Completion Details Naminal l0 coxOUCTOq; a9sui6 Tap NIKBI Top (TVO)91KB) Top Incl (°I Item Des Com (in) 37.8 37.8 0.09 HANGER FMC TUBING HANGER 3.500 504.2 504.2 1.16 NIPPLE CAMCOBP-61 LANDINGN(PPLE 2.875 6,1082 5,7746 21.13 NIPPLE CANDO DS' NIPPLE 2,812 NIPPLe6wx 6,113.2 51781.1 2099.LOCATOR BAKER GBW22 LOCATOR 2.850 6,113.5 5.]61.4 20.98 SEALASSY BAKER BOT GBH -22 SEAL ABBY285'DRIFT 2.980 Perforations & Slots snm Da- TopDVD) Ban (WD) (shops"' Top (f.) abn ex.) (XKB) (XKB) i W. U Type Co. GAs uFr'.z T6s.T 6,2500 6.280.0 5,9100 5,938.8 GA, Os, 3N- 611511998 40 RPERF 2"8"ERCJH, 0 D., ph 26 6,250.0 6,2800 5,910.0 5,938.6 Ci, CS. 311- 41W1997 4.0 IPERF 111/16° PIVOTS, Ise 26 deg. ph 6.306.0 6,336.0 5,953.4 5,992.2 A-3, A-2, 3H- 62411994 4e IPERF 2118° EnerJel, 90 deg. 26 ph Mandrel Inserts s1 nl &URFgCE:468>,14g8 vn Top MD) Top2.755. (2KBR,76 Nrte Moael Value Two Por{5 TRp Run Type (Psi" fl4 Date Com OO (in) SLI 1 1 2.J85.] 2,]fi3.5 CAMCO KBG2- -L 1 GAS LIFT GLV BTM 0.108 1,242.0 524201fi 0.1 9 2 4,124.4 4,096.2 CAMCO KBG-2- 1 GAS LIFT -M BTM 0.250 0.0 52412016 GAS LIFT: 4.1MA 9 3 4.907.6 4,836.7 CAMCO KBG-2- t GAS LIEF pMY BTM 0000 0.0 1/3/2016 9 4 5,630.9 5,351.9 CAMGO KBG2- 1 GAS LIFT DMV OK -1 0.000 0.0 61302005 9 5 5,055.1 5,]2].0 CAMCO KBG-2- 1 GAS LIFT 5MY OK -1 0.000 0.0 MW2005 9 GNSUFD4,9878 r11OtC5: Genard1 &Safi ty Fna Gal a 4129/2005 NOTE: TREE'. FMC3-118"" IGENIV15000psimtW 1"262009 NOTE', View scM1ematicwl Alaska SChema'ic9.0 GFSUFT:5.Ma9 GA9 LIFT; 6."55.1 NIPPLE;6.1863 &FPLAS&V:8.113.5 I RPERF; a.a506a;gap0 1PERF',8.25066$a0A IPERR630pe6.DgO PRODUCTION 5S-QKS521 as T".., I 311-26 Proposed CTD Schematic '6"6 6" hoe 62# H-40 s @ 121' MD 7-5/8" 29.7# L-80 shoe @ 3143' MD 3-112" 9.3# L-80 shoe @ XXXXMD 5-1/2" 179 L-80 @ 6133' MD C -sand perfs 6250' - 6280' MD A -sand perfs 6306'- 6336' MD 5" 18# L-80 shoe @ 6643' MD 3-1/2" Cameo Landing Nipple@ 504' MD (2.875" min ID) 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Cameo gas lift mandrels @ 2766', 4124', 4988', 5631', 6055' 3-1/2" Cameo DS nipple @ 6106' MD (2.812" min ID) Baker 3-1/2" GBH -22 seal assembly @ 6114' MD (2.98 ID) 3H -26L1.02 wp01 TD @ 9726' MD Top of Liner @ 6272' MD 3H -26L1 wp02 TD @ 8900' MD Billet @ 7500' MD 3H-261-4-01 wp01 D @ 8900' MD Billet @ 7400' MD TRANSMITTAL LETTER CHECKLIST WELL NAME: Kk(k- 34—of&�) -a2' PTD: '� 17 — 6 9 0 /Development Service Exploratory _ Stratigraphic Test —Non -Conventional FIELD: ( 9,vAr POOL: Nva l°�.-V6 /��agtW VW g �ViI Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. l9 q - a2 9 , API No. 50-103 - 1010 e- 00 - 00 . (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 from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company—Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sam le intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, sus ension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KU_PARUICRI_V UNIT 3H-26L1-02 Program DEV Well bore seg r PTD#:2170900 Company CONOCOPHILLIPSALASKA.INC. Initial Class/Type DEYJ PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal r_ Administration 17 Nonconven. gas conforms to AS31.05.030lj.1..A),Q.2.A-D) NA 1 Permit fee attached.. _ _ _ NA Yes Rig has steel tanks; all waste to approved disposal wells 2 Lease number appropriate _ _ Yes _ ADL0025531, entire wellbore.. 3 Unique well name and number Yes _KRU 3H-261-1-02 4 Well located in a defined pool _ _ Yes KUPARUK RIVER,. KUPARUK RIV OIL - 490100,. governed. by Conservation Order No, 432D. 5 Well located proper distance from drilling unit boundary_ _ Yes CO 432D contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells Yes CO 432D has no interwell spacing restrictions. 7 Sufficient acreage available in drilling unit Yes .ppg 8 If deviated, is wellbore plat. included _ _ _ Yes _ 9 Operator only affected party.. Yes Wellbore will be more than 500' from an external property line where ownership or landownership changes. 10 Operator has. appropriate bond in force Yes 32 Appr Date 11 Permit can be issued without conservation order Yes PKB 6/15/2017 12 Permit can be issued without administrative approval Yes H2S measures required 13 Can permit be approved before 15 -day wait _ Yes NA 14 Well located within area and. strata authorized by Injection Order # (put 10# in comments) (For. NA Permit can be issued w/o hydrogen sulfide measures 15 All wells within 1/4 mile area of review identified (For service well only) _ NA 36 16 Pre -produced injector; duration of pre -production less than 3 months (For. service well only) NA Appr Date 18 Engineering Conductor string provided _ _ NA Conductor set in KRU 3H-26 19 Surface casing protects all known USDWs NA Surface casing set in KRU 31-1-26 20 CMT vol adequate to circulate on conductor & surf esg NA Surface casing set and fully cemented 21 CMT vol adequate to tie-in long string to surf csg_ NA 22 CMT will cover all known productive horizons No Productive. interval will be completed with slotted liner 23 Casing designs adequate for C, T, B & permafrost Yes 24 Ade uat tank Geologic Engineering q e an age or reserve pit Yes Rig has steel tanks; all waste to approved disposal wells Commissioner: Date 25 If a re -drill, has 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; no major risk failures 27 Ifdiverter required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic .& equip list adequate Yes Max formation pressure is 3990 psig(12.7 ppg. EMW); will drill w! 8.6 EMW and maintain overbal w/ MPD VTL 6/22/2017 29 BOPEs, do they meet regulation Yes .ppg 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 3405 psig; will test BOPs to 3750 psig 31 Choke manifold complies w/API RP -53 (May 84) _ Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S measures required 34 Mechanical condition of wells within AOR verified (Far service well only) NA Geology 35 Permit can be issued w/o hydrogen sulfide measures No Wells on 3H -Pad are 1 -12S -bearing, 1-12S measures required. 36 Data presented on potential overpressure zones Yes Max. potential reservoir pressure is 12.7 EMW; will be drilled using 8.6 p P ppg - 9 PP9 mud and MPD technique. Appr Date 37 Seismic analysis of shallow gas. zones. _ NA PKB 6/15/2017 38 Seabed condition survey (if off -shore) _ _ _ _ _ _ _ NA 39 Contact name/phone for weekly progress reports [exploratory only] NA _ Onshore development lateral to be drilled. Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner (IDate
