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Home My WebLink About217-088DATA SUBMITTAL COMPLIANCE REPORT 11/7/2017 Permit to Drill 2170880 Well Name/No. KUPARUK RIV UNIT 314-261-1-01 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20208-61-00 MD 8890 TVD 5841 Completion Date 8/5/2017 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION / / Mud Log No ✓ Samples No✓ Directional Survey Yes v DATA INFORMATION Types Electric or Other Logs Run: GR/Res (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH I Type Med/Frmt Number Name Scale Media No Start StopReceived CH Comments ED C 28510 Digital Data 8/21/2017 _ Electronic File: 31-1-261-1-01 EOW - NAD27.pdf• ED C 28510 Digital Data 8/21/2017 Electronic File: 31-1-261-1-01 EOW - NAD27.txt ` Log C 28510 Log Header Scans 0 0 2170870 KUPARUK RIV UNIT 3H-261-1-01 LOG HEADERS ED C 28546 Digital Data 6219 8890 8/28/2017 Electronic Data Set, Filename: 3H-261-1-01 GAMMA RES.Ias ED C 28546 Digital Data 8/28/2017 Electronic File: 31-1-261-1-01 21AD Final Log.cgm . ED C 28546 Digital Data 8/28/2017 Electronic File: 31-1-261-1-01 51AD Final Log.cgm ED C 28546 Digital Data 828/2017 Electronic File: 31-1-261-1-01 5TVDSS Final ' Log.cgm ED C 28546 Digital Data 98/28/2017 Electronic File: 31-1-261-1-01 21VID Final.pdf • ED C 28546 Digital Data 0/28/2017 Electronic File: 31-1-26L1-01 5MD Final.pdf ED C 28546 Digital Data J28/28/2017 Electronic File: 3H-261-1-01 5TVDSS Final.pdf ED C 28546 Digital Data 8/28/2017 Electronic File: 31-1-261-1-01 EOW - NAD27.pdf ED C 28546 Digital Data 8/28/2017 Electronic File: 31-1-261-1-01 EOW - NAD27.txt ED C 28546 Digital Data 828/2017 Electronic File: 31-1-261-1-01 Final surveys . 8890TD.csv ED C 28546 Digital Data 8/28/2017 Electronic File: 31-1-261-1-01 Final surveys 8890TD.xlsx ED C 28546 Digital Data 828/2017 Electronic File: 31-1-261-1-01 Survey Listing.bd ED C 28546 Digital Data 8/28/2017 Electronic File: 3H-261-1-01 Surveys.txt - ED C 28546 Digital Data 828/2017 Electronic File: 3H-261-1- 01_25_tapescan_RHI_CTK.txt AOGCC Page I of7- Tuesday, November 7, 2017 DATA SUBMITTAL COMPLIANCE REPORT 11/7/2017 Permit to Drill 2170880 Well Name/No. KUPARUK RIV UNIT 31-1-261-1-01 MD 8890 TVD 5841 Completion Date 8/5/2017 ED C 28546 Digital Data ED C 28546 Digital Data ED C 28546 Digital Data ED C 28546 Digital Data ED C 28546 Digital Data Log C 28546 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report OY Production Test Information A Geologic Markers/Tops COMPLIANCE HISTORY Completion Date: 8/5/2017 Release Date: 6/26/2017 Description Comments: Interval Start Stop Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20208-61-00 Completion Status 1-0IL Current Status 1-0I1- UIC No 8/28/2017 Electronic File: 31-1-261-1- 01_5_tapescan_BHI_CTK.txt 8/28/2017 Electronic File: 31-1-261-1-01_output.tap ' 8/28/2017 Electronic File: 31-1-261-1-01 2MD Final Log.tif 8/28/2017 Electronic File: 31-1-261-1-01 SMD Final Log.tif ' 8/28/2017 Electronic File: 31-1-261-1-01 5TVDSS Final Log.tif - I 0 0 2170870 KUPARUK RIV UNIT 3H-261-1-01 LOG HEADERS Sample Set Sent Received Number Comments Directional / Inclination Data/jf� Mud Logs, Image Files, Digital Data Y { !A Core Chips Y Mechanical Integrity Test Information llY//,l� Composite Logs, Image, Data Files Y� Core Photographs Y /r(J Daily Operations Summary Cuttings Samples Y / IQ Laboratory Analyses Y /A Date Comments Compliance Reviewed By: - AOGCC Page 2 of Date: Tuesday, November 7, 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED AUG 31 2017 WELL COMPLETION OR RECOMPLETION REPORT A 1a. Well Status: Oil ❑� - Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.m5 20AAC 25.110 GINJ❑ WIND❑ WAGE] WDSPL❑ No. of Completions: ib. Well Cl s. Development Exploratory ❑ Service [J Stratigraphic Test❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 8152017 14. Permit to Drill Number/ Sundry: 217-088 . 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 7/28/2017 15, API Number: 50-103-20208-61-00 4a. Location of Well (Governmental Section): Surface: 1384' FNL, 281' FWL, Sec 12, T12N, R83, UM Top of Productive Interval: 3093' FNL, 5212' FEL, Sec 12, T1 2N, R8E, UM Total Depth: 5083' FNL, 5252' FEL, Sec 12, T1 2N, R8E, UM 8. Date TD Reached: -ri290204'F 16. Well Name and Number: KRU 31-1-261-1-01 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 ' 41b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498655 y- 6000273 Zone- 4 TPI: x- 498443 y- 5998564 Zone- 4 Total Depth: x- 498408 y- 5996574 Zone- 4 11. Total Depth MDfTVD: 8690/5841 , 19. DNR Approval Number: ALK 2657 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21, Re-drill/Lateral Top Window MD/TVD: NtA- (9_q 7 2',/ S`7SL/ ' `'' 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD HOLE SIZE CEMENTING RECORD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H40 41 121 41 121 24 200 sx CMT 7.625 29.7 L-80 41 3142 41 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 23/8 4.6 L-80 7407 8890 5891 5841 3 Slotted Liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Slotted Liner@ 7426 - 8859 MD and 5891 - 5849 TVD 30MPLETION DAT 2d1� VERIFIED w 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 6127 6117/5785 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes EJ No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 8/8/2017 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 8/12/2017 Hours Tested: 3.33 Production for Test Period Oil -Bbl: 32.68 Gas -MCF: 126.93 Water -Bbl: 1198.9 Choke Size: 176 bean Gas -Oil Ratio: 1273 Flow Tubing Press. 250 Casinq Press: 1 1380 Calculated 24 -Hour Rate Oil -Bbl: 760 Gas -MCF: 967 Water -Bbl: Oil Gravhv- API (corr): 24 Form 1,0/474 vise512017 VT L a/�`'' �J CONTINUED ON PAGE 2 Rg®��V �r.� - 5 2017 Submit ORIGINAL only 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, Fromrro), 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 6772 5954 information, including reports, per 20 AAC 25.071. Formation @ TPI - Kuparuk C Kuparuk D 8860 5849 TO 8890 5841 Formation at total de the Kuparuk D 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, naleontolouical report. production or wellresults, r 20 AAC; 25,070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: Mike Callahan Pte Authorized Title: Staff CTD Engineer Contact Email: mike.callahan co .com Authorized��/, Contact Phone: 263-4180 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 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ' Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only fw} ) M ! ] 7| 5 ) � � / ` KUP PROD COnOCOPItilGpSWellAttribE AIas1la.InG. wmm�e APuurvn FwN 3H-26 NIPPLE 1 190 12/42016 Last WO: 1 429/2005 1 40 NJ NV19W AnnNNbn_F" nJ Dab Annolalmn Last of By EM Dale Last Tag: RKB -T66,2999 7=1] Rev Reason'. CTD SIDETRACK jennatt 629201] HANGER', 378 as ng ngs iDU6aerlptlon o011n1 ml1 Top lnNal set MpN 01,M)121 eees"RVO)_.WULm9,..6H4Z7 TOP CONDUCTOR 16 CONDUCTOR 15.062 409 121.0 6250 H<0 DZVD WELDED eaerptlon o1n 1011n1 op IK G SURFACE )SIB 8..P'—.' 6 40 9"""no"., . 3,1428 3,140.3 29.]0G LTc cMmouhmcrmmn opme38 ) 9N CepN (arcaxceNbDI..9. WNRp..0 'LZ PRODUCTION 5112 42]6 6I290170 TCm 5.5x5"@6552' Tubing Strings Tumnp Desonpeon so-iiq Ma... m pn) Too IKK01 sN Oey.N m.. SN oegn (NDI (... WYpIIM) Grade Top ConnMho TUBING WO 312 2.992 37.8 6,126.0 5,)93.1 9.30 L-80 IBT Completion Details GGXDUCTOR: w 0-121 o nemmaM TaPNKa1 T"Red) IM ET Top MCI C) I was Des Dom en)' 37.8 HANGER FMC TUBING HANGER 3.500 5042 NIPPLE CAMEO BP41 LANDING NIPPLE WPPIE. 50e.3 6,106.2 5.]]46 21.13 NIPPLE CAMCO DS' NIPPLE 2.812 61132 5.]81.1 20.99 LOCATOR BAKER GSH -22 LOCATOR 2.850 6,113.5 5,]81J 20.6 11SEAL ASSY BAKER BOT GBH -22 SEAL ASSY 285"DRIFT 2980 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Te"S Top Incl Gab LIET:;AS.] T°P(rtaa) (M(61 P) Des Com Be. Oam 101A1 6,229.0 5,690.1 19.64 WHIPSTOCK BAKERWHIPSTOCK.DAL=4T,OAW330LBS, 71122017 0000 MAX TOOL OD = 2.70, SET WHIPSTOCK 29.4 - I LEFT OF HIGHSIOE, TOP OF WHIPSTOCK SET @ 6229 (2 RA TAGS) Perforations & Slots Shot Dena Top('D) BMIrvD) show Tap plRe) aha MIKE) gm.) MEQ Zane Dare M Type Co. suftEmE:4o.aa.I4ze— 6,250.0 Q280.0 5,910.0 5.9386 C-4, CJ.3H- 6/1511998 4.0 RPERF 2118° EnerJet, 0 deg ph 26 6,250.0 6,280.0 5,9100 5,938.6 C4, E-3, 3H- 4911997 4,0 PERE 111117 PIVOTS, 180 26 deg, ph GASUFF4.I2e.s 6,306.0 6336.0 5,9634 5,9922 A-3. A-2, 3H- &2M994 4.0 (PERF 211W EnerJet, 90 deg. 26 ph Mandrel Inserts en GAG UR; 4.9117 6- N Top(M(BI Top (Ted" (III(B) NaM MoIN VaWe ODlenl 8ery Type lekh Pa[SW TRO Type (m) Run IPs4 Run pass Com 2,]65.] 2,7635 CAMCO KBG-2- 1 GAS LIFT GLV BTM 0.188 1,253.0 801201] 9 2 4,1244 4,096.2 CAMCO KBG-2- 1 GASLIFT OV BTM 0250 00 &81201] 9 3 4,98)6 4,836] CAMEO KBG-2- 1 GASLIFT DMY BTM 0.000 0.0 1WO16 9 GAsuET s63oa 0 5,630.9 5,3519 CAMCO KBG-2- 1 GAS LIFT DMY DK -1 0.000 00 fila&2005 9 5 6,0551 5.7270 CAMCO K8G-2- 1 GAS LIFT DMY DK -1 0000 OD 613@2005 9 Notes: General & Safety End Des, i Ansessom 412912005 NOTE: TREE: FMC 3116"' 1 GEN M 15000 Psi rated GAs uEr'. e.m3l 112&2009 1 NOTE: View SPnemapc wl Alaska Schema0c9.0 NIPPLE: 6,1Wi SFµ At$Y; 6.11?5 wRIP6TGCIl a,?Ao RPERF', 9.=08.=0 IPERF', 6=00 8. 0' (PERF: 9,aE.0$.3Y.0� PRGDOCTIDNGEaSooesZ: 3a>-06131 Conoco`Phillips Alaska, Im KUP PROD 3H -26L1 12/42016 LAST WC: 1 1 40.01 316/1994 nnnmaoon De T(ft 6) ane Dam Annodtion La,Mm er E.,I. Last Tag' Rev Reason CTD SIDETRACK jennal, WWO17 µ4NGER: 37,9 as ng ngs Laslrp Descnptlon OD(inI ID IIn) ioplKKfil SN DepW (XNBI SN DapW ITVDL.. WOLen I L.."0e T.Ilthtl Lt LINER 2318 1.992 6,1101 bii3.g 4.60 b80 STL Liner Details N minal lD roplraRl Top lrvDlK Top 1.1 C) I. T. Co. IInI fi,JJBJ 5.954 3 91.37 ALUMINUM Liner Top BlIIe, 1920. BILLET I Notes: General & Safety Era Dob Anti C0.NDUGTOR: 0 4121 O NOTE NIPPLE;5013 GAS UFT..7861 6DRFACE: 40.GG., 12d_J G16 LIFT: 4,SW.6 Gab LIFT, S..e GPS LIFT; 6,05kI BFA $1.. R„]5 WXIPSTCCIU GZA.O RP ERF:8.2YJ.64RJ0 PERF, 8,250.042W,0� I IPERF, e306 oo33 0� I PRODUCTION S.ffi'®P562;� 1 f W 7-6.616.+ C Lt UNEfl; B.iNTd,il30� ConoCI3Phillips Alaska, Im KUP PROD 3H -26L1-01 14/42016 LAST WO: 1 1 40.99 316n994 Anno n CYptlI LML9) Fna Oed AnnOlNnn IaaLMIXl ay Ena Oale ....._._,___ Lasi Tag: Rev Reason: CTD SIDETRACK jennalt 81 NNUGER:3T.6 asmg ngs casl'y Dexngien OD IIIl ID 11n) Top'RKel beiD as lnne� set oeWn Vivol... WULen II... ¢rase rop innea Lt -01 LINER 2318 1.992 ],d06.] 8.880.0 460 LA0 STL Notes: General 8 Safety End DaIm IAnnalalbn NOTE'. CCNDVCTOR,. 6-1210 NIPPLE: 60..2 GAS LIFT: 3,]65] SVRFgCE; a0 1428 G\611Fi: <.iM.Eq G96 LIR', <.99] fi GAS LIFT, 5iQ 8 G UFT', 811 NIPPLE;6,1IM2 SEPLA66V; 61115 WHIP6TOLK:6,Y®.0 RPERF2i006,iPo0 IPERP6.26006,20I0' IPERF: 6603 O6AV 0� PRODUCTIM bT®8b2: .1." I� LI UNER', 7,4e.]d.6W.0J `, KUP PROD Cormic iilips Well Attribl — NBSF.a.I1,C. Wellbore FpW WI T 3H -26L1-02 IDV2016 LAST WO'. 40991 31611994 An -nmInh Me) E 1 Dab Rnnobllen Lae1 By Enn Dab Last Rev ReaSOn: CTD SIDETRACK Iennait 5291201] HM ER,TS 881ng nga Casirq 0eactlplkn OD (nl ID(nl Top IflN01 Sv[Depµ Qil(B) Sel Depth VDl... Waien. Gea]e n TOITPread 11-02 LINER 2&8 1.992 Q113.fi 10,188.0 5,9JL8 4.60lL.LA0 STL Liner Details xnmilul lD Top (MK Tap(1VDIINLD) Topindl'1 Ibm Ox Can W 6,113.6 5,1819 19.8] DEPLOYMENT Shorty Deployment Sleeve 1920 SLEEVE 8,171.2 5,8995 69.19 DEPLOYMENT SIgRy Deployment Sleeve 1.000 I SLEEVE Notes: General & Safety Eno Dare AnnOWlon NOTE: CONDUCTOR: a&1210 NIPPLE, 504] Aae LIEr', ZM1 SURFA 40A 14Mb I AAS LTT: 4, IN.4 ays UFT. 4.W,6 . WFT;SA331 NIPPLE,AIM,2 PR0DUCTjGN0WS . 3074.1 11 1� 1 LIM UNER:5.113610.1M B Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start oepm Start Time End Tana Dur(hr) Phase Op Code AdiWi(y Code Time P -T -X operation (Po03) Endoepm(ftKa) 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, rig sows up to modules 7/21/2017 7/21/2017 5.50 MIRU MOVE MOB P Move to 3H -Pad 0.0 0.0 12:00 17:30 7/21/2017 7121/2017 4.50 MIRU MOVE MOB P Sub spotted over 31-1-26, 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 post 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 o'5- 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 7/2212017 0.70 MIRU WHDBOP BOPE P Continue with BOPE lest 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 7122/2017 2.50 MIRU WHDBOP BOPE P Continue with BOPE test 0.0 0.0 16:30 19:00 7/22/2017 7122/2017 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 1 slips. Function. Relocate test joint 7/22/2017 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 1-16ur test 7/22/2017 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 7/232017 7/23/2017 1.50 MIRU RIGMNT PRTS P Prep and pressure lest 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, R/D BPV equipment. WHIP after BPV removeal 2304 PSI Page 1113 Report Printed: 818/2017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time EM Time our (hr) Phase Op Cade Activity Code Time P -T-% Operation Start Depth We) End Depth CftKe) 7/23/2017 1712312017 0.40 PROD? 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 BBls away WHP=1440, @ 3.5 BPM, A=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 1 WHP=1100 PSI, monitor well 7/23/2017 7/23/2017 3.00 PROD? WHPST PULD P PJSM, crew change, another PJSM, 0.0 74.0 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 208610 74.0 3,189.0 09:48 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 PROD1 WHPST DLOG P Unable to tie into Kt , gamma is 6,160.0 6,213.0 12:36 13:00 reading coninuous -230 API, stop at TOWS 7/23/2017 7/23/2017 020 PROD1 WHPST TRIP P Confer with town, PUH to 6085'to 6,213.0 6,080.0 13:00 13:12 perform CCL, PUW = 32K 7/23/2017 7/23/2017 1.00 PROD1 WHPST DLOG 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 PROD1 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 borhom and appear to have exit. 7/23/2017 7124/2017 2.20 PROW 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: 81812017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth SWTime End -nm Phase Op Code Aavih Code Time P -T-% Operation (NCB) End Depth(MKB) 7/24/2017 7/24/2017 2.50 PROD1 WHPST WPST P 6255 @ rathole TO, 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. Repeat this pass and one more as drilled. Get clean dry drift 7/24/2017 7/24/2017 1.50 PRODt 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 PROW DRILL PULD P PJSM, M/U R 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 1 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 1 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, tie from CCL for +11' correction, allow Peter O'Brian time to install final software updates, upload caused circ pump reading issue, upload new update, close 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, WHIP = 493 psi, IA = 1430 psi, FS = 379 psi, multiple PU's required drilling BHA length past window, observed Siderite over shakers, PUW's = -36K 7/2412017 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, rate 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, difficulty 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 L1 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, slab on WH, tag up Page 3113 Report Printed: 81812017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Siad Time End Tena Dw (hr) Phase Op Code Addy code Tune P -T -X Operation MKD) End Depth (f KB) 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 PROD1 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 7/25/2017 0.10 PROD1 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 PROD1 DRILL DLOG P Log Re 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 PROM 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 PROM DRILL DRLG P 6387', Drill, 1.8 BPM @ 4924 PSI FS, 6,387.0 6,810.0 0048 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 7/25/2017 5.60 PROD1 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 PROD1 DRILL WPRT T PUH to cased hole, depth discrepancy 71125.0 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 PRODt 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 PROM DRILL WPRT P Continue in hole 6,205.0 6,250.0 13:12 13:18 7/25/2017 7/25/2017 0.30 PROM 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 13:35 16:06 program became corrupt, Call Jeff and CDR2, Remove erronious data from data base generated by bad encoder, 2.5 Him BHI NPT 7/25/2017 7/25/2017 0.30 PROD1 DRILL WPRT P Continue in hole to drill 7,020.0 7,123.0 16:06 16:24 7/25/2017 712512017 4.00 PROD1 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 PROD1 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 PROM 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 PROM 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, WHP 384, IA 1,290. OA 23 7/26/2017 7/26/2017 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 7126/2017 1.50 T POOH, to inspect BHA, (lost 650psi 7,861.0 78.0 00:45 02:15 diff), leaving EDC closed 7/26/2017 7126/2017 2.00 PULD T PJSM, PUD Drilling BHA# 3, following 78.0 0.0 02:15 04:15 checklist w/closed EDC 7/26/2017 7/2612017 2.60 TPRODIDRILLTRIP 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 TRIP T Trip in hole, BHA #4 with .5° motor 78.0 6,001.0 06:51 08:15 and RB HYC bit with agitator, Test agitator @900' Page 4113 Report Printed: 81812017 Drilliin Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Sint Tune End Tune Dur (hr) Phase Op code Activity Code Time P -T -x Operstion (HKB) End Depth(flKB) 7/26/2017 7/26/2017 0.40 PROD1 DRILL DLOG T Set tool to CCL mode. Log CCL fle in 6,001.0 6,215.0 08:15 08:39 for+7' 7/26/2017 7/26/2017 0.70 PRODt 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. DHWOS=1.1K 7/26/2017 7/26/2017 0.60 PROD1 DRILL 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 PROM DRILL 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 FDRLG 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 P Perform MADD PASS 7,535.0 7,325.0 18:00 18:30 7/26/2017 7/26/2017 0.50 PROM DRILL P Continue wiper to the window 7,325.0 6,200.0 18:30 19:00 ' 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 ND (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 PROM DRILL DRLG P BOBD, 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 PRODi 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 PROD1 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 PROD? 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 1 04:00 for plus 6.0' 7/27/2017 7/27/2017 0.90 PROD1 DRILL TRIP P Continue RIH, confirm TD 6,199.0 8,773.0 04:00 04:54 7/27/2017 7/27/2017 1.10 PRODt DRILL TRIP P POOH, laying in liner running pill with 8,773.0 6,926.0 04:54 06:00 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 1 OK - 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 7127/2017 1.80 PROM DRILL TRIP P Continue up to 6202 above window. 6,926.0 6,202.0 06:30 08:18 Circ out small bubble and perform flow check - good Page 5113 Report Printed: 8/8/2017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth sten Tum, End Time Our (hr) Phase Op Cade Activity Cade Time P -T -X Operation (110) End Depth(hKB) 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- 7127/2017 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 7127/2017 3.00 COMPZI CASING PUTS P PJSM, P/U 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 tmk to liner, 1,993.3 2,046.5 15:36 16:48 Secure coiltmk 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 COMPZI 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 COMPZI 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 4045 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 electrician/mechanic, trouble shoot weight cell, service crew showed up at 21:15 7/28/2017 7/28/2017 0.50 COMPZ1 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 COMPZI CASING RUNL P RIH 8,116.0 8,303.0 00:30 00:42 7/28/2017 7/28/2017 1.10 COMPZI 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 (-6,771') 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 COMPZI CASING OWFF P At surface, PJSM, Check well for flow 58.2 58.2 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# 6, surface 0.0 78.2 04:24 05:06 test Coiffrack 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+ 5.5' correction 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 NaBr 7/28/2017 7/2812017 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 e Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Stan Time End Time ow(hr) Phase Op Code AcNih Code Time P -T -X Opefdion (ftKB) End Depm(ftKB) 7/28/2017 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 7128/2017 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 09:48 10:06 15303 PSI FS 7/28/2017 7/28/2017 0.90 PROD2 DRILL DRLG P Time drill 2-4 FPH for 1 foot, 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 7/28/2017 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 7128/2017 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 IBHP=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 7/2812017 7/2812017 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 7/2812017 0.25 PROD2 DRILL DLOG T Log CCL for+5.5'comection 6,060.0 6,149.0 18:15 18:30 7/28/2017 7/2812017 0.75 PROD2 DRILL TRIP T Continue RIH, work pipe to bottom. 6,149.0 6,875.0 18:30 19:15 1 1 from 6835' to 6875' 7/28/2017 7/28/2017 3.88 PROD2 DRILL DRLG P BOBO, 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 7129/2017 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 7129/2017 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 7/29/2017 2.10 PROD2 DRILL DRLG P BOBD, 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 7/29/2017 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 1 1 7/29/2017 7/2912017 0.40 PROD2 DRILL DLOG P Run CCL logging pass for+2' 6,060.0 6,203.0 10:12 10:36 1 Page 7113 Report Printed: 818/2017 . Operations Summary (with Timelog Depths) yc 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Time I End Time Our (no Phase OP Code Adity Code Time P -T -X Operation (BKS) End Depth (11103) 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 6,077.0 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 14:39 15:24 trip up and down 7/29/2017 7/29/2017 2.87 PROD2 DRILL DRLG P 8490', 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, WHIP 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 1 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 7/30/2017 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 k 7/30/2017 7/30/2017 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 7130/2017 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 PUTS P Prep floor and pick up L1-01 0.0 1,424.4 06:54 12:00 completion with non ported bullnose, 1 Jt blank liner, 35 As slotted liner, and liner top billet 7/3012017 7130/2017 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 7/30/2017 7/30/2017 0.10 COMPZ2 CASING PUTS T PIU one joint slotted, Add 8' solid pup 1,477.7 1,473.9 13:54 14:00 7/30/2017 7/30/2017 0.80 COMPZ2 CASING PULD T P/U coil trak 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 7/30/2017 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 1 1 working pipe from - 8400 to bottom Page 8113 Report Printed: 818/2017 Operations Summary (with Timelog Depths) Milk 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start DePth Stan Time Entlnma our (hr) Phase Op Cone Activity Cone Time P-T-k Operation (Mal) End Deplh(llKa) 7/30/2017 7/30/2017 0.25 COMPZ2 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 PRODS 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 PRODS STK CTOP P Meg a-line, > 2000 mohms / 87 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 PRODS STK DLOG P Log CCL correction of plus 8.0', 6,060.0 6,199.0 23:48 00:00 PUW 7/31/2017 7/31/2017 0.50 PRODS 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 PRODS 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 PRODS 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, WHIP 259, IA 1250, OA 8, dry drift billet area clean. 7/31/2017 7131/2017 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 7/312017 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 (414210 PSI 7,546.0 7,708.0 05:36 10:12 FS, BHP=3760, Several pick ups - Ratty drilling 71312017 7/31/2017 0.50 PRODS DRILL WPRT P 7708', Wiper to billet, 7000', 7,708.0 7,708.0 10:12 10:42 PUW=39K 71312017 7/31/2017 1.10 PRODS DRILL DRLG P 7708', drill, 1.78 BPM @ 4238 PSI FS, 7,708.0 7,728.0 10:42 11:48 BHP=3802 7/312017 7/31/2017 1.90 PROD3 DRILL TRIP P Call end of tum I build, trip out, AVG 7,728.0 84.3 11:48 13:42 DLS=39.7°, Perform 200' jog at surface 7/312017 7/31/2017 1.80 PRODS 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 PRODS DRILL PULD P PD BHA # 10 with .6° motor, agitator, 0.0 78.2 15:30 17:12 and RB 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 18:24 shallow test agitator- Good Continue n well Page 9113 ReportPrinted: 8/812017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stasi Time Entl Time Dur(hr) Phase Op Code Activity Cone Time P -T -X Operation (fiKB) End Depth (MKS) 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 7/3112017 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 7/31/2017 8/1/2017 4.40 PRODS DRILL DRLG P 7723', drill, 1.79 BPM @ 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, WHIP 327, IA 1,343, OA 24, CTSW=2k, DHWOB=2 k, ROP 48 fph 8/1/2017 8/1/2017 0.50 PROD3 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 PRODS DRILL DRLG P OBD, 1.8 bpm at 5,108 psi, BHP 8,120.0 8,520.0 01:45 07:30 3,783, WHIP 299, IA 1,343, CA 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 PRODS 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 8/1/2017 2.50 PRODS DRILL DRLG P OBD, 1.8 bpm, 5134 psi, 3912 psi 8,715.0 8,920.0 13:12 15:42 BHP, 1220 psi dp, 6K CW, 1 k 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, WHIP 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 PROD3 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, WHIP 266, IA 1,330, OA 30 8/2/2017 8/2/2017 0.50 PROD3 DRILL WPRT P Wiper up hole, PUW 33 k 9,319.0 8,300.0 03:30 04:00 Page 10113 Report Printed: 8/812017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stmt Depth Sh t Time End Time Our (hr) Phase Op Code Activity Code Time P-T-X Operation MKB) End Depth (MB) 8/2/2017 8/2/2017 0.40 PROD3 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 256, 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'. 8/2/2017 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 8/212017 8/2/2017 1.40 PRODS 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 DLOG 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 PROD3 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 +5K. 8/212017 8/2/2017 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= 0.8K, ROP 25 to 45 FPH. 8/2/2017 812/2017 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 PROD3 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 8/3/2017 0.50 PROD3 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=0 k, DHWOB=1.4 k, ROP30- 60 fph, pumping low-vis and high-vis beaded sweeps 8/3/2017 8/3/2017 0.50 PROD3 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 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 PROD3 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 11/13 Report Printed: 8/8/2017 Operations Summary (with Timelog Depths) 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Tinto Log sw Depth Stad Tlme Ertl Tame Dur (tv) Phase Op cotle Acbvtiy Coem Time PJA Operation MKB) End Di(ftKB) 8/3/2017 8/3/2017 1.50 PRODS 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 competion 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 1" 78.2 78.2 23:12 00:00 haliburton valve, shut in and monitor well, WHP 28 psi, open choke bleed off pressure to the pits, continue to monitor well, observed flow, Gose 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, WHP 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 8/4/2017 0.50 PROD3 DRILL DLOG T Log CCL correction of plus 6.0' 6,060.0 6,208.0 01:27 01:57 8/412017 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 PROD3 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 PRODS DRILL CIRC T Circulate bottoms up 6,208.0 6,208.0 03:57 04:57 8/4/2017 8/4/2017 0.50 PROD3 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 PROD3 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 8/4/2017 2.70 COMPZ3 CASING PUTS P Prep rig floor, PJSM, pick-up L7-02 0.0 0.0 07:45 10:27 lower liner segment; non -ported bullnose, 50 Its of 2-3/8" slotted liner, and shorty deployment sleeve. Fill hole every 10 jnts. 8/4/2017 8/42017 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 UQC, MU to coil, surface test, strip on well, set counters 8/412017 8142017 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: 818/2017 Operations Summary (with Timelog Depths) AM k 3H-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Cade AcUvdy Code Time P -T -X Operation (ftKB) End Depth(ftKB) 8/4/2017 8/4/2017 0.50 COMM 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 seffting 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 COMPZ3 CASING PUTB P PU/MU upper liner segment with 51 jts 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 2,107.8 01:15 02:00 test, (good lest), 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' EDP flag plus 6,093.0 7,808.0 03:15 04:00 1 83, puw 30 K, continue IH 8/5/2017 815/2017 0.70 COMM 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 815/2017 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 815/2017 1.10 COMPZ3 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 WIS. 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 COMPZ3 CASING PULD P PUD and laydown BHA#12. 44.2 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 WHDBOP 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: 818/2017 sI ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H -26L1-01 50-103-20208-61 Baker Hughes INTEQ Definitive Survey Report 11 August, 2017 BAKER UGHES -F,, ConocoPhillips �r�uGHES 13 ConocoPhillips Definitive Survey Report Company: ConodePhlllips(Alasks) Inc .-Kup2 Local Coordinate Reference: Well 3H-26 Proal Kuparuk River Unit TVD Reference: 3H 26@8000usft CH26) She: Kuparuk 3H Pad MD Reference'. 3H-26 @ 80.00usft (31-26) Well: 3H-26 North Reference: True Wellbore: 3H -26L1 Survey Calculation Method: Minimum Curvature Design: 3H-2611 Database: EDT Alaska Sandbox Praised Kuparuk River Unit. North Slope Alaska, United Stites Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADOON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor _ _. .. .. _........_... Well 3H36 Well Position •NIS 000 ash Northing: 600027270usft Latitude: 70.24'43.124N -Ef-W 0.00 deft Easting: 498.654.81 deft Longitude: 150° 0 39.435 W Position Uncertainty 000 deft Wellhead Elevation: deft Ground Level: 000 ush ' Wellbao 3H-2811-01 Magnelics Model Name Sample Date Decgnatlmr Dip Angle Field Strength (1) V) (nn BGGM2017 9/1/2017 17.42 80.95 57,48].12 Design 3H -26L1-01 Audit Notes: Version: 10 Phase: ACTUAL Te On Depth: 6.76974 Vertical Section: Depth From(TVD) -ki eSkee Ditecbon (had) (us") (usm) V) 8000 0.00 000 18000 8/1 f,2017 4 29 36P Page 2 COMPASS 5000.14 Build 85 �,. ConocoPhillips 13PLLER.__ 0 C0nocoP IIllIps Definitive Survey Report Company: ConomPhillips(Naska) Inc.-Kup2 Local Coartlaute Reference: Mil 311-26 P.,m: Kupamk River Unit NO Reference: 31-1-28®80.00usft(311-28) SIM: Kuparuk 3H Pad MD Reference: 3H-26 ® 8000usft (31-1-28) Well: 31-1-26 North Reference: True WellEore: 3H-2611 Survey Calcula4on Medmtl MbireurCurvature Oeslgn: 3H-26Ll D3M6ese: EDT Alaska Sandbox survey P"nalt Was 64/2017 From To Surety Survey (uaft) (usft) Se"(WellOore) Tppl Name OeseRpilan SMrt Dale ErWDate 12100 5,974.70 3H -26 (3H-26) MWD MWD-SMndard 111212001 6229.65 6,32DA5 31-1-2611 MVi(31-ML1) MWD-INC_ONLY MWDINCONLYFILLER ?232017 ]242017 6,350.41 8,]69.]4 31-1-2611 MWD(3H-2611) MWD MWD -Standard! ]24201] 72]0017 6,T?200 6,080.12 3H -26L1-01 MWD -INC (3H-2811-01) MW INC_ONLY MW IN0_ONLY FILLER ]261201] 71292017 j1 68119.59 8,880.02_ 3H-2611411 MM (31-1-2611-01) MWD MWD-StanJad -_ - 70&2017 7/302017 Survey Map Map VeNcal MD Inc Azi Ti .1,114/S +O -W Nandi, Eason, DLS Section Sa, Tool Name Annotamon (ura) 1°) I°I luraan l rom) lam) laml (ft) (1D (^n W) (ft) 870.74 97.33 1]694 5851425874A2 1]0].08 -21188 59%ev5.82 490,442.84 5.97 1]0]08 MrYD(3) TIP 6 M 9743 1]].0] 595413 5074.13 120.4 -211.56 5898583.59 498442.96 7 22 1.709 32 MWDINC ONLY (4) NOR { owl all 101.88 176.90 594912 Saw 12 1,73073 210.01 505534.18 498,444.50 14.W 1,73073 MVDINCONLY(4) nMlpolated ALI11uto f(t{t( 6MI77 1014 1]8.80 5942.14 5,082.14 1,76775 2118.41 59WW5.17 498446.07 1091 1]87]5 IMD-INC ONLY(4) IMelpolated AfimuN ( &060.12 101515 17650 593449 5.854.49 1.7950 -2+687 5998,477.82 49044784 381 1,7950 MN4INC 0VLY(4) nMRlalaled A2TUN 0009.59 10654 17631 5,916,20 5.8413.20 -1,82822 -2125.10 5,938449.0 490449.40 140 1'M2 MW➢(5) First Clean Survey j 8820.58 105.91 171.59 5,91754 5,83].54 -1852.78 -2111.90 5908.42) 14 490.452.51 14.63 1,85238 MWD (5) 6.85159 103.32 171.08 5,603.71 5.829.71 -1,862.50 -197.64 5,998,393.43 480,49!65 040 1,04,6 MWO(5) 8,98162 93.23 170.74 5,80.04 5,82384 -19110 -19320 5.998381 .32 498,48129 1413 1.9116 MWD (5) 701574 95.60 1[579 5.099.42 5,819.42 -1914.]1 -18631 5.890, 328. Y2 495,40.1] 1].]9 1,944,]1 MAK) (5) j 7.040.55 92.18 15915 5.07M 5,0178 -1,9039 -9086 5,88B,3W.0 499.47581 30.18 1,90.29 MWD (5) 7,07079 92.0 15019 5,80m 5,81639 -1.956.24 -16738 5.902760 49848].08 10.6 199824 MWD(5) t 7,10069 Mile 151.05 5,8058 iselsm -2023.0 -154.11 5,998,249.0 498,50035 19.43 2,023.00 k (N 7,12861 91 4] 15029 5891.18 5,81510 -2,04731 -140,43 5,996.2250 49851402 536 3,04734 MND(5) ],16]8 W67 WA2 5894.59 5814.59 3,074.19 -low eM.19074 490.53 % 1252 2,074.19 MWD(5) 7,10.93 94.02 14574 5,883,37 5.81437 -2,098.87 -10729 5,96,1740 4)OM715 1146 2,00.87 MND(5) ],220.56 8155 143.19 5,0180 5,811.88 -2123.78 4`9 SO 5.998148.15 480,584.94 1155 2123.78 MM (5) ],254.4] 0.65 114.10 5,01.82 5,811.82 -2,15107 X41 5.898121.6 187,50.0 900 215107 MM (6) 7.206.54 91.44 11652 5,016 5.811.6 2,178.61 51.73 5,0806.32 498,62.0 Wee 2178.81 MWD (5) flMf4017 4:29:3" Pepe 3 COMPASS 5000.14 EIdW 85 Conoo3Phillips Company: ConocoPhllllps(Alaskal Inc.-Kup2 Pmjed: Kupamk River Unit Site'. Kupamk 3H Pad Were 31126 Weilnin, 3H261.1 Design: 3H-26LI ConocoPhillips Definitive Survey Report Coal Co-ordinate Reference: Mil 311-26 TN Reference: 31-26 a 80MOusR (31-26) MD Reference: 31-26 C 80.00usR (31426) North Reference: True Survey Calculation Ma41o6: Minimum Curvature Inawl EDT Alaska Sandbox Moral Section Suney Tool Name Annotation I'd 2202.00 ..D (5) zoom MWO(5) 2249.53 all 22]9.55 MVvn(5) z3W.56 vival 233130 MWD(51 2.36063 holill 23903 MND(5) 2,42013 MWD(5) 243.% MM (5) z4ai am (5) 253.3 a1W0(6) z53.94 MWD(5) 253.02 MWD(5) 259].33 WIVD(5) 262'/93 kmal 265785 04070(51 23167 MND(5) 2,71107 MM (5) 2,751.91 MM (5) 2.78171 "D(5) 201004 MWD(5) z840.19 am (5) 2807.45 all (5) 238.79 MWD(5) 2929.20 04.40(51 29W34 MND(5) 2,98581 MJUD(5) 3,01833 MND(5) 3,0475a MWD(5) 3 0734 MWD (5) 811120 f7 4 29 36P Face 4 COMPASS 5000.14 8.11d 85 Map MD Inc AU TVD TVD55♦Nh9 ♦EI -W NoWrtlp Eng OLS (Malt) (°) i°I idea) (am) luac) talent int (R) (°noor) ],315]8 89.11 14] ]3 5.891]6 5.811.16 -2202.00 -3532 5,998070.92 49861910 987 1,30.5.45 W65 15165 5.892.44 5.81240 3,221`.61 -MM 5,980,045.32 498634.W 1321 7339 93 90.43 15560 5,89264 5.81264 -2,24953 -948 599¢02340 498,644.92 1].]0 ].402.05 will 163.19 5,3167 5,81167 -2.27950 1.81 5,997,99337 499,656.21 2495 ].430.09 will 16503 509340 5,8lD40 -2,30.55 924 5.997,965 37 490,681.64 1054 1.455.43 91.18 169.33 5,83.53 5,803.53 -2,331.30 14.84 5,077,9413 498,6363 13.11 7,485.11 9224 173.05 5,W&M 5,00.48 3,33.63 19.3 5,37,912.39 490,67142 14o 1,51533 074 17498 5,80110 5,31.70 -2393.69 Z2.0 5,31.8335 498.976.40 6.3 7,54551 87M 174.07 5,83.24 5,38.24 -2,4M,73 2478 5,3],84.20 498,8]815 11.01 ],5]5.96 3.16 17386 5,83.41 5,03.47 -245083 21.84 569].31 .95 498.6321 390 1,3550 3.13 171.38 5.807.94 5,010.94 -243.26 3163 5,997,]91.3 43,63,86 10.84 1.3564 3.3 1386 5.892.]9 5812.79 -2,5389 W80 5,907,]3 .07 4983115 869 ],607.44 06.3 16621 5.894.49 5.81449 -2.530.94 43.20 5,907,)34.07 4983155 8]2 7,69539 3.81 16885 anal 5.81821 -2.560.02 WAS 5,99],704.91 498,704 49 207 7.75.27 07.87 171.51 5,3165 5,81765 -2,597.33 5575 5.991.67562 4987l0.3 15.81 ],]5664 82.31 17884 awda 5,617.65 -2o7M 334 5,991814.3 49&]126] 2819 ],]8594 50.12 18072 5,89].03 5,817.03 -2,657.85 W45 5,997,61510 490,11278 9.65 ],815]0 87M 18294 5,8W.53 5,81753 -2,881.67 51.W 5,37,585.29 498,]11.82 10.43 ],845]1 0123 18338 5,03.19 5,01879 -2.71153 So 5,37,555.43 498)101] 279 7.88034 Man 181.94 S,9l 5,=74 -275182 M. 5937,52104 43,70675 1341 191057 07.15 190.49 5902.47 AMA] -2181.71 41.61 5,997p91.M 498,70191 flW 7,939.3 88.85 13.07 5.93.23 SOM.M -201020 41.57 5.997,483.11 49868597 12]] 7,970.42 8].54 192.3 5,9W.W allow -z840.19 34.07 5,991,432.79 498.09 25 540 awn all 15031 5.905.64 5,825.64 -283.45 29.19 5.997.43.51 43,63.40 994 0,0:.4.1] 3.61 10926 5.93191 5.82].97 3,850.79 24]3 5,991,374.19 49867842 357 plan in 99 18830 5,93997 5.82991 -2,92928 1940 5,99].343.71 49807380 529 80WA5 87.85 187.18 5,91129 5,83129 -295834 1543 5,991,31465 4986371 5.07 8119.16 91.17 18132 5,911,54 5,83154 2,9381 1181 8077,20718 490,665.08 11.57 8148.92 9335 190.47 5,910.65 5,030.35 y01633 824 5,07],2076] 490.6623 ].3 8.13.33 W68 185.22 5,909,71 53071 3.441`8 5.04 5997.225.47 490,63.31 451 8210.33 9181 18725 55,7154 5,82154 -3,077M 179 5,99].195.6] 498.6&04 7.36 Moral Section Suney Tool Name Annotation I'd 2202.00 ..D (5) zoom MWO(5) 2249.53 all 22]9.55 MVvn(5) z3W.56 vival 233130 MWD(51 2.36063 holill 23903 MND(5) 2,42013 MWD(5) 243.% MM (5) z4ai am (5) 253.3 a1W0(6) z53.94 MWD(5) 253.02 MWD(5) 259].33 WIVD(5) 262'/93 kmal 265785 04070(51 23167 MND(5) 2,71107 MM (5) 2,751.91 MM (5) 2.78171 "D(5) 201004 MWD(5) z840.19 am (5) 2807.45 all (5) 238.79 MWD(5) 2929.20 04.40(51 29W34 MND(5) 2,98581 MJUD(5) 3,01833 MND(5) 3,0475a MWD(5) 3 0734 MWD (5) 811120 f7 4 29 36P Face 4 COMPASS 5000.14 8.11d 85 ConoCOPhillip5 ConocoPhillips Definitive Survey Report Company: CorocoPhl9lps(Alaska)ioc-Kup2 Local Coordinate Reference: NMII 314-26 Pretest: Kupamk River Unit Pro Rehrence: 311-26 Q SOnOustl(3W26) SRe: Kumbuk 3H Pad MD Reference: 3H-26 Q 80.00usft(311-28) Well: 311-26 North Reference: True Wellbore: 311-2611 Survey Calculation Method: Minimum Curvature Design: 3H26L1Dma6a5e. EaMhg EDTAiasha sandbox Annotation 5R IsI {K�6s 8/112017 4:n 3l1W Page 5 COMPASS 5000.14 6ui1d85 Map Map WMI MD (uoft) Inc l°I Aai 1"1 ND loan Miss lusrt) *NIS (use) +E/ -W luau) Normal, EaMhg OLS ruga) Sainan survey Tool No. (RI (fq Oil 824041 92.45 189.29 5.90592 5025.42 3,10708 -2.53 5997,16593 49805172 7.11 3,10.08 MWD(5) 8,270.33 9301 19310 5.904.98 5,824.98 -3,136.39 $34 5,931,133.62 498,84.5.91 1287 3136.39 MAIDS) Amass W37 19306 5904.09 5,82408 y165.80 -15.17 5997,10TZ2 498,6390 8.04 3,1aca0 waS(5) am.29 91.01 194.88 5.903.M Son 72 3,194.89 -2233 5.997,0&N 49863193 513 3.181.60 MND (5) 8350.21 saw 196.39 5,903.25 5.82335 3,223.`.4 C3031 5.991104952 498823.92 582 3.22350 MW0(5) 0,390.0 9138 191.0 5902.60 5.=65 3,252.12 38.90 5,99,02091 499,81533 282 3252.12 MWD (6) 8,421.51 91.211 19778 5902.00 5.822.00 3,28114 47M 5.996,991 SO 490,606.24 263 328114 MWD (6) 8450.89 0.18 199.39 5,960.80 5,920.1.4 3.30.91 S765 5,990,988.13 493,596.56 1001 3,390.91 MWD(5) 8.480.57 084 2(11.36 5.898.70 5,016.70 -3,337,67 b7,95 5.9.4,935.39 498,58025 6.0 3.33197 MhDS) 851084 90.40 20321 5,896.26 501626 -3,355.39 -7934 569&90.90 490,57487 836 3,365.39 MWD(6) 81539.01 93.51 24.93 5,81 5,81397 3,39193 41.22 5,90,881.13 498.562.98 899 3,39193 MM (5) 8,57050 9396 20585 5,391.90 5.811.90 341959 -104.36 5,990,853.47 49854904 324 3,419.59 MW0(5) soul 05 89.96 290.34 5091.10 5,611.10 3,447.85 -11790 5,990,825.22 499,536.30 16M 3.447.85 8109(5) 8,630.19 91.72 206.42 5,89101 5,81101 3,473.34 -13027 5,99l73 496,523.93 1046 3473.34 NMl 8,W021 93. 2(525 5,88968 5,09089 -3,500.33 -14333 5991 490,51085 &88 3.500.33 MWD(5) 8,69326 9783 21622 5.8W.75 5805 75 -3,527,27 -15&32 5,990,745.81 490.49787 15.25 3.527.27 MAV(5) 8,720.38 10070 X534 5.881.91 5,80191 3,5530 -169.49 5996,719.11 498,484.71 954 3,553.92 am (5) 8750.65 10233 10.99 5,875.85 5.79585 3,51.45 48042 5.995,69164 498,473.76 3074 3,58105 MWD (6) 8715.37 10368 218.68 5,870.21 5,19128 3W378 48836 5.990,66931 4984&.02 3&90 3,53]8 MWD (5) 080.38 104.31 288.81 5,85423 5,184.23 3,62524 -20065 5,90847.86 40,453,53 &05 3825.24 MWD(5) 0,830.17 104.14 2110li 989075 5.M.75 3,550.24 -21505 5,956.622.0 490,488.13 745 365034 Wools) 6,830.02 10475 2110 5.84916 5,75.18 -3,81470 -23037 5,996.59840 498.423.00 65 3,61070 WYKi(5) 8,89000 10475 21309 5,84152 5761.52 -3,6099 -246.20 5998574.12 49840.97 000 3,698.99 PROJECTEDto TD Annotation 5R IsI {K�6s 8/112017 4:n 3l1W Page 5 COMPASS 5000.14 6ui1d85 �7 AT BA ER PRINT DISTRIBUTION LIST F�U aGEcom!,P S any COMPANY ConocoPhillips Ala CEIVED WELL NAME 3H-261,1-01 AUG 2 8 2017 FIELD Greater Kuparuk Are aA n n r►vtav611( %J COUNTY North Slope Borough BHI DISTRICT Alaska 21 7088 28546 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 700 G Street. DATA LOGGED Anchorage, Alaska 99510 9 / N. /201'1 to acknowledge receipt of this data. M. K. BENDER LOG TYPE - RES LOG DATE August 4, 2017 AUTHORIZED BY Patrick Rider EMAIL Patrick Rider(cilbakerhughes. com TODAYS DATE August 24, 2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: - COMPANY ADDRESS (FEDEX PALL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V 1 I3P North Slope. EOA, PBOC, PRB-20 (Office 109) D&G WO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage. Alaska 99506 FIELD/ FINAL CD/DVD FINAL PRELIM (las, dlis, PDF, META, SURVEY I REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES # OF COPIES 4 4 4 4 J; 4 2 ConocoPhillips Alaska Inc. 0 0 0 0 0 Attn: Tom Osterkamp ATO 3-344 700 G Street Anchorage, AK 99510 3 F.xxonMobil, Alaska 0 0 0 0 0 Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska -AOGCC 0 0 Attn: Makana Bender 333 W. 7th Ave, Suite 100 ,Anchorage, Alaska 99501 5DNR -Division ofOil&Gas *** 0 0 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 99509 TOTALS FOR THIS PAGE: 0 2 3 3 0 ConocoPhillips SECEIVED AUG 2 8 2017 AOGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H -26L1-01 50-103-20208-61 Baker Hughes INTEQ Definitive Survey Report 11 August, 2017 BA ER I UGHES a GE company 21 7088 28546 '. ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 3H-26 Project Kupamk River Unit TVD Reference: 31-1-26 @ 80.00usft (31-1-26) Site: Kupamk 3H Pad MD Reference: 31-1-26 @ 80.00usft (31-1-26) Well: 31-1-26 North Reference: True Wellbore: 31-1-2611 Survey Calculation Method: Minimum Curvature Design: 31-1-2611 - Database: EDT Alaska Sandbox 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) Tie On Depth: 6,769.74 Using Well Reference Point Map Zone: Alaska Zone 04 -N/-S Using geodetic scale factor Well ----------------- 3H-26 _.. _,. _... .,. .. ., ___....... Well Position +N/ -S 0.00 usft Northing: 6,000,272.70usft +E/.W 0.00 usft Easting: 498,654.81 usft Position Uncertainty 0.00 usft Wellhead Elevation: usft Wellbore 3H -26L1-01 Magnetics Model Name Sample Date Declination (`) BGGM2017 9/1/2017 17.42 Design 31-1-261-1-01 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,769.74 Vertical Section: Depth From (TVD) -N/-S +E/ -W (usft) (usft) (usft) 80.00 0,00 0.00 Latitude: Longitude: Ground Level: Dip Angle l�) 60.95 Direction (1) 180.00 SA (EH {UGHES 70° 24'43,124 N 150° 0'39,435 W 0,00 usft Field Strength (nT) 57,487.12 81112017 4:29:36PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips 6P1 <ER ES ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit MD Reference: Site: Kuparuk 3H Pad True - Well: 3H-26 Database: Wellbore: 31-1-2611 7/30/2017 Design: 3H-2611 TVDSS Survey Program +E/•W Date 8/4/2017 From To Section (usft) (usft) Survey(Welibore) 121.00 5,974.70 3H-26 (311-26) 6,229.65 6,320.45 3H-261-1 MWD4NC (311-2617) 6,350.41 6,769.74 311-2617 MWD (311-2617) 6,772.00 6,860.12 311-261-1-01 MWD -INC (3H-2611-01) 6889.59 8,860.02 31H-261.1-01 MWD (311-2611-01) Survey Local Co-ordinate Reference: Well 3H-26 TVD Reference: 31-1-26 Q 80.00usft(311-26) MD Reference: 3H-26 @ 80.00usft(31-1-26) North Reference: True - Survey Calculation Method: Minimum Curvature Database: EDT Alaska Sandbox Tool Name Description MWD MWD - Standard MWD -INC -ONLY MWD -INC -ONLY -FILLER MWD MWD - Standard MWD -INC ONLY MWD -INC -ONLY -FILLER MWD MWD - Standard Survey Survey - Start Data End Date 1/12/2001 7/23/2017 7/24/2017 7/24/2017 7/27/2017 7/28/2017 7/29/2017 7/28/2017 7/30/2017 Annotation _ TIP KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth First Clean Survey 8/11/2017 4.29:36PM Page 3 COMPASS 5000.14 Build 85 Map Map Verfical MD Inc Azi TVD TVDSS +NIS +E/•W Northing Easting DLS Section Survey Tool Name - (usft) ( (°) (°) (usft) ft (usft) (waft) (usft) (ft) (ft) (°1100') (ft) 6,769.74 9733 17694 5,954.42 5,874.42 -1,707.08 -211.68 5,998,565.82 498,442.84 5.97 1,707.08 MWD(3) 6,772.00 97.43 177.07 5,954.13 5,874.13 -1,709.32 -211.56 5.998.563.59 498,442.96 7.22 1,709.32 MWD -INC _ONLY (4) 6,801.88 101.88 176.90 5.949.12 5,869.12 -1,738.73 -210.01 5,996,534.18 498,444.50 14.90 1,738.73 MWD -INC -ONLY (4) 6,83177 105.14 176.90 5,942.14 5,862.14 -1,767.75 -208.44 5,998.505.17 498,446.07 10.91 1,767.75 MWD -INC -ONLY (4) 6,860.12 106.15 176.50 5,934.49 5,854.49 -1,795.0. -206.87 5,998.477.92 498,447.64 3.81 1,795.0 MWD-INC_ONLY (4) 6,889.59 106.54 176.31 5,926.20 5,846.20 -1,823.22 -205.10 5,998,449.69 498,449.40 1.46 1823.22 MWD (5) 6,920.56 105.91 171.58 5,917.59 5,837.54 -1,852.78 -201.96 5.998,420.14 498,452.54 14.80 1,852.78 MWD (5) 6,951.59 103.32 171.89 5,909.71 5,829.71 -1,882.50 -197.64 5,998,390.43 498,456.85 8.40 1,882.50 MWD(5) 6,981.62 99.23 170.74 5,903.84 5,823.84 -1,911.60 -193.20 5,998,361.32 49Q461.29 14.13 191180 MWD (5) 7,015.74 95.66 165.79 5,899.42 5,819.42 -1,944.71 -186.31 5,998,328.22 498,468.17 17.79 1.944.71 MWD (5) 7,040.55 92.18 159.15 5,897.72 5,817.72 -1,968.29 -178.86 5,998,304.63 498,475.61 30.16 1,968.29 MWD (5) 7,070.79 92.89 156.19 5,896.38 5,816.39 -1,996.24 -167.38 5,998,276.69 498,487.08 10.06 1,996.24 MWD (5) 7,100.69 90.18 15105 5,895.58 5,815.58 -2,023.00 -154.11 5,998,249.93 498,500.35 19.43 2,023.00 MWD (5) 7,128.61 91.47 150.29 5,895.18 5,815.18 -2.047.34 -140.43 5,998,225.59 498.514.02 5.36 2,047.34 MM (5) 7,160.16 90.67 146.42 5,894.59 5,814.59 -2,074.19 -123.89 5,998,198.74 496,530.56 12.52 2,074.19 MWD (5) 7,189.93 94.02 145.74 5.893.37 5,813.37 -2,098.87 -107.29 5,998,174.06 498.547.15 11.48 2,098.87 MWD (5) 7,220.58 91.56 143.19 5,891.88 5,81188 -2,123.78 -89.50 5,998,149.15 496,564.94 11.55 2,123.78 MWD(5) 7,254.47 88.65 144.10 5,891.82 5,811.82 -2.151.07 69.41 5,998,121.86 498,585.02 9.00 2,151.07 MWD(5) 7.285.54 91.44 14652 5,891.80 5,811.80 -2,17661 -5173 5,998,096.32 498,602.69 11.89 2,176.61 MWD (5) Annotation _ TIP KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth First Clean Survey 8/11/2017 4.29:36PM Page 3 COMPASS 5000.14 Build 85 r ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 311-26 Project: Kuparuk River Unit TVD Reference: 311-26 @ 80.00usft (31-1-26) Site: Kuparuk 3H Pad MD Reference: 311-26 @ 80.00usft (31-1-26) Well: 311-26 North Reference: True Wellborn: 31-1-2611 Survey Calculation Method: Minimum Curvature Design: 3H -26L1 Database: EDT Alaska Sandbox Survey 871112017 4.'29.36PM Page 4 Annotation COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD NDSS -N/-S •El -W Northing Eastin g DLS Section survey Tool Name (usft) (°) V) (usft) (usft) (usft) (usft) (ft) (ft) (7100') (ft) 7,31578 88.71 147.73 5,891.76 5,811.76 -2,202.00 ]5.32 5,998,070.92 498,619.10 9.87 2,202.00 MWD (5) 7,345.45 88.65 151.65 5,892.44 5,812.44 -2,227.61 -20.35 5,998,045.32 498,634.06 13.21 2,227.61 MWD (5) 7.369.93 90.43 155.60 5,892.64 5,812.64 -2,249.53 5.48 5,998,023.40 498,644.92 17.70 2,249.53 MWD (5) 7,402.05 93.01 163.19 5,891.67 5,811.67 -2,279.56 1.81 5,997,993.37 498,656.21 24.95 2,279.55 MWD (5) 7,430.09 92.18 166.03 54890.40 5,810.40 -2,306.56 9.24 5,997,966.37 498,653,64 - 10.54 2,306.55 MWD(5) 7,455.43 91.78 169.33 5,889.53 5,809.53 -2,331.30 14.64 5,997.941.63 498,659.03 13.11 2,331.30 MWD (5) 7,485.11 92.24 173.65 5,888.48 5,808.48 -2,360.63 19.03 5,997,912.30 498,673.42 14.63 2.360.63 MWD (5) 7,515.33 90.74 174.98 5,887.70 5,807.70 -2,390.69 22.03 5,997,882.25 498,676.40 6.63 2,390.69 MWD (5) 7,545.51 87.20 174.56 5,888.24 5,808.24 -2,420.73 24.78 5,997,852.20 498,679.15 11.81 2,420.73 MWD (5) 7,575.95 88.16 173.86 5,889.47 5,809.47 -2,450.99 27.84 5,997,821.95 498,682.21 3.90 2,450.99 MWD (5) 7,605.50 86.13 171.38 5,890.94 5,810.94 -2,480.26 31.63 5,997,792.69 498,685.99 10.84 2,480.26 MND (5) 7,63564 86.85 168.86 5,892.79 5,812.79 -2,509.89 36.80 5,997,763.05 498,691.15 8.69 2,509.89 MWD (5) 7,665.44 86.59 166.27 5,894.49 5,814.49 -2,538.94 43.20 5,997,734.0 498,697.55 8.72 2,536.94 MWD (5) 7,695.39 86.81 166.85 5,896.21 5,816.21 -2,568.02 50.15 5,997,704.92 498,704.49 2.07 2,568.02 MND (5) 7,725.27 87.67 171.51 5,897.65 5,817.65 -2,597.33 55.75 5,997.675.62 498,710.09 15.84 2,597.33 MWD (5) 7,756.04 92.31 178.84 5,897.66 5,817.66 -2,627.96 58.34 5,997,644.99 498,712.67 28.19 2,627.96 MWD (5) 7,785.94 90.12 180.72 5,897.03 5,817.03 -2,657.85 58.45 5,997,615.10 498,712.78 9.65 2,657.85 MWD (5) 7,81578 87.94 182.94 5,897.53 5,817.53 -2,687.67 57.50 5,997,585.29 498,711.82 10.43 2,687.67 MWD (5) 7,845.71 87.23 183.38 5,898.79 5,818.79 -2,717.53 55.85 5,997,555.43 498,710.17 2.79 2,717.53 MWD (5) 7,880.34 86.31 187.94 5,900.74 5,820.74 -2,751.92 52.44 5,997,521.04 498,706.75 1341 2,751.92 MWD (5) 7,910.57 87.15 190.49 5,902.47 5,822.47 -2,781.71 47.61 5,997,491.26 498,701.91 8.87 2,781.71 MWD (5) 7,939.69 89.85 193.05 5,903.23 5,823.23 -2,810.20 41.67 5,997,462.77 498,695.97 12.77 2,810.20 MWD (5) 7,970.42 87.79 192.09 5,90'86 5,823.86 -2,840.19 34.99 5,997,432.79 498,689.28 7.40 2,840.19 MWD (5) 8,000.30 85.41 190.31 5.905.64 5,825.64 -2,869.45 29.19 5,997,403,54 498.683.48 9.94 2,869.45 MWD (5) 8,030.17 65.61 189.26 5,907.97 5,827.97 -2,898.79 24.13 5,997,374.19 498,678.42 3.57 2,898.79 MWD (5) 8,061.09 86.99 188.38 5,909,97 5,829.97 -2,929.28 19.40 5,997,343.71 498,673.68 5.29 24929.28 MWD (5) 8,090.45 87.85 187.18 5,911.29 5,831.29 -2,958.34 15.43 5,997314.65 498,669.71 5.03 2,958.34 MWD (5) 8,119.16 91.17 187.32 5,911.54 5,831.54 -2,986.81 11.81 5,997,286.18 498,666.08 11.57 2,986.81 MAD (5) 8,148.92 93.35 186.47 5,910.35 5,830.36 -3,016.33 8.24 5,997,256.67 498662.50 7.86 3,016.33 MWD (5) 8,180.33 92.68 185.22 5,908.71 5,82871 -3,047.54 5.4 5,997,225.47 498,659.31 4.51 3,047.54 MWD(5) 8,210.33 91.61 187.25 5,907.54 5,827.54 -3,077,34 1.79 5,997 195.67 498656.04 7.36 3077.34 MWD (5) 871112017 4.'29.36PM Page 4 Annotation COMPASS 5000.14 Build 85 Survey Well 3H-26 31-1-26 @ 80.00usfl (3H-26) 31-1-26 @ 80.00usft (31-1-26) True Minimum Curvature EDT Alaska Sandbox ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Project: Kupanik River Unit TVD Reference: Site: Kupamk 3H Pad MD Reference: Well: 31-1-26 North Reference: Wellbore: 31-1-261-1. Survey Calculation Method: Design: 3H -26L1 Database: Survey Well 3H-26 31-1-26 @ 80.00usfl (3H-26) 31-1-26 @ 80.00usft (31-1-26) True Minimum Curvature EDT Alaska Sandbox Annotation BVLEGHES 4 811112017 4:29:36PM Page 5 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc AN TVD TVDSS -N/-S +EI -W DLS (usft) (°) (•) (usft) (usft) (usft) (usft) Northing Easting (=DLS Section Survey Tool Name (ft) (ft). (ft) 8,240.41 92.46 189.29 5,906.42 5,82642 3,107.08 -2.53 5,997,165.93 498,651.72 7.11 3.107.08 MWD (5) 8,270.33 93.04 193.10 5,904.98 5,824.98 -3,136.39 -3,34 5,997,136.62 498,645.91 12.87 3,136.39 MWD (5) _ 8,300.54 90.37 193.08 5,904.08 5,824.08 -3,165.80 -15.17 5,997,107.22 498639.07 8.84 3,165.80 MWD (5) 8,330.29 91.01 194.66 5.903.72 5,823.72 -3194.68 -22.30 5,997,078,34 498,631.93 5.73 3,194.68 MWD (5) 8,360.21 90.80 196.39 5,903.25 5,823.25 -3,223.50 -30.31 5,997649.52 498,623.92 5.82 3,223.50 MWD (5) 8,390.09 91.38 197.00 5,902.68 5,822.68 -3,252.12 -38.89 5.997,020.91 498,615.33 2.82 3,252.12 MWD (5) 8,420.51 91.20 197.78 5,902.00 5,822.00 -3,281.14 47.98 5,936,991.90 498,606.24 2.63 3,281.14 MWD (5) 8,450.89 93.78 199.39 5,900.68 5,820.68 -3,309.91 57.65 5,996,963.13 498,595.56 10.01 3,309.91 MWD (6) 8,480.57 93.84 201.36 5,898.70 5,818.70 3,337.67 57.% 5,996.935.38 498,586.25 6.63 3,337.67 MWD (5) 8,510.64 95.48 203.27 5,896.26 5,816.26 -3,365.39 49.34 5,996,907.66 498,574.87 6.36 3,355.39 MWD (5) 8,539.81 93.51 204.96 5,893.97 5,813.97 -3,391.93 -91.22 5,996,881.13 496,562.98 B.89 3.391.93 MWD (5) 8.570.50 93.96 205.85 5,891.98 5,811.98 -3,419.59 -104.% 5,996,853.47 498,549.84 3.24 3,419.59 MWD (5) 8,601.85 88.96 205.34 5,891.18 5,811.18 -3,447.85 -117.90 5,996,825.22 498.536.30 16.03 3,447.85 MWD (5) 8630.19 91.72 206.42 5,891.01 5,811.01 $473.34 -130.27 5,998799.73 498,523.93 10.46 3,473.34 MWD (5) 8,660.21 93.35 205.25 5,889.6B 5,809.68 -3,500.33 -143.33 5,998772.74 498,510.86 6.68 3,500.33 MWD (5) 8,690.26 97.83 206.22 5.886.75 5,806.75 -3,527.27 -156.32 5,998745.81 498,497.87 15.25 3,527.27 MWD (5) 8,720.38 100.70 206.34 5,881.91 5.801.91 -3,553.92 469.48 5,996,719.17 498,48471 9.54 3,553.92 MWD (5) 8,750.65 102.33 196.99 5,875.85 5,795.85 -3,581.45 -180.42 5,998691.64 498,473.76 30.74 3.581.45 MWD (5) 8,775.37 103.68 206.68 5,870.27 5,790.28 -3,603.78 -189.36 5,998669.31 498,464.82 38.58 3,603.78 MWD (5) 8,800.36 104.31 208.81 5,864,23 5.784.23 -3,625.24 -200.65 5,996,647.86 498,453.53 8.65 3,625.24 MWD (5) 8,830.17 104.74 211.06 5,856.75 5,776.75 -3,650.24 -215.05 5,998622.86 498,439.13 7.45 3,650.24 MWD (5) 8,060.02 104.75 213.09 5.849.16 5,769,16 -3,674.70 -230.37 5.996.598.40 498,423.80 6.58 3,674.70 MWD (5) 8890.00 104.75 213.09 5,841.52 5,761.52 -3,698.99 -246.20 5,9%,574.12 498,407.97 oco 3,698.99 PROJECTED to TD Annotation BVLEGHES 4 811112017 4:29:36PM Page 5 COMPASS 5000.14 Build 85 RECEIVE'') AUG 2 1 2017 AOGCC BA ER F UGHES a GE company To: Letter of Transmittal Date: DATA LOGGCD August 18, 2017 '9a.8�20i1 g :d. K. BENDER Makana Bender AOGCC 333 West 711 Ave, Suite 100 Anchorage, Alaska 99501 From: Yosha Ragbirsingh / Michael Soper Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3H -26L1 21 70 87 3H -26L1 -02q 2 1 7 0 88 RHO O 3H -26L1-02 2 1 7 0 5 0 28 5 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.Ragbirsingh@BHGE.com ConocoPhillips RECEIVED AUG 2 1 2017 A®GCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H -26L1-01 Baker Hughes INTEQ Definitive Survey Report 11 August, 2017 BAER UGHES a GE company 21 7088 28510 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kuparuk 3H Pad Well: 31H-26 Wellbore: 31H-261-1 Design: 31H-261-1 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 3H-26 ConocoPhillips Definitive Survey Report BA ER $ UGHES .�Eo�.m Local Co-ordinate Reference: Well 311-26 Model Name Sample Date Declination l°) TVD Reference: 3H-26 @ 80.00usft (3H-26) BGGM2017 9/1/2017 17.42 MD Reference: 3H-26 @ 80.00usft (3H-26) 3H-2611-01 North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT Alaska Sandbox Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Position +N/ -S 0.00 usft Northing: 6,000,272.70 usft +E/ -W 0.00 usft Easting: 490,654.81 usft Position Uncertainty 0.00 usft Wellhead Elevation: usft Wellbore 3H -26L1-01 Magnetics Model Name Sample Date Declination l°) BGGM2017 9/1/2017 17.42 Design 3H-2611-01 Audit Notes: Latitude: Longitude: Ground Level: Dip Angle (% 80.95 Version: 1 0 Phase: ACTUAL Tie On Depth: 6,769.74 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 80.00 0.00 0.00 180.00 70° 24'43.124 N , 150° 0'39.435 W 0.00 usft Field Strength (nT) 57,487.12 811112017 4:29:36PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips 6aCLR 0 ConocoPhillips p UGHES Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 3H-26 Project: Kuparuk River Unit TVD Reference: 31-1-26 @ 80.00usft (31-1-26) Site: Kuparuk 3H Pad MD Reference: 31-1-26 @ 80.0Ousft (31-1-26) Well: 311-26 North Reference: True Wellbore: 31-1-261-1 Survey Calculation Method: Minimum Curvature Design: 31-1-261-1 Database: EDT Alaska Sandbox Survey Program Date 8/4/2017 T From To Survey Survey (usR) (usR) Survey (Wellbore) Tool Name Description Start Date End Date 121.00 5,974.70 31-1-26 (3H-26) MWD MWD -Standard 1/12/2001 t 6,229.65 6,320.45 31-1-261-1 MWD-INC (31-1-261-1) MWD -INC -ONLY MWD -INC -ONLY -FILLER 7/23/2017 7/24/2017 6,350.41 6,769.74 31-1-261-1 MWD(314-261-1)MWD MWD -Standard 7/24/2017 7/27/2017 list 6,772.00 6,860.12 3H-2611-01 MWD-INC(3H-2611-01) MWD -INC ONLY MWD -INC ONLY_FILLER 7/28/2017 7/29/2017 6,889.59 8,860.02 3H -26L7-01 MWD(3H-261-1-01) MWD MWD -Standard 7/28/2017 7/30/2017 Survey MD Inc Azl TVD TVDSS +N/•S +EI -W Map Map VerticalDL3 (uaR) (°) (°) (usR) (usR) (usR) (usR) Northing Eastin9 (°I100') Section Survey Tool Name Annolati0n (R) (R) (R) 6,769.74 97.33 176.94 5,954.42 5,874,42 -1,707.08 -211.68 5,998,565.82 498,442.84 5.97 1,707.08 MWD (3) TIP 6,772.00 97.43 177.07 5,954.13 5,874.13 -1,709.32 -211.56 5,998,563.59 498,442.95 7.22 1,709.32 MWD -INC ONLY(4) KOP 6,801.88 101.88 176.90 5,949.12 5,869.12 -1,738.73 -210.01 5,998,534.18 498,444.50 14.90 1,738.73 MWD -INC _ONLY (4) Interpolated Azimuth 6,831.77 105.14 176.90 5,942.14 5,862.14 -1,767.75 -20844 5,998,505.17 498,446.07 10.91 1,767.75 MWD -INC ONLY(4) Interpolated Azimuth 1 I 6,860.12 106.15 176.50 5,934.49 5,854.49 -1,795.00 -206.87 5,998,477.92 498,447.64 3.81 1,795.00 MWD-INC_ONLY (4) Interpolated Azimuth 6,889.59 li:,eu 176.31 5,926.20 5,84620 -1,823.22 -205.10 5,998,449.69 498,449.40 1.46 1,623.22 MWD(5) First Clean Survey 6,920.56 105.91 171.58 5,917.54 5,83754 -1852.78 -201.96 5,998,420.14 498,452.54 14.80 1,852.78 MWD (5) 6,95159 103.32 171.89 5,909.71 5,829.71 -1,882.50 -197.64 5,998,39043 498,456.85 840 1,882.50 MWD (5) tttkP 6,981.62 99.23 170.74 5,903.84 5,823.84 -1,911.60 -193.20 5,998,361 32 498,461.29 14.13 1 911 60 MM (5) 7,015.74 95.66 165.79 5,899.42 5,819.42 -1,944.71 -186.31 5,998,328.22 498,468.17 17.79 1,944.71 MWD (5) 7,040.55 92.18 159.15 5,897.72 5,817.72 -1,968.29 -178.86 5,998,304.63 498,475.61 30.16 1,968.29 MM (5) I 7,07079 92.89 156,19 5,896.38 5,816.39 -1,996.24 -167.38 5,998,276.69 498,48708 10.06 1,99624 MWO(5) 7,100.69 90.18 151.05 5,895.58 5,815.58 -2,023.00 -154.11 5,998,249.93 498,500.35 19.43 2,02300 MWD (5) 7,128.61 91.47 150.29 5,895.18 5,815.18 -2,047.34 -140.43 5,998,225.59 498,514.02 5.36 2,047.34 MM (5) ' 7,160.16 9067 14642 5,894.59 5,814.59 -2,074.19 -123.89 5,998,198.74 498,530.56 12.52 2,074.19 MWD (5) 7,18993 94.02 14574 5,893.37 5,813.37 -2898.87 -107.29 5,998,174. D6 498,547.15 1148 2,098.87 MWD (5) 7,220.58 91.56 143.19 5,891.88 5,811.88 -$123.78 -89.50 5,998,149.15 498,564.94 11.55 2,123.78 Mm (5) 7.254.47 88.65 144.10 5,891.82 5,811.82 -2,151.07 -6941 5,998,121.86 498,585.02 9.00 2,151.07 MM (5) 7,285.54 91.44 146.52 5,891.80 5,811.80 -2,176.61 -51.73 5,998,096.32 498.602.69 11.89 2,176.61 MM (5) 8/11/2017 4:29:36PM Page 3 COMPASS 5000.14 Build 85 Survey MD ConocoPhillips Azi ConocoPhillips Definitive Survey Report +N/ -S Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 31 Project: Kuparuk River Unit TVD Reference: 31-1-26 @ e0.00usft (31-1-26) site: Kuparuk 3H Pad MD Reference: 31-1-26 @ 80.00usft (31-1-26) Well: 31-1-26 North Reference: True Wellbore: 31-1-2611 Survey Calculation Method: Minimum Curvature Design: 31-1-2611 Database: EDT Alaska Sandbox Survey MD Inc Azi ND NDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (°) (°) (usft) (usft) (usft) (usft) Easting (°/100') Section Survey Tool Name (ft) (ftNorthing e) 7,315.78 88.71 14].]3 5,891.]6 5,811.76 -2,20200 -35.32 5,998,070.92 498,8, 619.10 9.87 2,202.00 MWD (5) 7,345.45 8865 151.65 5,892.49 5,812.44 -2,22761 -20.35 5,998,045.32 498,634.06 13.21 2,22]61 MM (5) 7,369.93 90.43 155.60 5,892.64 5,812.64 -2,249.53 -9.48 5,998,023.40 498,64492 17.70 2,249.53 MWD (5) 7,40265 93.01 163.19 5,891.67 5,811.67 -2,279.56 1.81 5,997,993.37 498,656.21 24.95 2,279.56 MWD(5) 7,430.09 92.18 166.03 5,890.40 5,810.40 -2,306.56 9.24 5,997,966.37 498,663.64 10.54 2,306.56 MWD (5) 7,455.43 91.78 169.33 5,889.53 5,809.53 -2,331.30 14.69 5,997,94163 498,669.03 13.11 2,331.30 MWD (5) 7,485.11 92.24 173.65 5,888.48 5,80648 -2,360.63 19.03 5,997,912.30 498,673.42 1463 2,360.63 MWD (5) 7,515.33 90.74 174.98 5,887.70 5,807.70 -2,390.69 22.03 5,997,882.25 498,67640 6.63 2,390.69 MWD (5) 7,545.51 87.20 17456 5,888.24 5,80824 -2,420.73 24.78 5,997,85220 498,679.15 11.81 2,420.73 MWD(5) 7,575.95 88.16 173.86 5,889.47 5,809.47 -2,450.99 27.84 5,997,821.95 498,682.21 3.90 2,450.99 MWD (5) 7,605.50 86.13 171.38 5,890.94 5,810.94 -2,480.26 31.63 5,997,792.69 498,685.99 10.84 2,480.26 MWD(5) 7,635.64 86.86 168.86 5,892.79 5,812.79 -2,509.89 36.80 5,997,763.05 498,691.15 8.69 2,509.89 MWD (5) 7,665.44 86.59 166.27 5,894.49 5,814.49 -2,538.94 43.20 5,997,734.00 498,697.55 8.72 2,538.94 MWD (5) 7,695.39 86.81 166.85 5,896.21 5,816.21 -2,568.02 5015 5,997,704.92 498,704.49 2.07 2,568.02 MM (5) 7,725.27 87.67 171.51 5,897.65 5,817.65 -2,597.33 55.75 5,997,67562 498,710.09 15.84 2,597.33 MWD (5) 7,756.04 92.31 178.84 5,897.66 5,817.66 -2,627.96 58.34 5,997,644.99 498,712.67 28.19 2,627.96 MWD(5) 7,785.94 90.12 180.72 5,897.03 5,817.03 -2,657.85 SEAS 5,997,615.10 498,712.78 965 2,657.85 MWD (5) 7,815.78 87.99 182.94 5,897.53 5,817.53 -2,687.67 57.50 5,997,585.29 498,711.82 10.43 2,687.67 1(5) 7,845.71 87.23 183.38 5,898.79 5,818.79 -2,717.53 55.85 5,997,55543 498,710.17 2.79 2,717.53 MWD (5) 7,880.34 86.31 187.94 5,900.74 5,820.74 -2,751.92 52.44 5,997,521.04 498,706.75 13.41 2,751.92 MWD (5) 7,910.57 87.15 190.49 5,902.47 5,822.47 -2,781.71 4761 5,997,491.26 498,701.91 8.87 2,781.71 MM (5) 7,939.69 89.85 193.05 5,903.23 5,823.23 -2,81020 41.67 5,997,462.77 498,695.97 12.77 2,810.20 MWD (5) 7,970.42 87.79 192.09 5,903.86 5,823.86 -2,840.19 34.99 5,997,432.79 498,689.28 7.40 2,840.19 MM (5) 8,000.30 8541 190.31 5,905.64 5,825.64 -2,869.45 29.19 5,997,403.54 498,683.48 9.94 2,869.45 MWD(5) 8,030.17 85.61 189.26 5,907.97 5,827.97 -2,898.79 24.13 5,997,374.19 498,678.42 3.57 2,898.79 MWD (5) 8,061.09 86.99 188.38 5,909.97 5,829.97 -2,929.28 19.40 5,997,343.71 498,673.68 5.29 2,929.28 MM (5) 8,090.45 87.85 187.18 5,911.29 5,83129 -2,958.34 15,3 5,997,31465 498,669.71 5.03 2,958.34 MWD (5) 8,119.16 91.17 187.32 5,911.54 5,831.54 -2,986.81 11.81 5,997,286.18 498,666.08 11.57 2,986.81 MWD (5) 8,198.92 93.35 185.47 5,910.36 5,830.36 -3,016.33 8.24 5,997,25667 498,662.50 7.86 3,016.33 MWD (5) 8,180.33 92.68 185.22 5,908.71 5,828.71 -3,04754 5.04 5,997.225.47 498,659.31 4.51 3,047.54 MWD (5) 8210.33 9181 187.25 5,907.54 5827.54 -307734 179 5,997.195.67 498,656.04 7.36 3,07734 MWD (5) Annotation HA.ICUGHES 8/11/2017 4: 29 36P Page 4 COMPASS 5000.14 Build 85 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: Well 31-1-26 ConocoPhillips Company: ConocoPhillips (Alaska) Inc -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 31-1-26 Wellborn: 31-1-2617 Design: 3H-2BL1 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: Well 31-1-26 TVD Reference: 3H-26 @ 80.00usft (31-1-26) MD Reference: 31-1-26 @ e0,00usft (31-1-26) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT Alaska Sandbox MD Inc Azi TVD N +N7 -S +E/ -W Map Map DLS verticalD55 (usft) (usft) (usft) (usft) (usft) Northing Easting Section Survey Tool Name (ft) (ft) (°/100') (ft) 8,240.41 92 46 92 18 189.29 5,906.42 5,826.42 -3,10708 -2.53 5,997,165.93 498,651.72 7.11 3,107.08 MAD (5) 8,270.33 93,04 193.10 5,904.98 5,824.98 3,136.39 .8.34 5,997,136.62 498,645.91 12.87 3,136.39 MWD (5) 8,300.54 90.37 193.08 5,904.06 5,824.08 3,165.80 -15.17 5,997,10722 498,639.07 8.84 3,165.80 MWD(5) 8,330.29 91.01 19466 5,903.72 5,823.72 -3,194.68 -22.30 5,997,07834 498,631.93 5.73 3,194.68 MWD(5) 8,360.21 90.80 196.39 5,90325 5,823.25 -3,223.50 -30.31 5,997,049.52 498,623.92 5.82 3,223.50 MWD (5) 8,390.09 91.38 197.00 5,902.68 5.822.68 -3,252.12 39.89 5,997,020.91 498,615.33 2.82 3,252.12 MWD (5) 8,420.51 9120 197.78 5,902.00 5,822.00 -3,281.14 47.98 5,996,991.90 498,606.24 2.63 3,281.14 MWD (5) 8,450.89. 93.78 19939 5,900.68 5,820.68 3,309.91 5765 5,996,963.13 498,596.56 10.01 3,309.91 MWD(5) 8,480.57 93.84 201.36 5,898.70 5,818.70 -3,337.67 67.96 5,996,935.38 498,586.25 6.63 3,33767 MIND(5) 8,510.64 95.48 203.27 5,896.26 5,816.26 -3,365.39 -79.34 5,996,907.66 498,574.87 8.36 3,365.39 MWO(5) 8,539.81 93.51 209.96 5,893.97 5,813.97 3,391,93 -91.22 5,99,881.13 498,562.98 8.89 3,391.93 M4VD (5) 8,570.50 93.96 205.85 5,891.98 5,811.98 -3,41959 -104.36 5,996,853.47 498,549.84 3.24 3,419.59 MVM (5) 8,601.85 88.96 20&M 5,891.18 5,811.18 -3,447.85 -117.90 5,99,82522 498,536.30 16.03 3,447.85 MWD (5) 8,630.19 91.72 206.42 5,891.01 5,811.01 -3,473.34 -13027 5,996,799.73 498,523.93 10.46 3,473.34 MM (5) 8,660.21 93.35 205.25 5,889.68 5,809.68 3,500.33 -143.33 5,996,772.74 498,510.86 6.68 3,500.33 MWD (5) 8,69026 97.83 206.22 5,886.75 5,806.75 -3,527.27 -156.32 5,996,745.81 498,497.87 15.25 3,527.27 MWD (5) 8,720.38 100.70 206.34 5,881.91 5,801.91 3,553.92 -16948 5,996,719.17 498,484.71 9.54 3,553.92 MWD (5) 8,750.65 102.33 196.99 5,875.85 5,795.85 -3,581.45 -18042 5,996,691.64 498,473.76 30.74 3,58145 MWD (5) 8,775.37 10368 206.68 5,870.27 5,790.28 3.60378 -189.36 5,996,669.31 498,464.82 38.58 3,603.78 MWD (5) 8,800.36 104.31 208.81 5,864.23 5,784.23 3,625.24 -200.65 5,99,647.86 498,453.53 865 3,625.24 MWD (5) 8,830.17 104]4 211.6 5,8%75 5,77675 -3650.24 -215.05 5,996,62286 49,439.13 7.45 3,650.24 MWD(5) 8,860.02 10475 213.09 5,849.16 5,76916 -3,674.70 -230.37 5,99,598 .40 498,423.80 6.58 3,6]4]0 MWD (5) 8,890.00 104.75 213.09 5,891.52 5,761.52 -3,698.99 -246.20 5,996,574.12 498,407.97 0.00 3,698.99 PROJECTED to TD 811112017 4'29:36PM Page 5 BAKl1GHE5 Annotation 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.cogcc.clasko.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3H -26L1-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-088 Surface Location: 1384' FNL, 281' FWL, Sec. 12, TI 2N, R8E, UM Bottomhole Location: 4992' FNL, 5192' FEL, Sec. 12, T12N, 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'Z6 day of June, 2017. STATE OF ALASKA ALA_,, A OIL AND GAS CONSERVATION COMMIS, uN PERMIT TO DRILL 20 AAC 25.005 RECEiVEU JUN 12 2017 AOGCC 1a. Type of Work: Drill ❑ Lateral ❑✓ Redrill ❑ Reentry ❑ 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ Stratigraphic Test ❑ Development - Oil ❑� Service - Winj ❑ Single Zone ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑� 1 c. Specify if well is proposed 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-261-1-01 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: 3V f. MD: 8900_, ND: 5 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: 3704' FNL, 5026' FEL, Sec 12, T12N, R8E, UM Total Depth: 4992' FNL, 5192' 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: 5340' 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: 1350' (31-1-09) 16. Deviated wells: Kickoff depth: 7500 feet 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 I Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7 ppf L-80 ST -L 1500' 7400' 5827' 8900' 5812' N/A 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 6660' 6306' N/A 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 ASII I, 300 sx Class G 3143' 3140' Intermediate Production 6643' 5" x 5-112" 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 Q OP Sketch 20. Attachments: Property Plat ❑ Divertter Sketch e lling Program DSeabed Report e Dri ngeFluid Progv. Depthram e✓ 20 AAC 25.050 requirementslot Hazard ealyse 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@mnocophillips.com Authorized Title: Staff CTD Engineer Contact Phone: 263-4180 Authorized Signature: Date: 4'AA-7 Commission Use Only Permit to Drill Number: I - API Number: 50- O3- O O - -Q� Permit Approval Data. .2(R- \'� 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: 1yOp �r,5 tp r't 55 L re f'0,?3 7-5r p 51.q Samples req'd: Yes ❑ No Lv� Mud log req'd: Yes ,❑] No EK d-h�v(Q`prL V�ft-'f'Z'r�' 12�,rj ZsU O P51kjnreasures: Yes[✓ NOE] Directional svy req'd: Yes u No❑ -2 Sr O y rJ^�6� Vary'r. h, C C +S� pacing exception Ireeq'd: Yes ❑ No L�J1 Inclination -only svy req'd: Yes ❑ Nord 1<l c k FF V o l a n Y ? D r VG r a�� y / a r ' f l GLT-trct �al injection MIT req'd: Yes ❑ NOL APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: / Font 10-401 vif sed 5/ 0 7 / /rhi rti 1 V li fo 24 months fr m the date of a Submit Form and ff � h R $ pg[ � -$ @ Q r,— approval per 20 AAC 25.005(8) Attachments in Duplicate {/� I !(` NAI �� 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: RECEIVED JUN 12 2017 AOGCC 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 3H-261-1, 3H -26L1-01, and 3H-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 31-1-261-1-02 — 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 -26L1, 31-1-261-1-01, & 3H -26L1-02 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b))....................................................................................................................2 2. Location Summary .......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)).....-...........................................................................................................................................2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)).................................................................................................................................................. 3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8))..................................................................................................................................................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9)).................................................................................................................................................. 4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................ 4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 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.................................................................................................................................................... 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 3H -26L1-02 laterals......................................................7 Attachment 2: Current Well Schematic for 31-1-26............................................................................................................7 Attachment 3: Proposed Well Schematic for 3H-261-1, 31-1-261-1-01 and 31-1-261-1-02 laterals........................................7 Page 1 of 7 June 9, 2017 PTD Application: 3H-261-1, 3H-261-1-01, & 31-1-2611-02 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 31-1-261-1, 31-1-261-1-01, 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 31-1-09 (i.e. 12.7 ppg EMW), the maxim potential surface pressure in 3H-26, assuming a gas gradient of 0.1 psi/ft, 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 31-1-09 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 31-1-26 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, & 31-1-261-7-02 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-261-1 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-261-7-01 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' 2'8", 4.7#, L-80, ST -L slotted liner; 7740 6290 Production 5" 18 Liner top packer Existing Casing/Liner Information Category OD Weight l pq Grade Connection Top MD Btm MD Top TVD Btm ss i Collapse psi Conductor 1 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 EUE IRT 0' 6126' 0' 5793' 1 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). 1This 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, 31-1-261-1-01, & 3H-261-1-02 Pressure at the 3H-26 Window (6277' MD. 5856' TVD) Usino MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations 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 3H-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 nqi 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 ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background 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 3H-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-261-1-02 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 BOPE, 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 -26L1-01, & 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 — 31-1-26 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 DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6 of 7 June 9, 2017 PTD Application: 3H -26L1, 3H -26L1-01, & 3H -26L1-02 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-261-1 5215' 3H -26L1-01 5340' 3H-261-1-02 5470' - Distance to Nearest Well within Pool Lateral Name I Distance Well 3H-261-1 1 1328' 1 31-1-09 3H-261-1-01 1350' 3H-09 3H -26L1-02 1 1050' 1 3H-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 314-261-1, 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: 3H-26L1_wp02 Standard Planning Report 01 June, 2017 MA Pk'-- BAKER HUGHES ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConowPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 311 Pad Well: 31-1-26 Wellbore: 31-1-261-1 Design: 3H-26L1_wp02 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-26 Mean See Level 3H-26 @ 80.00usft (31-1-26) 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 FeAN BAKER HUGHES Site Kuparuk 3H Pad 3H-26 Site Position: Northing: 6,000,110.73usft Latitude: 70° 24'41.531 N 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 Audit Notes: Well Position +N/ -S 0.00 usft Northing: 6,000,272.70 usft Latitude: 70° 24'41124 N 5,974.70 +E/ -W 0.00 usft Easting: 498,654.81 usft Longitude: 150° 0'39.435 W Position Uncertainty (usft) 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 31-1-261-1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength P) 1") (nT) BGGM2016 9/1/2017 17.39 80.96 57,536 Design 3H-26Ll_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 5,974.70 Vertical Section: Depth From (ND) +N/ -S +E/ -W Direction Depth (usft) (usft) (usft) V) +El -W 0.00 0.00 0.00 180.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +El -W Rate Rate Rate TFO (usft) (1 (`) (usft) (usft) (usft) (°/100ft) (-1100ft) (-1100ft) V) Target 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 5,679.36 -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 6.80 103.00 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 6/12017 3:54:59PM Page 2 COMPASS 5000.1 Build 74 ( ConocoPhillips WON ConocoPhillips Planning Report BAKW HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 31-1-26 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 31-11-26 Q 80.00usft (31-1-26) Site: Kuparuk 3H Pad North Reference: True Well: 31-1-26 Survey Calculation Method: Minimum Curvature Wellbore: 31-1-261-1 Depth Inclination Design: 31-1-2617_wp02 +N/S +E/ -W Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/S +E/ -W Section Rate Azimuth Northing Easting (usft) (o) (o) (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 dls 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 46 dls, Start 7 dis 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 80.00 182.67 5,961.01 -1,445.68 -340.63 1,445.68 7.00 -90.00 5,998,827.22 498,313.96 6 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 5,998,556.24 498,314.19 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 a 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 -111.36 5,998,276.73 498,399.81 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 7,40000 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 7,60000 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 5,997,770.94 498,705.98 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 -2,897.58 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 -3345.58 -141.34 3,345.58 7.00 -69.83 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 8,800.00 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 6/12017 3:54:59PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips FIRA:. ConocoPhillips Planning Repoli BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 3H-26 Wellbore: 3H-261-1 Design: 3H-26Ll_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-26 Mean Sea Level 314-26 @ 80.00usft(3H-26) True Minimum Curvature Planned Survey 0.0D 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 Measured TVD Below Diameter Vertical Dogleg TooNace Map Map Depth Inclination Azimuth System +N1 -S +EI -W Section Rate Azimuth Northing Easting (usft) (1 (e) (usft) (usft) (usft) (usft) ('/10Dft) 0 (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 -1,813.00 764.50 5,997,128.04 Point 0.00 Targets Target Name -hitimiss target Dip Angle Dip Dir. TVD +Nl-5 +El -W Northing Easting -Shape V) (1) (usft) (usft) (usft) (usft) (usft) 3H-2611 T03 0.00 0.00 5,823.00 -3,677.761,139,929.86 5,996,39000 - plan misses target center by 1139844.31 usft at 7975.00usft MD (5787.28 TVD, -2773.55 N, 85.91 E) - Point 3H-26 CTD Polygon Sot 0.0D 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 Depth Depth Diameter Point 1 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 1,638,513.00 1,638,222.00 Latitude Longitude 70" 9'57.835 N 140° 48'32.529 W 70° 10'22.971 N 140° 48'28.517 W 3H-261-1_701 0.00 0.00 5,961.00 -1,419.551,139,811.44 5,998,648.00 1,638,352.00 70° 10' 19.934 N 140" 48'26,074 W - plan misses target center by 1139726.35usft at 7975.00usft MD (5787.28 TVD, -2773.55 N, 85.91 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 1139992.61 usft at 7975.00usft MD (5787.28 TVD, -2773.55 N, 85.91 E) - Polygon Hole Depth Depth Diameter Point 1 0.00 0.00 0.00 5,998,059.00 Point 0.00 -173.96 236.06 5,997,885.01 Point 3 0.00 2,007.38 769.61 6,000,066.04 Point 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 7 0.00 -424.07 -138.92 5,997,635.00 Point 0.00 -174.07 -242.98 5,997,884.99 Point 9 0.00. 0.00 0.00 5,998,059.00 1,638,604.00 70° 10' 13.842 N 140° 48'21.431 W I 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 3H -26I -1-T02 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" 48'20.01 - 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 6/12017 3:54..59PM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips BAKER• ConocoPhillips Had Report HUGHES Database: EOM Alaska NSK Sandbox Local Co-ordinate Reference: Well 3H-26 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kupawk River Unit MD Reference: 31-4-26 @ 80.00usft (3H-26) Site: Kuparuk 3H Pad North Reference: True Well: 3H-26 Survey Calculation Method: Minimum Curvature Wellbore: 3H-2611 -308.86 TIP Design: 3H -26L1 wp02 -1,250.27 -317.72 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (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 -316.80 End 14 dls, Start 45 dls 6,455.29 5,961.01 -1,376.27 -334.42 End 45 dis, Start 7 dls 6,525.00 5,961.01 -1,445.68 -340.63 5 6,700.00 5,942.66 -1,619.32 -345.46 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 TO at 8900.00 6/1/2017 3:54..59PM Page 5 COMPASS 5000.1 Build 74 Baker Hughes INTEQ Ff.. ConocoPhiilips Travelling Cylinder Report BAKER HUGHES Company: ConomPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 31-1 Pad Site Error: 0.00 usft Reference Well: 31-1-26 Well Error: 0.00 usft Reference Wellbore 311-261-7 Reference Design: 31-1-2611_wp02 Local Coordinate Reference: Well 31-1-26 TVD Reference: 311-26 @ 80.00usft (31-1-26) MD Reference: 3H-26 @ 80.00usft (311-26) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: OAKEDMP2 Offset TVD Reference: Offset Datum Reference 3H-26L7_wp02 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Vertical Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 5,974.70 to 8,900.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,082.00 usft Error Surface: Elliptical Conic Survey Tool Program Date 5/2412017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 121.00 5,974.70 31-1-26 (3H-26) MWD MWD -Standard 5,974.70 8,900.00 3H-26L1_wp02(31-1-2611) MWD MWD - Standard Casing Points Kupamk 3H Pad -3H -26 -3H -26-3H-26 Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (••) (-) 121.00 121.00 16" 16 26 3,142.80 3,140.36 7 518" 7-5/8 9-7/8 8,900.00 5,902.94 2318" 2-3/8 3 Summary Kupamk 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 Most Well Error: 0.00 usft Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kupamk 3H Pad Measured vertical Measured whorl 31-1-01 - 311-01 - 31-1-01 T Iface+ Onset Wellbore Centre Casing- Centreto Out of range 31-1-02 - 31-1-02 - 31-1-02 Depth Depth Depth Depth Avmuth Out of range 31-1-03 - 31-1-03 - 31-1-03 Hde Size centre Distance Worth, oevlation (oan) foenl Out of range 31-1-04 - 311-04 - 3H-04 loan) (ura) (•I (.aft) (usft) 1'1 Out of range 311-05 - 31-1-05 - 311-05 lush 5,975.00 5,653.30 5,975.00 5,653.30 000 0.00 Out of range 31-1-06 - 31-1-06 - 31-1-06 -308.86 4414 0.00 0.81 -0.45 FAIL -Major Risk, CC Out of range 31-1-07 - 31-1-07 - 3H-07 557622 0.12 0.09 -175.95 -1,154.21 -309.36 Out of range 31-1-09 - 31-4-09 - 3H-09 1,85 -083 FAIL - Mayr Risk 6,025.00 5,699.23 6,02500 5,699.23 Out of range 31-1-10 - 31-1-10 - 311-10 -1,163.97 -309.90 4-114 000 235 Out of range 31-1-10 - 3H -10C - 3H -10C Out of range 311-10 - 31-1-10CL7 - 3H-10CL1 Out of range 31-1-11 - 31-1-11 - 31-1-11 Out of range 3H -28 -3H -26-3H-26 6,275.00 6,275.00 0.01 9.38 -4.75 FAIL - Major Risk 3H-26-31-1-2611-01-31-1-261-1-01_wp01 7,524.99 7,525.00 0.40 1.24 -0.51 FAIL - Minor 1/10 311-26-311-261-1-02-31-1-261-7-02_wp01 7,400.00 7,400.00 0.00 0.29 -0.22 FAIL - Minor 1/10 Offset Design Kupamk 3H Pad -3H -26 -3H -26-3H-26 oneel sit, Error: 0.00 usft survey Program: 121 -MWD Rule A.kaed:MsJkr Rlsk Most Well Error: 0.00 usft Reference Onset Semi McJ.Ails Measured vertical Measured whorl Reference Dead T Iface+ Onset Wellbore Centre Casing- Centreto No Go Allowable Depth Depth Depth Depth Avmuth +NIS +Erm Hde Size centre Distance Worth, oevlation (oan) foenl Judo loft) loan) (ura) (•I (.aft) (usft) 1'1 lush) luahl lush 5,975.00 5,653.30 5,975.00 5,653.30 000 0.00 -171.30 4,144.24 -308.86 4414 0.00 0.81 -0.45 FAIL -Major Risk, CC 6,00000 5,676.22 6,090.00 557622 0.12 0.09 -175.95 -1,154.21 -309.36 4-114 000 1,85 -083 FAIL - Mayr Risk 6,025.00 5,699.23 6,02500 5,699.23 0.21 0.17 -176.07 -1,163.97 -309.90 4-114 000 235 .118 FAIL -M j R' k CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 51242017 10:53:27AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: 3H-26 ,SNwmrurn.. Navin eaeseem ue,m: nar u.reN¢FNN WELLBORE DETAILS: 3H-261-1 REFS NDE 1NFORWn0N �'.. Parent WeIIDDM. 3H-26 c &,W(W RA. Wee 3&x. nue N.& Wellbore: 3x-261-1 su•DIPA, snr DIPA, ane °e11J1R01r Te on MD: 5974.70 vemwl(ND)Rereaze: &t -(D Lae section NS7ltelnen[e: SkL10mN, O.BDn BAKER Plan: 3H-261-1 w 02 3H -26/3H- 6Li _ P t 2 % MptleL 03°MNN Easting wemea DeRN Rekn�ar 3xasn B00aorypH-MI Latitude Longitude 0.00 0.00 HUGHES 11 Mean 0 -350 ao -1050 -14W -1750 o-1700 h -z45D -2800 0 -3150 IL 7-3500 0 -3850 -4200 4550 -4900 !I■■■■■■■■■■■■MEN '�■■■■■■■■■■■■■■■■■■� WELL DETAILS: 1■Ill■■■■MEN 3H-26 +N/ -S +E/ -W Northing Easting EII■...�.■. 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 +N/ -S +E/ -W Meg TFace VSect Annotation 1 5974.70 23.80 182.70 5573.02 -1144.12 -308.86 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 Irv° KOP 3 6302.00 21.02 187.55 5879.36 -1258.45 -318.80 14.00 0.00 1258.45 p_p F� End 14 d1s, Start 45 dls 4 6455.29 90,00 187.55 5961.01 -1376.27 -334.42 45.00 0.00 1376.27 5695 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 3H- 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 7.DD 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 67.22 215.53 5802.17 -3216.38 -65.90 7.00 94.00 3216.38 13 14 8900.00 87.63 184.00 5822.94 -3634.09 -216.01 7.00 270.00 3634.09 Planned TD at 8900.00 11 Mean 0 -350 ao -1050 -14W -1750 o-1700 h -z45D -2800 0 -3150 IL 7-3500 0 -3850 -4200 4550 -4900 !I■■■■■■■■■■■■MEN '�■■■■■■■■■■■■■■■■■■� 1■Ill■■■■MEN EII■...�.■. 4940 ■■ ■■■��6r'F 5525 ---------------- 5610 �■■ NEE ■� Irv° No p_p F� I 5695 ■■■■■■■ I1/l�/■■■■■■ON ■� ■■■■■■■■1/J■■■■■0ME■ 3H- 311-26 1-D2 311-21 AH -2 W -DI it■■■■■■■■„%�I■■■■■■■■, 578D II■■■■■■■�■■■■■■, OP ;�■■■■■ II■■■■■■■■■� ■■■■ ■■■■N,�■■■■■� 5865 5950 En 14 d1 6tan Shcs West( -)Bast(+) (350 usff/in) 5355 4940 5525 ---------------- 5610 UP x Irv° p_p F� I 5695 3H- 311-26 1-D2 311-21 AH -2 W -DI 578D OP 5865 5950 En 14 d1 6tan Shcs 1 Pannb3m at t now j 8 3H-2 3H-2 LI 6035 6120 s,rus 6205 H¢6/ H-26 lea L _ _ VeftlOae Section at t6u.vu" (85 ustvin) ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-26 31-1-261-1-01 Plan: 3H-26L1-01_wp01 Standard Planning Report 01 June, 2017 rias BAKER HUGHES ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-26 Mean Sea Level 311-26 @ 80.00usft (3H-26) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US Stale 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 FORM BAKER BUGM Site Kuparuk 3H Pad 3H-26 ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3H Pad Well: 3H-26 Wellbore: 31-1-261-1-01 Design: 31-1-261-1-01_wp01 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3H-26 Mean Sea Level 311-26 @ 80.00usft (3H-26) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US Stale 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 FORM BAKER BUGM 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: 0.000 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 3H-261-1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (`) V) oT) BGGM2016 9/1/2017 17.39 50.96 57,536 Design 3H-26LI-01_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,500.00 Vertical Section: Depth From (TVD) +N/ -S +EI -W Direction (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) (1) 0 (usft) (usft) (usft) (°1100ft) (`1100ft) (-1100ft) (1) 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 -169.83 7.00 -0.08 -7.01 270.00 6112017 3:57.'55PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips ��.. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 31-1-26 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kupamk River Unit MD Reference: 3H-26 @ 80.00usft (31-1-26) Site: Kuparuk 3H Pad North Reference: True Well: 31-1-26 / Survey Calculation Method: Minimum Curvature Wellbore: 31-1-261-1-01 Depth Inclination Azimuth Design: 3H-261-1-Oi_wp01 +E1 -W Section Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N1 -S +E1 -W Section Rate Azimuth Northing Easting (usft) (9 (I (usft) (usft) (usft) (usft) (-1100ft) V) (usft) (usft) 7,500.00 96.62 149.89 5,815.01 -2,319.47 -25.49 2,319.47 0.00 0.00 5,997,953.47 498,628.90 TIPlKOP 7,600.00 90.27 152.85 5,809.00 -2,407.03 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 5,997,485.25 498,786.07 4 8,100.00 91.73 184.12 5,824.58 -2,887.61 130.39 2,887.61 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 5,997,286.39 496,771.70 6 8,300.00 93.84 197.81 5,812.98 -3,083.21 92.80 3,083.21 7.00 90.00 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 8,600.00 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 TO at 8900.00 6112017 3:57:55PM Page 3 COMPASS 5000.1 Build 74 11. ConocoPhillips -2,008.561,140,063.57 F&.. ConocoPhillips Planning Report Target Name BAKER N, 131.77 E) Depth - Polygon HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 3H-26 Northing Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level (1) (usft) Project Kupamk River Unit MD Reference: 3H-26 Q e0.00usft (31-1-26) Latitude Longitude Site: Kupamk 3H Pad North Reference: True 5,998,941.00 Well: 31-1-26 Survey Calculation Method: Minimum Curvature N. 131.77 E) Wellbore: 31-1-261-1-01 1,639,373.89 - Polygon 0.00 Design: 3H-26L1-01_uvp01 1,096.66 6,000,003.06 1,639,700.90 Targets 0.00 0.00 0.00 -2,008.561,140,063.57 5,998,059.00 1,638,604.00 70° 10' 13.842 N 140° 48'21.431 W - plan misses target center Target Name TVD, -2787.69 N, 131.77 E) Depth - Polygon Diameter • hit/miss target Dip Angle Dip Dir. TVD +N1 -S +El -W Northing Easting 0.00 -Shape (1 (1) (usft) (usft) (usft) (Left) (usft) Latitude Longitude 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 70° 10'22+971 N 140° 48'28.517 W - plan misses target center by 1139565.71 usft at 8000.00usft MD (5825.72 TVD, -2787.69 N. 131.77 E) 6,000,066.04 1,639,373.89 - Polygon 0.00 1,944.45 1,096.66 6,000,003.06 1,639,700.90 Points 0.00 0.00 0.00 5,998,941.00 1,638,222.00 1,639,201.01 Point 0.00 -813.08 -6.81 5,998,128.00 1,638,215.04 1,638,916.03 Point 0.00 -1,278.06 277.32 5,997,663.02 1,638,499.06 1,638,465.02 PoMt4 0.00 -1,674.08 396.43 5,997,267.02 1,638,618.09 1,638,361.01 Point 5 0.00 -3,028.34 -145.31 5,995,912.99 1,638,076.16 1,638,604.00 Point 0.00 -3,14627 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 5,998,156.02 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 -261.1-01_T02 0.00 0.00 5,776.00 -3,650.751,139,955.86 5,996,417.00 1,638,496.00 70'V5&058 N 140'48'31.668 W - plan misses target center by 1139B24.42usft at 8000.00usft MD (5825.72 TVD, -2787.69 N, 131.77 E) - Point 3H-261.1-01_701 0.00 0.00 5,825.00 -2,808.611,140,275.74 5,997,259.00 1,638,816.00 70° 10'5.761 N 140° 48' 18.852 W -plan misses target center by 1140143.97usft at 8000.00usft MD (5825.72 TVD, -2787.69 N, 131.77E) - Point 3H-26 CTD Polygon Nor 0.00 0.00 0.00 -2,008.561,140,063.57 5,998,059.00 1,638,604.00 70° 10' 13.842 N 140° 48'21.431 W - plan misses target center by 1139946.96usft at 8000.00usft MD (5825.72 TVD, -2787.69 N, 131.77 E) Depth - Polygon Diameter (usft) (usft) Name (in) (in) Points 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 Points 0.00 -367.90 597.14 5,997,691.03 1,639,201.01 Point6 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 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 +N/ -S +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 Start 7 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 8900.00 611/2017 3:57:55PM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips Company: ConomPhillips (Alaska) Inc. -Kup2 Project Kupamk River Unit Reference Site: Kupamk 3H Pad Site Error: 0.00 usft Reference Well: 3H-26 Well Error: 0.00 usft Reference Wellbore 31-1-261-1-01 Reference Design: 3H-261-7-01_wp01 ( Baker Hughes INTEQ FEW Travelling Cylinder Report BAKER HUGHES Local Co-ordinate Reference: Well 31-1-26 TVD Reference: 31-1-26 @ 80.00usft (31-1-26) MD Reference: 3H-26 @ 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 3H-26L1-01_wp01 Filter Type: GLOBAL FILTER APPLIED: All wellpalhs 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: 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 Casing Hole (usft) (usft) Survey (Wellbore) Tool Name Description 121.00 5,974.70 31-1-26 (31-1-26) MWD MWD -Standard 5,974.70 7,500.00 31-1-261-7_Wp02(31-1-2611) MWD MWD- Standard 7,500.00 8,900.00 3H-261-1-01_wp01 (31-1-2611-01) MWD MWD -Standard Casing Points Kupamk 3H Pad Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name Measured 121.00 121.00 16" 16 26 3,142.60 3,140.36 75/8" 7-5/8 9-7/8 6,900.00 5,856.34 23/8" 2-3/8 3 Summary Kupamk 3H Pad Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Ruk Assigned: Minor Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kupamk 3H Pad 31-1-01 - 31-1-01 - 31-1-01 Vertical Measuretl vertical Rooranu Groat Out of range 31-1-02 - 31-1-02 - 31-1-02 Centre Casing- Centreb No Go Allowable Out of range 31-1-03 - 31-1-03 - 31-1-03 Depth D.,th Aaisuth Out of range 31-1-04 - 31-1-04 - 3H-04 Hour Sue Centre maroons warning Deviation (usft) Out of range 31-1-05 - 31-1-05 - 31-1-05 (-R) luaft) ('s K) 19 (usft) Out of range 31-1-09 - 31-1-09 - 31-1-09 (vain (usft) (soft) 7,500D0 5,89501 Out of range 31-1-26-31-1-2611-31-1-2611_wp02 7,524.99 7,525.00 0.40 1.25 -0.48 FAIL -Minor 1/10 3H -26 -3H -2611 -02 -3H -26L1-02 wp01 7,518.19 7,525.00 33.54 1.34 33.25 Pass -Minor 1/10 Offset Design Kupamk 3H Pad -3H-26-3H-2611-3H-26L1_wp02 Montsee Emac em no Survey Prognosis 121 -MWD, 5975 -MM Ruk Assigned: Minor 1110 Onset Well Error, 0.00 usR ftMarenne GRxt Semi Majorgzis Measured Vertical Measuretl vertical Rooranu Groat Toolf..n Offset Wellbore Centre Casing- Centreb No Go Allowable Morn north Depth D.,th Aaisuth -1118 a£ -W Hour Sue Centre maroons warning Deviation (usft) (usft) (usft) (-R) luaft) ('s K) 19 (usft) loan) 1"1 (vain (usft) (soft) 7,500D0 5,89501 7.500.00 5,895.01 OLD 0.00 149.89 -2,31947 -2549 2-11116 000 a29 -0.22 FAIL -Minor 1110, CC 7,524.99 5.892.47 7,525.00 5,892.13 049 033 -176.06 -2,341.14 -13.37 2-11116 340 1.25 -0.48 FAIL -Minor 1/10, ES, SF 7,549.95 5,89062 7,550,00 5,809,28 0.97 1.27 -175.23 8363.18 -1.91 2-11/18 1.61 1.37 0.39 Pass - Minor 1110 7,57433 5,089.47 7,575.00 5,688.53 1.40 1.76 -173.67 -2.385.56 8.00 241/16 3.55 1.36 2.24 Pass - Mina, 1110 7.599.62 51889.00 7,600.00 5,883.95 1.83 2.25 472,36 -2,40827 18.99 2-11116 6,15 1.30 5.13 Pass -Minor 1/10 7.624.29 5,809.21 7,625.00 5,881.55 223 2.67 -17097 -2,431,30 28.44 2-11116 941 1.37 9.19 Pax-Mlnorl/10 7,648.81 5,890.09 7,650.00 5,879.32 2.62 3.09 -169.70 -245430 37.20 2-11116 13.33 1.32 13.13 Pass -Mina 1110 7,673.17 5,891.62 7,67500 5.877.28 2.99 345 -168.53 4.478.18 4526 2-11116 17.89 1.36 17.67 Pass-Minar1llo CC - Min Centre to Center distance or mvergent point, SF - min separation factor, ES - min ellipse separation ,512412017 11:03:24AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips Project: Kuparuk River Unit Site: Kuparuk ]H Pad Well: 3H-26 nnnwieean�. Nmx xea�mewea 17V xeaceue Fee WELLBORE DETAILS: 3H -261-1-0t REFERENCE REFERENCE INFORNgTION WELL Parent Wellbore: 3H-261-1 Coamree(Nk]RNvenn: WY3x-16,Tme xmm Wellbore: 3H-261-7-01 fine einn6. PipCe w&mse Te on MD: 7500.00 V.6I(TVD)FNW-: Mem fim LaN Sm n(M)Ren..: MI-PA0K0.WE) BAKER Plan: 3H-261-1-01_wPUt(3H-2613H-261.1.01) Mese �GA401 Easting Mmwre4 Dein Relerznce:3x-E6®WWnfi (fix-tef Latitude Longitude 0.00 0.00 HUGHES Mean E West( -)/East(+) (350 usft/in) 5355 WELL DETAILS: 311-26 - - - +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 6000272.70 498654.81 70e 24' 43.124 N 150° 0' 39.435 W Sec MD Inc Ai TVDSS +N/ -S +E/ -W Dleg TFace VSect Annotation 1 7500.00 96.52 149.89 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 E West( -)/East(+) (350 usft/in) 5355 - - - - 5440 5525 5610 Y 5695 P nned et 00.00 3H-2 14-26 I-02 7H=2 H-2 LI -DI BO 5865 TIP OP Sean dls 6 5950 4 311-2 14- Ll 6035 6120 6205 H-26! H -2G ea L V Vetticat Section at 180.00° (85 usft/in) ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3H Pad 3H-26 3H -26L1-02 Plan: 3 H-26L1-02_wp01 Standard Planning Report 01 June, 2017 rias BAKER HUGHES ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kupamk 3H Pad Well: 31-1-26 Wellbore: 31-1-261-1-02 Design: 31-1-261-1-02_wp01 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 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Gee Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Fed .I 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 usfl Easting: 498,654.81 usft Longitude: 150° 0'39.435 W Position Uncertainty +E/ -W 0.00 usft Wellhead Elevation: usfl Ground Level: 0.00 usft Waltham 3H-261-1-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 0 (% mT) BGGM2016 9/1/2017 17.39 80.96 57,536 Design Audit Notes: Version: Vertical Section: 31-1-261-1-02_wp01 Phase: Depth From (TVD) lush) 0.00 PLAN +N/ -S (usft) 0.00 Tie On Depth: +EI -W (usft) 0.00 7,400.00 Direction (') 0.00 Plan Sections Measured TVD Below Dogleg Build Tum Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) V) V) (usft) (usft) (usft) (-/1o0it) (°/1o0ft) (°110oft) 1") Target 7,400.00 96.75 142.85 5,826.66 -2,236.82 -80.46 0.00 0.00 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 81.94 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 6/12017 3:58.35PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips RAN 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: Kupamk River Unit MD Reference: 3H-26 @ 80.00usft (3H-26) Site: Kuparuk 3H Pad North Reference: True Well: 314-26 Survey Calculation Method! Minimum Curvature Wellbore: 3H-261-1-02 Depth Inclination Azimuth Design: 3H-261-1-02_wp01 +E1 -W Section Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +;I1 -S +E1 -W Section Rate Azimuth Northing Easting (usft) (I (I inert) (usft) (usfq (usft) (°1100@) (°) (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 25 dls 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 5,997,942.61 498,676.65 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 25 dls, Start 7 dls 8,000.00 91.84 23.41 5,804.71 -2,159.49 380.48 -2,159.49 7.00 -90.00 5,998,113.36 499,034.87 6,050.00 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 A,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 8,600.00 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 89.00 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 5,842.54 -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 69946 482.49 7.00 -90.49 5,999,790.14 499,354.13 Planned TD at 9725.00 6112017 3:58:35PM Page 3 COMPASS 5000.1 BuiW 74 ConocoPhillips .EFA. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupawk River Unit Site: Kuparuk 3H Pad Well: 3H-26 Wellbore: 31-1-261-1-02 Design: 311-281.1-02_wp01 Targets 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 Target Name -hit/miss target Dip Angle Dip Dir. TVD -NIS +El -W Northing Easting -Shape V) (1) (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 - plan misses target center by 1138990.72usft at 9600.00usft MD (5840.38 TVD, -607.18 N, 705.75 E) - Polygon Point 0.00 0.00 0.00 5,998,941.00 Point 0.00 -813.08 -5.81 5,998,126.00 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 3H -261-1-02_T01 0.00 0.00 5,803.00 -2,108.491,140,560.64 5,997,959.00 - plan misses target center by 1139855.88usft at 9600.00usft MD (5840.38 TVD, -607.18 N, 705.75 E) - Point 31-1-261-1-02_T02 0.00 0.00 5,856.00 -1,535.411,140,671.55 5,998,532.00 -plan misses target center by 1139966.18usft at 9600.00usft MD (5840.38 TVD, -607.18 N, 705.75 E) - Point 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 Latitude 70° 10'22.971 N Longitude 140° 48'28.517 W 1,639,101.00 70" 10'12.136 N 140" 1,639,212.00 70° 10' 17.536 N 140° 48' 1.981 W 31-1-2611-02_703 0.00 0.00 5,838.00 -526.281,140,845.39 5,999,541.00 1,639,386.00 70` 10'27.075 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 CTO 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 (5840.38 TVD, -607.18 N, 705.75 E) - Polygon Point 1 0.00 0.00 0.00 5,998,059.00 Point 0.00 -173.96 236.06 5,997,885.01 Point 3 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 5 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 8 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' 13.642 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) 9725.00 5,837.78 23/8" 2.375 3.000 61IM17 3:58:35PM Page 4 COMPASS 5000.1 Build 74 11 ��:. ConotoPitillips ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kuparuk 3H Pad Well: 311-26 Wellbore: 311-261-1-02 Design: 311-261-1-02_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 311-26 Mean Sea Level 3H-26 @ 80.00usft(311-26) True Minimum Curvature Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/S +E/ -W (usft) (usft) (usft) lush) Comment 7,400.00 5,826.66 -2,236.82 -8046 TIP/KOP 7,470.00 5,827.19 -2,288.51 -33.66 Start 25 cls 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 dls, Start 7 dls 8,050.00 5,803.12 -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 5,645.29 -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 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 3H Pad Site Error: 0.00 usft Reference Well: 31-1-26 Well Error: 0.00 usft Reference Wellbore 31-11-261.1-02 Reference Design: 3H-26L7-02_wp01 Baker Hughes INTEQ IGFAI Travelling Cylinder Report BAKER HUGHES Local Co-ordinate Reference: Well 311-26 TVD Reference: 311-26 @ 80.00usft (31-1-26) MD Reference: 31-1-26 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 3H-26L1-02_wp01 Filter type: GLOBAL FILTER APPLIED: All welipaths 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 Tool Program Date 5/24/2017 From To Well (usft) Survey(Wellbore) Tool Name Description 121.00 5,974.70 31-1-26 (31-1-26) MWD MWD - Standard 5,974.70 7,400.00 31-1-261-1W1302 (31-1-2611) MWD MWD - Standard 7,400.00 9,725.00 3H-26L7-02_wp01 (31-1-2611-02) MWD MWD -Standard Casing Points (usft) from Plan Measured Vertical (usft) Casing Hole (usft) Depth Depth (usft) Diameter Diameter Kupawk 3H Pad (usft) (usft) Name 121.00 121.00 16" 16 26 Measured 3,142.80 3,140.36 75/8" Reference 7-5/8 9-718 Toolrace+ 9,725.00 5,917.78 2318" 3H-02 - 3H-02 - 3H-02 2-3/8 3 Summary Kuparuk 3H Pad 31-1-09 3H-09 3H-09 Reference Offset Centre to No -Go Allowable - Measured Measured Centre Distance Deviation Warning Site Name Depth Depth p Distance (usft) from Plan Offset Well - Wellbore - Design 9 (usft) (usft) (usft) (usft) Kupawk 3H Pad 3H-01 - 31-1-01 - 31-1-01 Measured Vertical Reference offset Toolrace+ Out of range 3H-02 - 3H-02 - 3H-02 can.,- centrew No Go ABossoule Depth Depth Out of range 31-1-03 - 3H-03 - 31-1-03 Aaimulh M114 +VM Out of range 31-1-04 - 31-1-04 - 31-1-04 Oiskncs Wzmin9 Craw ion (team (usft) (usft) (earl) Out of range 31-1-05 - 31-1-05 - 31-1-05 (1) uAm (ism fl (raft) Out of range 311-07 - 31-1-07 - 31-1-07 8,05955 5,862,85 7,200.00 6273.67 27.61 35.86 Out of range 3H -09 -3H -09-3H-09 8,067.07 6,675.00 1,050.35 780.20 871.62 Pass - Major Risk 31-1-10 - 3H -10C - 3H -10C 8,248.] 27.81 35.83 128.14 2.458.18 Out of range 3H-10 - 31-1-10CL1 - 31-1-10CL1 1.15235 19138 979.93 Pass -Major Risk 8060.56 5,802.93 7.15900 Out of range 3H -25 -3H -26-3H-26 8,650.00 6,325.00 673.25 63.59 809.80 Pass - Major Risk 31-1-26-31-1-2611-3H-26L1_wp02 7,400.00 7,400.00 0.00 0.29 -0.22 FAIL - Minor 7/70 3H -26 -3H -2617-01-3H-261-1-01 wp01 7400.00 7,400.00 0.00 0.29 -0.22 FAIL - Minor t/10 Offset Design Kuparuk 3H Pad 31-1-09 3H-09 3H-09 - - - oeaer Error, 0.00treft Survey Program: 100.eoSSGYRO Rule Assigned: Major Risk careered: Error: 0.00 11 Well E 0.00 .uaR RHerence Gnsel Semi MaprAais Measured Vertkal Measured Vertical Reference offset Toolrace+ Offset Wellbore Centre can.,- centrew No Go ABossoule Depth Depth came Depth Aaimulh M114 +VM How Ste centre Oiskncs Wzmin9 Craw ion (team (usft) (usft) (earl) (tear!) (ism (1) uAm (ism fl (raft) (usft (ueR) 8,05955 5,862,85 7,200.00 6273.67 27.61 35.86 129.29 -2,459.12 1438.37 2-11/16 1.16258 181.43 99989 Pass - Major Risk 8,050.06 5882.84 7,175.00 8,248.] 27.81 35.83 128.14 2.458.18 1434.45 2-11/16 1.15235 19138 979.93 Pass -Major Risk 8060.56 5,802.93 7.15900 6,223.W 2160 35.79 126.96 4,457.24 1432.52 2-11116 1,142.56 181.32 909.46 Pass - Major Risk 8,06103 5.882.82 7,126.00 6,198.95 27.60 3575 125.H -2.456.31 1,430.50 241116 1,13324 181.27 959.47 Pass - Major Risk 8,061.48 5,882.81 7,100.00 6,174.05 2159 35.72 124.58 -2,455.41 1.420.60 2-11/16 1,12437 181.21 94996 Paas -Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 5,242017 11:09.44AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips Protect: Kuparuk River Unit aammmmrme xwln u.4aeuc noon: n.ss• WELLBORE DETAILS: 3H-2611 I REFERENCE INFORIMn0N Site: Kuparuk 3H Pad 3H-26 ------------- Well: 3H-26 +E/ -W xapnane nu Parent Wellbore: 3H -26L 1 aax Ix¢I R.I.-.' wee fiS. ime Nam. Wellbore: 3H-2811-02 Longitude 9rergm: el5]B.Nr m. anon: easfi Tle on MD: 7400.00 vem®I(No)Rele,enre: M1ks sea Lp6el Plan: 3H-261-1-02 wp01(3H-26/3X-261-1-02) 498654.81 GaN: wlrzwv 24'43.124 N 150° semaa CVS)RNwen¢: slat-Ia.00N, a.00E) N Cepm 61146 Sec MD nyyy: aGGNAI Azi we RAH ce: ir 10.00m, PH -26)U vo n w1hpd Mmmum ce ave 0 as ao -1050 -1400 c �1-1750 c-1700 u, naso f-2800 0 3150 x-3500 0 DO -3650 -4200 -4550 -4900- RUN BAKER HUGHES ■■■■■■■■�.�■M■■■■■■� WELL DETAILS: 3H-26 ------------- +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 6000272.70 498654.81 70a 24'43.124 N 150° 0'39.435 W Sec MD Inc Azi TVDSS +N/ -S +EAW Dleg TFace Vsect Annotation 1 7400.00 96.75 142.85 5826.66 -2236.82 -60.46 0.00 0.00 -2236.82 TIP/K0P 2 7470.00 82.38 132.83 5827.19 -2288.51 -33.66 25.00 215.00 -2288.51 Stan 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 dls, 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 0 as ao -1050 -1400 c �1-1750 c-1700 u, naso f-2800 0 3150 x-3500 0 DO -3650 -4200 -4550 -4900- RUN BAKER HUGHES ■■■■■■■■�.�■M■■■■■■� ------------- ■■■■■■■■tl■��WIN■'■■■■� F 1126H-26 1 End 2: 115.5 n7dl n 2 !■■■■0■■11.��/ 31 s46/31 -26L1 O1 4 6 ' �■■�ill�■■� 3 P/KO 9 1 mac 9725.0 10 Sm 1251 H- MH- raaaaaala�aaaaa��aaaaa��aaaa�aaaaaalaaaa�aaaaaalaaa�aa6aaalaaa� 0 0 0 0 0 o g o o a o 0 0 0 0 West( -)/East(+) (350 usfVin) 5355 5440 C 5525 5610 7 GAO 5695 y 5760 Q 5865 O 5950 J � 6035 F 6120 6205 Mean Sea L ' Vertical Section at 0.001 (85 usff/in) M ------------- F 1126H-26 1 End 2: 115.5 n7dl n 2 31 s46/31 -26L1 O1 4 6 3 P/KO 9 1 mac 9725.0 10 Sm 1251 H- MH- 6 ' Vertical Section at 0.001 (85 usff/in) M ConocoPhillips Project. Kuparuk River Unit Site: Kuparuk 3K Pad wmwFamnw wnn M.erm xon6: nsr MyroG[Fleb WELLBORE DETAILS: 3H -26L1 REFERENCE INFORATION Parent Wellbore: 3H-26 UA dmle(N�E) Refereve: Wdl3&26, True Nvb Well: 3X•26 Wellbore: 311 261_1 a4eiblk 5I636AnT Dw TmM: m.ae• Tie on MD: 6974.]0 Verdin (TVD) RNverc 3X-26®8D.DDueD(3H-M Plan: 3H -26L1 wp02 (3X -2813H -26L1 a le. snrmn nw Leoov]ot Sector lVfi)RNerenx: bbl -ro.mN, O.mE) Mea Sect OM) RNee.: 31446 AN,Oa13H 26) Cakuhlmn mvhw: M'unnum Cueabre 31-1-26 @ 80.00usM (31-1-26) West( -)/East(+) (200 usft/in) FPS .I BAKER HUGHES KUP PROD 3H-26 ConocoPhilhps Well Attributes Max Angle $ MD 70 Alaska, lr1C V/el noee APIII1Wl Fieltl Name Well0oto 51alua 501032020800 KUPARUK RIVER UNIT PROO nal l") MG (NNR) p[I64n (1168) 39.20 5,149.90 6,6600 Comment .. (ppml Gale SSSV: NIPPLE 120 1/]12016 Annotate.Eno GaLL Leal WO: 429/2005 KBGp(R) Rig Rata.. Bala 40.99 31811994 a8a6, snvmlfiaares AM van- eel.n.ue yam An...an BBpIM1 (fll(B) EnG Oale L.MTag: SLIV 8,3230 3/22/2015 pnnolalion tact Moo By Eno he Rev RnnuRH2S,GLVGO ppmven 5252018 KPNGER:3]a a5 ng trin S - - Caaing h-h,Von OO(n)Ip lin) tap (nKB) Snl Depth (XKBI Sel Depth lNpl... WVIen 11... GnEe TopTbaaE CONDUCTOR t6 15062 409 121.0 121.0 62501+40 WELOED Ca6ina GeampInto Op llnf ,vee Top (NKBf SN PopIN IflKB) £el MON 1TVG)... WULm 11... Gn4e Top TM1reaE SURFACE ]518 68]5 40.9 3,142.8 3,140.3 29.]D L-80 LTC Culn9 Ges<nptlon Op lin' 10(In) TOP INK.) Bel Oepe(XNBf Sal Depth ITVO)... W'ULen'l Rl.. TOPTn d PRODUCTION 51/2 4.2]6 38] 6,6431 6,290.9 1].00 L-80 LTC 5.5x5"@6552' Tubing Strings T.tanu n ,,u.n senna ma_. mOnl mPln.a' sal papa Ix.. set..Pm I. b.. wtOmp' Tp connemm. TUBING WO 31/2 2.992 3L0 6,126.0 5,]93.1 9.30 Lr60e EoIIE IBT CORIP1.t10O Details xnmaal l0 TnP 1NK0) Top ING)INKB) Top Incl ('j Item Bzs Cem gn) cONOUCTOR:ID9131A 3>.8 3].B 0.09 HANGER FMCTUBINGHANGER 3500 504.2 504.2 1.16 NIPPLE CAM CE"'D DINGNIPPLE 2875 6,106.2 5,]]66 21.13 NIPPLE CAMOO'DS' NIPPLE 2.812 NIPPLE WBR 6,113.2 5,781.1 20.99 LOCATOR BAKER GBH -2 -LOW un, 2.850 6,1135 S.7SA 20.98 SEALASSY BAKER 30T GBH -22 SEAL ASSY 2.W DDRIFT 2900 Perforations 8 Slots Shot Da. To, (11)) IRS(rv(t) (.he. Gas uR;l T6s.l Top(ftm) BM/XKB) (XKB) MK.) Ipne Gab I) Type Co. 5,250.0 6,280.0 5,9100 5.938.6 C4, Cd, 31+ 611511998 40 RPERF 2IM' Spode, O deg ph 26 6.260.0 6,200.0 5.910.0 5,9386 C-0. C3, 3H- 4I9I1997 401PERF 111I16'PNOTS, 180 26 deg. ph 8308.0 6,336.0 5,9634 5,9922 A 'A2, 3H- 26 0124/1994 40 (PERF 2118' EnerJeL 90 tleg. Ph Mandrel Inserts BI Mi 3U0.FaCE:90 S].tI1A- H Tap (NO) Valva 1a1µ PoNBiaa TRGRun Top(XKBI (XKB) Make MotlN 00 (in) 4ery Type Type len) het) Run Gate Lam 1 2,]65] 2,763.5 CAMCO KBG-2- 1 GAS LIFT GLV BTM 0.188 7,2420 51242015 9 2 4,1244 4,096.2 CAMCO KBG-2- 1 GASLIF1- OV BTM 0.250 80 5242016 GASUFi'. a.na,a 9 3 4,987.6 4836) CAMCO KB -&-27- 1' SUET DMY BTM 0.000 0.0 1IN2016 9 9 5,6309 5,351.9 CAMCO KBG-2- 1 GASLIFT DMY 5K4 0.000 0.0 67302005 9 5 6,055.1 5.]2]0 CAMCO KSG-2- 1 GAS LIFT DMY DK -1 0000 0.0 fi13G/2005 9 GASLIFTICS810 Notes: General &Safety - Entl120pate Mnoletian 412905 NOTE: TREE '.FMC 3 -110 -"GEN IV /5000 psi calm 1112612009 NOTE: View BCM1amaticwl Nasky Bcxemalic9.0 cAs uFrs.W6A ws uFT. s.csE.. NWPLE 6, 1082 SE010.¢ST. 6.11]6 RPERF:8350.081W.0 (PERF: 8.260.0 S.2W0 IPERF.B3060.6.Ai80- PRODUCTION SAY®BSS3� ]B>d Na.t '6"6 6" 62# H-40 shoe @ 121' MD 7-5/8" 29.7# L-80 shoe @ 3143' MD F3-1-12—'9 .3# L-80 shoe @ XXXX' MD 5-1/2" 17# L-80 @ 6133' MD C -sand perfs 6250' - 6280' MD A -sand perfs 6306'- 6336' MD 5" 18# L-80 shoe @ 6643' MD 311-26 Proposed CTD Schematic .. •.. • 3-1/2" Camco Landing Nipple@ 504' MD (2.875" min ID) 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco gas lift mandrels @ 2766', 4124', 49881, 56311, 6055' 3-1/2" Camco DS nipple @ 6106' MD (2.812" min ID) Baker 3-1/2" GBH -22 seal assembly @ 6114' MD (2.98" ID) 3H-261.1-02 wp01 TD @ 9725' MD Top of Liner @ 6272' MD 311-261.1 wp02 TD @ 6900' MD Billet @ 7500' MD 3H -26L1-01 wp01 TD @ 8900' MD Billet @ 7400' MD TRANSMITTAL LETTER CHECKLIST WELL NAME: MU, 3 µ - az(ui -o ff PTD: c2/ 7 - O W Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: I�U46L�POOL: ` �t A11/4 oi/ 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. - 0 2 , API No. 50-LO3 - RO 9 OR - 06 - 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 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 sam les arefirst caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company -Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Companv Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 _ —Well Name: KUPARUK RIV-INIT3H_26L1-01 Program DEV Well bore seg PTD#:2170880 Company CONOCOP II S ALASKA INC _ __- Initial Class/Type DEV LPEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal Administration 17 Nonconven. gas conforms to AS31,05,0300A.A),0,2.A-D) _ NA 1 Permit fee attached. _ _ NA 2 Lease number appropriate. _ _ _ _ Yes ADL0025531, entire wellbore. 3 Unique well name and number Yes KRU 31-1-261-1-01 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 Yes Geologic Engineering ��Puuubblliic Commissioner: Date: Commissioner: Date Copi mis�j� er Date (/�E-F, (' 11-6 � t + 8 If deviated, is wellbore plat included Yes _ 9 Operator only affected party _ Yes Wellbore will be more than 500' from an external property line where ownership or landownership changes. 10 Operator has. appropriate bond in force _ Yes Appr Date 11 Permit can be issued without conservation order Yes PKB 6/14/2017 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait _ Yes _ 14 Well located within area and strata authorized by Injection Order # (put. 10# in comments)(For NA 15 All wells. within 1/4 mile. area. of review identified (For service well only). _ _ _ NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) _ NA 18 Conductor string. provided ......... _ _ _ NA Conductor set. in KRU 31-1-26 Engineering 19 Surface casing protects all. known USDWs _ _ NA _ Surface casing set in KRU 3H-26 20 CMT vol adequate to circulate on conductor & surf. csg NA Surface casing set and fully cemented 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT. will cover all known productive horizons No. Productive. interval will be completed with slotted liner 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all waste to approved disposal wells 25 If a. re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is 3990 psig(12.7 ppg EMW); will drill W/ 8,6 ppg EMW and. maintain overbal w/ VTL 6/22/2017 29 BOPEs, do they meet regulation Yes .MPD 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 3405 psig; will lest BOPS to 3760 psig _ 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of 1-12S gas probable Yes H2S measures required 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Wells on 3H -Pad are H2S-bearing. 1-12S measures required. Geology 36 Data presented on potential overpressure zones Yes Max. potential reservoir pressure is 12.7 ppg EMW; will be drilled using 8.6. ppg mud and MPD technique. Appr Date 37 Seismic analysis of shallow gas zones NA PKB 6/14/2017 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 ��Puuubblliic Commissioner: Date: Commissioner: Date Copi mis�j� er Date (/�E-F, (' 11-6 � t +