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218-085
DATA SUBMITTAL COMPLIANCE REPORT 1/18/2019 Permit to Drill 2180850 Well Name/No. KUPARUK RIV U WSAK 1H -104L1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23610.60.00 MD 15792 TVD 3915 Completion Date 9/18/2018 Completion Status 1-0I1 Current Status 1-0I1 UIC No REQUIRED INFORMATION f Mud Log No v'/ Samples Nov./ Directional Survey Yes DATA INFORMATION List of Logs Obtained: Gr/Res (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 29842 Digital Data 8396 15972 10/17/2018 Electronic Data Set, Filename: CPAI_1H- 104L 1_Scope_Resistivity_L W D006_RM_LAS.las ED C 29842 Digital Data 103 1906 10/17/2018 Electronic Data Set, Filename: CPAI_1H- 104_VISION_Resistivity_LW D001_RM_LAS.las ED C 29842 Digital Data 1781 9514 10/17/2018 Electronic Data Set, Filename: CPAI_1H- 104_VISION_Resistivity_LW D002_RM_LAS.las ED C 29842 Digital Data 140 15972 10/17/2018 Electronic Data Set, Filename: CPAI 1H- - 1041-1—Scope 104L 1 _Scope_ Resistivity_RM_LAS.las ED C 29842 Digital Data 10/17/2018 Electronic File: CPAI_1H- H- 104 VISION—Resistivity_RM 104VISION_Resistivity_RMDLIS_L W D001.dlis ED C 29842 Digital Data 10/17/2018 Electronic File: CPAI_1 H - 104_V IS ION_Resistivity_RM_DLIS_LW D001.htm I ED C 29842 Digital Data 10/17/2018 Electronic File: CPAI_1H- 104_VIS ION_Resistivity_RM_DLIS_LW D002.dlis ED C 29842 Digital Data 10/17/2018 Electronic File: CPAI_1H- 104_VIS ION_Resistivity_RM_DLIS_LW D002.htm I ED C 29842 Digital Data 10/17/2018 Electronic File: CPAI_1H- 10411 Scope_Resistivity_RM_DLIS_LWD006_D rilling.dlis ED C 29842 Digital Data 10/17/2018 Electronic File: CPAI_1H- 10411 Scope_ Resistivity_RM_DLIS_LWD006_D rilling.html ED C 29842 Digital Data 10/17/2018 Electronic File: CPA] _1H- 104L1—Scope _ Resistivity_RM_DLIS_LW D006_M ad Pass.dlis AOGCC Page 1 of 4 Friday, January 18, 2019 DATA SUBMITTAL COMPLIANCE REPORT 1/18/2019 Permit to Drill 2180850 Well Name/No. KUPARUK RIV U WSAK 1H -104L1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23610-60-00 MD 15792 TVD 3915 Completion Date 9/18/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 29842 Digital Data 10/17/2018 Electronic File: CPAI_1H- 104L1 _Scope_Resistivity_RM_DLIS_LW D006_M ad Pass.html ED C 29842 Digital Data 10/17/2018 Electronic File: CPAI_1H- 104L 1 _Scope_Resistivity_DLI S_RM.dlis ED C 29842 Digital Data 10/17/2018 Electronic File: CPAI 1H - 104L 1 _Scope_ Resistivity_DLI S_RM. htm I ED C 29842 Digital Data 10/17/2018 Electronic File: CPAI 1H - 104L 1 __ScopeResistivity_2MD_RM.pdf ED C 29842 Digital Data 10/17/2018 Electronic File: CPAI_1H- 104L 1 _Scope_Resistivity_2T VD_above_90deg_ RM.pdf ED C 29842 Digital Data 10/17/2018 Electronic File: CPAI_11-1- 104L 1 _Scope_Resistivity_2TVD_RM.pdf ED C 29842 Digital Data 10/17/2018 Electronic File: CPAI 1H - 104L 1 _Scope_Resistivity_5MD_RM. pdf ED C 29842 Digital Data 10/17/2018 Electronic File: CPAI_1H- 1041.1Scope_Resistivity_5TVD_above_90deg_ RM.pd_f ED C 29842 Digital Data 10/17/2018 Electronic File: CPAI_11-1- 104L1_Scope_Resistivity_STVD_RM.pdf ED C 29842 Digital Data 10/17/2018 Electronic File: 1H-104L1_PhntSurveyList.csv ED C 29842 Digital Data 10/17/2018 Electronic File: Gyrodata Survey - 1 H-104 - Post SLB SAG.pdf ED C 29842 Digital Data 10/17/2018 Electronic File: 1H-1041-1 NAD27 EOW Compass Surveys [Canvas].txt ED C 29842 Digital Data 10/17/2018 Electronic File: 1H-1041-1 NAD27 EOW Compass Surveys [Macro].txt ED C 29842 Digital Data 10/17/2018 Electronic File: 1H-1041-1 NAD27 EOW Compass Surveys [Petrel].txt ED C 29842 Digital Data 10/17/2018 Electronic File: 1H-1041-1 NAD27 EOW' Compass Surveys [Surveys].dd ED C 29842 Digital Data 10/17/2018 Electronic File: 1H-1041-1 NAD27 EOW Compass Surveys.pdf ED C 29842 Digital Data 10/17/2018 Electronic File: 1H-1041-1 NAD83 EOW Compass Surveys [Canvas].txt AOGCC Page 2 of 4 Friday, January 18, 2019 INFORMATION RECEIVED r� Completion Report V Production Test Information@Y / NA Geologic Markers/Tops O COMPLIANCE HISTORY Completion Date: 9/18/2018 Release Date: 8/1/2018 Description Comments: Directional / Inclination Data U/ Mud Logs, Image Files, Digital Data Y / !�P Core Chips Y /(5) DATA SUBMITTAL COMPLIANCE REPORT Daily Operations Summary V Cuttings Samples Y / 6 Laboratory Analyses Y / A 1/18/2019 Permit to Drill 2180850 Well Name/No. KUPARUK RIV U WSAK 1H -104L1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23610-60-00 MD 15792 TVD 3915 Completion Date 9/18/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 29842 Digital Data 10/17/2018 Electronic File: 1H-1041-1 NAD83 EOW Compass Surveys [Macro].txt ED C 29842 Digital Data 10/17/2018 Electronic File: 1H-1041-1 NAD83 EOW Compass Surveys [Petrel].txt ED C 29842 Digital Data 10/17/2018 Electronic File: 1H-1041-1 NAD83 EOW Compass Surveys [Surveys].bd ED C 29842 Digital Data 10/17/2018 Electronic File: 1H-1041-1 NAD83 EOW Compass Surveys.pdf Log C 29842 Log Header Scans 0 0 2180850 KUPARUK RIV U WSAK 1H-1041-1 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name start Stop Sent Received Number Comments INFORMATION RECEIVED r� Completion Report V Production Test Information@Y / NA Geologic Markers/Tops O COMPLIANCE HISTORY Completion Date: 9/18/2018 Release Date: 8/1/2018 Description Comments: Directional / Inclination Data U/ Mud Logs, Image Files, Digital Data Y / !�P Core Chips Y /(5) Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Y Core Photographs Y/ A Daily Operations Summary V Cuttings Samples Y / 6 Laboratory Analyses Y / A Date Comments AOGCC Page 3 of 4 Friday, January l8, 2019 DATA SUBMITTAL COMPLIANCE REPORT 1/18/2019 Permit to Drill 2180850 Well Name/No. KUPARUK RIV U WSAK 1H-1041-1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23610-60-00 MD 15792 TV 3915mple ion Dates 9/18/2018 Completion Status 1 -OIL Current Status 1 -OIL / UIC No Compliance Reviewed By: � 2 Date: AOGC'.0 Page 4 o(4 Friday, January 18, 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ta. Well Status: Oil ❑ Gas El SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ❑ WINJ❑ WAGE] WDSPL❑ No. of Completions: 1b. Well Class: Development 2) Exploratory ❑ Service ❑ Stratigraphic Test El 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: • 9/18/2018 14. Permit to Drill Number / Sundry: 218-085 3. Address: P.O. Box 100360 Anchorage, AK 99510.0360 7. Date Spudded: -8126/2018 15. API Number: 50-029-23610-60.00 4a. Location of Well (Governmental Section): Surface: 5201' FNL, 772' FEL, Sec 28, T12N, R10E, UM Top of Productive Interval: 2076' FNL, 5520' FEL, Sec 35, T12N, R10E, UM Total Depth: 2120' FNL, 3928' FEL, Sec 26, T12N, R10E, UM 8. Date TO Reached: • 8/31/20-18- 16. Well Name and Number: KRU 1H -104L1 9. Ref Elevations: KB:92.79 GL:54.1 BF: 17. Field / Pool(s): Kuparuk River Field/West Sak Oil Pool 10. Plug Back Depth MD/fVD: N/A 18. Property Designation: ADL25639, ADL 25638 41b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 649569 y- 5980782 Zone- 4 TPI: x- 555699 y- 5978670 Zone- 4 Total Depth: x- 556945 y- 5983915 Zone- 4 11. Total Depth MD/TVD: .15792/3915 19. DNR Approval Number: 80-261, 931695000 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1738/1646 5. Directional or Inclination Survey: Yes B (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL)J 21. Re-drill/Lateral Top Window MD/TVD: 8335/3817 22. Logs Obtained: List all logs run and, pursuant to AS 31 .05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 94 L-80 40 118 40 118 42 Existing cement to surface 103/4 45.5 L-80 40 1899 40 1777 13112 885 sx 11.0ppg Class G 75/8 29.7 L-80 37 9493 37 4086 97/8 1401 sx 15.8ppg Class G 41/2 12.6 L-80 8329 15935 3815 3917 63/4 Slotted Liner 24. Open to production or injection? Yes ❑r No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER @: 8464-15935 MD and 3828-3917 TVD.... 9/4/2018 COMPLETION26. QAV AT�. _ q r 0Ira_ VE IFIIIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 41/2 8051 NIA ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes El No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) 1AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 9/29/2018 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 10/6/2018 Hours Tested: 14hrs, 7min. Production for Test Period Oil -Bbl: 2181 Gas -MCF: 569 Water -Bbl. 19 Choke Size: - Gas -Oil Ratio: 261 Flow Tubing Press. 340psi JCasinq Press: Calculated 24 -Hour Rate Oil -Bbl: 37 Gas -MCF: Water -Bbl: Oil Gravity - API (corr): 19 Form 10-407 Revised 5/2017 - <1�2 /d8 -/ GQNTINUED ON PAGE 2 4r, r n o Submit ORIGINIAL o 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No EZ If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1738 1646 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 8335 3817 information, including reports, per 20 AAC 25.071. Formation @ TPI -West Sak D TD 15972 3915 Formation at total depth: WEST SAK B 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontolooical report. production orwell test results ner 20 AAC 25,070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. c. ' 1 G— Authorized Name: G.L. Alvord Contact Name: Scott Brunswick /7 Authorized Title: Alaska Drilling Manager Contact Email: Scott.A.Brunswick o co .com Authorized Contact Phone: 263-4249 Signature: ' Date: / 01(7/2-,18 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 11b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10407 Revised 5/2017 Submit ORIGINAL Only uuloxd Covel for cam6.ID", 949, K55 x 34".0312' W Cin 134'MD 10-3/4".4559, 1-1hQ HW563I MDI Mr TVD Wellbend /Tubing Head I Tree, 13-3/e"x4-'A", 5,000 ku 4.1/3',12 6 k. L40IBT-M Ga Lin Mandrel, 4-1/2" x v w/ SOv 2500' MD Gu Lin Mandrtl, 4.1/2" x 1" w/dummy vdve 5)32' MD H s 1H-104 Producer Schematic Fr al ae mpr pleted G. Lift Mandrel, 4-12" x 1" W dmmny vah'e n = �)164'hII) F £ 4-W SSD wiU 3812" DB Nipple profile ))99' MD nO Pemmnent Down Hoo Gwgc A 25tukd Baker HaokHwu 796TMD Isvel3 Junrdoo Syarwnr �. Tubing Seel Aacmbly f� 8019' MD ZKP Pxkers� ��L2"D'Swd Upper Loh Windmv (oJ 816)'MDl3)tl5'ND IH -10,112: Harz' MD IH -104 LI: 82)1'MD �I 4-Ih"Slowed Liner wd frank pipe 1269 6-80 T%P/IBTM 3.75" DB Nipple Pmfil. ... ............ ....................................... 8100 MD LI "D' Sand Lower Loh Window I& 8334' MD 1381@ TVD Lateral Ent, Module 0.]2 Sknted Liner wd Blank pipe 120 680 TXP/IBTM __----.--______________________ Tubing Seel Aammbly ............ .. .............................. 3.562" DP Nipple Pmfie %439 MD LO Z)Ppoker 412" Stoned Liner aM Blank Pipe, 1269 TKP5LHT L80 8444'MO ____________ __ .. 0-5/8", 29)k, 1-80. Hyd563, C _________ ------------ In `> 9,193'MD/409I'TVD .... ........... M..M1A ........................ 63X DIB III (L I) tuner&) 15972' MD / 3915' TVD G 3/4" AVA3 KUP PROD f,..�' Well A" but ConoeoPhillips MM Name — AaskP,bIC. WESTSAK 1H-104 IH-1o4nmlgama 3 U47 PM Last Tag Vmuul x mrnrw Pearl Ax-amon EM Data war "a) L.xl Mod er EAST TAG: lennah ...............................__.__....................................... NBING ItAHOER, 33 a Last Rev Reason I. Animal End Daft last MOO BY ...axho................................................... ... .. ............ REVREASON'. New Mululal, Installed Gas Lift Design 8 Pulled RHC SI28MS jannalt Casing Strings CasinpDaxcriplion OD (an) ID Dna Top NUOU Sal Depth (SHE) SetDepth PVD)... Walan ll... Graft Top Th—d CONDUCTOR: ab sues CONDUCTOR N 1912. 404 118.5 1185 94.00 LA0 Welded Earn. DesCriptlon OD (ira) ID lint Top HUMEN Stl De,m HVUR Set Depth RV01... W nN... Graft Top Thread SURFACE 10314 SISK 40.3 1,899.3 1,7774 45.50 L40 Hyddh 563 CaeLq Deeerlpibn ODUnl IDllnl TopinitV SM Depm lRMel SM Sapth RVOI... YNLan 11...Grtle Top Thread ro RME; an...a INTERMEDIATE 7518 6.88 37.5 9,493.2 4.086.2 29.]0 L40 Hyd 563 Casinp Dncnppon ODIMI 106n) Top lnn8l SN DepIh InR01 set DeWh lrvOl.-1VULen o... cane Top ThrcaO GAS LIEr'2sz3e SLOTTED LINER (MAIN 4112 3.96 8p4d.9 15.993.8 4925.8 12.fi0 L-80 SLHT WELLBORE) Liner Details Nominal lD GAS LIFT: 6,M3 Top (.xe) Top"OURKe1 Tap ISSU') Item Dex Con (in) 8,4649 3,6404 7903 NIPPLE Baker 85" "RS"PackO eel Nipple N L- 4.880 GAS LET: 7 I 5 Hyd 563 box x box 8,46].] 3,8410 78.93 MAN ER Baker 6Y x 7. "FImoL ck Liner hanger #L- 4.800 SLICING SLEEVE; 7BUT 1 Hyd 563 pin x pin 8,4]].5 3,8429 7862 SHE BOW 190-N,4 7F ID Seat 80re E.Hmaod, 112" 47M Hyd 563 box x pin 8,497.1 3,8469 77.82 XO 58' Hyd 56315.5#box . 4D'12.6# TXP- on 3.970 REDUCING Crossover LOCATOR: B.,2 FACNER,9.m37 10,718.1 4,0962 9179 I1 E EGRETS .0"OD Swell Packer #6 ( N: t- 3.940 SEA Asay: SM9 PACKER 21 SSE: S.GC7 11,012.3 4,0933 88.99 ELL Baker 6.0" OD 6w611 Packer #5(2) N: 5 1- 3.940 CROSSOVER Ixol BUSHING. RESID PACKER 32 MCTL TRI9ME CONNECTBSMNUS.G: a1 11,585.5 4,0766 9281 PACKER Baker 6 T OD Svrell Packer #4(1) N: - 5 3.940 NG iR19RE CONNECT BUS , Be..g,R.E. L38LOTTEDLIN'EW6 11, .0 4,047.9 94.63 A LL PACKER akar 0" OO Ewell Packer#3(C) SN; 054 - 1 16 3.950 6,1@$14010 PACKER: gats 13,5)4.) 4,008.8 9199 W LL ker well Packer#Z B) SN: 05400 1 - 3.940 sB 2 PACKER 20 os SHIN [fls oVEfl lxo)au epm9 13SLU,4 4,013.9 82.0> LL Baker 6P 00 Swell Packer #1 (A)SIN 0540091 - 3940 TRIWLE CONNECT BUSHING; PACKER 14 0,3E0 Tubing Stringss iRIFP1E CONNECT BUSHING. 'UNITx,ip,mn stung Ma... lD lml Top(nKel sxt Dxp,n ln. 9x0 De pm (rvD14.. Gm0a Top Connecron uSLOTTED LINER (LI), g32RG1s,m4.T TUBING- 41/2 3968,0508 3,Ifi4.1 12.60 12.60 L-80 IBT-m PRODUCTION Completion Details ToplMl rvomim lop III In711 Imm Des cold 10181 8031 ],8031 3,7114 76 7630 LEEVE 4-12 "Sliding Sleeve.IBT-m,3812 CMU, RHC Plug wl DB Lock 3.812 SLEEVE 7,971. ,7 . 78.43 GAUGE " Olid gauge Mandrel, , single gauge, RO -15 3.898 gauge TXP-m 8,0 1. 3,]58.6 ]9.13 LOCATOR Baker 1 locator sea assembly(OD 5.38" Larger D Rama, 3.870 located INTERMEDIATE 3).69.493] ,7599 79.16 SEALASSY Baker 19247 locator seal assembly Wmule shot beloN located 3.870 Mandrel inserts nr N ToRKIN Vehre Iskn Port Size TRO Run Top InKB) gIKB) MOF, Modes OOlinl 9ery Type Type 9n1 (ps)) Run Oate Cam 1 2523.9 2,190.8 Camco KBMG t GAS LIFT GLV BK 0.188 1,4580 92A2018 5,]36.8 3,149.3 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,4670 92]2018 3 J, 16].5 3,554.3 Camco KBMG t GAS LIFT OV BK 0.313 00 92]12018 Notes: General & Safety EnODah i Anroafton 1011112018 NOTE: View SChemalidw/Alaska Schemalic100 SLOTTED LINER Gra. � W WELLBORELB.M'Glassz.T KUP PROD 1H -104L1 C0r10CUPFn��ips AIBSkB, Inc. Well Attribut WEST SAK Max Angle. 1 TD WellbxeAPNUW WeIIWre9Ytua °t HIGHACIBImI NBt 500292361060 PRGD 4.87 11,958.w 15,792.0 Co...., N251ppm1 Oale AnnahNan EnE bat N9G�a lflt Ria Release Uale I�LST WO'. 38.89 9118/2018 1n-1oaLTlmarzmes�aa:ae PM Last Tag vcnblrcMr,Ym I�Nd) Mo.. LAST TAG: End Oah Ueplk lNKe) usi Moa By jennalt ................_......_........._.................._............._._.......__.... TUBING WINGER: a2. a Last Rev Reason _.................._................__....................... ................ ................... Bnnohtion EM Dab b.IMM Rr ........................................................ ... ..........._. REV REASON. New Muiulet, lostalletl Gas Lift Design B Pulled RHC 928/2918 Iernat ml Casing Strings Caaing Dexrblion oolIn' Io pnl TOP MKRU ell Own(UNS) oegW 1110).-WAen p_. Gude Top Tho -d LI SLOTTED LINER(11) 412 3SO 3.96 8,329.0 15,934.7 3,9169 1269 L-80 IBT-m Liner Details LCNOUCTOR; 40.61165 Nominal lD TOP(a.0) Tnp TVD)pord Topincle) Nem Uec Com lin) 8,329.0 3,8154 79.36 HANGER Baker'13-T Flanged hook harder. 4.5"X7. ' bade 5620 casing SURFALE40.34.8910 8.3484 3.818.7 81.35 HANGER Baker' -"Flanged hookhanger. 45"X'1.63'BOW 8348.34' MD 3990 GAS LIFT: as24.e 8.4486 3,827.6 8826 SWELL PACKER Baker 6 IF OD Swell Packera 927' SN: 054003 010-15 3.958 10,4008 39019 8639 SWELL Baker D Svvell Packerp " 59 03 3.958 PACKER 010-10 614 LIFT; S,Tade 10.6516 3,915.4 8549 SWELL Baker ." OD Swag Packer #5 -BB SN 054007- 3,958 PACKER 010-23 10,811.3 39363 81.43 SWELL Baker D well Packerp "AA" SN 0540N. 3958 ],1.5 GAS UFr;91 PACKER 010-25 11,176.6 3.97.5 87.66 SWELL Baker .'OD well Packer "F" M 5409- 3.958 SUOING SEEVE: 7AGA PACKER 010-16 13,6450 3,9498 83.12 SWELLBaker 8O'0D weN Packer #2 "E" N'. 3.958 PACKER 010-24 13,830.1 3,9710 MAE WE Baker 60" 0D Swell Packer Bl "D" SN; 3.958 PACKER 010-1 LOGBIDN;8M2 Tubing Strings Tuelna oeacaPrwn Smna Ma... Iv tin) roP(UK.) sn Deom In..sal D MEND) 1... cal(IM) Grafi ropCkonMo v.....121 sEUAasv: ER29 L1 LEM/ZXPLINER 4112 3.Be 8271.4 8,4905 3.828.6 1260 L-89 TXP-m BTC am .9021 TOP PACKER GROWCAG! ped BOSHM. 9.6523 Completion Details TaPo`d) TOPlud Nark. mP INKa) I (-9) I r) I Com 1011n1 NIVPLE:8.100.T 8,271.4 PACKER Baker ZXP Liner Top Packer 5.5"x]63",5 -1/2'H563 4. TNIPGLE CONNECT BUSHING, 8,291.2 SBE Baker 19047 Seal Bare EMen9ion, 5-12' 4350 9,ISae TRIPPLE CONNECT BU9Ha1G1 8,310.8 3,812.0 79.26 V ReBuOng Crossover sub SK"HYB 563X 4-17Y'TXP 3.960 meso (XO) BUSHING 1-291-07TEDUNER $325.8 3,814.8 79.34 TITPaker45'x763-LCM#1(Above Hookhanger) SN# 7 30 SGGG`5.02r.0 CONNECT 4)2 BUSHING PACKER; ESH a.\ 8.3290 381 44 79.36 Baker 4.5"x 7.&E LEM Ni (Below Hook Hanger @8328.95) B WE;S.s CROW OVER p0) BUSHING: CONNECT B.al6B BUSHING TRIPPLE CONNECT BUSHING, I..a 8,439.9 3,827.3 8792 NIPPLE Cam. 4-112"x3.563'DB-6 Rippe, TXP-m She 57732 S INTERMEDIATE: W 584962 Bp873 3,828.5 8900 SEAL ASSY akert -aT GBH-22.4-tYC', L-eO StreigM1t NOR -Locating Bal 389 TRIPPLE CONNECT BUSHING a.aso Ass, Notes. General & Safety End Dau Arno., - 10/11/2018 NOTE: View Schematic w/ Alaska SChemebrIC0 xlPVLe.aaae.a am May. 8.441.2 L19LOTTEO LINER o l), 1' WSS O.15,HKA7 KUP PROD 1H -104L2 dL11W-E1d2T1S1AK Well AHribut Max Angle 1 TD Corm;hilhPs Wenbore APYUW ia.u.ne sai MOIL. Ad BGo FSKO) Alaska.lrlc 500292361061 PROD 628 12.329.UO 1563]0 AST WO 1 138.89 I,Se2. 1nards". U. He Last Tag V✓eW (pace) Anacreon LAST TAG'. EM de" eapib(HKB) LeeLMCOBy lennall Last Rev Reason iNBING MANGER: a3.6 AnnolNbn EnE BN! tISIMW BY -" """"' --- -- ---'- REVREASON: New MulglaL Instilled Gas Lift Design B Pulled RHC 92812018 lennalt ml Casing Strings ............................................................... .............. canine Description oo (In) mpn) Top IM1Ke) el Do III pilon set Oe Pm Roc), WULen(I Grade Top Thema L2 SLOTTED LINER H2) 4112 3.96 8,162.9 15,82].0 3.868.6 1260 L80 IBT-m j%'827 Liner Details Nommal10 Top lnxe) Top RrvId UKB) Top Inc) l°) I. BK Cam U,,) 8162.9 3784.6 79.39 HANGER Baker "B -Y' Flanged hook hanger, 4.5"X].63"Inside 5.630 CONDUCTOR: er N I85 casing 8,1823 37879 8115 PANGER Flanged hook hanger. 46 X 7.63BOW 3.990 @ 81MR5' MD 8,281.9 3,7974 8886 W LL Baker SO" GO 8.11 Packer #"MM' 7010719= 3.958 PACKER 001-9 SURFACE. NYI saea 13,819.6 3.864 7 7858 SWELL Baker FYOD Swell Packer # "LL" SN: 001893- 3.958 PACKER 001-15 13,9214 3.9020 8676 WE . " LL a er OD Swell Packer "KK" -S-N-0-0-1-83T= 3.958 GAB LIFT: ZS2a.9 PACKER 001-10 Tubing Strings rneilq oo¢aPtbn slnny ma... mpnl Top lnke Ser Depm (ft DepmlTVm1...M Raflu Gnde Top Connmem, L2 LEM2XPLINER 4112 3.96 8,0127 8.302.0 19; 3J9J.6 12.60 L-80 TXP-M TOP PACKER GAS OFT:.,.a Completion Details mp two)Top Incl NamBul Tap IRKB) (nKB) 1°) parvo s Com ID (n) 8,0127 PACKER Baker ZXP liner Tap Pecker 5 5" x 7 63", 5-112'H553 4 920 .UFT ueDs $0327 SBE Baker 190A7 Seal Bore Extension, 5-12" 4.750 BAS. R VER Reducing Cmssrer sub SG" Hyd 563 X 4-12" TXP 3950 (XO)BUSHING 6LIDINGELEEYE:1,0001 8.1083 NIPPLE CamcO4-i@"x3750"DB4i Nipple, TXP-m SN# 58-1R 3.750 8.159.8 3784.0 79.36 TffffiiB8aG4S-x7.63"LEM#1boW Hook hanger N#10 368 3700 CONNECT -02 BUSHING 8.1630 3784.6 ]9.39 PPIE Baker45"x763"LEM#1 (Below Hook Hanger @81 ') 3.688 CONNECT BUSHING 8298.] 3,79]6 90.15 SL ASSY 8dker 19 AJ BH- ",L pmgl o cabng Seal EA 38]0 LOWOR: 8,@L2 PACKER: 8,0127 Asay SEALA66Y: A0226 6BE: GONG Notes: General $I Safety End Base "U'v " CROSEPose pro)BUSHING; 1011112016 NOTE'. View $thematic wl Alaska 5chemaliel O.0 Sours NIPPLe 81 W ] TRIPPLE CONNECT BUSHING. &1%a INTERBEWITE, "N'S"'TRIPPLE CONNECT BUSHING. &iW0 6EAL AsV' said, L2SLOTTED LINER (Up 81air"E' 2].0 Vperations Summary (with Timelog Drpths) Jul 11-1-104 NW Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log stun Depth Stan Time End Time Dur (hr) Phase Op Code ActiAly Code Time P -T -X Operation (111®) End Depth(%KB) 8/512018 8/5/2018 11.00 MIRU MOVE MOB P Move Rig F/1 H-1086-T/1H-104 0.0 0.0 09:00 20:00 Rig release F/1 H-1088 at 09:00 Rig accepted on 1 H-104 at 20:00 8/5/2018 8/5/2018 2.00 MIRU MOVE RURD P Make up surface riser to Diverter 0.0 0.0 20:00 22:00 annular, Obtain RKB Measurements, Take on remaining fluid to pits, Dress shakers. 8/5/2018 8/512018 0.50 MIRU MOVE BOPE P Perform surface diverter test, Koomey 0.0 0.0 22:00 22:30 drawdown, Test of H2S, & Gas alarms done Sim -Ops. Tested Gain loss alarms for pits, Flow alrms and trip tank alarm. Witness to test waived by AOGCC Rep Bob Noble. 8/5/2018 8/5/2018 1.00 MIRU MOVE SFTY P Held Pre -Spud Meeting with all 0.0 0.0 22:30 23:30 personnel &Table top diverter drill. 8/5/2018 8/6/2018 0.50 MIRU MOVE BHAH P Pick up bit, Motor, crossover and 1 0.0 0.0 23:30 00:00 stand HWDP. Prior to filling surface stack with spud mud. 8/6/2018 8/6/2018 2.00 MIRU MOVE SHAH P Make Up BHAand lag at 95' MD, Fill 0.0 118.0 00:00 02:00 lines and hole, Check for leaks. Pressure test mudline to 3,500 psi. Clean out conductor to 118' MD (RKB) 8/6/2018 8/612018 1.75 SURFAC DRILL DDRL P Drill 13-1/2" Surface interval F/ 118' 118.0 224.0 02:00 03:45 MD - T/ 224' MD 224' TVD. 450 gpm, 480 psi, 28% flow out,40 rpm, 2 k. torque,bit wt. 7-8k. Off bottom 400 psi. Up 57k. down 57k. Rot 57k. I torque off bottom, Max gas = 0, AST = 0. Art =1.25, Bit hrs. 1.25, Jar his. 25.78. 8/6/2018 8/6/2018 2.25 SURFAC DRILL BHAH P Rack back 2 stands HWDP, Make up 224.0 224.0 03:45 06:00 remaining BHA. 8/6/2018 8/6/2018 6.00 SURFAC DRILL DDRL P Drill 13-1/2" Surface interval F/ 224' 224.0 606.0 06:00 12:00 MD - T/ 606' MD 605' TVD. 450 gpm, 845 psi, 31% flow out,60 rpm, 4 k. torque,bit wt. 20k. Off bottom 675 psi. Up 74k. down 79k. Rot 79k. 2k torque off bottom, Max gas = 0, AST = 2.06. Art =1.83, Bit hrs. 3.89, Jar his. 29.12. 8/6/2018 8/6/2018 6.00 SURFAC DRILL DDRL P Drill 13-112" Surface interval F/ 606' 606.0 1,148.0 12:00 18:00 MD - T/ 1,148' MD 1,126' TVD. 550 gpm, 1,430 psi, 32% flow out,60 rpm, 51k. torque,bit wt. 30k. Off bottom 1,200 psi. Up 89k. down 89k. Rot 89k. 2k torque off bottom, Max gas = 0, AST = 1.21. Art =2.47, Bit hrs. 7.52, Jar hrs. 32.80. 8/6/2018 8/7/2018 6.00 SURFAC DRILL DDRL P Drill 13-1/2" Surface interval F/ 1,148' 1,148.0 1,815.0 16:00 00:00 MD - T/ 1,815' MD 1,709' TVD. 550 gpm, 1,520 psi, 36% flow out,60 rpm, 6k. torque,bit wt. 30k. Off bottom 1,286 psi. Up 99k. down 94k. Rot 95k. 2k torque off bottom, Max gas = 7,500 Hydratess at 1,375' MD+/ - AST = 1.75. Art =2.47, Bit hrs. 11.79, Jar his. 37.02. Page 1/36 Report Printed: 9/24/2018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log stad DepN Start Time End Time our (hr) Phase Op Code Activity Cade Time P -T -X Operation (flKB) End Depth (19(B) 8/7/2018 817/2018 0.50 SURFAC DRILL DDRL P Drill 13-1/2" Surface interval F/ 1,815' 1,815.0 1,906.0 00:00 00:30 MD - T/ 1,906' MD 1,783' TVD. 550 gpm, 1,520 psi, 36% flow out,60 rpm, 6k. torque,bit wt. 30k. Off bottom 1,286 psi. Up 99k. down 94k. Rot 95k. 2k torque off bottom, Max gas = 7,500 Hydrates at 1,375' MD+/ - AST = .44. Art =.07, Bit hrs. 12.3, Jar hrs. 37.53. 8/7/2018 817/2018 0.25 SURFAC CASING OWFF P Monitor well, static. 1,906.0 1,906.0 00:30 00:45 8/7/2018 8/7/2018 3.50 SURFAC CASING BKRM P BROOH f/ 1906'-863' MD, 550 gpm, 1,906.0 863.0 00:45 04:15 1350-1150 psi, 60 rpm, FO 34%, Tq 2- 4K. BROOH 1st stand pumping a BU. BROOH last 2 stands pumping a BU. 8/7/2018 8/7/2018 0.25 SURFAC CASING OWFF P Monitor well, static. 863.0 863.0 04:15 04:30 8/7/2018 8/7/2018 3.00 SURFAC CASING BHAH P Lay down BHA 1 f/ 863'-0' MD as per 863.0 0.0 04:30 07:30 1 SLB DD. 8/7/2018 817/2018 0.50 SURFAC CASING BHAH P Clear & clean rig floor. 0.0 0.0 07:30 08:00 8/7/2018 8/7/2018 1.75 SURFAC CASING RURD P Pick up & rig up GBR casing 0.0 0.0 08:00 09:45 equipment; CRT, link extensions, slips & elevators. SIMOPS download & remove BHA f/ shed, load shoe track & verify pipe count. 8/7/2018 8/7/2018 1.00 SURFAC CASING PUTB P Makeup shoe track to 161' MD, 0.0 161.0 09:45 10:45 Bakerl-ok first 3 Connections & torque to 19.4K, install 2 bow spring centralizer 1 O' from each end on first 2 joints. Fill & check floats, good. 877/2018 8/7/2018 5.00 SURFAC CASING PUTB P Continue running 10-3/4", 45.5 #, L- 161.0 1,855.0 10:45 15:45 80, Dopeless Hydnl 563 rasing f/ 161'- 1855' MD, PU 115K, SO 92K, Tq connections to 19.4K, install bow spring centralizers on each collar. Ran a total of 46 bow spring centralizers & 4 slop collars. 817/2018 8/7/2018 0.50 SURFAC CASING HOSO P Make up hanger& landing joint f/ 1,855.0 1,899.3 15:45 16:15 1855'-1899' MD, washing down at 1 bpm, 120 psi, FO 4%, SO 92K. 8/7/2018 8/7/2018 1.25 SURFAC CEMENT CIRC P Circulate& Condition mud for 1,899.3 1,899.3 16:15 17:30 cementing staging up the pump to 7 bpm, 160 psi, FO 20%, PU 119K, SO 108K. 877/2018 8/7/2018 0.50 SURFAC CEMENT RURD P Blow down top drive & rig up cement 1,899.3 1,899.3 17:30 18:00 lines to CRT. 8/7/2018 8/7/2018 1.50 SURFAC CEMENT CIRC P Circulate& condition mud for 1,899.3 1,899.3 18:00 19:30 cementing staging up the pump to 7 bpm, 289 psi, FO 20%, PU 119K, SO 108K. SIMOPS PJSM for cementing. Page 2136 Report Printed: 9/24/2018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Dept Start Time End Time Dur(hn Phase Op Cotle Aotidty Code Time P -T -X Operation peva) 1,899.3 End Dept MKB) 0.0 8/7/2018 8/7/2018 4.00 SURFAC CEMENT CMNT P Pump 5 bbls of CW100 & PT lines to 19:30 23:30 4000 psi, good. Pump 35 bels of CW100 at 4.8 bpm, 120 psi. Pump 80 bels of 10.5 ppg MPII at 4 bpm, 115 psi. Drop bottom plug. Pump 300.9 bbls of 11.0 ppg Lead cement at 6 bpm, 175 psi. Observed bottom plug bump w/ 179 bbls away. Observed MPH at surface at 265 bbls away. Pump 67 bbls of 12.0 ppg Tail cement at 6 bpm, 270 psi. Drop top plug. Pump 10 bbls of fresh H2O at 5 bpm, 160 psi. Swap to rig & pump 165.1 bbls of 9.5 ppg spud mud to bump plug. Observe good 11.0 ppg cement back w/ 75 bbl mud pumped. Landed on hanger w/ 80 bbls of mud pumped. Pressure up to 784 psi & hold for 5 minutes. Check floats, good. CHP 23:22 hrs. Total of 109 bels of 11.0 ppg lead cement to surface. 8/7/2018 8/8/2018 0.50 SURFAC CEMENT PRTS P Pressure lest 10-3/4" casing. Pump 0.0 0.0 23:30 00:00 2.9 bbls, pressuring up at 5 spm to 3250 psi. Shut in & observed pressure for 30 minutes ISP 3250 & FSP 3195 psi bled back 2.7 bbls. 8/8/2018 8/x/2018 3.00 SURFAC CEMENT KURD P Rig down cementing & casing running 0.0 0.0 00:00 03:00 equipment. Drain cement from stack & flush w/ black water. Clean out cementing valves. Clean out cellar box. 8/8/2018 8/8/2018 3.00 SURFAC CEMENT NUND P Remove flow riser, disconnect diverter 0.0 0.0 03:00 06:00 line, remove surface annular, diverter tee & starting head. Prep casing hanger for well head. 8/8/2018 8/8/2018 3.00 SURFAC WHDBOP NUND P Pick and set wellhead as per GE Rep. 0.0 0.0 06:00 09:00 Confirm alignment w/ Lounsbury. Nipple up wellhead annulus valves. 8/8/2018 8/8/2018 0.25 SURFAC WHDBOP PRTS P Test seal between casing hanger & 0.0 0.0 09:00 09:15 wellhead to 2000 psi for 10 minutes, witnessed by CPAI Rep. 8/8/2018 8/8/2018 2.75 SURFAC WHDBOP NUND P Nipple up DSA & spacer spool. Pick & 0.0 0.0 09:15 12:00 set BOP stack. Torque all flanged connections. Install choke & kill lines. 8/8/2018 8/8/2018 3.75 SURFAC WHDBOP -§V-RG P Make up potato masher &pup joint. 0.0 0.0 12:00 15:45 Change out annular element. 8/8/2018 818/2018 1.25 SURFAC WHDBOP RURD P Install test plug, rig up test equipment 0.0 0.0 15:45 17:00 & flood lines. Page 3136 ReportPrinted: 912 412 01 8 Operations Summary (with Timelog Depths) 111-104 %Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth SteriTune End Time Dur(hr) Phew Op Code Activity Cade Time P -T -X Operation (nKB) End DBplh(WB) 8/8/2018 8/8/2018 4.50 SURFAC WHDBOP BOPE P Test BOPE w/4", 4-1/2", & 7-5/8" test 0.0 0.0 17:00 21:30 joints to 250/3500 psi fors minutes each charted. Test choke valves 1-14, upper & lower IBOP, 4" & 4-1/2" dart valves, 4" & 4-1/2" FOSV, lower VBR's w/ 4" & 4-1/2" TJ, Blind rams, upper 7- 5/8" rams, annular w/ 4" & 7-5/8" TJ, manual kill & choke valves, HCR kill & choke valves, 2 kill in line Demco valves. Test manual & super choke 250/2000 psi & show bleed down. Accumulator draw down initial system pressure 2900 psi, after functioning 1850 psi, 200 psi recovery in 9 seconds, full in 48 seconds. Nitrogen bottles 6 @ 2000 psi. Tested gas detection system, flow & pit level indicators. Test witnessed waived by AOGCC Rep Brian Bixby. 8/8/2018 8/812018 0.50 SURFAC WHDBOP RURD P Remove test plug & install wear 0.0 0.0 21:30 22:00 bushing. Blow down & dg down test equipment. 81812018 8/8/2018 1.00 SURFAC CEMENT SHAH P Make up BHA 3, 9-7/8" assembly as 0.0 378.0 22:00 23:00 per SLB DD to 378' MD. 8/8/2018 8/912018 1.00 SURFAC CEMENT TRIP P TIH f/ 378'-1706' MD, PU 90K, SO 378.0 1,706.0 23:00 00:00 79K. 8/912018 8/9/2018 0.25 SURFAC CEMENT CIRC P Fill pipe & SHT tools, 520 gpm, 800 1,706.0 1,706.0 00:00 00:15 psi. 8/912018 8/912018 0.25 SURFAC TEMENT P Line up & test OA valve to 3000 psi for 1,706.0 1,706.6- 00:15 00:30 5 minutes, good. Blow down lines. 819/2018 8/9/2018 0.50 SURFAC CEMENT YRIP TRIPP TIH f/ 1706'-1813' MD, tagging top of 1,706.0 1,813.0 00:30 01:00 plugs on the float collar. 8/9/2018 8/9/2018 4.00 SURFAC CEMENT DRLG P Drill out shoe track & rat hole f/ 1813'- 1,813.0 1,906.0 01:00 05:00 1906' MD, 450 gpm, 715 psi, 60 rpm, Tq 3-51K, WOB 2-10K, PU 90K, SO 86K, ROT 86K. 81912018 8/9/2018 0.25 SURFAC CEMENT DDRL P DDrill 9-7/8" intermediate section f/ 1,906.0 1,926.0 05:00 05:15 1906'-1926' MD, 1799' TVD, 524 gpm, 926 psi, FO 35%, 80 rpm, Tq 5K, WOB 4K, ECD 10. 13, OFF BTM 910 psi, PU 91K, SO 80K, ROT 87K, Tq 2K, Max gas 0, ADT .17, Bit .17, Jars 97.77, Total footage 20'. 8!9/2018 8/9/2018 1.25 SURFAC CEMENT CIRC P Pull inside shoe & circulate for FIT at 1,926.0 1,926.0 05:15 06:30 650 gpm, 1337 psi, 50 rpm, Tq 24K, MW 9.6 ppg 8/9/2018 8/9/2018 0.50 SURFAC CEMENT FIT P Rig up & perform FIT at 1899' MD, 1,926.0 1,926.0 06:30 07:00 1777' TVD to an EMW of 12.0 ppg, w/ 9.6 ppg spud mud. Pump .5 bbl to 230 - psi. Shut in & record pressure for 10 minutes ISIP 220 psi, FSIP 180 psi. Bled back .4 bbl. Rig & blow down test equipment. 8/9/2018 8/9/2018 5.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 1,926.0 2,498.5- 0700 12:00 1926'-2498' MD, 2179' TVD, 650 gpm, 960 psi, FO 33%, 160 rpm, Tq 3.51K, WOB 13K, ECD 9.89, OFF BTM 950 psi, PU 94K, SO 84K, ROT 88K, Tq 2K, Max gas 103, ADT 3.12, Bit 3.12, Jars 100.72, Total footage 572'. SCR @ 1968' MD, 1833' TVD, MW 9.0 ppg, 08:05 hrs #1 @ 30 = 100 psi, @ 40 = 120 psi #2@30=90 psi, @40=110 psi Spill Drill CRT 2:10, 11:00 hrs Page 4136 Report Printed: 9/24/2018 Operations Summary (with Timelog Depths) 11-1-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dw (hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth (MKS) 8/9/2018 8/9/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 2,498.0 3,324.0 12:00 18:00 2498'-3324' MD, 2467' TVD, 650 gpm, 1040 psi, FO 32%,150 rpm, Tq 7K, WOB 15K, ECD 9.87, OFF BTM 1030 psi, PU 105K, SO 73K, ROT 87K, Tq 4K, Max gas 126, ADT 4.11, Bit 7.23, Jars 104.83, Total footage 826'. 8/9/2018 8/10/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section V 3,324.0 4,311.0 18:00 00:00 3324'4311' MD, 2742' TVD, 650 gpm, 1170 psi, FO 32%,170 rpm, Tq 8K, WOB 20K, ECD 10.0, OFF BTM 1162 psi, PU 109K, SO 78K, ROT 92K, Tq 5K, Max gas 35, ADT 4.03, Bit 11.26, Jars 108.86, Total footage 987'. SCR @ 3511' MD, 2516' TVD, MW 9.0+ ppg, 19:05 ms #1 @ 30 = 140 psi, @ 40 = 170 psi #2@30=130 psi, @40=160 psi 8/10/2018 8/10/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section V 4,311.0 5,107.0 00:00 06:00 4311'-5107' MD, 2974' TVD, 650 gpm, 1376 psi, FO 32%, 140 rpm, Tq 11 K, WOB 20K, ECD 10.22, OFF BTM 1350 psi, PU 127K, SO 70K, ROT 94K, Tq 7K, Max gas 33, ADT 3.98, Bit 15.24, Jars 112.84, Total footage 796'. 8/10/2018 8/10/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 5,107.0 5,806.0 06:00 12:00 5107'-5806' MD, 3170' TVD, 650 gpm, 1600 psi, FO 32%, 140 rpm, Tq 11 K. WOB 20K, ECD 10.18, OFF BTM 1580 psi, PU 128K, SO 73K, ROT 96K, Tq 9K, Max gas 33, ADT 3.76, Bit 19.0, Jars 116.6, Total footage 699'. SCR @ 5601' MD, 3113' TVD, MW 9.2 ppg, 10:45 hrs #1 @ 30 = 200 psi, @ 40 = 220 psi #2 @ 30 = 200 psi, @ 40 = 220 psi 8/10/2018 8/10/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 5,806.0 6,458.0 12:00 18:00 5806'-6458' MD, 3357' TVD, 650 gpm, 1532 psi, FO 32%, 140 rpm, Tq 1 OK, WOB 15K, ECD 10.06, OFF BTM 1530 psi, PU 130K, SO 77K, ROT 103K, Tq 8K, Max gas 151, ADT 4.16, Bit 23.16, Jars 120.76, Total footage 652'. SCR @ 6553' MD, 3383' TVD, MW 9.1 ppg, 19:15 hrs #1 @ 30 = 240 psi, @ 40 = 280 psi #2 @ 30 = 220 psi, @ 40 = 260 psi 8/10/2018 8/11/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 6,458.0 7,028.0 18:00 00:00 6458'-7028' MD, 3518' TVD, 650 gpm, 1581 psi, FO 32%,140 rpm, Tq 10K, WOB 15K, ECD 10.27, OFF BTM 1550 psi, PU 147K, SO 81 K, ROT 107K, Tq 8K, Max gas 61, ADT 4.21, Bit 27.37, Jars 124.97, Total footage 570'. 8/11/2018 8/11/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 7,028.0 7,556.0 00:00 06:00 7028'-7556' MD, 3656' TVD, 650 gpm, 1698 psi, FO 32%,150 rpm, Tq 11 K, WOB 15-22K, ECD 10.27, OFF BTM 1690 psi, PU 148K, SO 80K, ROT 104K, Tq 9K, Max gas 34, ADT 3.89, Bit 31.27, Jars 128.86, Total footage 530'. Page 5/36 Report Printed: 9/2412018 .I.. Operations Summary (with Timelog Depths) 11-1-104 • Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Eur(hr) Phase Op Code Activity Code Time P -T -X Open (MKe) End Depth (111<13)8/11/2018 8/11/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section?/ 7,556.0 8,028.0 b6:00 12:00 7556'-8028' MD, 3769' TVD, 650 gpm, 1770 psi, FO 32%,160 rpm, Tq 12K, WOB 20-23K, ECD 10.42, OFF BTM 1732 psi, PU 149K, SO 78K, ROT 108K, Tq 6K, Max gas 106, ADT 4.05, Bit 35.31, Jars 132.91, Total footage 530'. Spill Drill CRT 2 min @ 08:00 hrs SCR @ 7598' MD, 3672' TVD, MW 9.1 ppg, 07:00 tins #1 @ 30 = 240 psi, @ 40 = 280 psi #2 @ 30 = 240 psi, @ 40 = 280 psi 8/11/2018 8/11/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 8,028.0 8,360.0 12:00 18:00 8028'-8360' MD, 3828' TVD, 650 gpm, 1764 psi, FO 33%,150-120 rpm, Tq 12K, WOB 3-22K, ECD 10.37, OFF BTM 1772 psi, PU 150K, SO 70K, ROT 107K, Tq 9K, Max gas 210, ADT 3.58, Bit 38.89, Jars 136.49, Total footage 332'. 8/11/2018 8/12/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 8,360.0 8,605.0 18:00 00:00 8360'-8605' MD, 3885' TVD, 650 gpm, 1836 psi, FO 33%, 150-120 rpm, Tq 13K, WOB 3-22K, ECD 10.4, OFF BTM 1800 psi, PU 153K, SO 72K, ROT 112K, Tq 11 K, Max gas 39, ADT 2.92, Bit 41.81, Jars 139.41, Total footage 245'. SCR @ 8549' MD, 3865' TVD, MW 9.0 ppg, 21:30 him #1 @ 30 = 280 psi, @ 40 = 320 psi #2 @ 30 = 280 psi, @ 40 = 320 psi 8/12/2018 8/12/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section V 8,605.0 9,090.0 00:00 06:00 8605-9090' MD, 4031' TVD, 650 gpm, 2000 psi, FO 33%, 140-120 rpm, Tq 13K, WOB 8-25K, ECD 10.68, OFF BTM 1862 psi, PU 162K, SO 75K, ROT 113K, Tq 11 K, Max gas 29, ADT 3.69, Bit 45.5, Jars 143. 10, Total footage 485'. 8/12/2018 8/12/2018 5.50 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 9,090.0 9,514.0 06:00 11:30 9090'-9514' MD, 4100' TVD, 650 gpm, 1942 psi, FO 33%,150 rpm, Tq 13K, WOB 8-25K, ECD 10.65, OFF BTM 1944 psi, PU 154K, SO 75K, ROT 108K, Tq 10K, Max gas 226, ADT 2.88, Bit 48.38, Jars 145.98, Total footage 424'. Kick w/ Drilling Drill CRT 1:44 @ 08:00 hrs. 8/12/2018 8/12/2018 1.25 INTRMI CASING CIRC P Circulate CBU at 650 gpm, 1944 psi, 9,514.0 9,414.0 11:30 12:45 FO 33%, 100 rpm, Tq 10K. Obtain final survey & SCR. SCR @ 9512' MD, 4099 TVD, MW 9.2 ppg, 12:30 tins #1 @ 30 = 340 psi, @ 40 = 380 psi #2 @ 30 = 330 psi, @ 40 = 380 psi 8/12/2018 8/12/2018 0.50 INTRMI CASING -6W—FF P Monitorwell, static. 9,414.0 9,414.0 12:45 13:15 8/12/2018 8/12/2018 4.75 INTRM1 CASING BKRM P Backream out of hole f/ 9414'-7792' 9,414.0 7,792.0 13:15 18:00 MD, 700 gpm, 2195 psi, FO 35%,120 rpm, Tq 1 OK, ECD 10.85, Max Gas 530 psi, PU w/ reaming IOOK. Page 6136 Report Printed: 9124/2018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Surf Deptii Stan rime End Time Dur(hr) Phase Op cme Activity Coae Tma P-T-X Operation (fixe) End Depth (WO) 8/13/2018 6.00 INTRM1 CASING BKRM P Backream out of hole f/ 7792'-4970' 7,792.0 4,970.0 00:00 MD, 700 gpm, 1800 psi, FO 35%,120 rpm, Tq 9K, ECD 10.82, Max Gas 84psi, PU wl reaming 90K.8/13/2018 6.75 INTRMI CASING BKRM P Backream out of hole laying down DP 4,970.0 1,890.006:45 f/ 4970'-1890' MD, 700-600 gpm, 1127 psi, FO 35%,120-80 rpm, Tq 4K, ECD 10.85, PU w/ reaming 81 K. 8/13/2018 8113/2018 1.25 INTRM1 CASING CIRC P Circulate hole clean @ 750 gpm, ICP 1,890.0 1,890.0 06:45 08:00 1431 psi, FCP 1384 psi, FO 34%, 70 rpm, Tq 3K, ECD 9.91, PU 88K, SO 83K, ROT 86K. 8/13/2018 8113/2018 0.50 INTRM1 CASING OWFF P Monitor well, static. 1,890.0 1,890.0 08:00 08:30 8/13/2018 8/13/2018 0.25 INTRM1 CASING CIRC P Pump dry job & blow down TO. 1,890.0 1,890.0 08:30 08:45 8113/2018 8/13/2018 1.25 INTRM1 CASING TRIP P TOH f/ 1890'-378' MD. 1,890.0 378.0 08:45 10:00 8/13/2018 8/13/2018 2.00 INTRM1 CASING BHAH P Lay down BHA 3 as per SLB DD. 378.0 0.0 10:00 12:00 Bit Grade 4,5,BT,A,X,1,CT,TD 8/13/2018 8/1312018 1.00 INTRM1 CASING BHAH P Clear BHA & clean rig floor. 0.0 0.0 12:00 13:00 8/13/2018 8/13/2018 1.00 INTRM1 CASING W W WH P Make up stack wash tool & flush stack 0.0 0.0 13:00 14:00 @ 850 gpm, 150 psi. Lay down tool & make up bushing tool. Remove wear bushing & lay down tools. 8/13/2018 8/13/2018 1.00 INTRMI CASING RURD P Rig up GBR casing handling 0.0 0.0 14:00 15:00 equipment. 8/13/2018 8/13/2018 1.00 INTRMI CASING PUTB P PJSM, make up 7-518", 29.7 #, L-80, 0.0 174.0 15:00 16:00 Hydril 563 dopeless casing shoe track to 174' MD, Bakerl-ok connections to pin end of #5, Tq to 14K, floats checked good. 8/13/2018 8/13/2018 3.25 INTRMI CASING PUTB P Continue RIH w/ 7-518", 29.7 #, L-80, 174.0 1,899.0 16:00 19:15 Hydril 563 dopeless casing shoe 174- 1899' MD, connections Tq to 14K, fill pipe on the fly, top off every 10 for displacement, install centralizers installed free floating. 8/13/2018 8/13/2018 0.75 INTRM1 CASING CIRC P Circulate casing volume at the shoe 1,899.0 1,899.0 19:15 20:00 reciprocating pipe, 3.5 bpm, 100 psi, PU 93K, SO 90K. 8/13/2018 8/13/2016 2.50 INTRM1 CASING PUTB P Continue RIH w/ 7-5/8", 29.7 #, L-80, 1,899.0 3,650.0 20:00 22:30 Hydril 563 dopeless casing shoe 1899 -3650' MD, connections Tq to 14K, fill pipe on the fly, lop off every 10 for displacement, install centralizers installed free floating. 8/13/2018 8/13/2018 1.00 INTRM1 CASING CIRC P Circulate casing volume, reciprocating 3,650.0 3,650.0 22:30 23:30 pipe, staging pump up to 4.5 bpm, 185 psi, PU 118K, SO 95K. 8/13/2018 8/14/2018 0.50 INTRM1 CASING PUTB P Continue RIH w/ 7-5/8", 29.7 #, L-80, 3,650.0 4,028.0 23:30 00:00 Hydril 563 dopeless casing shoe 3650'-0028' MD, connections Tq to 14K, fill pipe on the fly, top off every 10 for displacement, install centralizers installed free floating. 8/14/2018 8/14/2018 3.50 INTRM1 CASING PUTB P Continue to RIH with 7 5/8" 29.7#, L- 4,028.0 6,116.0 00:00 03:30 80 563 Dopless casing as per detail from 4,028' MD - 6,115' MD Fill on fly every 10 and TO connections to 14K FT/LB. Page 7/36 ReportPrinted: 912412018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth StartTime I End Time Our (hr) Phase Op Code Acliviy Code Time P -T -X Operation (feta) End Depth (flKa) 8/14/2018 8/14/2018 1.25 INTRMI CASING CIRC P Circulate casing volume while rec from 6,116.0 6,116.0 03:30 04:45 6,116' MD - 6,085' MD. stage pumpe to 7 BPM @ 364 PSI UP WT = 152K, DWN WT = 93K. total stks pumped = 2,800. 8/14/2018 8114/2018 6.00 INTRM1 CASING PUTS P Continue to RIH with 7 5/8" casing as 6,116.0 9,461.0 04:45 10:45 per detail from 6,115' MD - 9,461' MD. Fill pipe every ten. TQ all connections to 14K. Work past obstruction at 9,320' MD with 4 BPM @ 483 PSI DPP. UP WT=200K. DWN WT= 77K. 8114/2018 8/14/2018 0.25 INTRMI CASING HOSO P MU hanger and landing joint. Wash 9,461.0 9,503.0 10:45 11:00 down @ 2 BPM 424 PSI DPP.12% F/O. DWN WT = 65K. 8/14/2018 8114/2018 3.00 INTRMI CEMENT CIRC P Recip pipe from 9,483' MD- 9,503' 9,503.0 9,503.0 11:00 14:00 MD while staging up pumps to 6 BPM @ 369 PSI DPP. FCP = 454 PSI DPP. 20% F10 UP WT=200K DWN WT= 77K. pumped 9,961 STKS. . 8/14/2018 8/14/2018 4.00 INTRMI CEMENT CMNT P PJSM and RU cement hose PT lines 9,503.0 9,493.2 14:00 18:00 to 4,000 PSI. (PASSED). Reciprocate pipe from 9,503' MD - 9,488' MD. UP WT=211K. DWNWT=101K. Pump 41.3 BBLS MP II. @ 3 BPM 312 PSI, 12% F/0. Drop BTM Plug pump 250 BBLS of 15.8# class G cement stage up pumps to 6 BPM with ICP 400 Sl. FCP 270 PSI. 22% F/O. Drop top plug and chase with 10 BBLS H2O. followed with 9.2 PPG treated LSND @ 7 BPM icp 161 PSI, Obsereve DWN WT to 50K - 10' high. Attempt to free pipe with no success. UP WT = 228K, DWN WT = 98k. continue to pump 7 BPM with FCP 1,265 PSI. teduce rate to 3 BPM @ 4,025 Stks. ICP 1,175 PSI. FCP 1,320 PSI. Bump plug with 422 STKS. CIP @ 1730 his. Increase pressure to 1,853 PSI and hold for 5 min. Bleed off and check floats. Holding. 8/14/2018 8/15/2018 6.00 INTRMI CEMENT WOC T WOC. Prep stack for nipple down. 9,493.2 9,493.2 18:00 00:00 BD and remove cement hose. Clean up cementing eqiupment and valves. PU subs and prep for upcomming BHAchnage over. Load and tally 4" OP. 8115/2018 8/15/2018 5.00 INTRMI CEMENT WOC T WOC. Prepare stack for ND. RD 9,493.2 9,493.2 00:00 05:00 Volant / install 150T elevators, flean out cement valves. Load and tally 4" DP. Sim ops clean. 8/15/2018 8/15/2018 1.00 INTRMI CEMENT NUND T Drain stack/ Break flange to hoist/ 9,493.2 9,493.2 05:00 06:00 release air from boots. 8/15/2018 8/15/2018 5.00 INTRM1 CEMENT RURD T Hoist stack and penetrate 2' above 9,493.2 9,493.2 06:00 11:00 flange for drainage. Clean and prep for emergency slip install. PU to 200K on indicator and install slips as per GE rep. Install Wachs cutter and cut casing as per GE rep. 8/15/2018 8/15/2018 1.00 INTRMI CEMENT CUTP T LD landing joint and cut 7 518" casing, 9,493.2 9,493.2 11:0012:00 elevators and casing hand slips. 8/15/2018 8/1512018 1.00 INTRMI CEMENT WWSP P MU 41/2" landing joint with X10, and 9,493.2 0.0 12:00 13:00 packoff running tool. Set 10 314" X 7 5/8" Packoff as per GE rep. Page 8136 Report Printed: 912 412 01 8 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Siad rime End Time Durrm) Phaw Op Cotle Aciviry Code Time P -T -X Operation rKKS) End Depth(fiKB) INTRMI CEMENT NUND P NU BOP stack and change out saver 0.0 0.0 8/15/2018 8/15/2018r1.75 13:00 14:00 sub to 4" XT39 dimops. 8/15/2018 8/15!2018 INTRMI CEMENT PRTS P Witness packoff test to 3,832 PSI for 0.0 0.0 14:00 14:30 10 min / (PASSED). 8/15/2018 8115/2018 INTRMI CEMENT RURD P Install wear bushing of 9" plus run in 0.0 0.0 14:30 15:00 LDS X2 8/15/2018 8/15/2018 INTRMI CEMENT BHAH P PJSM for PU 6 3/4" BHA#3 as per 0.0 336.0 15:00 16:45 SLB rep.lo 336' MD UP WT = 51K OWN WT= 57K. Sim -ops with LRS for FP of 10 3/4" X 7 518" arm with 100 BBLS fresh / 80 BBLS diesel. Pressure break over at 900 PSI. Average rate of 3 BPM 7-800 PSI. 8115/2018 8/16/2018r2.00 INTRMI CEMENT TRIP P Trip in hole with 4" DP from 336' MD 336.0 7,788.0 16:45 00:00 to 7,788' MD. UP WT = 145K OWN WT = 62K. Monitor disp via TT. 8/16/2018 8/16/2018 INTRMI CEMENT TRIP P Continue to RIH with 6 3/4" BHA on 4" 7,788.0 9,300.0 00:00 02:00 DP from 7,778'MD - 9,300'MD. UP WT=162K, DWNWT=60K Monitor disp via TT. 8/1612018 6/16/2018 INTRMI CEMENT PRTS P Rig up to pressure test 7 5/8" casing. 9,300.0 9,300.0 02:00 02:45 Pump 6 BBLS to achieve 3,680 PSI hold and chart for 30 min. Lost 5 PSI fin 30 min. (PASSED). bleed off total 6.2 BELS. 8/16/2018 8/16/2018 3.00 INTRMI CEMENT DRLG P Ream down and drill out shoe track 9,300.0 9,514.0 02:45 05:45 assym. 220 GPM @ 1,170 PSI. 50 RPM 9K TQ. UP WT = 155K, OWN WT = 53K. 10K RT. top of plug found at 9,397.5' MD. 8!16/2018 8/16/2018 0.25 INTRM1 CEMENT DDRL P Drill 63/4" hole from 9,514'MD- 9,514.0 9,534.0 05:45 06:00 9,534' MD 4,086' TVD. 220 GPM @ 1,660 PSI, 18% NO, 80 RPM 11 K TQ, 8K WOB, OB 1,600 PSI. UP WT = 155K, DWN WT= 53K. ROT 102K, 9K TQ, Max gas units 0. ADT .16, Bit hrs .16, Jar HRS 43 8/16/2018 1811612018 1.00 INTRMI CEMENT CIRC P Rotate and circulate from 9,453' MD - 9,534.0 9,534.0 06:00 07:00 9,450' MD. 240 GPM @ 1,655 PSI. 16% F/O, 40 RPM 11 K TQ, UP QT = 170K, DWN WT= 52K, ROT 102K, pumped 2,872 STKS. 8116/2018 8/16/2018 1.25 INTRMI CEMENT FIT P STD back stnd 97, RU for FIT/ @ 9,534.0 9,534.0 07:00 08:15 4,091' TVD. 13.1 EMW achieved at 16 STKS pumped 800 PSI with 9.3 PPG test mud 8/16/2018 8/16/2018 0.25 PROD1 DRILL RURD P RD test equipment. 9,534.0 9,534.0 08:15 08:30 8/16/2018 8/16/2018 0.50 PROD1 DRILL SVRG P Grease top drive / PM / service saver 9,534.0 9,534.0 08:30 09:00 and air slips. 8116/2018 8/16/2018 1.25 PR0D1 DRILL DISP P Swap hole over to 9.2 PPG Flo -Pro, 9,534.0 9,534.0 09:00 10:15 pump 20 BBL high vis sweep 250 GPM @ 1,940 PSI. 17% FIG. 40 RPM IOK TQ. ECD 10.76. 1,683 FCP. UP WT= 134K DWN WT= 85K. Page 9136 Report Printed: 9FO77,781 Operations Summary (with Timelog Depths) V, 1 H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start DapN Stan Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (RKS) End Depth (fKB) 8/16/2018 8/16/2018 7.75 PROD1 DRILL DDRL P Drill 6 3/4" hole from 9,534' MD 4,086' 9,534.0 10,112.0 10:15 18:00 TVD - 10,112' MD 4,097' TVD. 260 GPM @ 1,811 PSI, 19% F/O, 130 RPM 71K TQ, 31K WOB, OB 1,808 PSI. UP WT = 137K, DWN WT = 75K. ROT 103K, 61K TQ, Max gas units 86. ADT 5.37, Bit hrs 6.8, Jar HRS 48.37 SPR's 9,532' MD 4,087' TVD MW = 9.2 PPG HR 10:15 MP -1) 20 SPM420 PSI 30 SPM -580 PSI MP -2) 20 SPM -420 PSI 30 SPM -580 PSI 8/16/2018 8/17/2018 6.00 PROD1 DRILL DDRL P Drill 3/4" hole from 10,112' MD 10,112.0 10,605.0 18:00 00:00 4,097'TVD- 10,605' MD 4,095 TVD. 260 GPM @ 1,815 PSI, 19% F/O, 130 RPM 8K TQ, 2-51K WOB, OB 1,810 PSI. UP WT=139K, DWN WT=71 K. ROT 101 K, 61K TO, Max gas units 63. ADT 4.10, Bit hrs 9.63, Jar HRS 52.47 SPR's 10,589" MD 4,095' TVD MW = 9.2 PPG HR 20:30 MP -1) 20 SPM -510 PSI 30 SPM -710 PSI MP -2) 20 SPM -550 PSI 30 SPM -790 PSI 8/17/2018 8/17/2018 6.00 PROD1 DRILL DDRL P Drill 6 3/4" hale from 10,605' MD 10,605.0 11,226.0 00:00 06:00 4,095 TVD - 11,226' MD 4,052' TVD. 260 GPM @ 2,175 PSI, 19% F/O, 130 RPM 1 OK TQ, 2-71K WOB, ECD = 11.96 OB 2,150 PSI. UP WT = 139K, DWN WT = 66K. ROT 99K, 8K TO, Max gas units 8. ADT 4.21, Bit hrs 13.84, Jar HRS 56.68 6/17/2018 8/17/2018 1.50 PROD1 DRILL BKRM T BKRM from 11,226' MD- 10,879' MD. 11,226.0 10,879.0 06:00 07:30 250 GPM @ 2,027 PSI DPP. 18% F/O, 80 RPM, 6K TQ. UP WT = 139K, DWN WT = 66K, ROT = 99 8/17/2018 8/17/2018 0.50 PROD1 DRILL PMPO T Pump OOH from 10879' MD - 10780' 10,879.0 10,780.0 07:30 08:00 MD at 250 GPM 1,925 PSI DPP, 8/17/2018 8/17/2018 4.00 PROD1 DRILL KOST T Open hole side track. Work string 10,780.0 10,860.0 08:00 12:00 from 10,830' MD - 10,860 1,910 PSI 18% F/O, 150 RPM, 8K TQ, UP WT w/pump = 99K. DWN = 95K. 8/17/2018 8/17/2018 2.00 PROD1 DRILL KOST T Open Hole side track as per DD. 10,860.0 10,860.0 12:00 14:00 Working string from 10,830' MD - 10,860' MD. 250 GPM @ 1,910 PSI DPP. 18% F/O, 150 RPM @ 8K TO. UP / DNW WT with pumps on 99K/95K. 8/17/2018 8/18/2018 10.00 PROD1 DRILL KOST T Open Hole side track as per DD. 10,860.0 10,874.0 14:00 00:00 Working string from 10,860' MD - 10,874' MD. 250 GPM @ 1,829 PSI DPP. 19% F/O, 150 RPM @ 91K TQ. UP / DNW WT with pumps on 99K/95K. 8/18/2018 8/18/2018 6.00 PRODi DRILL KOST T Continue to perform open hole 10,874.0 10,969.0 00:00 06:00 sidetrack time driling form 10,874' MD - 10,969' MD 250 GPM @ 1,875 PSI, 18% F/O, 150 RPM, 8K TO, UP WT = 129K, DWN WT = 78K. ROT = 100K, Max gas = 14 Page 10136 Report Printed: 9/2412 01 8 Alai', Operations Summary (with Timelog Depths) AM 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Smrt Depth Siert Time End Time Dur(hr) Phase Op COW A RyCode Time P -T -X Operation (flKB) End Depih(ftKB) 8/18/2018 8/18/2018 3.00 PROD1 DRILL DDRL T Drill 6 3/4" hole fotl 10,969' MD - 10,969.0 11,227.0 06:00 09:00 11,227' MD 4,104' TVD. Q 248 GPM, 2,051 PSI, 18% FIO, 125 RPM, 9.5K TO. 3.5K WOB, ECD = 11.07, OB = 2,048 PSI, UP WT = 129K, DWN WT = 78K, ROT = 100K, 9K TO, Max gas = 340, ADT 6.44, Bit hrs 31.1, Jar hrs 73.94. 8/18/2018 8/18/2018 2.00 PROD1 DRILL OWFF T Observe well for flow. Observe rise in 11,227.0 11,277.0 09:00 11:00 fluid at rotary table. SI well and monitor pressure. ISIDPP = 25 PSI, ISICP = 20 PSI Pbserve [ressure rise to 200 PSI SIDPP, 180 PSI SICP. Increase of 4BBLS to pits. 8/18/2018 8/18/2018 2.50 PROD1 DRILL KLWL T Circulate well around usingddllers 11,277.0 11,277.0 11:00 13:30 method @ 3BPM, 1,080 PSI DPP Casing pressure peaked at 650 PSI during circulation with gas to surface. Pumped a total of 4,569 STKS. Rotated pipe for one min to ensure free. Talk with production folks and have them shut in 11 -1 -News injection support. Talk with KRU operations about postponing bridge closure until well stabilized. Order out more KCL from Ml. 8/18/2018 8/18/2018 4.00 PRODI DRILL OWFF T Shut down pumps and SI casing to 11,277.0 11,227.0 13:30 17:30 monitor pressures and WT UP pits to new KW F based off new calcs. Maintain 200 PSI on Casing pressure. WT UP pits to 9.7 PPG with new calculations proving a 10.2 PPG needed. Went with 9.7 PPG for first circulation so crews could keep up with 30 SEC SX at 9.7. 8/1812018 8/18/2018 2.75 PROD1 DRILL KLWL T Pump 9.7 PPG mud utilizing kill sheet 11,227.0 11,277.0 17:30 20:15 pump schedule. ICP = 1,016 PSI, FCP = 1,036 PSI. Maintain 200 PSI Casing pressure. Total stks pumped = 5,515. 8/18/2018 1811812018 0.75 PRODI DRILL OWFF T Sl and monitor pressure while 11,277.0 11,277.0 20:15 21:00 weighing up to 10.2 PPG KWF in surface pits. SIDPP = 380 PSI, SICP = 240 PSI. Rotate for 1 min with 9K TO to break over and 5-8K TQ stable. 8/18/2018 8/1912018 3.00 PROD1 DRILL KLWL T Pump 10.2 PPG MW utilizing kill sheet 11,277.0 11,277.0 21:00 00:00 (drillers method), pump schedule. ICP = 970 PSI. CP = 919 PSI. Pump 5,605 STKS. MW in = 10.2 MW out = 10.1+. Rotate pipe at 10 RPM broke over at 8K TQ. 8/19/2018 8/19/2018 0.50 PROD1 DRILL KLWL T 6,623 STKS pumped. MW in/out 10.2 11,277.0 11,277.0 00:00 00:30 PPG. Rotate pipe 10 RPM with 13K Ito break over - 8K TQ 8/192018 8/19/2018 0.75 PROD1 DRILL KLWL T Monitor pressure via choke and 11,277.0 11,277.0 00:30 01:15 confirm zero pressure. Open ann and monitor hale. 8/19/2018 8/19/2018 2.25 PROD1 DRILL CIRC T Circulate up 2X BU at 250 GPM, 80 11,277.0 11,277.0 01:15 03:30 RPM / ECD =12.24 PPG, UP WT= 127K OWN WT= 85K. rot 102K. Page 11136 Report Printed: 912412 0 1 8 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten Depth san7me End Time Dur(hr) Phase Op Code Activity Code Time P -T -x Opemdon (fiKB) End Depth(nxB) 8/19/2018 8/19/2018 0.50 PROD1 DRILL OWFF T Monitor well for flow/blow down 11,277.0 11,277.0 03:30 04:00 choke / kill lines. Grease wash pipe. SPR's 11,255' MD 4,104' TVD, MW = 10.2 Time 0415 hrs MP 1) 20 SPM 570 PSI 30 SPM 780 PSI MP 2) 20 SPM 540 PSI 30 SPM 720 PSI 8/19/2018 8/19/2018 2.00 PROW DRILL DDRL P Drill 6 3/4" hole from 11,277' MD - 11,277.0 11,445.0 04:00 06:00 11,445 MD @ 250 GPM, 2,090 PDI 19% F/O, 130 RPM 10K TQ, 5K WOB, ECD's 12.1 PPG. OB 2,056 PSI UP WT = 137 OWN WT = 68K, Rol = 99K, 9K TQ, Max gas 43 units 8/19/2018 8/19/2018 6.00 PROD1 DRILL DDRL P DDRL 6 3W' hole from 11,445' MD - 11,445.0 11,965.0 06:00 12:00 11,965' MD 4,043' TVD 250 GPM 2,161 PSI DPP, 20% Flo, 150 RPM 1 O TQ, ECD's = 12.34, OFF BTTM = 2,150 PSI, UP WT= 150K, OWN WT = 52K, ROT 102K, 1 O TO, Max gas = 227 units, ADT 5.07, Bit his 36.17, Jar his 79.07 8/19/2018 8/19/2018 6.00 PROD1 DRILL DDRL P DDRL 6 3/4" hole from 1,965' MD 11,965.0 12,605.0 12:00 18:00 4,043' TVD - 12,605' MD 4,018 TVD 260 GPM t@ 2,179 PSI DPP, 21% F/O, 140 RPM 1 OK TQ, 1 K WOB ECD's = 12.3, OFF BTTM = 2,150 PSI, UP WT = 146K, OWN WT = K, ROT 102K, 1 OK TQ, Max gas = 2817 units, ADT 4.05, Bit hrs 40.22, Jar his 83.12 8/19/2018 8/20/2018 6.00 PROD1 DRILL DDRL P DDRL 6 3/4" hole from 12,605' MD 12,605.0 13,09-0- 18:00 00:00 4,018 TVD - 13,064' MD 4,012' TVD 260 GPM Q 2,292 PSI DPP, 20% F/O, 140 RPM 1 O TQ, 5K WOB ECD's = 12.37, OFF BTTM = 2,281 PSI, UP WT = 160K, OWN WT = K, ROT 104K, IOK TQ, Max gas = 7780 units, ADT 3.37, Bit hrs 43.80, Jar his 86.7 SPR's 12,684" MD 4,015' TVD MW = 10.2 PPG HR 1841 MP -1) 20 SPM -530 PSI 30 SPM -730 PSI MP -2) 20 SPM -490 PSI 30 SPM -690 PSI 8/20/2018 8/20/2018 6.00 PRODi DRILL DDRL P DDRL 6 3/4" hole from 13,064' MD 13,064.0 13,812.0 00:00 06:00 4,012'TVD - 13,812 MD 3,994' TVD 260 GPM @ 2,478 PSI DPP, 20% F/0, 140 RPM 10.7K TQ, 5.5K WOB ECD's = 12.71, OFF BTTM = 2,495 PSI, UP WT = 172K, OWN WT = K, ROT 106K, 1 OK TO, Max gas = 235 units, ADT 3.85, Bit hrs 47.65, Jar hrs 90.55 Page 12/36 Report Printed: 912412018 " Operations Summary (with Timelog Depths) 111-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth StartTime End Time our (Inn Please Op Code AcNity Code Time P -T -X Operation (M1KB) End Depth(flKB) 8/20/2018 8/20/2018 6.00 PROD? DRILL DDRL P DDRL 6 3/4" hole from 13,812 MD 13,812.0 14,454.0 06:00 12:00 3,994' TVD - 14,454' MD 4,084 TVD 260 GPM @ 2,840 PSI DPP, 19% F/O, 140 RPM 1 O To, 5K WOB ECD's = 12.92, OFF BTTM = 2,816 PSI, UP WT = 183K, DWN WT = K, ROT 118K, 10.5K TO, Max gas = 235 units, ADT 3.65, Bit hrs 51.3, Jar hrs 94.2 SPR's 13,900" MD 4,084' TVD MW = 10.1+ PPG HR 0615 MP -1) 20 SPM -700 PSI 30 SPM -890 PSI MP -2) 20 SPM -710 PSI 30 SPM -900 PSI 8/20/2018 8/20/2018 6.00 PROD1 DRILL DDRL P DDRL 6 3/4" hole from 14,454' MD 14,454.0 14,940.0 12:00 18:00 4,084 TVD - 14,940 MD 4,040' TVD 260 GPM @ 2,690 PSI DPP, 20% F/O, 150 RPM 1 O TO, 3K WOB ECD's = 12.75, OFF BTTM = 2,670 PSI, UP WT= 185K, DWN WT= K, ROT 122K, IOK TO, Max gas = 235 units, ADT 3.9, Bit hrs 55.2, Jar hrs 98.1 8/20/2018 8/21/2018 6.00 PROD1 DRILL DDRL P DDRL6 3/4" hole from 14,940 MD 14,940.0 15,191.0 18:00 00:00 4,040' TVD - 15,191' MD 4,031' TVD 260 GPM @ 2,794 PSI DPP, 20% F/O, 140 RPM 10.5K TO, 2.7K WOB ECD's = 12.84, OFF BTTM = 2,791 PSI, UP WT = 189K, DWN WT = K, ROT 122K, 10.7K TO, Max gas = 235 units, ADT 3.3, Bit hrs 56.5, Jar hrs 101.4 SPR's 14,917" MD 4,037' TVD MW = 10.2 PPG HR 1909 MP -1) 20 SPM -620 PSI 30 SPM -690 PSI MP -2) 20 SPM -640 PSI 30 SPM -680 PSI 8/21/2018 8/21/2018 6.00 PROD1 DRILL DDRL P DDRL 6 3/4" hole from 15,191' MD 15,191.0 15,648.0 00:00 06:00 4,031' TVD - 15,648' MD 4,029' TVD 250 GPM @ 2,605 PSI DPP, 19% FIO, 140 RPM 10.6K TO, 2K WOB ECD's = 12.83, OFF BTTM = 2,578 PSI, UP WT= 195K, DWN WT= K, ROT 126K, 1 OK TO, Max gas = 78 units, ADT 4.44, Bit hrs 62.94, Jar hrs 105.84 8/21/2018 8/21/2018 4.75 PROD1 DRILL DDRL P DDRL 6 3/4" hole from 15,648' MD 15,648.0 16,014.0 06:00 10:45 4,029' TVD - 16,014" MD 4,022' TVD 250-230 GPM @ 2,525 PSI DPP, 19% F/O, 140 RPM 1 O TO, 2-7K WOB ECD's = 12.87, OFF BTTM = 2,520 PSI, UP WT = 180K, DWN WT = K. ROT 127K, 1 OK TO, Max gas= 95 units, ADT 3.9, Bit hrs 66.84, Jar hrs 109.74 8/21/2018 8/21/2018 3.25 PROD1 CASING CIRC P Circulate and condition mud. Rotate 16,014.0 15,922.0 10:45 14:00 and reciprocate from 16,014' MD to 15,922' MD. 230 gpm, 2589 psi, 17% FO, 140 rpm, 8K tq, ECD=12.95 UP WT=175K , DWN WT= K, ROT 126K. Page 13136 Report Printed: 912412018 Operations Summary (with Timelog Depths) 1 H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan DepN Stan Time Fad Time Dur(hr) Phase Op Code Ac&4 Code Time P -T -x Operation (tIKB) End DepOQIKB) 8121/2018 6/21/2018 1.00 PROD1 CASING OWFF P Monitor well. Slight flow at .29 bph 15,922.0 15,922.0 14:00 15:00 diminishing to .14 bph. 8/21/2018 8/21/2018 3.00 PROD1 CASING BKRM P BROOH from 15,922' MD to 14,821 15,922.0 14,821.0 15:00 18:00 MD. 240 gpm, 2738 psi, 18% FO, 140 rpm, 8K tq, ECD=12.87. 8/21/2018 8/22/2018 6.00 PROD1 CASING BKRM P Continue to BROOH from 14,921' MD 14,821.0 12,774.0 18:00 00:00 to 12,774' MD. 240 gpm, 2274 psi, 16% FO, 140 rpm, 7.51K tq, ECD=12.57. OA=100 psi. 8/22/2018 8122/2018 6.00 PROD1 CASING BKRM P Continue to BROOH from 12,774' MD 12,774.0 10,763.0 00:00 06:00 to 10,763' MD. 240 gpm, 2095 psi, 18% FO, 140 rpm, 71K tq, ECD=12.21. 8122/2018 8/22/2018 3.00 PROW CASING BKRM P Continue to BROOH from 10,763' MD 10,763.0 9,445.0 06:00 09:00 to 9,445' MD. 240 gpm, 2002 psi, 18% FO, 140 rpm, 7K tq, ECD=11.89. 8/22/2018 8/22/2018 3.00 PROD1 CASING CIRC P Circulate and condition mud. Rotate 9,445.0 9,445.0 09:00 12:00 and reciprocate from 9,445' MD to 9,357' MD, 220 gpm, 1738 psi, 15% FO, 80 rpm, 5K tq, ECD=11.80, UP WT=120K S/O WT=88K ROT WT=97K. OA=95 psi 30 bbls loss previous 12 hrs. 8/22/2018 8/22/2018 2.75 PROD1 CASING CIRC P Circulate and condition mud. Perform 9,445.0 9,445.0 12:00 14:45 80% mud dilution. Rotate and reciprocate from 9,445' MD to 9,357' MD, 200 gpm, 1320 psi, 15% FO, 80 rpm, 4K tq, UP WT=120K S/O WT=88K ROT WT=97K. 8/22/2018 8/2212018 0.75 PROD1 CASING OWFF P Monitor well. Slight flow at 1.19 bph 9,445.0 9,450.0 14:45 15:30 1 1 diminishing to .28 bph. 8/2212018 8/22/2018 0.50 PROD1 CASING PMPO P Pump OOH from 9,450' MD to 9,262' 9,450.0 9,262.0 15:30 16:00 MD at 85 to 65 gpm with 415 psi. 7% FO 8/22/2018 8/22/2018 0.75 PROD1 CASING OWFF P Monitor well. Slight flow al .27 bph 9,262.0 9,262.0 16:00 16:45 diminishing to .13 bph. 8/22/2018 8/2212018 1.00 PRODt CASING MPSP P Make up and set Baker TST-3 9,262.0 0.0 16:45 17:45 retrievable packer. COE at 97.10' MD. UP WT=125K SO WT=80K 8/22/2018 8/22/2018 0.75 PROD1 CASING WWWH P Make up stack washing tool. Flush 0.0 0.0 17:45 18:30 BOPE with 900 gpm, 167 psi, 42% FO and 30 rpm. 8/22/2018 8/22/2018 0.50 PROD1 CASING MPSP P Test storm packer to 700 psi/10 mins 0.0 0.0 18:30 19:00 as per Baker Rep. 8/22/2018 8/22/2018 1.50 PROD1 CASING BOPE P Set test plug and change out upper 0.0 0.0 19:00 20:30 pipe rams to 3 112" x 6" VBR's. 8/22/2018 8/22/2018 1.50 PROD1 WHDBOP RURD P Rig up to test BOPS. Purge air from 0.0 0.0 20:30 22:00 system and perform shell test. Page 14136 Report Printed: 9/2412018 a Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log smn Ixv1n Start Time End Time Dur(hr) Phase Op Code Activity Code Time PJA Opmation (ftKB) End Depth MKB) 8/22/2018 8/23/2018 2.00 PROD1 WHDBOP BOPE P Perform bi-weekly BOPE test. 0.0 0.0 22:00 00:00 250/3500 psi- 5 min each. Following tests done with 4 1/2" test joint. Test #1-Annular,CV's 1,12,13,14, 4" kill Demco, 4" dart valve. Test #2 -Upper 3 1/2" x 6" VBR, CVs 9,11, mezzanine kill line valve, 4" FOSV. Test #3 -CV's 8,10, kill HCR. Test #4- CV's 6,7, manual kill line valve. OA=0 psi. 8/23/2018 8/23/2018 3.00 PROD1 WHDBOP BOPE P Continue bi-weekly BOPE test. Test 0.0 0.0 00:00 03:00 #5- Super choke and manual choke at 25012000 psi. Test #6- CVs 2,5. Test #7- Lower 3 1/2" x 6" VBR. Test #8 - Blind rams, CVs 3,4,6. Following tests done with 4" lest joint. Test #9 - Annular, upper IBOP, choke line HCR. Test #10- Upper 3l/2"x6"VBR, lower IBOP. Test #11- Lower 3 1/2" x 6" VBR. Accumulator draw down initial system pressure 2900 psi, after - functioning 1800 psi, 200 psi recovery in 10 seconds, full in 48 seconds. Nitrogen bottles 6 @ 2025 psi. Tested gas detection system, flow 8 pit level indicators. Test witness waived by AOGCC Rep Lou Laubenstein. 8/23/2018r3.25 PROD1 WHDBOP RURD P Rig down test equipment. Set 9" ID 0.0 0.0 03:45 wear ring. 8/23/2018 PROD1 CASING MPSP P Make up packer retrieval tool. Engage 0.0 9,262.0 04:45 packer and monitor for pressure up r03:45 DP. Close annular preventer and release packer. Monitor for pressure through choke. 0 pressure, 0 flow. POOH and lay down storm packer. 8/23/2018 PRODt CASING CIRC P CBU x2. Rotate and reciprocate from 9,262.0 9,262.0 04:45 08:00 9,260' MD to 9,167' MD. 200 gpm, 1296 psi, 18% FO, 80 rpm, 5K tq, UP=125K, SO=80K, Rot=100K. 8/23/2018 8/23/2018 0.25 PROD1 CASING OWFF P Monitor well. Slight diminishing flow. 9,262.0 9,262.0 08:00 08:15 1 8/23/2018 8/23/2018 3.75 PROD1 CASING PMPO P Pump OOH from 9262' MD to 6,590' 9,262.0 6,590.0 08:15 12:00 MD. 200 gpm, 1250 psi, 18% FO, UP=117K OA=45 psi 8/23/2018 8/23/2018 5.00 PRODt CASNG P Continue to Pump OOH from 6,590' 6,590.0 3,088.0 12:00 17:00 MD to 3,088' MD. 200 gpm, 786 psi, 18% FO, UP=83K. 8/23/2018 8/23/2018 0.25 PRODt CASING CIRC P CBU. 200 gpm, 786 psi, 18% FO. 3,088.0 3,088.0 17:00 17:15 8/23/2018 8/23/2018 1.25 PROD1 CASING OWFF P Monitor well. Well flowing at 2 bph 3,088.0 3,088.0 17:15 18:30 diminishing to .178 bph. 8/23/2018 8/23/2018 0.75 PROD1 CASING PMPO P Continue to Pump OOH from 3,088' 3,088.0 2,684.0 18:30 19:15 MD to 2,684' MD. 150 gpm, 530 psi, 13% FO, UP=80K. 8/23/2018 8/23/2018 4.00 PROD1 CASING PMPO P Continue to Pump OOH from 2,684' 2,684.0 336.0 19:15 23:15 MD to 336' MD. 84 gpm, 252 psi, 10% FO, UP=79K. 8/23/2018 8/24/2018 0.75 PROD1 CASING OWFF P Blow down TD. Monitor well. Slight 336.0 336.0 23:15 00:00 1 1flow at .66 bph diminishing to .27 bph. 8/24/2018 8/24/2018 0.25 PROD1 CASING OWFF P Continue to monitor well. Slight flow 336.0 336.0 00:00 00:15 at .27 bph diminishing to .21 bph. Page 15136 Report Printed: 9/2412018 Operations Summary (with Timelog DeNchs) 11-1-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan oeplh Start Time End Time Dur(hn Phaee Op Code Acevity Code Time P -T -X Operation (flKB) End OeM(ftKB) 8/24/2018 8/24/2018 1.25 PROD1 CASING BHAH P Stand back and lay down BHA as per 336.0 0.0 00:15 01:30 SLB DD. 8/24/2018 8/24/2018 0.50 PROD1 CASING BHAH P Clean and clear dg Floor. 0.0 0.0 01:30 02:00 8/24/2018 8/24/2018 1.00 COMPZI CASING RURD P Rig up to run 4 1/2" slotted liner. Verify 0.0 0.0 02:00 03:00 joint count in pipe shed. 8/24/2018 8124/2018 9.00 COMPZI CASING PUTB P Pick up and RIH with L-80 12.6# 0.0 5,290.0 03:00 12:00 IBT/SLHT slotted liner as per detail to 5290' MD. PU=84K SO=69K 8/24/2018 8/24/2018 4.25 COMPZ1 CASING PUTB P Continue to pick up and RIH with L-80 5,290.0 7,491.0 12:00 16:15 12.6# IBT/SLHT slotted liner as per detail from 5290' MD to 7491' MD. PU=96K SO=72K 824/2018 8/242018 1.25 COMPZI CASING OTHR P Pick up Baker liner hanger/packer 7,491.0 7,562.0 16:15 17:30 assembly. Mix and pour pal mix. Verify pin settings. 824/2018 8/24/2018 0.25 COMPZI CASING CIRC P Pick up one stand of DP. Break 7,562.0 7,562.0 17:30 17:45 circulation staging pump up to 3 bpm, 186 psi, 11% FO. PU=99K SO=75K 8/2412018 8/242018 1.25 COMPZI CASING RUNL P RIH with 41/2" slotted liner on 4" DP 7,562.0 9,461.0 17:45 19:00 from 7562' MD to 9461' MD. Drop 2" drift on each stand. 8/24/2018 8/24/2018 0.25 COMPZ1 CASING CIRC P Break circulation. Stage pump up to 4 9,461.0 9,461.0 19:00 19:15 bpm, 347 psi, 12% F0, PU=114K SO=79K 8/24/2018 8/25/2018 4.75 COMPZI CASING RUNL P Continue to RIH with 4 1/2" slotted 9,461.0 15,378.0 19:15 00:00 liner on 4" DP from 9461' MD to 15378' MD. Drop 2" drift on each stand. Work through tight hole at 10765' MD. PU=173K SO=79K OA=O psi. 8/25/2018 825/2018 0.75 COMPZI CASING RUNL P Continue to RIH with 4 1/2" slotted 15,378.0 16,019.0 00:00 00:45 liner on 4" DP from 15378' MD to 16019' MD. Drop 2" drift on each stand. PU=179K SO=85K. Tag TD al 89' in on stand #90 (16910' MD) 8/25/2018 8/25/2018 0.50 COMPZI CASING CIRC P Circulate DP volume of 80 bbls, 4 16,019.0 15,994.0 00:45 01:15 bpm, 875 psi, 14% FO. Space out to liner set depth. Observe PU increase to 225K without breakover and SO to block weight without breakover. 8/25/2018 825/2018 1.25 COMPZ1 CASING PACK P Drop 1.625" setting ball and pump 15,994.0 8,445.0 01:15 02:30 down at 3 bpm, 600 psi.Reduce rate to 1.5 bpm, 420 psi at 55 bbls. Ball on seat at 618 strokes. Pressure up to 1700 psi to set hanger. Slack off to block weight. Increase pressure to 2500 psi and hold for 5 min. Increase pressure to 4100 psi and hold for 3 min to set and release packer. TOL at 8445' MD. PU=147K SO=104K after release. 8/252018 8/2512018 0.50 COMPZI CASING PRTS P Test ZXP liner top packer to 3500 8,445.0 8,445.0 02:30 03:00 psi/10 mins on chart. Good test. 8/25/2018 8/25/2018 0.75 COMPZ1 WELLPR CRIH P P/U 12' out of RS packoff nipple and 8,445.0 8,445.0 03:00 03:45 spot 20 bbls of 10.4 ppg Cl brine to above Lt Whipstock @ 8335' MD, Pump @3 bpm= 690 psi w/ 14% FO, displace out of drill pipe with 760 strokes. Page 16136 Report Printed: 9124120181 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth start Time End Time Dur(hr) Phase Op Code Activity Code Tone P -T -x Operation (ftKB) End Depth (ftKB) 8/25/2018 8/25/2018 0.50 COMPZ1 WELLPR OWFF P Monitor well. Dropped in riser 9". 8,445.0 8,445.0 03:45 ID415 8/25/2018 8/25/2018 0.50 COMPZ1 WELLPR TRIP P POOH to 8330' MD. 8,445.0 8,330.0 04:15 04:45 8/25/2018 8/25/2018 2.00 COMPZ1 WELLPR SLPC P Slip and cut 77' drilling line. 8,330.0 8,330.0 04:45 06:45 8/25/2018 8/25/2018 0.75 COMPZ1 WELLPR TRIP P POOH from 8330' MD to 8053' MD. 8,330.0 8,053.0 06:45 07:30 1 1 PU=140K. 8/25/2018 8/25/2018 2.50 COMPZ1 WELLPR PMPO P Pump OOH due to swabbing from 8,053.0 6,030.0 07:30 10:00 8053' MD to 6030' MD. 1.5 bpm, 200 psi. PU=100K 8/25/2018 8/25/2018 3.25 COMPZ1 WELLPR TRIP P POOH from 6030' MD to 57' MD. 6,030.0 57.0 10:00 13:15 8/25/2018 8/25/2018 0.50 COMPZI WELLPR SHAH P Lay down running tools as per Baker 57.0 0.0 13:15 13:45 Rep. 8/25/2018 8/25/2018 0.50 PROD2 WHPST BHAH P Mobilize whipstock tools to rig floor 0.0 0.0 13:45 14:15 and prep for BHA PU. 8/25/2018 8/25/2018 2.00 PROD2 WHPST BHAH P Make up whipstock BHA as per Baker 0.0 110.0 14:15 16:15 Rep. 8/25/2018 8/25/2018 2.25 PROD2 WHPST BHAH P Change out x -o, float sub, 1 jt HWDP 110.0 267.0 16:15 18:30 and MWD x -o due to observed deflection in BHA. MWD pin x pin x -o was source of deflection. Continue to make up BHA to 267' MD, 8/25/2018 8/25/2018 1.00 PROD2 WHPST TRIP P RIH with whipstock BHA from 267' MD 267.0 1,682.0 18:30 19:30 to 1682' MD. PU=72K SO=72K 8/25/2018 8/25/2018 0.25 PROD2 WHPST DHEQ P Shallow pulse test MWD. 250 gpm, 1,682.0 1,682.0 19:30 19:45 1030 psi, 19% FO. 8/25/2018 8/26/2018 4.25 PROD2 WHPST TRIP P Continue to RIH with whipstock BHA 1,682.0 8,257.0 19:45 00:00 from 1682' MD to 8257" MD. Fill pipe every 20 stands. PU=147K SO=109K 8/26/2018 8/26/2018 0.75 PROD2 WHPST WPST P Orient tool face to 19-LOHS, pumping 8,257.0 8,334.8 00:00 00:45 @ 250 gpm, 1890 psi, PU 137K, SO 102K. Wash in hole maintaining 19° LOHS. Tag liner top @ 8445' MD, set I Ok down, PU 10k over, set down 25k over, & observe pin shear. 8/2612018 8/26/2018 5.25 PROD2 WHPST MILL P Mill 63/4" window from 8334.75'MD 8,334.8 8,347.1 00:45 06:00 to 8347.11' MD. 257 gpm, 1650 psi, 19% FO, 80 rpm, 3-7K tq. 1 K WOB. Pump hi -vis super sweep at 8341' MD. SCR @ 8326' MD, 3822' TVD, MW 10.4 ppg, 03:30 hrs #1 @ 20 = 540 psi, @ 30 = 660 psi #2 @ 20 = 560 psi, @ 30 = 700 psi 8/26/2018 8/26/2018 2.50 PROD2 WHPST MILL P Continue to mill 6 3/4" window and 8' 8,347.1 8,373.0 06:00 08:30 guage hole from 8347' MD to 8373' MD. 257 gpm, 1650 to 2500 psi, 19% FO, 80 rpm, 3-5K tq, 5-1 OK WOB. Pressure increase came after - pumping super sweep. TOL at 8441.91' MD TOW at 8334.75' MD BOW at 8348.34' MD. OA=250 psi @ 0700 hrs. 8/26/2018 8/26/2018 1.75 PROD2 WHPST REAM P Pump hi -vis super sweep. Work mills 8,373.0 8,330.0 08:30 10:15 through window. Ream up & down @ same drilling rates x3. Work mills through window w/ no pumps or rotary x2. 1.5K drag up and down. Pump on PU= 133k, SO = 104k. Pump off PU=147K SO=111K Page 17/36 Report Printed: 912412018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P -T -X Operation (fIKB) End Depth(WS) 8/26/2018 8/26/2018r3.00 PROD2 WHPST TRIP P POOH on elevators from 8330' MD to 8,330.0 8,144.0 10:15 10:30 8144' MD. PU=146K SO=110K 8/26/2018 8/2612018 PROD2 WHPST FIT P Rig up and perform FIT to 585 8,144.0 8,144.0 10:30 11:30 psi/13.3 EMW. Pumped .7 WIS. Bled back .4 bbis. Blow down and rig down test equipment. 8/26/2018 8/26/2018 PROD2 WHPST TRIP P POOH on elevators from 8144' MD to 8,144.0 7,688.0 1130 12:00 7688' MD. PU=140K SO=105K. 8/26/2018 8/26/2018 PROD2 WHPST CIRC P Pump 20 bbl 11.5 ppg dry job. Blow 7,688.0 7,688.0 12:00 12:30 down TD. 8/26/2018 8/26/2018 PROD2 WHPST TRIP P POOH on elevators form 7688' MD to 7,688.0 157.0 12:30 15:30 1 157' MD. 8/26/2018 1.00 PROD2 WHPST BHAH P Lay down milling BHA as per Baker 157.0 0.0 16:30 Rep. 8/26/2018 0.50 PROD2 WHPST SHAH P Clean and clear rig Floor. Drain BOPE. 0.0 0.0 17:00 Pull wearring. F17:OO 8/26/2018 1.00 PROD2 WHPST W W WH P Make up stack washing tool. Flush 0.0 0.0 18:00 BOPE at 853 gpm, Lay down tool. Set 9" ID wearring. OA= 0 psi. 8/26/2018 8/26/2018 0.50 PROD2 WHPST SVRG P Service lop drive and blocks 0.0 0.0 18:00 18:30 8/26/2018 8/26/2018 1.00 PROD2 WHPST BHAH P MU up motor/clean out assembly per 0.0 631.0 18:30 19:30 SLB to 631' MD. 8/26/2018 8/26/2018 0.50 PROD2 WHPST TRIP P RIH w/ clean out BHA on 4" DP from 631.0 1,765.0 19:30 20:00 derrick from 631' MD to 1765' MD. PU=69K, SO=69K. Monitor displacement via trip tank. 8/26/2018 8/26/2018 0.25 PROD2 WHPST DHEQ P Shallow hole test MWD. 250 gpm, 1,765.0 1,765.0 20:00 20:15 1315 psi, 19% FO. 8/26/2018 8/2612018 2.75 PROD2 WHPST TRIP P Continue to RIH w/ clean out BHA on 1,765.0 8,135.0 20:15 23:00 4" DP from derrick from 1765' MD to 8135' MD. PU=122K, SO=84K. Monitor displacement via trip lank. Fill pipe every 20 stands. 8/26/2018 8/26/2018 0.25 PROD2 WHPST TRIP P Orient motor to 22'LOHS. Trip down 8,135.0 8,372.0 23:00 23:15 though window from 8334.75' MD to 8348.34' MD, no issues. Tag bottom @ 8372' MD and set down 5K. 8/26/2018 8/27/2018 0.75 PROD2 DRILL DDRL P Drill 6 3/4" hole from 8373' MD to 8,372.0 8,460.0 23:15 00:00 8460' MD 3827' TVD. 250 GPM @ 1970 PSI, 19% F/O, 40 RPM 5K TO. 11K WOB, OB 1820 PSI. UP WT = 124K, DWN WT = 85K. ROT 95K, 81K TQ, Max gas units 0. ADT .45, ASR .09 Bit hrs .45, Jar HRS 110.13 SCR @ 8367' MD, 3822' TVD, MW 10.4 ppg, 23:15 hrs #1 @ 20 = 630 psi, @ 30 = 820 psi #2 @ 20 = 620 psi, @ 30 = 820 psi Losses for tour -11.6 bbis Page 18136 Report Printed; 912412018 °ta . Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Bran Depth Start Tlme End Time our inn Phase Op Code Activity Code Time P-T-X Operation (11KB) End Deplh (WB) 8/27/2018 8/27/2018 0.25 PROD2 DRILL DDRL P Drill 6 3/4" hole from 8460' MD 3827' 8,460.0 8,476.0 00:00 00:15 TVD to 8476' MD 3839' ND. 250 GPM @ 1990 PSI, 19% F/O, 40 RPM 5K TQ, 61K WOB, OB 1830 PSI. UP WT=125K, DWN WT=86K. ROT 95K, 4.51K TQ, Max gas units 0. ADT .11, AST 0 Bit hrs .56, Jar HRS 110.24 8/27/2018 8/27/2018 1.00 PROD2 DRILL CIRC P CBU while rotating and reciprocating 8,476.0 8,476.0 00:15 01:15 from 8476' MD to 8416' MD. 250 gpm, 1920 psi, 19% FO, 40 rpm, 4.51K lq, MW 10.4 ppg. Orient to 10° LOHS. 8/27/2018 8/27/2018 0.25 PROD2 DRILL TRIP P POOH from 8476' MD to 8321' MD. 8,476.0 8,321.0 01:15 01:30 No drag observed pulling though window. 8/27/2018 8/27/2018 0.50 PROD2 DRILL OWFF P Monitor well. Static. 8,321.0 8,321.0 01:30 02:00 8127/2018 8/27/2018 3.25 PROD2 DRILL TRIP P POOH from 8321' MD to 631' MD. 8,321.0 631.0 02:00 05:15 1 Monitor displacement via trip tank. 8/27/2018 8/27/2018 1.50 PROD2 DRILL BHAH P Monitor well at BHA. Static. Lay down 631.0 0.0 05:15 06:45 and stand back clean out BHA #6 as per DD. Monitor displacement via trip tank. 827/2018 8/27/2018 0.75 PROD2 DRILL BHAH P Clean and clear rig floor. Drain BOPE. 0.0 0.0 06:45 07:30 Pull wearring. Make up stack washer. 8/27/2018 8/27/2018 0.75 PROD2 DRILL WWWH P Function all rams and annular 0.0 0.0 07:30 08:15 preventer. Flush ROPE with 854 gpm x2. Install 9" ID wearring. Blow down TD. 8/27/2018 8/2712018 0.50 PROD2 DRILL SVRG P Service and inspect top drive and 0.0 0.0 08:15 08:45 blocks. 8/27/2018 8/27/2018 1.25 PROD2 DRILL BHAH P Make up RSS BHA#7 as per DO to 0.0 336.0 08:45 10:00 336' MD. Monitor displacement via trip tank. 8/27/2018 8/27/2018 0.50 PROD2 DRILL TRIP P RIH with 4" DP from 336' MD to 1750' 336.0 1,750.0 10:00 10:30 MD. Monitor displacement via trip tank. 812712018 8/27/2018 0.50 PROD2 DRILL DHEQ P Shallow hole test MWD. Stage pump 1,750.0 1,750.0 10:30 11:00 up to 241 gpm, 1100 psi, 17% FO. 8/27/2018 8/27/2018 2.75 PROD2 DRILL TRIP P RIH with 4" DP from 1750' MD to 1,750.0 8,405.0 11:00 13:45 8405' MD. Fill pipe every 25 stands. Monitor displacement via trip tank. PU=122K SO=82K 8/27/2018 8/27/2018 1.00 PROD2 DRILL DLOG P Wash down to bottom. MAD pass from 8,405.0 8,476.0 13:45 14:45 8405' MD to 8476' MD. 240 gpm, 1712 psi, 19% FO. Send downlink. Displace to new 10.2 ppg FloPro mud. 8/27/2018 8/272018 3.25 PROD2 DRILL DDRL P Drill 6 3/4" hole from 8476' MD 3839' 8,476.0 8,800.0 14:45 18:00 TVD to 8800' MD 3826' ND. 250 GPM @ 1835 PSI, 19% FlO, 150 RPM 7K TO, 31K WOB, OB 1830 PSI. UP WT= 116K, OWN WT = 81 K. ROT 93K, 4K TQ, Max gas units 20. ADT 2.63, Bit hrs 2.63, Jar HRS 112.87 SCR @ 8596' MD, 3828' TVD, MW 10-2+ ppg, 15:50 hrs #1 @ 20 = 490 psi, @ 30 = 680 psi #2 @ 20 = 480 psi, @ 30 = 680 psi Page 19136 ReportPrinted: 9/24/2018 Operations Summary (with Timelog Depths) 1 H-104 ... Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log $tart Depth Steri Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (fiKB) End Depth (WB) 8/27/2018 8/28/2018 6.00 PROD2 DRILL DDRL P Drill 6 3/4" hole from 8800' MD 3826' 8,800.0 9,720.0 18:00 00:00 TVD to 9720' MD3878' TVD. 250 GPM @ 1940 PSI, 19% F/O, 140 RPM 8K TO, 5K WOB, ECD=12.19 OB 1940 PSI. UP WT = 123K, DWN WT=81 K. ROT 96K, 4K TO, Max gas units 1400. ADT 4.19, Bit hrs 6.82, Jar HRS 117.06 SCR @ 8880' MD, 3841' TVD, MW 10.3 ppg, 18:30 hrs #1 @ 30 = 510 psi, @ 40 = 690 psi #2 @ 30 = 480 psi, @ 40 = 680 psi OA=305 psi 8/28/2018 8/28/2018 6.00 PROD2 DRILL DDRL P Drill 6 3/4" hole from 9720' MD 3878' 9,720.0 10,408.0 0000 06:00 TVD to 10408' MD3893' TVD. 250 GPM @ 2065 PSI, 19% NO, 140 RPM 8.5K TO, 8K WOB, ECD=12.56 OB 2050 PSI. UP WT = 128K, DWN WT=73K. ROT 95K, 8K TQ, Max gas units . ADT 3.92, Bit hrs 10.74, Jar HRS 120.98 8/28/2018 8/28/2018 6.00 PROD2 DRILL DDRL P Drill 6 3/4" hole from 10408' MD3893' 10,408.0 11,004.0 06:00 12:00 TVD to 11 004'MD 3959' TVD. 250 GPM @ 2220 PSI, 19% F/O, 140 RPM 8.7K TQ, 10.51K WOB, ECD=12.33 OB 2215 PSI. UP WT = 129K, DWN WT=81 K. ROT 99K, 7.2K TO, Max gas units 139. ADT 4.55, Bit hrs 15.29, Jar HRS 125.53 SCR @ 10495' MD, 3902' TVD, MW 10.3+ ppg, 06:38 hrs #1 @ 30 = 500 psi, @ 40 = 720 psi #2 @ 30 = 480 psi, @ 40 = 700 psi OA=310 psi 8/28/2018 8/28/2018 6.00 PROD2 DRILL DDRL P Drill 6 3/4" hole from 11004' MD 3959' 11,004.0 11,339.0 12:00 18:00 TVD to 11339' MD 3972' TVD. 260 GPM @ 2380 PSI, 19% F/O, 160 RPM, 8.51K TO, 5K WOB, ECD=12.23, OB 2370 PSI. UP WT = 132K, DWN WT=81K. ROT98K, 6KTQ,Max gas units 195. ADT 4.16, Bit hrs 19.45, Jar HRS 129.69 8/28/2018 8/29/2018 6.00 PROD2 DRILL DDRL P Drill 6 3/4" hole from 11339' MD 3972' 11,339.0 11,979.0 18:00 00:00 TVD to 11979' MD 3930' TVD. 260 GPM @ 2430 PSI, 19% F/O, 150 RPM, 7.7K TQ, 4K WOB, ECD=12.5, OB 2420 PSI. UP WT = 132K, DWN WT = 67K. ROT 97K, 8K TO, Max gas units 180. ADT 4.19, Bit hrs 23.64, Jar HRS 133.88 SCR @ 11350' MD, 3967' TVD, MW 10.2+ ppg, 18:13 hrs #1 @ 30 = 500 psi, @ 40 = 730 psi #2 @ 30 = 490 psi, @ 40 = 720 psi OA=165 psi Page 20136 Report Printed: 912412018 -- Operations Summary (with Timelog Depths) IH -104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Tme End Time Dur (hq Phase Op Code Activity Code Time P -T -X Operation (NCB) End Depth (flKB) 8/29/2018 8/29/2018 6.00 PROD2 DRILL DDRL P Directional drill 6 3/4" L1 hole f/ 11,979.0 12,445.0 00:00 06:00 11979' -12445' MD, 3901' TVD, 260 gpm, 2350 psi, FO 19%, 150 rpm, Tq 8.41K, WOB 5K, ECD 12.59, OB 2345 psi, PU 133K, SO 66K. ROT 96K, 81K TQ, Max gas 190, ADT 4.03, Bit 27.67, Jars 137.91 8/29/2018 8/29/2018 6.00 PROD2 DRILL DDRL P Directional drill 6 3/4" L1 hole f/ 12,445.0 12,946.6- 06:00 12:00 12445'- 12946' MD, 3895' ND, 260 gpm, 2400 psi, FO 19%,150 rpm, Tq 8.51K, WOB 3K, ECD 12.46, off btm 2400 psi, PU 137K, 50 67K, ROT 96K, Tq 8.5K, Max gas 251, ADT 4.28, Bit 31.95, Jars 142.19 SCR @ 12491' MD, 3699' TVD, MW 10.3 ppg, 06:36 hrs #1 @ 30 = 530 psi, @ 40 = 730 psi #2 @ 30 = 530 psi, @ 40 = 730 psi OA280 psi 8/29/2018 8/29/2018 6.00 PROD2 DRILL DDRL P Directional drill 6 3/4" L1 hole f/ 12,946.0 13,444.0 12:00 18:00 12946' - 13444' MD, 3913' TVD, 260 gpm, 2515 psi, FO 20%, 150 rpm, Tq 8.7K, WOB 4.21K, ECD 12.74, off btm 2490 psi, PU 141 K, SO 60K, ROT 94K, Tq 8.51K, Max gas 230, ADT 4.27, Bit 36.22, Jars 146.46 8/29/2018 8/29/2018 4.50 PROD2 DRILL DDRL P Directional drill 6 3/4" L1 hole f/ 13,444.0 13,900.0 18:00 22:30 13444'- 13900' MD, 3962' TVD, 260 gpm, 2767 psi, FO 16%,150 rpm, Tq 8.3K, WOB 5K, ECD 12.54, off btm 2660 psi, PU 146K, SO 60K, ROT 96K, Tq 8K, Max gas 20, ADT 3.4, Bit 39.62, Jars 149.86 Observed losses of initial rate of 30 bph at 13715' MD. 8/29/2018 8/29/2018 1.00 PROD2 DRILL OWFF T Monitor well with 5 rpm & Tq 8K, 13,900.0 13,900.0 22:30 23:30 perform well bore breathing test taking returns to the trip tank. Observe flow decrease from initial flow of 1 bpm to 0.2 bpm over 43 minutes. Total volume back 25 Wis. 8/29/2018 8/30/2018 0.50 PROD2 DRILL DDRL P Directional drill 6 3/4" Ll hole f/ 13,900.0 13,944.0 23:30 00:00 13900' - 13944' MD, 3965' TVD, 260 gpm, 2515 psi, FO 16%, 150 rpm, Tq 8.31K, WOB 2K, ECD 12.36, off blm 2510 psi, PU 146K, SO 60K, ROT 96K, Tq 8K, Max gas 23, ADT .34, Bit 39.96, Jars 150.2 Observed loss rale increase to 90 bph. 8/30/2018 8/30/2018 6.00 PROD2 DRILL DDRL P Directional drill 6 3/4" L1 hole f/ 13,944.0 14,379.0 00:00 06:00 - 13944'- 14379' MD, 3950' TVD, 250 gpm, 2430 psi, FO 17%, 150 rpm, Tq 9K, WOB 3K, ECD 12.41, off btm 2428 psi, PU 150K, SO 65K, ROT 109K, Tq 9K, Max gas 40, ADT 4.62, Bit 44.58, Jars 154.82 Observed loss rate - 100 bph. Page 21136 Report Printed: 912412018 Operations Summary (with Timelog Depths) IH -104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten Depth Sten Time End Time Our (m) Phase Op Code Aawy Cade Time P -TA Operadon (fixe) End Depth(fl)(e) 8130/2018 8/30/2018 2.00 PROD2 DRILL DDRL P Directional drill 6 3/4" L1 hole N 14,379.0 14,546.0 06:00 08:00 14379'- 14546' MD, 3940' TVD, 250 gpm, 2575 psi, FO 17%,120 rpm, Tq 8.5K, WOB 1.5K, ECD 12.42, off btm 2570 psi, PU 150K, SO 65K, ROT 116K, Tq 9K, Max gas 30, ADT 1.72, Bit 46.3, Jars 156.54 Observed loss rate - 100-80 bph. SCR @ 14452' MD, 3945' TVD, MW 10.2+ ppg, 06:45 hm #1 @ 20 = 530 psi, @ 30 = 730 psi #2 @ 20 = 530 psi, @ 30 = 730 psi OA 230 psi 8/30/2018 8/30/2018 0.75 PROD2 DRILL CIRC T Pump 40 bbls LCM pill at 250 gpm, 14,546.0 14,546.0 08:00 08:45 2640 psi, FO 16%, 120 rpm, Tq 7.51K. Reduce pump rate to 170 gpm, 1425 psi as pill was pumped across the suspected loss zone. 8/30/2018 8/30/2018 3.25 PROD2 DRILL DDRL P Directional drill 6 3/4" L1 hole f/ 14,546.0 14,679.0 08:45 12:00 14546' - 14679' MD, 3932' TVD, 240 gpm, 2420 psi, FO 17%,120 rpm, Tq 8K, WOB 3K, ECD 12.4, off btm 2400 psi, PU 152K, SO NIA, ROT 116K, Tq 9K, Max gas 61, ADT 2.65, Bit 48.95, Jars 159.19 Observed loss rate - 80-60 bph. 8/30/2018 8/30/2018 6.00 PROD2 DRILL DDRL P Directional drill 6 3/4" LTi hole fl 14,679.0 14,925.0 12:00 18:00 14679'- 14925' MD, 3929' TVD, 240 gpm, 2460 psi, FO 16%,120 rpm, Tq 8.81K, WOB 6K, ECD 12.48, off btm 2455 psi, PU 163K, SO NIA, ROT 109K, Tq 9K, Max gas 67, ADT 4.74, Bit 53.69, Jars 163.93 Observed loss rate - 40 bph. 8/30/2018 8/31/2018 6.00 PROD2 DRILL DDRL P Directional drill 6 3/4" L1 hole f/ 14,925.0 15,371.0 18:00 00:00 14925' - 15371' MD, 3928' TVD, 245 gpm, 2607 psi, FO 18%,120 rpm, Tq 8.51K, WOB 4K, ECD 12.54, off bon 2600 psi, PU 165K, SO N/A, ROT 106K, Tq 7.71K, Max gas 35, ADT 4.94, Bit 58.63, Jars 168.87 Observed loss rale - 40 bph. SCR @ 15004' MD, 3928' TVD, MW 10.1+ ppg• 19:10 hrs #1 @ 20 = 820 psi, @ 30 = 1040 psi #2 @ 20 = 860 psi, @ 30 = 1080 psi OA 195 psi 8/31/2018 8/31/2018 6.00 PROD2 DRILL DDRL P Directional drill 63/4"Lt hole f/ 15,371.0 15,737.0 00:00 06:00 15371'- 15737' MD, 3910' TVD, 245 gpm, 2740 psi, FO 17%,120 rpm, Tq 8.6K, WOB 4K, ECD 12.61, off btm 2735 psi, PU 169K, SO N/A, ROT 124K, Tq 8K, Max gas 35, ADT 5.09, Bit 63.72, Jars 173.96 Observed loss rate - 25 bph. Page 2206 Report Printed: 912 412 01 8 °r - , Operations Summary (with Timelog Depths) r 71t- 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time EM Time our (m) phase op Code Activity Code Time P -T -x Operation (flKB) End Depth (flKB) 8/3112018 8/31/2018 5.50 PROD2 DRILL DDRL P Directional drill 6 3/4" 1-1 hole f/ 15,737.0 15,972.0 06:00 11:30 15737'- 15972' MD, 3900' TVD, 250 gpm, 2910 psi, FO 18%,120 rpm, Tq 8.5K, WOB 5K, ECD 12.65, off btm 2900 psi, PU 169K, SO N/A, ROT 124K, Tq 8.5K, Max gas 375, ADT 4.18, Bit 67.90, Jars 178.14 Observed loss rate - 20 bph. SCR @ 15737' MD, 3810' TVD, MW 10.0+ ppg, 06:00 firs #1 @ 20 = 880 psi, @ 30 = 1100 psi #2 @ 20 = 800 psi, @ 30 = 1060 psi OA 75 psi 8/31/2018 8/31/2018 2.00 PROD2 CASING CIRC P Obtain final survey & CBU at 250 15,972.0 15,972.0 11:30 13:30 gpm, 2930 psi, FO 17,120 rpm, Tq 8K, ECD 12.61, PU 165K, SO NIA, ROT 123K. SCR @ 15972' MD, 3900' TVD, MW 10.0+ ppg, 13:30 his #1 @ 20 = 890 psi, @ 30 = 1120 psi #2 @ 20 = 900 psi, @ 30 = 1120 psi 8/31/2018 8/31/2018 2.00 PROD2 CASING OWFF P Monitor well, observing flow decrease 15,972.0 15,972.0 13:30 15:30 from 135 bph to 1.2 bph. PU 175K, SO 68K. 8/31/2018 9/1/2018 8.50 PROD2 CASING BKRM P BROOH V 15972'-12872' MD, 240 15,972.0 12,872.0 15:30 00:00 gpm, 1990 psi, FO 13%, ECD 11.72, 120 rpm, Tq 7K, PU 134K, SO 65K. 9/1/2018 9/1/2018 6.00 PROD2 CASING BKRM P BROOH f/ 12872'-10700' MD, 241 12,872.0 10,700.0 00:00 06:00 gpm, 1950 psi, FO 13%, ECD 11.8, 120 rpm, Tq 6.5K, PU 134K, SO 70K. 9/1/2018 9/1/2018 5.00 PROD2 CASING BKRM P BROOH f/ 10700'-8694' MD, 241 gpm, 10,700.0 8,694.0 06:00 11:00 1836 psi, FO 16%, ECD 11.63, 120 rpm, Tq 4.5K, PU 114K, SO 81 K. 9/1/2018 9/1/2018 1.00 PROD2 CASING PMPO P Pump out of the hole pulling the BHA 8,694.0 8,314.0 11:00 12:00 thru the window f/ 8694'-8314' MD, 1 bpm, 330 psi, FO 4%. 9/1/2018 9/1/2018 2.25 PROD2 CASING CIRC P Circulate rasing clean & raise MW to 8,314.0 8,314.0 12:00 14:15 10.4 ppg, 241 gpm, 1886 psi, FO 17%, ECD 11.89,100-120 rpm, Tq 4K. 9/1/2018 9/1/2018 2.00 PROD2 CASING OWFF P Monitor well, observe wellbore 8,314.0 8,314.0 14:15 16:15 breathing to static hole conditions. Measure flow back to trip tank & record reducing rate. 9/1/2018 9/1/2018 1.75 PROD2 CASING PMPO P Pump out of the hole If 8314'-6320' 8,314.0 6,320.0 16:15 18:00 MD, 50 gpm, 260 psi, FO 12%, PU 103K, SO 84K. 9/1/2018 9/1/2018 2.75 PROD2 CASING TRIP P TOH f/ 6320'-336' MD. 6,320.0 336.0 18:00 20:45 9/1/2018 9/112018 0.25 PROD2 CASING - OWFF P Monitor well, observe fluid level drop 336.0 336.0 20:45 21:00 4" in the riser. 9/1/2018 9/1/2018 1.00 PROD2 CASING BHAH P Lay down BHA 7, clear & clean rig 336.0 0.0 21:00 22:00 floor. 911/2018 9/112018 1.50 COMPZ2 FISH BHAH P Pick up BHA 8, 7-5/8" Whipstock 0.0 248.0 22:00 23:30 retrieval assembly to 248.43'. Offset 110.62 9/1/2018 9/2/2018 0.50 COMPZ2 FISH TRIP P TIH w/ BHA 8 f/ 248'-1292' MD, PU 248.0 1,292.0 23:30 00:00 62', SO 55K. 9/2/2018 9/2/2018 2.75 COMPZ2 FISH TRIP P TIH w/ BHA8 f/ 1292'-8287' MD, PU 1,292.0 8,287.0 00:00 02:45 113K, SO 79K. 9/2/2018 9/2/2018 1.00 COMPZ2 FISH CIRC P CBU at 230 gpm, 1600 psi, PU 108K, 8,287.0 8,287.0 02:45 03:45 SO 80K. Page 23136 Report Printed: 9/24/2018 •= - . Operations Summary (with Timelog Dep[hs) 1H-104 Conoco Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time EWTime our Qv) phase Op code Activity Code Time P -T -x Operation (ftKB) End DepN(hKB) 9/2/2018 9/2/2018 0.25 COMPZ2 FISH FISH P Wash in hole & orient tool face to 160 8,287.0 8,325.0 03:45 04:00 R & wash out whipstock slot 210 gpm, 1300 psi. Pick up above slide & orient to 20 L. Slack off & engage hook to slot at 8340' MD, w/ 5K. Pull to 170K & observe anchor release. Pull whipstock assembly past window to 8325' MD, PU 110K. 9/2/2018 9/2/2018 1.50 COMPZ2 FISH CIRC P CBU two times at 280 gpm, 1651 psi. 8,325.0 8,325.0 04:00 05:30 9/2/2018 9/2/2018 1.00 COMPZ2 FISH OWFF P Monitor well, with breathing. Observe 8,325.0 8,325.0 05:30 06:30 return flow reduce to .15 BPH. 9/2/2018 9/2/2018 3.75 COMPZ2 FISH PMPO P Pump out of hole due to swabbing fl 8,325.0 5,386.0 06:30 10:15 8325'-5386' MD, 58 gpm, 160 psi, FO 2%, PU 95K. 9/2/2018 9/2/2018 2.75 COMPZ2 FISH TRIP P TOH with whipstock assembly f/ 5,386.0 353.0 10:15 13:00 5386-353' MD, PU 53K. 9/2/2018 9/2/2018 0.25 COMPZ2 FISH OWFF P Monitor well, static 353.0 353.0 13:00 13:15 9/2/2018 9/2/2018 2.50 COMPZ2 FISH SHAH P Rack back HWDP & lay down 353.0 0.0 13:15 15:45 whipstock assembly as per BOT Rep. Clear & clean rig floor. 9/22018 9/2/2018 1.00 COMPZ2 CASING RURD P Mobilize & rig up 4-1/2" handling 0.0 0.0 15:45 16:45 equipment, verify pipe count. 92/2018 9/2/2018 0.25 COMPZ2 CASING SFTY P PJSM with all personnel involved in 0.0 0.0 16:45 17:00 running 4-1/2" lower completion. 9/2/2018 9/3/2018 7.00 COMPZ2 CASING PUTB P Make up 4-112", 12.6#, L-80, TXP / 0.0 4,784.0 17:00 00:00 IBTM as per detail to 4784' MD, PU 79K, SO 69K. Bakerl-ok first 2 connections, TXP torque to 7K ft/lbs. IBTM connections made up to the mark. Each joint centralized w/ 6-1/8" Volant Hyrdroform. 9/3/2018 9132018 3.50 COMPZ2 CASING PUTS P Make up 4-1/2", 12.6#, L-80, TXP I 4,784.0 7,580.0 00:00 03:30 IBTM as per detail f/ 4784'-7580' MD, PU 95K, SO 75K. TXP torque to 71K f}/lbs. IBTM connections made up to the mark. Each joint centralized w/ 6- 1/8" Volant Hyrdroform. Last 2 joints not centralized. 9/32018 9/3/2018 1.50 COMPZ2 CASING OTHR P Make up hook hanger assembly as 7,580.0 7,613.0 03:30 05:00 per BOT Rep. Make up & install slim pulse assembly as per SLB MWD. Verify offset 156.26. 9/3/2018 9/3/2018 0.50 COMPZ2 CASING CIRC P Circulate staging up to 2 bpm, 320 psi, 7,613.0 7,613.0 05:00 05:30 FO 10%, blow down TD. SIMOPS Change out handling equipment to TIH w/ 4" DP. 9/3/2018 9/3/2018 2.25 COMPZ2 CASING RUNL P TIH w/ 4-112" lower completion on 4" 7,613.0 10,450.0 05:30 0745 DP, drifting stands from derrick f/ 7613'-10450' MD, PU 112K, SO 76K. At the window PU 98K, SO 74K. 9/312018 9/3/2018 3.00 COMPZ2 CASING DHEQ T Test slim pulse tool at various rates 10,450.0 10,450.0 07:45 10:45 staging up to 180 gpm, 954 psi, FO 17%. Increase in pressure f/ 950 to 1300 psi at 2430 strokes pumped. Unable to pump over 80 gpm without exceeding 1300 psi max. No detection. Confer w/ town & decide to TOH & change out slim pulse. 9/32018 9/3/2018 0.50 COMPZ2 CASING OWFF T Monitor well, static. 10,450.0 10,450.0 10:45 11:15 9/3/2018 9/312018 1.75 COMPZ2 CASING TRIP T TUH f/ 10450'-7577' MD, PU 98K, SO 10,450.0 7,577.0 11:15 13:00 74K. 1 Page 24136 Report Printed: 9/2412018 Operations Summary (with Timelog DeNchs) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Opension (/IKB) End Depth (ftKB) 9/3/2018 9/3/2018 3.50 COMPZ2 CASING SHAH T Break out hook hanger assembly & 7,577.0 7,613.0 13:00 16:30 inspect. Change out slim pulse MWD. Test tools at 2 bpm, 290 psi, FO 11 %. 9/3/2018 9/3/2018 0.50 COMPZ2 CASING TRIP T TIH f/ 7613'-8278' MD, PU 100K, SO 7,613.0 8,278.0 16:30 17:00 74K. 9/3/2018 9/312018 0.50 COMPZ2 CASING SRW T Shallow hole test slim pulse tools 2 8,278.0 8,278.0 17:00 17:30 bpm, 312 psi, FO 11 %, good. 9/3/2018 9/3/2018 1.00 COMPZ2 CASING RUNL T TIH w/ 4-1/2" lower completion on 4" 6,278.0 8,450.0 17:30 18:30 DP, 8278'-8460' MD, nogo out at 8460' MD. Pick up & rotate 90° right & attempt to enter window. Repeat process 3 times to enter Li. 9/3/2018 9/3/2018 1.00 COMPZ2 CASING RUNL T TIH w14-1/2" lower completion on 4" 8,450.0 10,450.0 18:30 19:30 DP, f/ 8450'-10450' MD. 9/3/2018 9/4/2018 4.50 COMPZ2 CASING RUNL P TIH w/ 4-1/2" lower completion on 4" 10,450.0 15,882.0 19:30 00:00 DP, drifting stands from derrick f/ 10450'-15882' MD, PU 165K, SO 76K. 9/4/2018 9/4/2018 1.75 COMPZ2 CASING HOSO P Orient toot face to 160°R at 120 glprn, 15,882.0 15,943.0 00:00 01:45 1030 psi & wash down to 15935' MD setting down w/ 7K, string turned to 173'R (appear to be on the hook). Pick up & re-orient string to 20°L and drift thou to 15943' MD. Pick back up above & discuss orientation. Orient string to 170°R & go down to 15935' MD & set 20K SOW. Observe TF roll to 170°L, on the hook. 9/4/2018 9/4/2018 1.00 COMPZ2 CASING HOSO P Release running tool f/ Hook hanger, 15,943.0 8,323.0 01:45 02:45 drop 29/32th ball and pump down @ 118gpm, 1000 psi. Reduce pump rate 64 gpm, 580 psi. Ball on seat @ 724 strokes. Pressure up to 3500 psi & pick up 4' and confirm release w/ P/U wt. of 135K. Pressure up to 4500 psi to blow ball seat. Flanged hook hanger BOW @ 8348' MD, hook hanger inside casing @ 8328' MD. 9/4/2018 9/4/2018 1.00 COMPZ2 WELLPR OWFF P Monitor well; observe reduction in flow 8,323.0 8,323.0 02:45 03:45 rate return to confirm wellbore breathing. 9/4/2018 9/4/2018 0.25 COMPZ2 WELLPR TRIP P TOH f/ 8323'-8171' MD, PU 130K, SO 8,323.0 8,171.0 03:45 04:00 74K. 9/4/2018 9/4/2018 1.00 COMPZ2 WELLPR SLPC P Cut & slip 88' of drill line. 8,171.0 8,171.0 04:00 05:00 9/4/2018 9/42018 7.00 COMPZ2 WELLPR TRIP P TOH f/ 8171'-40' MD, serviced super 8,171.0 40.0 05:00 12:00 sliders f/ 4897' on the way out of the hole. 9/42018 9/4/2018 0.75 COMPZ2 WELLPR BHAH P Lay down SLB slim pulse MWD & 40.0 0.0 12:00 12:45 BOT running tool. 9/4/2018 9142018 0.50 COMPZ2 WELLPR SHAH P Clear & clean rig floor. 0.0 0.0 12:45 13:15 9/4/2018 9/4/2018 0.50 COMPZ2 RWRID RURD P Rig up GBR torque turn & handling 0.0 0.0 13:15 13:45 equipment. 914/2018 9/42018 2.75 COMPZ2 RWRID RCST P Make up 4.5", 12.6#, L-80, TXP, 0.0 232.0 13:45 16:30 LEM/ZXP assembly, torque turned, as per detail to 232' MD. Scribe & orient MWD, tool face offset 26.18. 9/4/2018 9/42018 0.25 COMPZ2 RWRID DHEQ P Make up a stand of DP & test slim 232.0 320.0 16:30 16:45 pulse tools 2 bpm, 242 psi, FO 11 %, acquired detection. 9/4/2018 9/412018 1.00 COMPZ2 RWRID RCST P TIH w/ LEM assembly on DP f/ 320'- 320.0 1,657.0 16:45 17:45 1657' MD, PU 65K, SO 66K. Page 25136 ReportPrinted: 9/2412018 Operations Summary (with Timelog Depths) &WWOM 1H-104 ConocoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth StertTMe End Time our (M) Phase Op Code Activity Code Time P -T -X Operation (RKB) End Depth mKB) 914/2018 9/4/2018 0.25 COMPZ2 RWRID DHEQ P Shallow test MWD at t bpm, 310 psi, 1,657.0 1,657.0 17:45 18:00 FO 11%, good. 9/4/2018 9/4/2018 3.75 COMPZ2 RWRID RCST P TIH wl LEM assembly on DP f/ 1657'- 1,657.0 8,223.0 18:00 21:45 8223' MD, PU 137K, SO 100K. 9/4/2018 9/4/2018 1.75 COMPZ2 RWRID PACK P Wash down from 8223' - 8490' MD & 8,223.0 8,271.0 21:45 23:30 orient LEM to 82°L w/ 91 gpm, 745 psi, FO 10%. PU 137K, SO 100K. Engage seal assembly & latch LEM in Hook Hanger on depth @ 8490.50' MD. Observe LEM rotate to 34" L. Set down 20K. PU 147K to verify LEM is engaged. Drop 1.625" OD ball. Set down 30K & pump @ 127-84 gpm, 1000-665 psi, FO 13-11 %. Ball on seat @ 600 stks. Observe hydraulic pusher tool stroke & set ZXP packer @ 2,400 psi, neutralized @ 3,700 psi & 4200 psi holding for a couple minutes. Bleed off pressure & PU 3' per Baker, PU 137K. 9/4/2018 9/5/2018 0.50 COMPZ2 RWRID PRTS P Line up & test ZXP liner top packer to 8,271.0 8,271.0 23:30 00:00 3500 psi for 10 minutes, CPAI Rep witness. Bleed off & blow down kill line. 9/5/2018 9/5/2018 0.75 COMPZ2 RWRID CRIH P PU above ZXP to 8239' MD & spot 20 8,271.0 8,239.0 00:00 00:45 bbls of corrosion inhibited pill at 126 gpm, 550 psi, 9/5/2018 9/5/2018 0.75 COMPZ2 RWRID OWFF P Monitor well, track return flow to verify 8,239.0 8,239.0 00:45 01:30 reduction in rate (wellbore breathing). 9/5/2018 9/5/2018 3.50 COMPZ2 RWRID TRIP P TOH w/ LEM/ZXP running tools f/ 8,239.0 0.0 01:30 05:00 8239'-O' MD 9/5/2018 9/5/2018 0.50 COMPZ2 RWRID SHAH P Lay down running tool & slim pulse 0.0 0.0 05:00 05:30 MWD. 9/5/2018 9/5/2018 1.25 COMPZ2 RWRID SVRG P Change out 4" XT39 saver sub on top 0.0 0.0 05:30 06:45 drive, threads wom. 9/5/2018 9/5/2018 0.75 COMPZ2 WHDBOP RURD P Rig up test equipment & flood lines. 0.0 0.0 06:45 07:30 Pull wear bushing & install test plug. 9/5/2018 9/5/2018 0.50 COMPZ2 WHDBOP SVRG P Service & inspect top drive, blocks & 0.0 0.0 07:30 08:00 the crown. 9/5/2018 9/5/2018 4.25 COMPZ2 WHDBOP BOPE P Test witnessed by AOGCC Rep Guy 0.0 0.0 08:00 12:15 Cook. Test w/ 4" & 4.5" test joints. Perform bi-weekly ROPE test. 250/3500 psi- 5 min each. Following tests done with 4 1/2" test joint. Test #1-Annular,CV's 1,12,13,14, 4" kill Demon, 4" dart valve. Test #2 -Upper 3 1/2" x 6" VBR, CV's 9,11, mezzanine kill line valve, 4" FOSV. Test #3 -CV's 8,10, kill HCR, Upper IBOP. Test #4 - CV's 6,7, lower IBOP, manual kill line valve. Test #5- Super choke and manual choke at 250/2000 psi. Test #6 - CV's 2,5. Test #7- Lower 3 1/2" x 6" VBR. Test #8- Blind rams, CV's 3,4. Following tests done with 4" test joint. Test #9 -Annular, choke line HCR. Test #10- Upper 3 1/2" x 6" VBR & manual choke. Test #11- Lower 3 1/2" x 6" VBR. Accumulator draw down initial system pressure 3000 psi, after functioning 1750 psi, 200 psi recovery in 6 seconds, full in 50 seconds. Nitrogen bottles 6 @ 2158 psi. Tested gas detection system, flow & pit level indicators. 1-12S alarm in pits FP. Page 26/36 Report Printed: 912 412 01 8 a Operations Summary (with Timelog Depths) 1H-104 qW Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Tema I End Time Dur (hr) Phase Op Code Activity Code Time PS -X Operation WS) End Depth(ftKa) 9/5/2018 9/5/2018 0.75 COMPZ2 WHDBOP RURD P Rig down & blow down all lines & test 0.0 0.0 12:15 13:00 equipment. Pull test plug & install 9" ID wear bushing. 9/512018 9/5/2018 0.50 PROD3 WHPST BHAH P Mobilize whipstock BHA 9 to rig floor. 0.0 0.0 13:00 13:30 9/5/2018 9/5/2018 2.50 PROD3 WHPST SHAH P Make up mill assembly w/ MWD & 0.0 262.0 13:30 16:00 rack back in the derrick. Make up whipstock assembly to 262' MD as per BOT Rep, SO 49K. 9/5/2018 915/2018 1.25 PROD3 WHPST TRIP P TIH w/ whipstock BHA 9 for L2 11262'- 262.0 2,160.0 16:00 17:15 2160' MD, SO 75K. 9/5/2018 9/5/2018 0.50 PROD3 WHPST DHEQ P Pulse test MWD at 220 gpm, 675 psi, 2,160.0 2,160.0 17:15 17:45 FO 16%, good. Blow down TD. 9/5/2018 9/5/2018 3.75 PROD3 WHPST TRIP P TIH w/ whipstock BHA 9 for L2 f/ 2,160.0 8,160.0 17:45 21:30 2160'-8160' MD, PU 142K, SO 75K. 9/5/2018 9/5/2018 0.75 PROD3 WHPST WPST P Establish parameters & orient tool 8,160.0 8,167.0 21:30 22:15 face to 20°L at 231 gpm, 1580 psi, FO 16%, PU 142K, SO 103K. Wash down f/ 8160'-8272' MD, tagging w/ 4K. Observe screws shear at 95K SO to set anchor. Set down to 90K. Pick up to 150K confirm anchor set. Slack off to 74K & observe bolt shear. Pick up & confirm release 144K. TOW 8167' MD. 915/2018 9/6/2018 1.75 PROD3 WHPST MILL P Mill window from 8167' MD (TOW)- 8,167.0 8,169.0 22:15 00:00 8169' MD w/ 250 gpm, 1830 psi, FO 18%, 100 rpm, 4-8k Tq, WOB 2-4K. PU 143K, SO 111K, ROT 117K. SCR @ 8167' MD, 3793' TVD, MW 10.4, 22:00 hrs #1 @ 30 = 660 @ 40 = 870 psi #2 @ 30 = 660 @ 40 = 880 psi 9/6/2018 9/6/2018 8.50 PROD3 WHPST MILL P Mill window from 8169' MD - 8205' 8,169.0 8,205.0 00:00 08:30 MD w/ 250 gpm, 1960 psi, FO 18%, 100 rpm, 4.5k Tq, WOB 6-81K. PU 143K, SO 111 K. ROT 117K. 9/6/2018 916/2018 2.75 PROD3 WHPST REAM P Dress window 8204'-8165' MD, 250 8,205.0 8,165.0 08:30 11:15 gpm, 1960 psi, FO 18%, 100 rpm, Tq 2-61K, PU 146K, SO 108K w/out pumps. Work tight spot 8178'-8180' MD till clean. 9/6/2018 9/6/2018 1.50 PROD3 WHPST CIRC P CBU f/ 8165'-8048' MD, 296 gpm, 8,165.0 8,048.0 11:15 12:45 2270 psi, FO 20%, PU 143K, SO 106K. 9/6/2018 9/6/2018 0.75 PROD3 WHPST FIT P Perform FIT to an EMW of 13.4 ppg, 8,048.0 8,048.0 12:45 13:30 TOW 8167' MD, BOW 8188' MD, hole depth 8205' MD, 3792' TVD, MW 10.4+. Pressure up to 575 psi with .7 bbls pumped. Shut in & record pressure for 10 minutes. Initial shut in pressure 530 psi, final pressure 450 psi. Bled back .6 bbls. Rig down & blow down test equipment. 9/6/2018 9/6/2018 3.50 PRODS WHPST TRIP P TOH f/ 8048'-157' MD, PU 49K, SO 8,048.0 157.0 13:30 17:00 52K. 916/2018 9/6/2018 0.25 PROD3 WHPST OWFF P Monitor well, static. 157.0 157.0 17:00 17:15 9/6/2018 9/6/2018 0.75 PROD3 WHPST BHAH P Lay down window mill BHA as per 157.0 0.0 17:15 18:00 BOT Rep. Recover 60 lbs of swarf from magnets in the BHA. Window mill bit 3/8" under, lower watermelon mill 1/4" under, & upper watermelon mill was in gauge. Page 27136 ReportPrinted: 912412018 -®s - Operations Summary (with Timelog Depchs) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (111<13) End Depth(W13) 9/6/2018 9/612018 0.50 PROD3 WHPST BHAH P Clear & clean dg floor. 0.0 0.0 18:00 18:30 9/6/2018 9/6/2016 1.00 PROD3 WHPST W W WH P Pull wear bushing. Make up stack 0.0 0.0 18:30 19:30 wash tool, flush at 854 gpm, 3X. Function VBR's & annular. Lay down stack tool & install 9" ID wear bushing RILDS X2. 9/6/2018 9/6/2018 0.50 PROD3 WHPST SVRG P Inspect & service top drive & blocks. 0.0 0.0 19:30 20:00 9/6/2018 9/6/2018 1.50 PRODS WHPST SHAH P Pick up 6-3/4", kick off, motor 0.0 631.0 20:00 21:30 assembly, BHA 10, to 631' MD, PU 58K, SO 62K. 9/6/2018 916/2018 0.75 PROD3 WHPST TRIP P TIH f/ 631'-2040' MD, PU 77K, SO 631.0 2,040.0 21:30 22:15 77K. 9/6/2018 9/6/2018 0.50 PRO03 WHPST DHEQ P Shallow hole test MWD, 240 gpm, 2,040.0 2,040.0 22:15 22:45 1257 psi, good. 9/6/2018 9/712018 1.25 PRODS WHPST TRIP P TIH f/ 2040'-5850' MD, PU 130K, SO 2,040.0 5,850.0 22:45 00:00 83K. 9/7/2018 9/7/2018 1.50 PRODS WHPST TRIP P TIH f/ 5850'-8067' MD, PU 119K, SO 5,850.0 8,067.0 00:00 01:30 82K. 9/7/2018 9/7/2018 0.50 PRODS WHPST CIRC P Orient tool face to 20° L at 57 gpm, 8,067.0 8,205.0 01:30 02:00 1850 psi, FO 18%. Pumps off & drift through window f/ 8067-8205' MD. 9/712018 9/7/2018 5.25 PRODS DRILL DDRL P Directional drill 6 3/4" 1-2 hole f/ 8205' 8,205.0 8,312.0 02:00 07:15 - 8312' MD, 3807' TVD, 240 gpm, 1940 psi, FO 19%,50 rpm, Tq 6K, WOB 14-8K, ECD -, off btm 1870 psi, PU 119K, SO 82K, ROT 97K, Tq 4K, Max gas 16, ADT 3.41, AST 1.4, Bit 3.41, Jars 181.56 9/7/2018 9/7/2018 0.50 PROD3 DRILL CIRC P Obtain SCR's. Orient tool face to 20° L 8,312.0 8,039.0 07:15 07:45 at 55 gpm, 1815 psi, FO 17%, PU 121 K, SO 79K. Pumps off & drift through window f/ 8312'-8039' MD SCR @ 8311' MD, 3807' TVD, MW 10.4 ppg, 07:00 hrs #1 @ 20 = 670 psi, @ 30 = 900 psi #2 @ 20 = 670 psi, @ 30 = 860 psi 9/7/2018 9/7/2018 0.50 PROD3 DRILL CIRC P CBU at 240 gpm, 1850 psi, 40 rpm, Tq 8,039.0 8,039.0 07:45 08:15 1 1 5K, PU 121K, SO 79K. 9/7/2018 9/72018 0.25 PRODS DRILL OWFF P Monitor well, static. 8,039.0 8,039.0 08:15 08:30 9/7/2018 9/72018 4.00 PRODS DRILL TRIP P TOH with kick off BHA 10 f/ 8039'- 8,039.0 631.0 08:30 12:30 631' MD, 917/2018 9/7/2018 1.25 PRODS DRILL BHAH P Lay down BHA 10 as per SLB. 631.0 0.0 12:30 13:45 9/7/2018 9/72018 0.75 PROD3 DRILL SHAH P Clear & clean rig floor. 0.0 0.0 13:45 14:30 9/7/2018 9/7/2018 1.00 PROD3 DRILL BHAH P Make up 6-3/4" RSS BHA per SLB DD 0.0 339.0 14:30 15:30 to 339' MD, PU 52K, SO 58K 9/7/2018 9/7/2018 0.75 PROD3 DRILL TRIP P TIH f/ 339'-1751' MD. 339.0 1,751.0 15:30 1615 9/7/2018 9/7/2018 0.25 PRODS DRILL DHEQ P Shallow hole test MWD 230 gpm, 1,751.0 1,751.0 16:15 16:30 1087 psi, FO 16%. 9/7/2018 977/2018 3.50 PRODS DRILL TRIP P TIH f/ 1751'-8211' MD, FII pipe every 1,751.0 8,211.0 16:30 20:00 20 stands. SCR @ 8208' MD, 3794' TVD, MW 10.2 ppg, 19:50 firs #1 @ 20 = 640 psi, @ 30 = 840 psi #2 @ 20 = 640 psi, @ 30 = 840 psi 9/7/2018 917/2018 0.50 PROD3 DRILL 5RVY P Survey/Log f/ 8211'-8310' MD, 240 8,211.0 8,310.0 20:00 20:30 gpm, 1824 psi, FO 18%,60 rpm, Tq 4K, PU 118K, SO 86K, ROT 96K. Page 28136 Report Printed: 9124/2018 y - - Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Cede Activity Code Time P -T -X Operalbn (ftKa) End Demh (flK8) 9/7/2018 9/7/2018 1.25 PROD3 DRILL DISP P Displace well to new 10.2 ppg 8,310.0 8,312.0 20:30 21:45 FLOPRO NT mud at 250 gpm, 1838 psi, FO 18%, 60 rpm, Tq 4K. 9/7/2018 9/8/2018 2.25 PRODS DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 8312' 8,312.0 8,410.0 21:45 00:00 - 8410' MD, 3804' TVD, 250 gpm, 1830 psi, FO 19%,120 rpm, Tq 7K, WOB 2-8K, ECD 11.48, off btm 1833 psi, PU 121 K. SO 82K, ROT 99K, Tq 7K, Max gas 120, ADT 1.21, Bit 1.21, Jars 1.21 9/8/2018 9/8/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f18410' 8,410.0 8,840.0 00:00 06:00 - 8840' MD, 3816' TVD, 250 gpm, 1880 psi, FO 19%, 150 rpm, Tq 8K, WOB 2K, ECD 11.6, off btm 1870 psi, PU 120K, SO 82K, ROT 99K, Tq 7K, Max gas 120, ADT 3.711, Bit 4.92, Jars 4.92 9/8/2018 9/8/2018 6.00 PROD3 DRILL DDRL P Directional drill 63/4"L2 hole f/8840' 8,840.0 8,989.0 06:00 12:00 - 8989' MD, 3825' TVD, 270 gpm, 2116 psi, FO 19%, 100 rpm, Tq 9K, WOB 2-9K, ECD 11.45, off btm 2079 psi, PU 120K, SO 82K, ROT 99K, Tq 7K, Max gas 301, ADT 3.99, Bit 8.91, Jars 8.91 SCR @ 8882' MD, 3820' TVD, MW 10.2 ppg, 07:45 his #1 @ 20 = 420 psi, @ 30 = 620 psi #2 @ 20 = 420 psi, @ 30 = 620 psi 9/8/2018 9/8/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 8989' 8,989.0 9,330.0 12:00 18:00 - 9330' MD, 3841' TVD, 270 gpm, 2172 psi, FO 19%, 100 rpm, Tq 9K, WOB 1-10K, ECD 11.57, off btm 2166 psi, PU 132K, SO 76K, ROT 102K, Tq 8K, Max gas 63, ADT 4.57, Bit 13.48, Jars 13.48 9/8/2018 9/9/2018 6.00 PRODS DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 9330' 9,330.0 9,895.0 18:00 00:00 - 9895' MD, 3851' TVD, 270 gpm, 2170 psi, FO 19%, 140 rpm, Tq 9K, WOB 1-10K, ECD 11.97, off btm 2160 psi, PU 133K, SO 71K, ROT 102K, Tq 8K, Max gas 33, ADT 4.07, Bit 17.55, Jars 17.55 SCR @ 9737' MD, 3849' TVD, MW 10.1 ppg, 22:30 hrs #1 @ 20 = 480 psi, @ 30 = 700 psi #2 @ 20 = 500 psi, @ 30 = 710 psi 9/9/2018 9/9/2018 6.00 PRODS DRILL DDRL P Directional drill 314" L2 hole f/ 9895' 9,895.0 10,360.0 00:00 06:00 - 10360' MD, 3868' TVD, 270 gpm, 2250 psi, FO 19%, 100 rpm, Tq 9K, WOB 2-8K. ECD 11.97, off btm 2200 psi, PU 132K, SO 68K, ROT 96K, Tq 8K, Max gas 22, ADT 4.91, Bit 22.46, Jars 22.46 9/9/2018 9/9/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 314" L2 hole f/ 10,360.0 10,591.0 06:00 12:00 10360' - 10591' MD, 3890' TVD, 270 gpm, 2290 psi, FO 19%,140 rpm, Tq 9K, WOB 2-8K, ECD 12.04, off btm 2285 psi, PU 134K, SO 76K, ROT 97K, Tq 8K, Max gas 107, ADT 4.58, Bit 27.04, Jars 27.04 SCR @ 10400' MD, 3870' TVD, MW 10.2 ppg, 08:00 hrs #1 @ 20 = 510 psi, @ 30 = 700 psi #2@20=520 psi, @30=710 psi Page 29136 Report Printed: 9/2 412 01 8 -- Operations Summary (with Timelog Depths) j 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Time Dur(hr) Phase Op Code Activity Code Time P -T -x Operation (aKB) End Dept (fXB) 9/9/2018 9/9/2018 6.00 PRODS DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 10,591.0 10,951.0 12:00 18:00 105911- 10951' MD, 3921' TVD, 270 gpm, 2380 psi, FO 19%,140 rpm, Tq 9K, WOB 2-8K, ECD 12.08, off trim 2300 psi, PU 135K, SO 73K, ROT 100K, Tq 8K, Max gas 77, ADT 4.94, Bit 31.98, Jars 31.98 9/9/2018 9/10/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole it 10,951.0 11,211.0 18:00 00:00 10951'- 11211' MD, 3914' TVD, 270 gpm, 2350 psi, FO 19%,140-100 rpm, Tq 9K, WOB 2-81K, ECD 12.05, off btm 2320 psi, PU 137K, SO 76K, ROT 96K, Tq 8K, Max gas 66, ADT 5.31, Bit 37.29, Jars 37.29 SCR @ 10972' MD, 3923' TVD, MW 10.2 ppg, 19:15 hrs #1 @ 20 = 500 psi, @ 30 = 700 psi #2 @ 20 = 490 psi, @ 30 = 680 psi 9/10/2018 9/10/2018 6.00 PROD3 DRILL DDRL P Directional drill 63/4"L2 hole f/ 11,211.0 11,460.0 00:00 06:00 11211' - 11460' MD, 3901' TVD, 270 gpm, 2350 psi, FO 19%,120-100 rpm, Tq 8K, WOB 2-6K, ECD 12.0, off btm 2320 psi, PU 135K, SO 68K, ROT 98K, Tq 8K, Max gas 180, ADT 4.77, Bit 42.06, Jars 42.06 OA 160 psi 9/10/2018 9/10/2018 6.00 PRODS DRILL DDRL P Directional drill 63/4"L2 hole f/ 11,460.0 11,789.0 06:00 12:00 114601- 11789' MD, 3875' TVD, 270 gpm, 2409 psi, FO 19%,150 rpm, Tq 8.61K, WOB 2-10K, ECD 12.18, off btm 2400 psi, PU 136K, SO 65K, ROT I OOK, Tq 8.41K, Max gas 183, ADT 4.39, Bit 46.45, Jars 46.45 SCR @ 11636' MD, 3890' TVD, MW 10.2 ppg, 10:00 hrs #1 @ 20 = 560 psi, @ 30 = 740 psi #2 @ 20 = 540 psi, @ 30 = 720 psi 9/10/2018 9/10/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole it 11,789.0 12,047.0 12:00 18:00 11789' - 12047' MD, 3866' TVD, 270 gpm, 2423 psi, FO 20%,150 rpm, Tq 10K, WOB 1-12K, ECD 12.23, off btm 2405 psi, PU 136K, SO 64K, ROT 98K, Tq 8.51K, Max gas 265, ADT 5.09, Bit 51.54, Jars 51.54 OA 155 psi 9/10/2018 9/11/2018 6.00 PRODS DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 12,047.0 12,270.0 18:00 00:00 112047'- 12270' MD, 3856' TVD, 270 gpm, 2450 psi, FO 20%,150 rpm, Tq 8K, WOB 1-12K, ECD 12.25, off btm 2420 psi, PU 137K, SO 62K, ROT 96K, Tq 8.5K, Max gas 36, ADT 5.0, Bit 56.54, Jars 56.54 SCR @ 11636' MD, 3890' TVD, MW 10.2 ppg, 10:00 hrs #1 @ 20 = 560 psi, @ 30 = 740 psi #2 @ 20 = 540 psi, @ 30 = 720 psi 9/11/2018 9/11/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole It 12,270.0 12,766.0 00:00 06:00 12270' MD, 3856' TVD - 12,766' MD 3,833' TVD, 270 gpm, 2500 psi, FO 20%,150 rpm, Tq 8K, WOB 1-61K, ECD 12.28, off Dim 2480 psi, PU 142K, SO 53K, ROT 90K, Tq 8.5K, Max gas 46, ADT 4.36, Bit 60.9, Jars 60.9 Page 30136 Report Printed: 9/2412018 Operations Summary (with Timelog Depths) IH -104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start -rime Entl Tme Dur (6r) Phase Op Code ActivityCotle Time P -T-% Opeation Start Depth (RKB) End Depm(ftKB) 9/11/2018 9/11/2018 6.00 PROD3 DRILL DDRL P Directional drill 63/4"L2 hole f/ 12,766.0 13,460.0 06:00 1200 12,766' MD 3,833' TVD - 13,460' MD 3,836' TVD, 270 gpm, 2631 psi, FO 21%,170 rpm, Tq 11.51K, WOB 1-8K, ECD 12.37, off btm 2630 psi, PU 150K, SO OK, ROT 103K, Tq 9K, Max gas 330. ADT 4.23, Bit 65.13, Jars 65.13 SCR @ 12,773' MD, 3834' TVD, MW 10.2 ppg, 0600 hrs #1 @ 20 = 540 psi, @ 30 = 740 psi #2 @ 20 = 520 psi, @ 30 = 720 psi 9/11/2018 9/11/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ - 13,460.0 14,107.0 12:00 18:00 13,460' MD 3,836' TVD - 14,107' MD 3,911' TVD, 270 gpm, 2765 psi, FO 20%,170 rpm, Tq 9K, WOB 1-71K, I ECD 12.86, off btm 2,745 psi, PU 163K, SO OK, ROT 103K, Tq 10K, Max gas 189. ADT 4.13, Bit 69.26, Jars 69.26 9/11/2018 9/12/2018 6.00 PROD3 DRILL DDRL P Directional drill 63/4"L2 hole f/ 14,107.0 14,442.0 18:00 00:00 14,107' MD 3,911' TVD - 14,442' MD 3,909' TVD, 270 gpm, 2,917 psi, FO 20%,130 rpm, Tq 9K, WOB 2-14K, ECD 12.76, off btm 2,900 psi, PU 167K, SO OK, ROT 106K, Tq 9K, Max gas 71. ADT 4.93, Bit 74.19, Jars 74.19 SCR @ 14,353' MD, 3906' TVD, MW 10.2 ppg, 2230 hm #1 @ 20 = 640 psi, @ 30 = 880 psi #2 @ 20 = 600 psi, @ 30 = 860 psi 9/12/2018 9/12/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 14,442.0 14,932,0 00:00 06:00 14,442' MD 3,909' TVD - 14,932' MD 3,862' TVD, 270 gpm, 3,041 psi, FO 20%,130 rpm, Tq 9.8K, WOB 6K, ECD 12.78, off btm 2,989 psi, PU 170K, SO OK, ROT 105K, Tq 9K, Max gas 39. ADT 4.49, Bit 78.68, Jars 78.68 9/12/2018 9/1212018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" 1-2 hole f/ 14,932.0 15,637.0 06:00 12:00 14,932' MD 3,862' TVD - 15,637' MD 3,857' TVD, 270 gpm, 3,175 psi, FO 20%,120 rpm, Tq 10K, WOB 6K, ECD 13, off btm 3,168 psi, PU 192K, SO OK, ROT 110K, Tq 10K, Max gas 279. ADT 4.46, Bit 83.14, Jars 83.14 SCR @ 15,000' MD, 3,860' ND, MW 10.2 ppg, 0615 hrs #1 @ 20 = 680 psi, @ 30 = 920 psi #2 @ 20 = 660 psi, @ 30 = 900 psi Page 31/36 ReportPrinted: 9/2412018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Cade Time P -T -X Operation (ftK8) End Depth (Ma) 9/12/2018 9/12/2018 3.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 15,637.0 15,872.0 12:00 15:00 15,637' MD 3,857' TVD - 15,872' MD 3,864' TVD, 270 gpm, 3,269 psi, FO 20%,120 rpm, Tq 1 OK, WOB 8K, ECD 13.02, off btm 3,268 psi, PU 189K, SO OK, ROT 114K, Tq 10K, Max gas 53. ADT 2.14, Bit 85.28, Jars 85.28 SCR @ 15,822' MD, 3,867' TVD, MW 10.2 ppg, 1700 his #1 @ 20 = 720 psi, @ 30 = 1,000 psi #2 @ 20 = 680 psi, @ 30 = 960 psi 9/12/2018 9/12/2018 1.50 PRODS CASING CIRC P Rotate and reciprocate from 15,872' 15,872.0 15,872.0 15:00 16:30 MD - 15,827' MD 270 GPM @ ICP 3,269 PSI - FCP = 3,236 PSI. IECD = 13.02, FECD = 12.8 EMW. 120 RPM 8.51K TO. UP WT=183K, DWN WT= 0, ROT WT = 105K. total stks pumped = 5,010. 9/12/2018 9/1212018 0.50 PROD3 CASING OWFF P OWFF (drop 4'). 15,872.0 15,872.0 16:30 17:00 9/12/2018 9/13/2018 7.00 PROD3 CASING BKRM P BKRN OOH from 15,872' MD - 13,000' 15,872.0 13,000.0 17:00 00:00 MD with 270 GPM @ 3,236 PSI. 20% F/O, 120 RPM 8.5K TO, 105K ROT, UP WT = 125K w/pumps. 9/13/2018 9/13/2018 11.50 PRODS CASING BKRM P BKRM OOH from 13,100' MD - 8,507' 13,000.0 8,507.0 00:00 11:30 MD. 270 GPM @ ICP 2,600 PSI, 20% F/O, 120 RPM, 5-71K To, ECD = 11.73, UP WT = 95K pumps on. 9/13/2018 9/13/2018 0.50 PROD3 CASING TRIP P POOH on elevators from 8,507' MD - 8,507.0 8,032.0 11:30 12:00 8,032' MD. pulling BHAthrough window. UP WT = 125K, DWN WT = 83K, Monitor disp via TT. No overpull witnessed. 9/13/2018 9/13/2018 2.00 PROD3 CASING CIRC P PUmp out stand 81 and rack back. 8,032.0 7,936.0 12:00 14:00 ROT/Recip while weight up to 10.4 PPG, frin 7,840'-7,936' MD. 270 GPM @ 2,088 PSI, 17% FIO, 11.95 ECD, 120 RPM 5K TO. UP WT=120K, DWN WT=83K, ROT WT=95K Total stks = 5,786 pumped. 9/13/2018 9/13/2018 0.50 PROD3 CASING OWFF P OWFF. (static) pump dry job. BD/TD. 7,936.0 7,936.0 14:00 14:30 9/13/2018 9/1312018 0.50 PRODS CASING SVRG P Service TD. 7,936.0 7,936.0 14:30 15:00 9/13/2018 9/13/2018 6.00 PROD3 CASING PULD P POOH on elevators from 7,936' MD to 7,936.0 339.0 15:00 21:00 339' MD laying down sideways 4" DP. UP WT=120K, DWN WT=83K. Monitor disp via TT. 9/13/2018 9/13/2018 1.50 PROD3 CASING BHAH P Break down and lay down 6 3/4" L2 339.0 0.0 21:00 22:30 1 1 drilling BHA. 9/13/2018 9/13/2018 0.50 COMPZ3 FISH BHAH P MU Baker BHAforwhipstock retrieval 0.0 0.0 22:30 23:00 while scdbe tool face. 9/13/2018 9/14/2018 1.00 COMPZ3 FISH TRIP P RIH with whipstock retrieval system on 0.0 1,300.0 23:00 00:00 4" DP from Derrick. 9/14/2018 9/14/2018 3.50 COMPZ3 FISH TRIP P Continue to trip in hole with whipstock 1,300.0 8,148.0 00:00 03:30 retrieval system from 1,300' MD - 8,148' MD UP WT = 140K DWN WT = 109K. Monitor disp via TT. Page 32136 Report Printed: 9124120181 Operations Summary (with Timelog Depths) 11-1-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log stat Depth sten Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation (IIKB) End Depth(ftKB) 9114/2018 9/14/2018 0.50 COMPZ3 FISH FISH P Orient tool face to wash whipstock 8,148.0 8,172.0 03:30 04:00 slot. reciprocate at 250 GPM 1,980 PSI to 8,172' MD. Orient and latch whipstock 20 DEG left. Slack off 1 O OWN WT then pull 1 O over to confrm hook. Pull 40K over slowly to allow forjars to bleed. Pull 80K straight pull and sheared at 75K. Stand back stand 142K UP WT. 9/14/2018 9/14/2018 2.00 COMPZ3 FISH CIRC P Circulate 2 bottoms up at 250 GPM 8,172.0 8,080.0 04:00 06:00 1,550 PSI. 5,000 STKS pumped 9/14/2018 9/1412018 2.50 COMPZ3 FISH OWFF T OWFF- Observe flow back @ 5.95 8,080.0 8,248.0 06:00 08:30 BPH. reduce to .45 BPH. 9/14/2018 9/14/2018 0.25 COMPZ3 FISH CIRC T Stage pumps up to 200 GPM @ 1,171 8,248.0 8,248.0 08:30 08:45 PSI with 17% F/0. Observe erratic returns with 3 BBL pit gain. and 1,555 units of gas. Shut down pumps and observe perculating fluid. fluid level dropped 1'. 9/14/2018 9/14/2018 0.50 COMPZ3 FISH OWFF T Close annular and monitor DPP and 8,248.0 8,248.0 08:45 09:15 casing pressure for 30 min. observe 0 PSI. 9/14/2018 9/142018 1.75 COMPZ3 FISH CIRC T Circulate through choke at 4 BPM, 6,248.0 8,248.0 09:15 11:00 171 GPM, ICP 880 PSI, FCP 900 PSI. Total STKS pumped 3,165. Loss of 8 BBLS during circ. 9/14/2018 9/14/2018 0.50 COMPZ3 FISH OWFF T OWFF. Monitor pressure observe 0 8,248.0 8,248.0 11:00 11:30 PSI gain on choke and DP. 9/14/2018 9/14/2018 1.50 COMPZ3 FISH CIRC T Open bag and circulate at 200 GPM 8,248.0 8,248.0 11:30 13:00 1,183 PSI with 15% F/O while increasing MW to 10.4 PPG. total stks pumped 4,434 with a 7 BBL loss during circ. 9/14/2018 9/14/2018 0.25 COMPZ3 FISH OWFF T OWFF. note 6 BBL bleed back. 8,248.0 8,248.0 13:00 13:15 9/14/2018 9114/2018 1.00 COMPZ3 FISH CIRC T Continue to circ BU with 10.5 PPG @ 8,248.0 8,248.0 13:15 14:15 180 GPM 966 PSI 15% F/O, total stks pumped 2,538. Observe no gas to surface 10 BBL loss during circ. 9114/2018 9/14/2018 2.50 COMPZ3 FISH OWFF T Observe well for flow. Rate decreased 8,248.0 8,248.0 14:15 16:45 from 15 BPH - .16 BPH. Good to go. 9/14/2018 9/14/2018 4.50 COMPZ3 FISH TRIP P Drop 1.875" rabbit and POOH on 8,248.0 173.0 16:45 21:15 elevators from 8,248' MD - 173' MD. Monitor disp via TT. recover drift in stnd#1. 9/142018 9114/2018 0.25 COMPZ3 FISH OWFF P OWFF. Observe gas breaking out. 173.0 173.0 21:15 21:30 Fluid level dropped 2'. 91142018 9/15/2018 2.50 COMPZ3 FISH SHAH P LD whipstock BHA system as per 173.0 0.0 21:30 00:00 Baker rep. Monitor disp via TT. 9/15/2018 9/15/2018 1.50 COMPZ3 FISH BOPE T Test BOPE to 25013,500 PSI F 5/5 0.0 0.0 00:00 01:30 charted min with exception of Superchoke t 2,000 PSI, W 4 and 4/1/2" test joint. choke valves 1,3,5,6 test witness waived by Bob Noble. Sim ops clean rig floor. 9/15/2018 9/15/2018 0.50 COMPZ3 CASING ROPE T Pull test plug and set wear bushing. 0.0 0.0 01:30 02:00 9/1512018 9/152018 2.00 COMPZ3 CASING SLPC P Slip and cut 75' Drill line 0.0 0.0 02:00 04:00 9/152018 9/15/2018 0.50 COMPZ3 CASING SVRG P Service rig and c/o washpipe, test 0.0 0.0 04:00 04:30 same to 3,500 PSI. Page 33/36 Report Printed: 9124120181 . Operations Summary (with Timelog Depths) IH -104 qW Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log I Staff Depth start Time End Tina our (hr) Phase Op Code Activity Code Time P -T -X Operation Ws) End Depth (fiKa) 9/15/2018 9/15/2018 9.00 COMPZ3 CASING PUTS P PJSM and RIH with 4 1/2" 12.6# L-80 0.0 5,700.0 04:30 13:30 IBTM liner to 4,807' MD' Monitor disp via TT. UP WT=81K DWN WT= 72K. 9/15/2018 9/15/2018 0.50 COMPZ3 CASING SVRG P Lubricate pipe skate 5,700.0 5,700.0 13:30 14:00 9/15/2018 9/15/2018 2.50 COMPZ3 CASING PUTB P Continue to RIH with 4 112" L-80 12.5# 5,700.0 7,640.0 14:00 16:30 IBTM liner from 5,700' MD - 7,640' MD. UP WT=96K DWN WT=78K. Monitor disp via TT. 9/15/2018 9/15/2018 0.50 COMPZ3 CASING OTHR P PU/MU Baker flanged hook hanger _ 7,640.0 7,690.0 16:30 17:00 and SLMD slimpulse MWD. Orient & RIH from 7,640' MD - 7,690' MD UP WT= 96K DWN WT= 78K Monitor disp via TT. 9/15/2018 9/15/2018 0.50 COMPZ3 CASING DHEO P RIH with lower completion on 4" DP 7,690.0 8,132.0 17:00 17:30 7,690' MD - 8,132' MD Shallow hole test MWD at 86 GPM, 315 PSI 12% F/O. Passed. 9/15/2018 9/1512018 5.00 COMPZ3 CASING RUNL P RIH with L2 lower completion from 8,132.0 15,655.0 17:30 22:30 8,132' MD- 15,655' MD UP WT = 160K. DWN WT=87K. Monitor disp via TT. 9/15/2018 9/16/2018 1.50 COMPZ3 CASING HOSO P Kelly up and wash down from 15,655' 15,655.0 15,827.0 22:30 00:00 MD while orienting to 180 deg. Wash down 5' past window (shoe depth) 15,830' MD. PU above window and orient 24 DEG left.. Set hook hanger at shoe depth of 15,827' MD with 20K dwn wt. PIU 15' and confine tag. Observe loolface rool to 18 DEG L. Drop 29/32" ball and pump down at 3 BPM, 1,070 PSI 9/16/2018 9/16/2018 0.75 COMPZ3 CASING HOSO P Continue to pump 29132" ball down 15,827.0 15,827.0 00:00 00:45 follow BOT pup schedule. Final rate of 1 BPM ball on seat at 703 stks. Pressure up and shear out ball set at 4,430 PSI. raise rate to 2 BPM and PU above liner top to 8,150' MD UP WT= 139K, DWN WT= 105K. 9/16/2018 9/16/2018 1.50 COMPZ3 WELLPR DISP P Circulate while reciprocate form 8,150- 8,150.0 8,150.0 00:45 02:15 8,040' MD. Displace well t/10.4 PPG brine @ 340 GPM, 2,100 PSI, 24% F/0, max gas = 3,370 units. Total stks pumpede 4,180. MW in = 10.4 MW out =10.4 UP WT=135K, DWN WT = 113K. 9/16/2018 9/16/2018 0.75 COMPZ3 WELLPR CRIH P Spot 20 BELS Cho 7,150' MD. Chase 8,150.0 8,150.0 02:15 03:00 with 76 BBLS brine at 5 BPM, 5 BPM 650 PSI. 16% F/O. 9/16/2018 9/16/2018 0.50 COMPZ3 WELLPR OWFF P OWFF. Timed flow back with 8,150.0 8,150.0 03:00 03:30 diminishing rate. start 1gt110 sec- 1 OT144 SEC. prep to POOH. 9/16/2018 9/16/2018 2.50 COMPZ3 WELLPR TRIP P POOH from 8,150 MD-1,985'ME 8,150.0 1,985.0 03:30 06:00 Monitor disp via TT UP WT = 73K, DWN WT= 75K. 9/16/2018 9/16/2018 1.00 COMPZ3 WELLPR TRIP P POOH from 1,985'MD - 85'MD. 1,985.0 85.0 06:00 07:00 1 1 1 1 1 1 Monitor disp via TT. 9/16/2016 9/16/2018 0.75 COMPZ3 WELLPR BHAH P Lay down liner running tools and 85.0 0.0 07:00 07:45 slimpulse MWD. Clean rig floor and prep for ZXP/LEM 9/16/2018 9/16/2018 1.00 COMPZ3 RWRID RURD P RU GBR casing running tools and To 0.0 0.0 07:45 08:45 tum equipment. Page 34136 Report Printed: 9/2412018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Som Time Entl Time Our (M) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (fiKe) 9/16/2018 9/16/2018 2.25 COMPZ3 RWRID PUTB P PJSM / MU L2 LEM/ ZXP as per 0.0 303.0 08:45 11:00 detail from 0- 269' MD. Monitor disp via TT. Slimpulse and liner top pkr. UP WT=48K, DWN WT=53K. 9/16/2018 9/16/2018 5.00 COMPZ3 RWRID RCST P RIH with LEM/ZXP from 303' MD to 303.0 8,192.0 11:00 16:00 8,192' MD on 4" DP out of derrick. UP WT=142K DWN WT=113K. Monitor disp via TT. 9/16/2018 9/16/2018 0.75 COMPZ3 RWRID RCST P Wash down from 8,192 MD -8,287' 8,192.0 8,302.0 16:00 16:45 MD with 120 GPM 603 PSI, 12% F10. orient to 60 DEG L high side. Wash down to 8,302' MD set dwn 15K. _ Observed shift to 30 DEG left high side. Pulled up 1 O over pull to confirm latch. Set down 10K. 9/16/2018 9/16/2018 0.75 COMPZ3 RWRID PACK P Drop 1.625 OD ball and pump dwn at 8,302.0 8,302.0 1645 17:30 3BPM 738 PSI 10% F/O. Reduce rate at 400 STKS. to 2 BPM, 330 PSI. 9% FIC. Ball on seat at 609 stks. Pressure up to 4,000 PSI and set PKR & release. bleed pressure to 0 PSI. 9/16/2016 9/16/2018 1.00 COMPZ3 RWRID PRTS P Pick up 1' with 140K UP WT to confirm 8,302.0 8,004.0 17:30 18:30 release. close upper rams. Pump down kill line and pressure lest IA to 3,500 PSI charted. (PASSED). LD 3 singles. 9/16/2018 9/16/2018 0.50 COMPZ3 RWRID OWFF P OWFF. Note fluid dropped 1'. 8,004.0 8,004.0 18:30 19:00 9/16/2018 9/17/2018 5.00 COMPZ3 RWRID PULD P POOH laying down 4" DP sideways 8,004.0 4,830.0 19:00 00:00 from 8,004' MD - 4,830' MD. Removing SS on rig floor. monitor disp via TT UP WT = 92K, DNW WT = 84K. 9/17/2018 9/17/2018 7.75 COMPZ3 RWRID PULD P Continue to POOH laying down 4,830.0 0.0 00:00 07:45 singles and pulling super sliders off on rig floor. Monitor disp via TT. UP WT =64K, DWNWT=66K. 9/17/2018 9/17/2018 0.75 COMPZ3 RWRID BHAH P LD Baker linner running tools and 0.0 0.0 07:45 08:30 wash stack. BD top drive 9/17/2018 9/17/2018 0.50 COMPZ3 RPCOMP W W WH P Wash stack pull wear ring. 0.0 0.0 08:30 09:00 9/17/2018 9/17/2018 2.00 COMPZ3 RPCOMP RURD P RIG up SLB control line systems 0.0 0.0 09:00 11:00 clampsland GBR running equip. Rig up to RIH with 4 112" 12.6# L-80 IBTM upper completion. 9/17/2018 9118/2018 13.00 COMPZ3 RPCOMP PUTB P PU/MU4 1/2" 12.6# L-80 IBTM upper 0.0 7,039.0 11:00 00:00 completion a RIH from surface to 7,039' MD with DHG wire conection testing realtime to 9,500 PSI. Install clamps on every collar. At 3,400' UP WT = 74K DNW WT = 72K. Monitoring disp via TT UP WT = 94K DWN WT = 78K. 9/18/2018 9/18/2018 1.75 COMPZ3 RPCOMP PUTB P Continue to RIH with 4 1/2" L-80 12.6# 7,039.0 8,020.0 00:00 01:45 IBTM upper completion from 7,039' MD to 8,020' MD. Istall clamps on every collar and TO all conneciton to 4,500 FULBS. Monitor disp via TT. UP WT=98K, DWN WT=78K. Total full cannon clamp count = 267. Total half clamps = 6 Page 35/36 ReportPrinted: 912412018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op CDCs Activity Code Time P-T-% OpembDn Slant Depth (flKB) End Oepih(flKB) 9/18/2018 9/18/2018 1.00 COMPZ3 RPCOMP HOSO P Bring on pumps to 1 BPM and wash 8,020.0 7,963.0 01:45 02:45 down from 8,020' MD to observe seals enter seal asym at 8,036.47' MD, DO pumps and no go out at 8,054.15 MD. with 20K DWN WT. LD 4joints to 7,963' MD 9/18/2018 9/18/2018 1.50 COMPZ3 RPCOMP HOBO P MU space out pups of 7.82'/ 3.90' rig 7,963.0 7,963.0 02:45 04:15 1 up circ lines / hanger / landing joint. 9/18/2018 9/18/2018 1.25 COMPZ3 RPCOMP CRIH P Circulate and spot corrosion inhibitor 7,963.0 7,963.0 04:15 05:30 145 BBI-S. 4 BPM @ 245 PSI, 12% F/O. chase with 120 BBLS brine. simops with termination of tech wire. 9/18/2018 9/18/2018 1.50 COMPZ3 RPCOMP W WSP P LAnd hanger and RILDS. PT upper I 7,963.0 8,054.0 05:30 07:00 lower seals to 5,000 PSI for 10 min each. 9/18/2018 9/18/2018 2.00 COMPZ3 RPCOMP PRTS P PT IA to 1,000 PSI for 5 min to confirm 8,054.0 8,054.0 07:00 09:00 seals are fully located , bleed off psi . Drop B&R and r/U to test tbg. Test TBG to 3,500 PSI for 30 Charted min. Bleed off tbg to 2,100 PSI and pressure test lA to 3,500 charted PIS for 30 min. Bleed off tbg and shear SOV. 9/18/2018 9/18/2018 1.00 COMPZ3 WHDBOP MPSP P LD landing joint and install BPV. / 8,054.0 8,054.0 09:00 10:00 jPmssure test BPV to 2,500 PSI from below for 5 min. 9/18/2018 9/18/2018 2.00 COMPZ3 WHDBOP OTHR P LD mouse hole and pulll riser. Install 8,054.0 8,054.0 10:00 12:00 drip nipple 9/18/2018 9/18/2018 1.50 COMPZ3 WHDBOP NUND P NO BOPE 0.0 0.0 12:00 13:30 9/18/2018 9/18/2018 2.00 COMPZ3 WHDBOP NUND P Clean well head and install test dart. 0.0 13:30 15:30 MU tree as per Vetco rep. 9/18/2016 9/18/2018 2.50 COMPZ3 WHDBOP PRTS P PT void on tree/ hanger seals / to 15:30 18:00 5,000 PSI for 10 min as per Vetco rep. Finalize termination of tech wire and verify reading PSI and tempurature. CO rep verify test. 9/18/2018 9/182018 3.25 COMPZ3 WHDBOP FRZP P PJSM / Pull test dart / ru and freeze 18:00 21:15 protect well IA-Tub with 112 EELS diesel at 3 BPM 1,650 PSI final 2.5 - BPM @ 2,000 PSI holding 100 PSI BP. Install BPV and test same to 1,500 PSI from direction of flow. RD lubricator. Final pressures read before installing BPV were tubing 250 psi, IA 30 psi and OA= 0 psi. 9/18/2018 9/19/2018 2.75 DEMOB MOVE RURD P Clean cellar while prepping to move 21:15 00:00 rig. Rig release 2359 hrs. Page 36136 ReportPrinted: 9124/2018 NADConversion Kuparuk River Unit Kuparuk 1H Pad 1H -104L1 1H -104L1 ConocoPhillips Definitive Survey Report 12 September, 2018 Final Definitive Survey Verified and Signed -off Ali targets andfor wellpostion objectives have been achieved. Ld yes I No I have checked to the best of tW abft that the following data is correct: 71 Surface Coordinates Declination & Convergence L GRS Survey Corrections Survey Tool Codes R y� Digitally signed by Brandon Temple SLB DE. Brandon Temple Date: 2018.10.0810:19:35-08'00• Client Representative scolt.a.brunswick@conocophillipsc0 q. : •_••'- Date: XMILIv11v&VIII ConocoPhillips ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1 H-104 Project: Kuparuk River Unit TVD Reference: 1H-104 actual Q 92.79usft (Doyon 142) Site: Kupamk 1H Pad MD Reference: 1H-104 actual Q 92.79usft (Doyen 142) Well: Rig: 1H-104 North Reference: True Wellbore: 1H-1041.7 Survey Calculation Method: Minimum Curvature Design: 1 H-1041.1 Database: OAKEDMP2 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 Nap Zone: Alaska Zone 04 Using geodetic scale factor Well Rig: 1H-104 Well Position +N/.S +E/.W Position Uncertainty Wellbore 1H-1041.1 Magnetics Model Name BGGM2018 0.00 usft Northing: 5,980,782.43 usft Latitude: 70' 21'29.809 N 0.00 Usti Easting: 549,568.74 usft Longitude: 149° 35'50.655 W 0.00 Usti Wellhead Elevation: usit Ground Level: 54.10 usft Sample Date Declination Dip Angle r) (% 8/15/2018 17.04 80.91 Field Strength (nT) 57,448 Design 1H-1041.1 Date Audit Notes: To Version: 1.0 Phase: ACTUAL Tie On Depth: 8,307.00 Vertical Section: Depth From (TVD) +N/S +E/ -W Direction 1,194.67 (usft) (usft) (usft) (1) 1,901.24 38.69 0.00 0.00 67.37 Survey Program Date From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 130.47 1,098.56 1H-104 Srvy 1 - SLB_GWD70 (1H-104PB GYD-GCS Gyrodata gyro single shots 8/6/2018 10:47:[ 1,194.67 1,804A01H-114 Srvy 2 -SLB MWD+GMAG(1 H- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/6/2018 10:55:( 1,901.24 1,901.241H-104 Srvy 3- SLB _MWD-INC-ONLY_F MWD -INC _ONLY MWD -INC_ ONLY_ FILLER 8/9/2018 10:05:( 1,977.75 8,307.001H-104 Srvy 4-SLB_DUAL+GMAG+SA MWD+IFR2+HDS+MS OWSG MWD+IFR2+HDS+Mufti-Station Correc8/9/2018 10:07:[ 8,334.75 8,443.02 1H-1041.7 Srvy 1-SLB_MWD-Ine-Only-F MWD-INC_ONLY MWD -INC -ONLY -FILLER 8/27/2018 9:18:. 8,536.66 15,912.021H-1041.1 Srvy2-SLB_DUAL+GMAG+S MWD+IFR2+HDS+MS OWSGMVvD+IFR2+HDS+Multi-Station Correce/27/2018 9:20: Survey Map Map Vertical MD Inc Act TVD TVDSS +W s +F/4N Northing Easting DLS Section (ualt) (1 (1) (usft) (usft) (-it) (usR) (N) (ft) (°/100') (ft) Survey Tool Nam 38.69 0.00 0.00 36.69 S4AD 0.00 0.00 5,980,782.43 549,56874 0.00 0.00 UNDEFINED 130.47 0.03 108.52 130.47 37.68 -0.01 0.02 5,980,782.42 549,568.76 0.03 0.02 GYD-GCSS(1) 170.09 0.12 87.41 170.09 77.30 -0.01 0.07 5,980,782.42 549,558.81 0.23 0.06 GYD.GCSS(1) 259.84 2.03 116.87 259.82 167.03 -072 1.59 5,980,781.72 549,570.33 2.15 1.19 GYD-GC-SS(1) 357.41 4.01 124.19 357.25 264.46 3.42 5.95 5,980,779.05 549,574.71 2.06 4.17 GYD-GC-SS(1) 449.01 5.79 114.28 448.51 355.72 -7.12 12.81 5,980,775.39 549,581.60 2.14 9.08 GYD-GC.SS(1) 540.15 6.91 118.50 539.09 446.30 -11.63 21.82 5,980,770.95 549,590.64 1.33 15.67 GYD-GC-SS(1) 631.94 8.38 116.35 630.06 537.27 -17.23 32.67 5,980,765.42 549,601.52 1.63 23.52 GYD-GCSS(1) 722.47 10.69 118.44 719.34 626.55 -24.16 45.96 5,980,758.58 549,614.85 2.57 33.12 GYD-GCSS(1) 813.86 12.56 116.31 808.85 716.06 -32.60 62.31 5,980,750.25 549,631.26 2.11 44.97 GYD.GCSS(1) 9/12/1018 7:15:584M Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Comparry: NADConversion Local Coordinate Reference: Well Rig: 11-1-104 Project: Kupamk River Unit TVD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Well: Rig: IH -104 North Reference: True Wellbore: IH -10411 Survey Calculation Method: Minimum Curvature Design: iH-1041-1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc An TVD TVDSS +WS +Ef-W Northing Easting DLS Section lust) (°) (') (usft) (usft) (usft) (wait) (to (ft) (°1100) (ft) Survey Tool Name 909.29 1546 116.02 901.43 808.64 42.78 83.06 5,980,740.20 549,652.07 3.06 60.20 GYD-GCSS(1) 1,003.79 16.85 113.72 992.19 899.40 53.83 106.94 5,980,729.32 549,676.02 1.60 77.98 GYD-GCSS(1) 1,098.56 16.48 111.78 1,082.49 98970 64.93 133.46 5,980,718.39 549,702.61 1.83 98.19 GYD-GCSS(1) 1,194.67 20.89 113.70 1,172.98 1,080.19 -77.47 163.30 5,980,706.05 549,732.53 2.60 120.91 MWD+IFR-AK-CAZ-SC(2) 1,234.61 22.13 113.61 1,210.14 1,117.35 63.34 176.71 5,980,700.27 549,745.98 3.11 131.03 MWD+IFR-AK-CAZ-SC(2) 1,329.20 25.32 113.89 1,296.72 1,203.93 58.67 211.54 5,980,685.17 549,780.91 3.37 157.27 MWD+IFR-AK-CAZSC(2) 1,421.11 29.49 113.16 1,378.30 1,265.51 -115.54 250.33 5,980,668.56 549,819.80 4.55 186.58 MWD+IFR-AK-CAZSC(2) 1,517.95 33.20 112.62 1,460.99 1,368.20 -135.12 296.73 5,980,649.29 549,865.33 3.84 221.88 MWD+IFR-AK-CAZSC(2) 1,613.27 33.72 113.53 1,540.51 1,447.72 -155.72 345.08 5,98,629.01 549,914.81 0.76 258.58 MWD+IFR-AK-CAZSC(2) 1,708.42 33.08 113.61 1,619.95 1,527.16 -176.66 393.09 5,980,608.39 549,962.95 0.67 294.83 MWD+IFR-AK-CAZ-SC (2) 1,804.10 33.67 115.86 1,699.85 1,607.06 -198.69 440.88 5,980,586.68 550,010.89 1.43 330.46 M6W+IFR-AK-CAZSC (2) 1,901.24 37.21 118.00 1,778.99 1,686.20 -224.23 491.07 5,980,561.47 550,061.23 3.86 366.95 MWD -INC ONLY (3) 1,977.75 39.23 117.71 1,839.09 1,746.30 -246.35 532.92 5,980,539.64 550,103.22 2.65 397.07 MWD+IFR2+HDS+MS(4) 2,007.00 40.35 117.25 1,861.57 1,768.78 -254.98 549.52 5,980,531.11 550,119.89 3.96 409.07 MWD+IFR2+HDS+MS(4) 2,037.00 41.52 116.92 1,884.23 1,791.44 -263.93 567.02 5,9BD,522.28 550,137.44 3.97 421.78 MWD+IFR2+HDS+MS(4) 2,067.00 42.58 116.71 1,906.51 1,813.72 -273.00 584.96 5,980,513.34 550,155.43 3.56 434.84 MWD+IFR2+HDS+MS(4) 2,097.00 43.63 116.51 1,928.41 1,835.62 -282.18 603.29 5,98,504.28 550,173.82 3.53 448.23 MWD+IFR2+HDS+MS(4) 2,127.00 44.75 116.43 1,949.92 1857.13 -291.50 622.00 5,980,495.08 580,192.80 3.74 461.92 MWD+IFR2+HDS+MS(4) 2,157.00 45.87 116.47 1,971.02 1,878.23 J01.00 641.10 5,980,485.71 550,211.75 3.73 475.89 MWD+1FR2+HDS+MS(4) 2,187.00 47.08 116.52 1,991.68 1,898.89 -310.70 660.57 5,980,476.14 550,231.28 4.04 490.12 MWD+IFR2+HDS+MS(4) 2,217.00 48.40 116.44 2,011.85 1,919.06 -320.60 680.44 5,980,466.37 550,251.22 4.40 504.65 MWD+IFR2+HDS+MS(4) 2,247.00 49.68 116.16 2,031.52 1,938.73 -330.64 700.75 5,980,456.47 550,271.59 4.32 519.53 MWD+IFR2+HDS+MS(4) 2,277.00 50.84 115.84 2,050.70 1,957.91 -340.75 721.48 5,98,446.50 550,292.39 3.95 534.78 MWD+IFR2+HDS+MS(4) 2,307.00 51.95 115.63 2,069.42 1,976.63 -350.93 742.60 5,980,436.46 550,313.58 3.74 550.35 MWD+IFR2+HDS+MS(4) 2,337.00 53.10 115.68 2,087.67 1,994.88 561.24 764.06 5,980,426.29 550,335.10 3.84 665.20 MWD+IFR2+HDS+MS (4) 2,367.00 54.38 115.81 2,105.41 2,012.62 J71.74 785.85 5,980415.93 550,356.96 4.26 582.26 MWD+IFR2+HDS+MS (4) 2,397.00 55.64 115.93 2,122.61 2,029.82 -382.47 807.% 5,980,405.35 550,379.14 4.21 598.55 MWD+IFR2+HDS+MS(4) 2,427.00 56.61 116.02 2,139.34 2,046.55 -393.38 830.36 5,980,394.59 550,401.60 3.24 615.01 MWD+IFR2+HDS+MS(4) 2,457.00 57.38 116.10 2,155.68 2,062.89 404.43 852.96 5,980,383.69 550,424.27 2.58 631.62 MWD+IFR2+HDS+MS(4) 2,487.00 58.37 116.14 2,171.63 2,078.84 415.61 875.77 5,980,372.66 550,447.15 3.30 648.37 MWD+IFR2+HDS+MS(4) 2,517.06 59.50 115.95 2,187.11 2,094.32 426.90 898.86 5,980,361.53 550,470.31 3.81 665.34 MWD+IFR2+HDS+MS(4) 2,547.00 60.42 115.63 2,202.13 2,109.34 -038.20 922.24 5,9B0,350.39 550,493.77 3.20 682.57 MWD+IFR2+HDS+MS(4) 2,577.00 61.29 115.29 2,216.74 2,123.95 449.6 905.90 5,980,339.28 550,517.50 3.06 700.07 MWD+IFR2+HDS+MS(4) 2,607.00 62.12 114.85 2,230.96 2,138.17 460.65 969.82 5,980,328.25 550,541.50 3.05 717.85 MWD+IFR2+HDS+MS(4) 2,637.00 63.06 114.32 2,244.77 2,151.98 171.73 994.04 5,980,317.33 55,555.78 3.50 735.94 MWD+IFR2+HDS+MS(4) 2.667.80 64.06 113.78 2,258.13 2,165.34 482.68 1,018.57 5,980,306.55 550,590.38 3.70 754.37 MWD+IFR2+HDS+MS(4) 2,697.00 65.0B 113.33 2,271.01 2,178.22 493.50 1,043.41 5,980,295.89 550,615.29 3.66 773.12 MWD+1FR2+HDS+MS(4) 2,727.00 66.25 112.97 2,283.37 2,190.58 -504.25 1,068.54 5,980,285.31 550,640.49 4.05 792.18 MWD+IFR2+HDS+MS(4) 2,757.00 67.57 112.62 2,295.14 2,202.35 514.94 1,093.98 5,980,274.79 550,666.00 4.53 811.55 MWD+IFR2+HDS+MS (4) 2,787.00 68.78 112.39 2,306.29 2,213.50 525.60 1,119.71 5,980,264.30 550,691.79 4.10 831.20 MWD+1FR2+HDS+MS(4) 9/12/2018 7:15:58AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordlnate Reference: Well Rig: 1H-104 Project: Kuparuk River Unit TVD Reference: 1 H-104 actual @ 92.79usR (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-104 actual @ 92.79usR (Doyon 142) Well: Rig: 1H-104 North Reference: True Wellbore: iH-1041.1 Survey Calculation Method: Minimum Curvature Design: 1H -104L1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +WS +FJ4N Northing Easting DLS Section (usft) (1) r) (usft) (usft) (usft) Wall) (Po (10 (111001 (ft) Survey Tool Name 2,817.00 69.85 112.35 2,316.89 2,224.10 536.28 1,145.66 5,980,253.79 550,717.81 3.57 851.04 MWD+IFR2+HDS+MS(4) 2,847.00 70.90 112.35 2,326.96 2,234.17 547.03 1,171.80 5,980,243.22 550,744.02 3.50 871.03 MMAFR2+HDS+MS(4) 2,877.00 71.12 112.39 2,336.72 2,243.93 557.82 1,198.03 5,980,232.60 550,770.32 0.74 891.08 MWD+IFR2+HDS+MS(4) 2,907.00 70.87 112.56 2,346.49 2,253.70 568.67 1,224.24 5,980,221.93 550,796.60 0.99 911.10 MWD+1FR2+H0S+MS(4) 2,937.00 70.73 112.76 2,356.36 2,263.57 579.58 1,250.38 5,980,211.19 550,822.61 0.78 931.03 MWD+IFR2+HDS+MS(4) 2,967.00 71.42 112.94 2,366.09 2,273.30 590.60 1,276.64 5,980,200.35 550,849.03 2.37 950.93 MWD+IFR2+HDS+MS(4) 2,997,0 72.16 113.02 2,375.46 2,282.67 501.73 1,302.77 5,980,189.40 550,875.34 2.48 970.86 MWD+IFR2+HDS+MS(4) 3,02700 72.76 113.06 2,384.50 2,291.71 -612.92 1,329.09 5,980,178.38 550,901.73 2.00 990.85 MWD+IFR2+HDS+MS(4) 3,057.00 73.19 113.13 2,393.29 2,3D0.50 -624.17 1,355.48 5,980,167.30 550,928.19 1.45 1,010.87 MWD+IFR2+HDS+MS(4) 3,087.00 73.23 113.36 2,401.95 2,309.16 535.51 1,381.87 5,980,156.14 550,954.65 0.75 1,030.87 MWD+IFR2+HDS+MS(4) 3,117.00 73.26 113.71 2,410.60 2,317.81 546.98 1,408.21 5,98,144.85 550,981,6 1.12 1,050.76 MWD+IFR2+HDS+MS(4) 3,147.00 7312 114.04 2,419.13 2,326.34 558.62 1,434.51 5,980,133.38 551,00244 1.86 1,070.56 MWD+IFR2+HDS+MS(4) 3,177.00 74.22 114.10 2,427.41 2,334.62 -670.38 1,460.83 5,980,121.79 551,033.84 1.68 1,090.33 MWD+IFR2+HDS+MS(4) 3,207.00 74.27 113.93 2,435.56 2,342.77 582.13 1,487.21 5,980,110.22 551,060.29 0.57 1,110.15 MWD+IFR2+HDS+MS(4) 3,237.00 74.45 113.75 2,443.65 2,350.86 -693.81 1,513.63 5,980,098.72 551,086.78 0.83 1,13D.05 MWD+IFR2+HDS+MS(4) 3,267.00 74.41 113.51 2,451.70 2,358.91 -705.39 1,540.11 5,960,087.31 551,113.33 0.78 1,150.03 MWD+IFR2+HDS+MS(4) 3,297.00 74.24 113.22 2,459.80 2,367.01 -716.85 1,566.62 5,980,076.03 551,139.92 1.09 1,170.09 MWD+IFR2+HDS+MS(4) 3,327.00 74.32 112.91 2,467.93 2,375.14 -728.16 1,593.19 5,980,064.90 551,166.56 1.03 1,190.26 MWD+IFR2+HDS+MS(4) 3,357.00 74.22 112.61 2,476.06 2,383.27 -739.33 1,619.62 5,980,053.90 551,193.26 1.02 1,210.54 MWD+IFR2+HDS+MS(4) 3,387.00 74.13 112.34 2,484.25 2,391.46 -750.37 1,646.49 5,980,043.05 551,220.00 0.92 1,230.91 MWD+IFR2+HDS+MS(4) 3,417.00 74.29 112.06 2,492.41 2,399.62 -761.27 1,673.22 5,980,032.32 551,246.80 1.04 1,251.38 MWD+IFR2+HDS+MS (4) 3,447.00 74.40 111.80 2,500.50 2,407.71 -772.06 1,700.02 5,980,021.71 551,273.66 0.91 1,271.96 MWD+IFR2+HDS+MS(4) 3,477.00 74.33 111.56 2,508.59 2,415.80 -782.73 1,726.86 5,980,011.22 551,300.58 0.80 1,292.63 MWD+IFR2+HDS+MS(4) 3,507.00 74.20 111.34 2,516.73 2,423.94 -793.29 1,753.74 5,980,000.63 551,327.52 0.83 1,313.37 MWD+IFR2+HDS+MS (4) 3,537.00 73.93 111.12 2,524.96 2,432.17 -803.74 1,780.63 5,979,990.57 551,354.48 1.14 1,334.17 MWD+IFR2+HDS+MS(4) 3,567.00 73.69 11092 2,533.33 2,440.54 -814,7 1,807.52 5,979,980.41 551,381.43 1.02 1,355.02 MWD+IFR2+HDS+MS(4) 3,597,0 7316 110.74 2,541.73 2,448.94 -824.31 1,834.44 5,979,970.35 551,08.41 0.62 1,375.92 MWD+IFR2+HDS+MS(4) 3,627.00 73.77 110.57 2,550.12 2,457.33 534.48 1,861.39 5,979,960.37 551,435.43 0.55 1,396.88 MWD+IFR2+HDS+MS(4) 3,657.00 73.86 110.48 2,558.48 2,465.69 -844.58 1,888.37 5,979,950.45 551,62.48 DA2 1,417.90 MWD+IFR2+HDS+MS(4) 3,687.00 73.77 110.44 2,566.85 2,474.06 -854.65 1,915.37 5,979,940.55 551,489.53 0.33 1,438.94 MW0+IFR2+HDS+M$(4) 3,717.00 73.67 110.40 2,575.26 2,482.47 564.70 1,942.35 5,979,930.69 551,516.58 0.36 1,459.98 MWD+IFR2+HDS+MS(4) 3,747.DD 73.89 110.46 2,583.64 2,490.85 -874.75 1,969.35 5,979,920.82 551,543.64 0.76 1,481.03 MWD+IFR2+HDS+M$(4) 3,777.00 73.58 110.60 2,592.04 2,499.25 584.85 1,996.32 5,979,910.90 551,570.67 1.13 1,502.03 MWD+IFR2+HDS+MS(4) 3,807.00 73.22 110.74 2,600.61 2,507.82 -895.00 2,023.22 5,979,900.93 551,597.64 1.28 1,522.96 MWD+IFR2+HDS+MS(4) 3,837.00 73.72 110.88 2,609.14 2,516.35 -905.22 2,050.10 5,979,890.89 551,624.59 1.73 1,543.84 MWD+IFR2+HDS+MS(4) 3,867,0 73.59 111.00 2,617.59 2,524.80 -915.50 2,076.99 5,979,860.78 551,651.54 0.58 1,564.69 MWD+IFR2+HDS+MS(4) 3,897.00 73.33 111.13 2,626.13 2,533.34 -825.84 2,103.82 5,979,870.62 551,678.44 0.96 1,585.48 MWD+IFR2+HDS+MS(4) 3,927.00 73.55 111.24 2,634.68 2,541.89 -936.23 2,130.63 5,979,860.41 551,705.32 0.81 1,606.23 MWD+IFR2+HDS+MS(4) 3,957.00 73.44 111.35 2,643.20 2,550.41 -946.68 2,157.43 5,979,850.14 551,732.18 0.51 1,626.95 MWD+IFR2+HDS+MS(4) 3,987.00 73.38 111.45 2,651.77 2,558.98 -957.17 2,184.20 5,979,839.83 551,759.02 0.38 1,647.62 MWD+IFR2+HDS+MS(4) 9/122018 7: 15:58AM Page 4 COMPASS 5"..14 BUfa 85 Survey ConocoPhillips Definitive Survey Report Map Company: NADConversion Local Coordinate Reference: Well Rig: 1H-104 Project Kuparuk River Unit TVD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Wen: Rig: 11-1-104 North Reference: True Wellbore: 11-1-1041.1 Survey Calculation Method: Minimum Curvature Design: 11-1-1041.1 Database: OAKEDMP2 Survey 9H212018 7:15:58AM Page 5 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS NUS +EI -VV Northing Easting DLS Section (usff) r) (9 (ustt) (MR) (waft) (usft) (ft) (ft) (')1004) (R) Survey Tool Name 4,017.00 73.38 111.51 2,660.35 2,567.56 567.70 2,210.95 5,979,829.48 551,785.83 0.19 1,668.26 MWD+IFR2+HDS+MS (4) 4,047.00 73.44 111.43 2,668.91 2,576.12 -978.22 2,237.71 5,979,819.14 551,812.66 0.32 1,688.90 MWD+1FR2+HDS+MS(4) 4,077.00 73.29 111.32 2,677.50 2,584.71 -988.70 2,264.48 5,979,806.84 551,839.49 0.61 1,709.58 MWD+IFR2+HDS+MS(4) 4,107.00 73.46 111.22 2,686.08 2,593.29 -999.12 2,291.26 5,979,798.59 551,866.34 0.65 1,730.29 MWD+IFR2+HDS+MS(4) 4,137.00 73.64 111.16 2,694.58 2,601.79 -1,009.52 2,318.09 5,979,788.37 551,893.24 0.63 1,751.05 MWD+IFR2+HDS+MS(4) 4,167.00 73.40 111.13 2,703.09 2,610.30 -1,019.90 2,344.92 5,979,778.17 551,920.13 0.81 1,771.82 MWD+IFR2+HDS+MS (4) 4,197.0 73.50 111.07 2,711.64 2,618.85 -1,030.25 2,371.75 5,979,767.99 551,947.03 0.38 1,792.60 MWD+IFR2+HDS+MS(4) 4,227.0 73.61 110.94 2,720.13 2,627.34 -1,040.57 2,398.61 5,979,757.86 551,973.95 0.55 1,813.42 MWD+IFR2+HDS+MS(4) 4,257.00 73.43 110.75 2,728.64 2,635.85 -1,050.80 2,425.50 5,979,747.80 552,000.90 0.85 1,834.29 MWD+IFR2+HDS+MS(4) 4,287.00 73.30 110.55 2,737.23 2644.44 -1,060.94 2,452.39 5,979,737.84 552,027.86 0.75 1,855.22 MWD+IFR2+HDS+MS(4) 4,317.0 73.34 110.39 2,745.84 2,653.05 -1,071.00 2,479.32 5,979,727.97 552,054.85 0.56 1,876.20 MWD+IFR2+HDS+MS(4) 4,347.00 73.38 110.23 2,754.43 2,661.64 -1,080.97 2,506.27 5,979,718.17 552,081.87 0.53 1,897.24 MWD+IFR2+HDS+MS(4) 4,377.00 73.48 110.07 2,762.98 2,670.19 -1,090.88 2,533.27 5,979,706.45 552,108.92 0.61 1,918.34 MWD+IFR2+HDS+MS(4) 4,407.0 73.40 110.10 2,771.53 2,678.74 -1,100.75 2,560.27 5,979,698.75 552,135.99 0.28 1,939.47 MWD+IFR2+HDS+MS(4) 4,437.0 73.36 110.34 2,760.12 2,687.33 -1,110.69 2,587.25 5,979,688.99 552,163.03 0.78 1,960.54 MWD+IFR2+HDS+MS(4) 4,467.00 73.15 110.60 2,788.76 2,695.97 -1,120.73 2,614.16 5,979,679.13 552,190.01 1.09 1,981.51 MWD+IFR2+HDS+MS(4) 4,497.00 73.16 110.83 2,797.45 2,704.66 -1,130.89 2,641.02 5,979,659.15 552.216.93 0.73 2,002.39 MWD+IFR2+HDS+MS(4) 4,527.00 73.31 111.00 2,806.11 2,713.32 -1,141.14 2,667.85 5,979,659.07 552,243.82 0.74 2,023.21 MWD+IFR2+HDS+MS(4) 4,557.00 73.32 111.16 2,814.72 2,721.93 -1,151.48 2,694.66 5,979,648.92 552,270.70 0.51 2,043.98 MWD+IFR2+HDS+MS(4) 4,587.00 73.28 111.36 2,823.34 2,730.55 -1,161.90 2,721.44 5,979,638.68 552,297.55 0.65 2,064.69 MWD+IFR2+HDS+MS(4) 4,617.00 73.39 111.62 2,831.94 2,739.15 -1,172.43 2,748.19 5,979,628.33 552,324.36 0.91 2,085.32 MWD+IFR2+HDS+MS (4) 4,647.00 73.46 111.91 2,840.50 2,747.71 -1,183.09 2,774.69 5,979,617.84 552,351.13 0.96 2,105.87 MWD+IFR2+HDS+MS(4) 4,677.00 73.31 112.19 2,849.08 2,756.29 -1,193.88 2.801.53 5,979,607.23 552,377.69 1.02 2,126.30 MWD+IFR2+HDS+MS(4) 4,707.00 73.35 112.45 2,857.69 2,764.90 -1,204.80 2,828.12 5,979,596.49 552,404.50 0.84 2,146.64 MWD+IFR2+HDS+MS(4) 4,737.00 73.29 112.71 2,866.30 2,773.51 -1,215.83 2,854.65 5,979,585.63 552,431.10 0.85 2,166.89 MWD+IFR2+HDS+MS(4) 4,767.00 73.33 112.96 2,874.91 2,782.12 -1,226.98 2,881.14 5,979,574.66 552,457.65 0.81 2,187.04 MWD+IFR2+HDS+MS(4) 4,797.0 73.32 113.14 2,883.52 2,790.73 -1,238.24 2,907.58 5,979,563.58 552,484.17 0.58 2,207.12 MWD+IFR2+HDS+MS(4) 4,827.00 73.33 113.28 2,892.13 2,799.34 -1,249.56 2,934.00 5,979,552.43 552,510.65 0.45 2,227.14 MWD+IFR2+HDS+MS(4) 4,857.00 73.26 113.40 2,900.75 2,807.96 -1,260.95 2,960.38 5,979,541.22 552,537.11 0.45 2,247.11 MWD+IFR2+HDS+MS(4) 4,887.00 73.23 113.39 2,909.40 2,816.61 -1,272.35 2,986.74 5,979,529.99 552,553.55 0.10 2,267.05 MWD+IFR2+HDS+MS(4) 4,917.00 73.23 113.26 2,918.06 2,825.27 -1,283.72 3,013.12 5,979,518.80 552,590.00 0.41 2,287.02 MWD+IFR2+HDS+MS(4) 4,947.00 73.08 113.12 2,926.75 2,833.96 -1,295.03 3,039.51 5,979,507.67 552,616.46 0.67 2,307.03 MWD+IFR2+HDS+MS(4) 4,977.00 73.13 113.01 2,935.47 2,842.68 -1,306.28 3,065.92 5,979,496.60 552,642.94 0.39 2,327.08 MWD+IFR2+HDS+MS (4) 5,007.00 73.36 112.94 2,944.12 2,851.33 -1,317.49 3,092.37 5,979,485.56 552,669.46 0.80 2,347.17 MWD+IFR2+HDS+MS(4) 5,037.00 73.47 112.87 2,952.68 2,859.89 -1,328.68 3,118.86 5,979,474.55 552,696.02 0.43 2,367.31 MWD+IFR2+HDS+MS(4) 5,067.0 73.63 112.70 2,961.17 2,868.38 -1,339.82 3,145.38 5,979,463.58 552,722.61 0.76 2,387.51 MWD+IFR2+HDS+MS (4) 5,097.00 73.67 112.35 2,969.62 2,876.83 -1,350.85 3,171.97 5,979,452.73 552,749.27 1.13 2,407.80 MWD+IFR2+HDS+MS (4) 5,127.00 73.61 111.98 2,978.07 2,885.28 -1,36171 3,198.63 5,979,442.D5 552,776.00 1.20 2,428.23 MWD+IFR2+HDS+MS(4) 5,157.0 73.70 111.71 2,966.51 2,893.72 -1,372.42 3,225.35 5,979,431.51 552,802.79 0.91 2,448.77 MWD+IFR2+HDS+MS(4) 5,187.00 73.65 111.73 2,994.95 2,902.16 -1,383.08 3,252.10 5,979,421.04 552,829.60 0.18 2,469.36 MM+IFR2+HDS+MS (4) 9H212018 7:15:58AM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1H-104 Project: Kuparuk River Unit TVD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Well: Rig: 1H-104 North Reference: True Wellbore: 1 H-1041-1 Survey Calculation Method: Minimum Curvature Design: 1H-1041.1 Database: OAKEDMP2 Survey 911212018 7:15:58AM Page 6 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (waft) r) r) Wait) (usR) (ust) (-ft) (ft) (it) (111001 (it) Survey Tool Name 5,217.00 73.57 111.84 3,003.41 2,910.62 -1,393.76 3,278.82 5,979,410.53 552,856.40 0.44 2,489.91 MND+IFR2+HDS+MS (4) 5,247.00 73.62 111.97 3,011.88 2,919.09 -1,404.49 3,305.52 5,979,399.98 552,883.16 0.45 2,510.43 MWD+IFR2+HDS+MS(4) 5,277.00 73.66 112.22 3,020.33 2,927.54 -1,415.32 3,332.20 5,979,389.33 552,909.90 0.81 2,530.88 MWD+IFR2+HDS+MS(4) 5,307.00 73.70 112.52 3,028.76 2,935.97 -1,426.28 3,358.82 5,979,378.55 552,936.60 0.97 2,551.23 MWD+IFR2+HDS+MS(4) 5,337.00 73.62 112.80 3,037.20 2,944.41 -1,437.37 3,385.39 5,979,367.63 552,963.23 0.93 2,571.48 MWD+IFR2+HDS+MS(4) 5,367.00 73.58 112.90 3,045.67 2,952.88 -1,448.55 3,411.91 5,979,356.63 552,989.83 0.35 2,591.66 MWD+IFR2+HDS+MS(4) 5,397.00 73.67 112.87 3,054.13 2,961.34 -1,459.74 3,438.42 5,979,345.62 553,016.41 0.31 2,611.83 MWD+IFR2+HDS+MS(4) 5,427.00 73.71 112.86 3,062.56 2,969.77 -1,470.93 3,464.95 5,979,334.61 553,043.02 0.14 2,632.01 MWD+IFR2+HDS+MS(4) 5,457.00 73.77 112.99 3,070.96 2,978.17 -1,482.15 3,0.91 48 5,979,323.56 553,069.61 0.46 2,652.18 MND+IFR2+HDS+MS (4) 5,487.00 73.86 113.23 3,079.32 2,986.53 -1,493.45 3,517.98 5,979,312.43 553,096.18 0.82 2,672.28 MWD+IFR2+HDS+MS(4) 5,517.0 73.71 113.48 3,087.70 2,994.91 -1,504.87 3,544.43 5,979,301.19 553,122.70 0.94 2,692.30 MWD+IFR2+HDS+MS(4) 5,547.00 73.70 113.64 3,096.11 3,003.32 -1,516.38 3,570.82 5,979,289.86 553,149.17 0.51 2,712.23 MWD+IFR2+HDS+MS(4) 5,577.0 73.63 113.67 3,104.55 3,01176 -1,527.93 3,597.19 5,979,278.48 553175.61 0.25 2,732.12 MND+IFR2+HDS+MS(4) 5,607.00 73.62 113.69 3,113.01 3,020.22 -1,539.49 3,623.55 5,979,267.10 553,202.05 0.07 2,752.00 MWD+IFR2+HDS+MS(4) 5,637.0 73.73 113.82 3,121.44 3,028.65 -1,551.09 3549.90 5,979,255.67 553,228.47 0.55 2,771.86 MWD+IFR2+HDS+MS(4) 5,667.00 73.82 114.13 3,129.82 3,037.03 -1,562.80 3,676.22 5,979,244.15 553,254.86 1.04 2,791.65 MWD+IFR2+HDS+MS(4) 5,697.0 73.79 114.48 3,138.19 3,045.40 -1,574.65 3,702.48 5,979,232.46 553,281.20 1.12 2,811.32 MWD+IFR2+HDS+MS (4) 5,727.00 73.78 114.83 3,146.57 3,053.78 -1,586.67 3,728.66 5,979,220.62 553,307.45 1.12 2,830.86 MWD+IFR2+HDS+MS(4) 5,757.00 73.82 115.15 3,154.94 3,062.15 -1,598.84 3,754.77 5,979,208.62 553,333.64 1.03 2,850.28 MWD+IFR2+HDS+MS(4) 5,787.00 73.84 115.46 3,163.29 3,070.50 -1,611.16 3,780.82 5,979,196.48 553,359.77 0.99 2,869.58 MWD+IFR2+HDS+MS(4) 5,817.0 73.89 115.74 3,171.63 3,078.84 -1,623.61 3,806.81 5,979,184.20 553,385.84 0.91 2,888.T7 MWD+IFR2+HDS+MS(4) 5,847.00 73.90 115.90 3,179.95 3,087.16 -1,636.16 3,832.75 5,979,171.82 553,411.86 0.51 2,907.89 MWD+IFR2+HDS+MS(4) 5,877.00 73.69 115.99 3,188.32 3,095.53 -1,648.T/ 3458.66 5,979,159.39 553,437.85 0.76 2,926.95 MWD+IFR2+HDS+MS(4) 5,907.00 73.80 116.07 3,196.72 3,103.93 -1,661.41 3,889.54 5,979,146.93 553,463.81 0.45 2,945.97 MWD+IFR2+HDS+MS(4) 5,937.00 73.88 116.06 3,205.07 3,112.28 -1,674.07 3,910.42 5,979,134.44 553,489.77 0.27 2,964.99 MWD+IFR2+HDS+MS(4) 5,987.00 73.96 115.97 3,213.38 3,120.59 -1,686.71 3,936.33 5,979,121.97 553,515.76 0.39 2,984.03 MWD+IFR2+HDS+MS(4) 5,997.00 73.82 115.88 3,221.70 3,128.91 -1,699.31 3,962.25 5,979,109.54 553,541.76 0.55 3,003.11 MWD+IFR2+HDS+MS(4) 6,027.00 73.67 115.68 3,230.10 3,137.31 -1,711.84 3,988.18 5,979,097.19 553,567.77 0.81 3,022.23 MWD+IFR2+HDS+MS(4) 6,057.00 73.44 115.36 3,238.60 3,145.81 -1,724.23 4,014.15 5,979,084.96 553,593.82 1.28 3,041.42 MWD+IFR2+HDS+MS (4) 6,087.00 73.19 115.04 3,247.21 3,154.42 -1,736.47 4,04045 5,979,072.90 553,619.90 1.32 3,060]1 MND+IFR2+HDS+MS (4) 6,117.00 73.23 114.70 3,255.87 3,163.08 -1,748.55 4,066.21 5,979,061.00 553,646.03 1.09 3,080.11 MND+IFR2+HDS+MS(4) 6,147.00 73.45 114.35 3,264.48 3,171.69 -1,760.48 4,092.35 5,979,049.24 553,672.26 1.34 3,099.66 MWD+IFR2+HDS+MS(4) 6,177.00 73.40 113.99 3,273.03 3,180.24 -1,772.25 4,118.59 5,979,037.64 553,698.56 1.16 3,119.34 MWD+IFR2+HDS+MS(4) 6,207.00 73.38 113.64 3,281.61 3,188.82 -1,783.86 4,144.89 5,979,026.21 553,724.94 1.12 3,139.15 MWD+IFR2+HDS+MS(4) 6,237.00 73.48 113.30 3,290.16 3,197.37 -1,795.31 4,171.26 5,979,014.94 553,751.38 1.14 3,159.08 MWD+IFR2+HDS+MS(4) 6,267.00 73.36 112.96 3,298.73 3,205.94 -1,806.60 4,197.70 5,979,003.82 553,777.90 1.16 3,179.14 MWD+IFR2+HDS+MS(4) 6,297.W 73.24 112.60 3,307.35 3,214.56 -1,817.73 4,224.20 5,978,992.67 553,804.46 1.22 3,199.31 MWD+IFR2+HDS+MS(4) 6,327.00 73.34 112.17 3,315.97 3,223.18 -1,828.67 4,250.76 5,978,982.10 553,831.10 1.41 3,219.62 MWD+IFR2+HDS+MS(4) 6,357.0 73.44 111.72 3,324.55 3,231.76 -1,839.42 4,277.43 5,978,971.54 553,857.83 1.48 3,240.10 MND+IFR2+HDS+MS (4) 6,387.00 73.36 111.33 3,333.12 3,240.33 -1,849.97 4,304.17 5,978,961.17 553,884.64 1.27 3,260.72 MWD+IFR2+HDS+MS(4) 911212018 7:15:58AM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 1 H-104 Project Kupamk River Unit TVD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Sfte: Kuparuk 1 H Pad MD Reference: 11-1-104 actual @ 92.79usft (Doyon 142) Well: Rig: 1H-104 North Reference: True WeRbom: 1 H-1041-1 Survey Calculation Method: Minimum Curvature Design: 1 H-1041-1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Aid TVD TVDSS +N14 +El -W Northing Easting OLS Section (usft) (*) P) (usft) (usft) (uaft) (usft) (ft) (ft) I.1100') (ft) Survey Tool Name 6,417.00 73.27 111.27 3,341.73 3,248.94 -1,860.40 4,330.95 5,978,950.91 553,911.48 0.36 3,28142 MWD+IFR2+HDS+MS(4) 6,447.00 73.44 111.41 3,350.32 3,257.53 -1,870.86 4,357.72 5,978,940.63 553,938.32 0.72 3,302.10 MWD+IFR2+HDS+MS(4) 6,477.00 73.38 111.55 3,358.89 3,266.10 -1,881.39 4,384.47 5,978,930.28 553,965.14 0.49 3,322.75 MWD+IFR2+HDS+MS(4) 6,507.00 71,12 111.56 3,357.46 3,274.67 -1,891.95 4,411.21 5,978,919.89 553,991.95 0.14 3,343.36 MWD+IFR2+HDS+MS(4) 6,537.00 73.47 111.48 3,376.01 3,283.22 -1,902.50 4,437.97 5,978,909.52 554,018.77 0.31 3,363.99 MWD+IFR2+HDS+MS(4) 6,567.00 73.40 111.40 3,384.56 3,291.77 -1,913.01 4,464.73 5,978,899.19 554,045.60 0.35 3,389.65 MW3+IFR2+HDS+MS(4) 6,597.00 73.61 111.25 3,393.08 3,300.29 -1,923.47 4,49153 5,978,888.91 554,072.46 0.85 3,405.36 MWD+IFR2+HDS+MS(4) 6,627.00 73.57 111.04 3,401.56 3,308.77 -1,933.85 4,518.37 5,978,878.70 554,099.37 0.68 3,426.14 MWD+IFR2+HDS+MS(4) 6,657.00 73.54 110.82 3,410.05 3,317.26 -1,944.13 4,545.24 5,978,868.61 554,126.30 0.71 3,446.98 MM+IFR2+HDS+MS(4) 6,687.03 73.62 110.66 3,418.53 3,325.74 -1,954.32 4,572.15 5,978,858.59 554,153.28 0.58 3,467.90 MWD+IFR2+HDS+MS(4) 6,717.00 73.61 110.58 3,426.99 3,334.20 -1,964.46 4,599.09 5,978,648.64 554,180.28 0.26 3,488.86 MWD+IFR2+HDS+MS(4) 6,747.00 73.57 110.52 3,435.47 3,342.68 -1,974.56 4,626.4 5,978,83812 554,207.29 0.23 3,509.85 MWD+IFR2+HDS+MS(4) 6,777.00 73.57 110.35 3,443.95 3,351.16 -1,984.61 4,653.00 5,978,828.85 554,234.32 0.54 3,530.87 MWD+IFR2+HDS+MS(4) 6,807.00 73.63 109.97 3,452.42 3,359.63 -1,994.53 4,680.02 5,978,819.11 554,261.40 1.23 3,551.99 MND+IFR2+HDS+MS (41 6,837.0 73.54 109.54 3,460.90 3,368.11 -2,004.25 4,707.10 5,978,809.56 554,288.54 1.41 3,573.24 MWD+IFR2+HDS+MS(4) 6,867.00 73.49 197.18 3,469.41 3,376.62 -2,013.79 4,734.24 5,97eWD.21 554,31514 1.16 3,594.62 MWD+IFR2+HDS+MS(4) 6,897.00 73.38 109.08 3,477.97 3,385.18 -2,()23.21 4,761.41 5,978,790.97 554,342.97 0.49 3,616.07 MWD+IFR2+HDS+MS(4) 6,927.00 73.48 109.07 3,486.52 3,393.73 -2,032.61 4,788.58 5,978,781.75 554,370.20 0.33 3,637.53 MWD+IFR2+HDS+MS (4) 6,957.00 73.67 109.09 3,495.00 3,402.21 -2,D42.02 4,815.78 5,978,772.52 554,397.46 0.64 3,659.01 MND+IFR2+HDS+MS (4) 6,987.00 73.69 109.24 3,503.43 3,410.64 -2,051.47 4,842.97 5,978,763.25 554,424.71 0.48 3,680.48 MWD+IFR2+HDS+MS(4) 7,017.0 73.62 109.47 3,511.88 3,419.09 -2,()61.01 4,870.13 5,978,753.09 554,451.93 0.77 3,701.88 MWD+IFR2+HDS+MS(4) 7,047.0(1 73.63 109.69 3,520.33 3,427.54 -2,070.65 4,897.25 5,978,744.43 55,479.11 0.70 3,723.19 MWD+IFR2+HDS+MS(4) 7,077.0 73.67 109.89 3,528.78 3,435.99 -2,080.40 4,924.34 5,978,734.86 554,506.26 0.65 3,744.44 MWD+IFR2+HDS+MS (4) 7,107.00 73.57 110.08 3,53T.24 3,444.45 -2,090.24 4,951.39 5,978,725.20 554,533.37 0.69 3,765.62 MWD+IFR2+HDS+MS(4) 7,137.00 73.62 110.25 3,545.71 3,452.92 -2,100.16 4,97840 5,978,715.46 554,560.45 0.57 3,786.74 MWD+IFR2+HDS+MS(4) 7,167.00 73.65 110.29 3,554.17 3,461.36 -2,110.13 5,005.41 5,978,705.67 55,587.51 0.16 3,807.82 MWD+IFR2+HDS+MS(4) 7,197.0 73.60 110.17 3,562.62 3,469.83 -2,120.8 5,032.41 5,978,695.90 554,614.58 0.42 3,828.92 MWD+IFR2+HDS+MS(4) 7,227.00 73.84 110.D4 3,571.03 3,478.24 -2,129.98 5,059.45 5,978,686.18 554,641.69 0.90 3,850.D7 MWD+IFR2+HDS+MS(4) 7,25200 74.75 109.63 3,579.15 3,486.36 -2,139.78 5,086.62 5,978,676.56 554,668.91 3.31 3,871.37 MWD+IFR2+HDS+MS(4) 7,287.0 75.63 108.83 3,586.82 3,494.03 -2,149.33 5,114.01 5,978,667.19 554,696.36 3.91 3,892.97 MWD+IFR2+HDS+MS(4) 7,317.00 76.06 107.97 3,594.15 3,501.36 -2,158.52 5,141.61 5,978,658.19 554,724.02 3.16 3,914.92 MND+IFR2+HDS+MS(4) 7,347.00 76.14 107.16 3,601.36 3,508.57 -2,167.30 5,169.37 5,978,649.59 554,751.84 2.63 3,937.16 MWD+IFR2+HDS+MS(4) 7,377.00 76.04 106.47 3,608.57 3,515.78 -2,175.73 5,197.25 5,978,641.35 551.779.77 2.26 3,959.65 MWD+IFR2+HDS+MS(4) 7,40200 75.64 105.80 3,615.91 3,523.12 -2,183.81 5,225.19 5,978,633.45 55,807.76 2.54 3,982.33 MWD+IFR2+HDS+MS(4) 7,437.0 75.00 105.03 3,623.51 3,53D.72 -2,191.53 5,253.17 5,978,625.93 554,835.78 3.27 4,005.18 MWD+IFR2+HDS+MS(4) 7,467.00 74.49 103.91 3,631.40 3,538.61 -2,198.76 5,281.19 5,978,618.88 554,863.85 3.98 4,028.26 MWD+IFR2+HDS+MS(4) 7,497.0 74.59 102.64 3,639.40 3,546.61 -2,205.40 5,309.33 5,978,612.43 554,892.03 4.09 4,051.68 MWD+IFR2+HDS+MS(4) 7,527.00 75.07 101.38 3,647.25 3,554.46 -2,211.42 5,337.65 5,978,606.59 554,920.39 4.36 4,075.50 MWD+IFR2+HDS+MS(4) 7,55200 75.66 100.36 3,654.83 3,562.04 -2,21690 5,366.16 5,978,601.31 554,948.93 3.83 4,099.70 MWD+IFR2+HDS+MS(4) 7,587.0 76.67 99.52 3,662.00 3,569.21 -2,221.92 5,394.85 5,978,596.47 554,977.65 4.33 4,124.25 MWD+IFR2+HDS+MS(4) 9/122018 7:15:58AM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1 H-104 Project: Kupamk River Unit TVD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1H-104 actual @ 92.79usR (Doyon 142) Well: Rig: 1H-104 North Reference: True Wellbore: 1 H -1 04L1 Survey Calculation Method: Minimum Curvature Design: 1 H -1 04L1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc AN TVD TVDSS +N/4 +EI -W Northing Easting DLS Section W) P) (1) NO* (MR) (uaR) (usft) (R) (ft) (9100') (ft) Survey Tool Name 7,617.00 77.66 98.72 3,668.67 3,575.88 -2,226.56 5,423.73 5,978,592.03 555,006.56 4.20 4,149.12 MWDAFR2+HOS+MS(4) 7,647.00 77.74 97.57 3,675.06 3,582.27 -2,230.71 5,452.75 5,978,588.07 555,035.60 3.75 4,174.31 MWD+IFR2+HDS+MS(4) 7,677.00 76.97 96.18 3,681.63 3,588.84 -2,234.22 5,481.81 5,978,584.75 555,064.66 5.20 4,199.78 MWD+IFR2+HDS+MS(4) 7,707.00 76.42 95.01 3,688.53 3,595.74 -2,237.06 5,510.86 5,978,582.10 555,093.75 4.21 4,225.50 MWD+IFR2+HDS+MS(4) 7,737.0 76.21 93.80 3,695.63 3,602.84 -2,239.30 5,539.92 5,978,580.05 555,122.82 3.98 4,251.46 MWD+1FR2+HDS+MS(4) 7,767.00 76.15 92.39 3,702.80 3,610.01 -2,240.88 5,569.01 5,978,578.67 555,151.92 4.57 4,277.71 MWD+IFR2+HDS+MS(4) 7,797.00 76.26 90.92 3,709.95 3,617.16 -2,241.72 5,598.13 5,978,578.02 555,181.04 4.77 4,304.26 MM+IFR2+HDS+MS(4) 7,827.00 76.47 89.20 3,717.02 3,624.23 -2,241.75 5,627.29 5,978,578.19 555,210.19 5.62 4,331.16 MWD+IFR2+HDS+MS(4) 7,857,00 76.61 87.30 3,724.01 3631.22 -2,240.86 5,656.45 5,978,579.27 555,239.34 6.18 4,358.41 MWD+IFR2+HDS+MS(4) 7,887.00 76.83 85.81 3,730.90 3,638.11 -2,239.10 5,685.59 5,978,581.22 555,268.47 4.89 4,385.99 MWD+IFR2+HDS+MS(4) 7,917.00 77.40 84.41 3,737.59 3,644.80 -2,236.61 5,714.73 5,978,583.90 555,297.59 4.93 4,413.84 MWD+IFR2+HDS+MS(4) 7,947.00 78.05 82.74 3,743.97 3,651.18 -2,233.33 5,743.86 5,978,587.38 555,326.69 5.86 4,441.99 MWD+IFR2+HDS+MS(4) 7,977.00 78.51 81.08 3,750.06 3,657.27 -2,229.19 5,772.94 5,978,591.70 555,355.74 5.63 4,470.42 MWD+IFR2+HDS+MS(4) B,W7.W 78.91 79.43 3,755.93 3,663.14 -2,224.21 5,801.93 5,978,596.87 555,364.70 5.56 4,499.10 MWD+IFR2+HDS+MS(4) 8,037.00 79.38 78.49 3,761.58 3,668.79 -2,218.57 5,83D.85 5,976,602.71 555,413.58 3.45 4,52796 MWD+IFR2+HDS+MS (4) 8,067.00 79.62 77.91 3,767.05 3,674.26 -2,212.54 5,859.72 5,978,608.93 555,442.41 2.06 4,556.93 MWD+IFR2+HDS+MS(4) 8,097.00 79.44 77.39 3,772.50 3,679.71 -2,206.23 5,888.54 5,978,615.43 555,471.18 1.81 4,585.96 MWD+IFR2+HDS+MS(4) 8,127.00 79.47 77.20 3,777.99 3,685.20 -2,199.74 5,917.31 5,978,622.11 555,499.90 0.63 4,615.01 MWD+IFR2+HDS+MS (4) 8,157.00 79.34 77.19 3,783.51 3,690.72 -2,193.21 5,946.07 5,978,628.83 555,528.61 0.43 4,644.07 MWD+IFR2+HDS+MS(4) 8,187.0 79.61 77.17 3,788.99 3,696.20 -2,186.66 5,974.83 5,978,635.56 555,557.32 0.90 4,673.13 MWD+IFR2+HDS+MS(4) 8,217.00 79.72 76.98 3,794.37 3,701.58 -2,180.06 6,OD3.59 5,978,642.36 555,586.04 0.72 4,702.22 MWD+IFR2+HDS+MS(4) 8,247.00 78.95 76.67 3,799.92 3,707.13 -2,17334 6,032.30 5,978,649.26 555,614.70 2.76 4,731.30 MWD+IFR2+HDS+MS(4) 8,277.00 79.01 76.36 3,805.66 3,712.87 -2,166.48 6,060.93 5,978,656.32 555,643.29 1.03 4,760.37 MWD+IFR2+HDS+MS(4) 8,307.00 79.24 76.18 3,811.32 3,718.53 -2,159.48 6,089.55 5,978,663.50 555,671.86 0.97 4,789.48 MWD+IFR2+HDS+MS(4) 8,334.75 79.39 76.14 3,816.46 3,723.67 -2,152.96 6,116.03 5,978,670.20 555,698.29 0.56 4,816.43 MWD -INC _ONLY (5) 8,348.34 81.35 75.80 3,818.74 3,725.95 -2,149.71 6,129.03 5,978,673.53 555,711.26 14.63 4,829.67 MWD -INC -ONLY (5) B,443.02 88.15 74.85 3,827.39 3,734.60 -2,125.84 6,220.18 5,978,698.01 555,802.25 7.25 4,922.99 MWD -INC ONLY(5) 8,536+66 89.94 73.93 3,828.96 3,736.17 -2,1W.64 6,310.35 5,978,723.79 655,892.24 2.15 5,015.91 MWD+IFR2+HDS+MS(6) 8,566.00 89.50 74.33 3,829.10 3,736.31 -2,092.62 6,338.57 5,978,732.00 555,920.40 2.03 5,045.05 MWD+IFR2+HDS+MS(6) 8,596.00 88.96 74.75 3,829.50 3,736.71 -2,084.62 6,367.48 5,978,740.19 555,949.26 2.28 5,074.81 MWD+IFR2+HDS+MS (6) 8,626.00 88.54 75.12 3,830.16 3,737.37 -2,076.83 6,396.44 5,978,748.18 555,978.16 1.87 5,104.54 MWD+IFR2+HDS+MS(6) 8,656.00 88.02 74.92 3,831.6 3,736.27 -2,009.08 6,425.41 5,978,756.12 556,007.08 1.86 5,134.26 MWD+IFR2+HDS+MS(6) 8,686.00 87.43 74.95 3,832.25 3,739.46 -2,061.29 6,454.36 5,978,764.10 556,035.97 1.97 5,163.98 MWD+IFR2+HDS+MS(6) 8,716.W 86.94 75.23 3,833.72 3,740.93 -2,053.58 6,483.31 5,978,772.00 556,064.87 1.88 5,193.67 MWD+IFR2+HDS+MS(6) 8,746.W 86.85 75.36 3,835.35 3,742.55 -2,045.97 6,512.29 5,978,779.79 556,093.79 0.53 5,223.34 MWD+IFR2+HDS+MS(6) 8,776.W 86.84 75.41 3,837.00 3,744.21 -2,038.41 6,541.27 5,978,787.54 556,122.72 0.17 5,253.W MWD+IFR2+HDS+MS(6) 8,808.00 87.01 75.46 3,838.61 3,745.82 -2,030.88 6,570.27 5,978,795.27 556,151.66 0.59 5,282.66 MWD+IFR2+HDS+MS (6) 8,836.00 86.99 75.49 3,840.18 3,747.39 -2,023.37 6,599.27 5,978,802.97 556,180.61 0.12 5,312.32 MWD+IFR2+HDS+MS (6) 8,866.00 86.88 75.48 3,841.78 3,748.99 -2,015.86 6,628.27 5,978,810.67 556,209.56 0.37 5,341.98 MWD+IFR2+HDS+MS(6) 8,896.00 86.89 75.48 3,843.41 3,750.62 -2,008.35 6,657.27 5,978,816.37 556,238.50 0.03 5,371.63 MWD+IFR2+HDS+MS(6) 9H2/2018 7:15:58AM Page 8 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 11-1-104 Project• Kuparuk River Unit TVD Reference: 1H-104 actual @ 92.7gusft (Doyon 142) Sita: Kuparuk 1 H Pad MD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Well: Rig: iH-104 North Reference: True Wallbom: 1 H-1041.1 Survey Calculation Method: Minimum Curvature Design: 1 H-1041.1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Aid TVD TVDSS +NIS +EI -W Northing Easting OLS Section Wo (1) (1) (usfo (usR) (usft) Waft) (N) (it) (°/1001 (It) Survey Tool Name 8.926.00 86.92 75.47 3,845.03 3,752.24 -2,000.84 6,686.27 5,978,826.08 556,267.45 0.11 5,401.29 MND+IFR2+HDS+MS (6) 8,956.00 87.11 75.47 3,846.59 3,753.80 -1,993.32 6,715.27 5,978,833.78 556,296.40 0.63 5,430.95 MND+IFR2+HDS+MS (6) 8,986.00 87.28 75.46 3,848.06 3,755.27 -1,985.80 6,744.27 5,978,841.50 556,325.35 0.57 5,460.61 MND+IFR2+HDS+MS (6) 9,016.00 87.27 75.39 3,849.49 3,756.70 -1,978.26 6,773.27 5,978,849.23 556,354.30 0.24 5,490.28 MWD+IFR2+HDS+MS(6) 9,046.00 87.53 75.11 3,850.85 3,758.06 -1,970.63 6,802.25 5,978,857.05 556,383.22 1.27 5,519.97 MWO+IFR2+HDS+MS(6) 9,076.00 87.86 74.83 3,852.05 3,759.26 -1,962.85 6,831.20 5,978,865.01 556412.12 1.44 5,549.68 MWD+IFR2+HDS+MS (6) 9,106.00 87.91 74.52 3,853.16 3,760.37 -1,954.93 6,860.12 5,978,873.13 556,440.98 1.05 5,579.42 MND+IFR2+HDS+MS (6) 9,136.00 87.94 74.11 3,854.25 3,761.46 -1,946.83 6,888.98 5,978,881.42 556,469.78 1.37 5,609.18 MWD+IFR2+HDS+MS(6) 9,166.00 87.89 73.69 3,855.34 3,762.55 -1,938.51 6,917.79 5,978,889.93 556,498.53 1.41 5,638.96 MND+IFR2+HDS+MS(6) 9,1%.0 87.26 73.23 3,856.61 3,763.82 -1,929.98 6,946.52 5,978,898.65 556,527.20 2.60 5,668.77 MWD+IFR2+HDS+MS(6) 9,226.00 86.97 72.50 3,858.12 3,765.33 -1,921.15 6,975.15 5,978,907.66 556,555.77 2.62 5,698.59 MWD+IFR2+HDS+MS(6) 9,256.0 85.73 71.69 3,859.77 3,766.98 -1,911.94 7,003.65 5,978,917.06 556584.21 2.81 5,728.44 MWD+IFR2+HDS+MS (6) 9,286.00 86.90 70.88 3,861.43 3,768.64 -1,902.33 7,032.02 5,978,926.86 556,612.51 2.75 5,758.33 MWD+IFR2+HDS+MS(6) 9,316.00 86.93 70.25 3,86305 3,770.26 -1,892.36 7,060.27 5,978,937.01 556,640.69 2.10 5,788.24 MWD+IFR2+HDS+MS(6) 9,346.00 86.87 69.70 3,864.67 3,771.88 -1,882.11 7,088.42 5,978,947.45 556,668.77 1.84 5,818.16 MWD+1FR2+HDS+M6(6) 9,376.00 86.36 69.15 3,866.44 3,773.65 -1,871.58 7,116.46 5,978,958.16 556,696.73 2.50 5,848.09 MWD+IFR2+HDS+MS 16) 9,406.00 86.19 68.73 3,868.39 3,775.60 -1,860.82 7,144.39 5,978,969.10 556,724.60 1.51 5,878.01 MW13+IFR2+HDS+MS(6) 9,436.00 86.54 68.42 3,870.29 3,777.50 -1,849.89 7,172.26 5,978,980.22 556,752.39 1.56 6907.95 MWD+IFR2+HDS+MS(6) 9,466.00 86.32 68.10 3,872.16 3,779.37 -1,838.80 7,200.08 5,978,991.50 556.780.13 1.29 6937.88 MWD+IFR2+HDS+MS(6) 9,496.00 86.43 67.92 3,874.06 3,781.27 -1,827.59 7,227.84 5,979,002.89 556,807.81 0.70 5,967.82 MWD+IFR2+HDS+MS(6) 9,526.00 87.06 67.94 3,875.76 3,782.97 -1,816.33 7,255.59 5,979,014.33 556,835.49 2.10 5,997.77 MWD+IFR2+HDS+MS(6) 9,556.00 87.80 67.96 3,877.11 3,784.32 -1,805.08 7,283.37 5,979,025.76 556,863.19 2.47 6,027.74 MWD+IFR2+HDS+MS(6) 9,586.00 89.17 67.95 3,877.90 3,785.11 -1,793.83 7,311.17 5,979,037.20 556,890.91 4.57 6,057.73 MWD+IFR2+HDS+MS(6) 9,616.00 89.39 67.87 3,878.28 3,785.49 -1,782.54 7,338.96 5,979,04B.W 556,918.62 0.78 6,087.72 MWD+IFR2+HDS+MS(6) 9,646.00 89.37 67]8 3,878.60 3,785.81 -1,771.22 7,366.74 5,979,060.17 556,996.33 0.31 6,117.72 MWD+IFR2+HDS+MS(6) 9,676.00 89.33 67.66 3,878.94 3,786.15 -1,759.85 7,394.50 5,979,071.72 556,974.01 0.42 6,147.72 MWD+IFR2+HDS+MS(6) 9,706.00 89.32 67.35 3,879.30 3,786.51 -1,748.37 7,422.22 5,979,083.38 557,001.64 1.03 6,177.72 MWD+IFR2+HDS+MS(6) 9,736.00 89.06 67.01 3,879.72 3,786.93 -1,736.74 7,449.87 5,979,095.20 557,029.21 1.43 6,207.71 MWD+IFR2+HDS+MS(6) 9,766.00 88.43 66.64 3,880.38 3,787.59 -1,724.93 7,477.44 5,979,107.18 557,056.70 2.44 6,237.70 MWD+IFR2+HDS+MS(6) 9,796.00 88.01 65.88 3,881.31 3,788.52 -1,712.86 7,504.89 5,979,119.43 557,084.07 2.89 6,267.68 MWD+IFR2+HDS+MS(6) 9,826.00 88.27 65.01 3,B82.28 3,789.49 -1,700.40 7,532.16 5,979,132.07 557,111.25 3.03 6,297.65 MWD+IFR2+HDS+MS(6) 9,856.00 88.30 64.14 3,883.18 3,790.39 -1,687.53 7,559.24 5,979,145.12 557,138.25 2.90 6,327.60 MWD+IFR2+HDS+MS(6) 9,886.00 88.36 63.42 3,884.05 3,791.26 -1,674.28 7,586.14 5,979,158.55 557,165.06 2.41 6,357.53 MWD+IFR2+HDS+MS(6) 9,916.00 88.09 62.78 3,884.98 3,792.19 -1.660.71 7,612.88 5,979,172.29 557,191.71 2.31 6,387.43 MWD+IFR2+HDS+MS(6) 9,946.0 80.22 62.13 3,885.95 3,793.16 -1,646.85 7,639.47 5,979,186.33 557218.20 2.21 6,417.31 MWD+IFR2+HDS+MS(6) 9,976.00 88.19 61.22 3,866.89 3,794.10 -1,632.62 7,665.86 5,979,200.73 557,244.49 3.03 6,447.14 MWD+IFR2+HDS+MS (6) 10,006.00 87.87 60.08 3,887.92 3,795.13 -1,617.93 7,692.00 5,979,215.60 557,270.53 3.94 6,476.92 MWD+IFR2+HDS+MS(6) 10,036.00 88.86 58.94 3,888.78 3,795.99 -1,602.71 7,717.84 5,979,230.98 557296.26 5.03 6,506.63 MWD+IFR2+HDS+MS(6) 10,066.00 88.97 57.78 3,889.34 3,796.55 -1,586.98 7,743.37 5,979,246.88 557,321.69 3.88 6,538.25 MWD+IFR2+HDS+MS(6) 10,096.00 87.85 56.56 3,890.18 3,797.39 -1,570.72 7,768.57 5,979,263.31 557,346.78 5.52 6,565.76 MWD+IFR2+HDS+MS(6) 9/12/2018 7:15:58AM Page 9 COMPASS 5000.14 SUW 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1H-1 D4 project Kuparuk River Unit TVD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Well: Rig: 1H-104 North Reference: True Wellbore: 1H-1041-1 Survey Calculation Method: Minimum Curvature Design: 1H -104L7 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +W.S +E/ -W Northing Easeng DLS Section (USM (1) (') (usft) ("it) (usft) (-ft) (11) (ft) (.11001 (ft) Survey Tool Name 10,126.W 88.33 55.35 3,891.18 3,798.39 -1,553.93 7,793.41 5,979,280.25 557,371.51 4.34 6,595.15 MWD+IFR2+HDS+MS(6) 10,156.00 89.23 64.33 3,891.82 3,799.03 -1,536.66 7,817.93 5,979,297.69 557,395.91 4.53 6,62443 MWD+IFR2+HDS+MS(6) 10,186.00 8888 53.87 3,892.31 3,799.52 -1,519.07 7,842.23 5,979,315.43 557,42009 1.93 6,653.63 MWD+IFR2+HDS+MS(6) 10,216.00 88.50 53.45 3,893.W 3,800.21 -1,501.30 7,866.39 5,979,333.35 557,444.13 1.89 6,682.77 MWD+IFR2+HDS+MS(6) 10,246.00 BBA" 52.90 3,893.80 3,801.01 -1,483.32 7,890.40 5,979,351.49 557,468.01 1.84 6,711.94 MWD+IFR2+HDS+MS(6) 10,276.00 87.94 51.63 3,894.74 3,801.95 -1,469.97 7,914.11 5,979,370.00 557,491.60 4.55 6,740.79 MWD+IFR2+HDS+MS (6) 10,3W.00 86.95 50.28 3,896.08 3,803.29 -1,446.10 7,937.39 5,979,389.03 557,514.75 5.58 6,769.54 MWD+IFR2+HDS+MS(6) 10,336.00 86.23 48.98 3,897.87 3,806.08 -1,426.70 7,960.20 5,979,408.57 557,537.43 4.95 6,798.06 MWD+IFR2+111)S+MS (6) 10,366.00 86.39 48.14 3,899.80 3,807.01 -1,406.89 7,982.64 5,979,428.53 557,559.74 2.84 6,826.40 MWD+IFR2+HDS+MS(6) 10,396.00 86.78 47.45 3,901.58 3,808.79 -1,3%.77 8,004.83 5,979,498.80 557,581.79 2.64 6,854.62 MWD+IFR2+HDS+MS(6) 10,426.00 86.83 46.85 3,903.26 3,810.47 -1,366.40 8,026.79 5,979,469.31 557,603.61 2.00 6,882.72 MWD+IFR2+HDS+MS(6) 10,456.0 86.89 45.92 3,904.90 3,812.11 .1,345.73 8048.47 5,979,490.11 557,625.16 3.10 6,910.69 MWD+IFR2+HDS+MS(6) 10,486.00 86.96 44.84 3,906.51 3,813.72 -1,324.69 8,069.80 5,979,511.29 557,646.34 3.60 6,938.47 MWD+IFR2+HDS+MS(6) 10,516.W 87.43 43.75 3,907.98 3,815.19 -1,303.25 8,090.72 5,979,532.88 557,667.12 3.95 6,966.04 MWD+IFR2+HDS+MS(6) 10,546.00 87.31 42.70 3,909.35 3,816.56 -1,281.41 8,111.24 5,979,554.85 557,68250 3.52 6,993.38 MWD+IFR2+HDS+MS(6) 10,576.W 87.13 41.67 3,910.81 3,818.02 -1,259.21 8,131.37 5,979,577.18 557,707.47 3.48 7,020.50 MWD+IFR2+HDS+MS(6) 10,606.00 86.79 40.64 3,912.40 3,819.61 -1,236.65 8,151.08 5,979,599.86 557,727.03 3.61 7,047.38 MWD+IFR2+HDS+MS(6) 10,636.00 86.06 39.83 3,914.27 3,821.48 -1,213.79 8,170.42 5,979,622.85 557,746.22 3.63 7,074.02 MWD+IFR2+HDS+MS(6) 10,666.00 84.96 39.38 3,916.62 3,823.83 -1,190.75 8,189.49 5,979,646.01 557,765.13 3.96 7,100.49 MWD+IFR2+HDS+MS(6) 10,696.00 83.55 38.94 3,919.62 3,826.83 .1,167.61 8,208.34 5,979,669.28 557,783.82 4.92 7,126.79 MWD+IFR2+HDS+MS (6) 10,726.00 82.01 38.70 3,923.39 3,830.60 .1,144.42 8,226.99 5,979,692.59 557,802.33 5.19 7,152.94 MWD+IFR2+HDS+MS(6) 10,756.00 81.03 39.03 3,927.82 3,835.03 -1,121.32 8,245.61 5,979,715.81 557,820.79 3.44 7,179.01 MWD+IFR2+HDS+MS(6) 10,786.00 81.18 39.39 3,932.46 3,839.67 -1,098.35 8,264.35 5,979,738.90 557,839.37 1.29 7,205.14 MWD+IFR2+HDS+MS(6) 10,816.00 81.48 39.68 3,936.98 3,844.19 -1,075.48 8,283.23 5,979,761.89 557,858.10 1.38 7,231.37 MWD+IFR2+HDS+MS(6) 10,846.00 81.39 39.65 3,941.45 3,848.66 -1,052.64 8,302.16 5,979,784.85 557,876.88 0.32 7,257.64 MWD+IFR2+HDS+MS (6) 10,876.W 81.55 39.57 3,945.90 3,853.11 -1,029.79 8,321.08 5,979,807.83 557,895.64 0.59 7,283.89 MWD+IFR2+HD5+MS(6) 10,906.00 81.22 39.48 3,950.39 3,857.60 -1,006.91 8,339.95 5,979,830.83 557,914.36 1.14 7,310.12 MWD+IFR2+HDS+MS (6) 10,936.00 81.67 39.20 3,954.85 3,862.06 -983.96 8,358.76 5,979,853.90 557,933.01 1.76 7,336.31 MWD+IFR2+HDS+MS (6) 10,966.00 82.70 38.88 3,958.93 3,866.14 -960.88 8,377.48 5,979,877.10 557,951.58 3.59 7,362.47 MWD+IFR2+HDS+MS(6) 10,996.00 83.49 38.56 3,962.54 3,869.75 -937.64 8,396.11 5,979,900.46 557,970.05 2.84 7,388.61 MWD+IFR2+HDS+MS(6) 11,026.00 84.95 38.19 3,965.56 3,872.77 A14.24 8,414.64 5,979,923.98 557,988.42 5.02 7,414.71 MWD+IFR2+HDS+MS(6) 11,056.00 87.03 37.94 3,967.66 3,874.87 -890.68 8,433.09 5,979,997.66 558,006.72 6.98 7,440.81 MWD+IFR2+HDS+MS(6) 11,085.00 87.92 37.87 3,968.98 3,876.19 -867.04 8,451.50 5,979,971.42 558,024.97 2.98 7,465.90 MWD+IFR2+HDS+1JS(6) 11,116.W 87.76 37.76 3,970.11 3,877.32 -843.35 8469.88 5,979,995.22 55B,M3A9 0.65 7,492.98 MWD+IFR2+HDS+MS(6) 11,146.W 87.68 37.62 3,971.30 3,878.51 4119.63 8,486.21 5,980,019.M 558,061.36 0.54 7,519.03 MWD+IFR2+HDS+M$(6) 11,176.W 87.67 37.49 3,972.52 3,879.73 -795.87 8,506.48 5,980,042.95 558,079.47 0.43 7,545.04 MWD+IFR2+HD5+MS(6) 11,206.00 87.35 37.29 3,973.82 3,881.03 -772.06 8,524.68 5,980,066.88 558,097.51 1.26 7,571.0 MWD+IFR2+HDS+MS(6) 11,236.W 87.82 37.02 3,975.09 3,882.30 .748.17 6,542.78 5,980,090.88 558,115.45 1.81 7,596.90 MWD+IFR2+HD5+MS(6) 11,266.00 89.63 36.75 3,975.75 3,882.96 -724.18 8,560.78 5,980,114.99 558,133.29 6.10 7,622.75 MWD+IFR2+HDS+MS(6) 11,296.00 91.33 WAS 3,975.50 3,882.71 -700.10 8,578.67 5,980,139.19 558,151.02 5.75 7,648.52 MND+IFR2+HDS+MS(6) 9/12/2018 7:15:58AM Page 10 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1 H-104 project: Kuparuk River Unit TVD Reference: 1H-104 actual Q 92.79usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-104 actual @ 92.79usft (Doyon 142) WOR: Rig: 1H-104 North Reference: True WeRbom: 1H-1041.1 Survey Calculation Method: Minimum Curvature Design: 1H-104LI Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azl TVD TVDSS +WS +E/ -W Northing Earrfing OLS Section (usm P) P) (USM Wall) (MR) (usIt) (R) (R) (91001 (R) Survey Tool Name 11,326.00 93.03 36.11 3,974.36 3,881.57 575.93 8,596.41 5,980,163.47 558,168.59 5.78 7,674.20 MWD+IFR2+HDS+MS(6) 11,356.00 92.79 35.76 3,972.84 3,880.05 551.67 8,613.99 5,980,187.84 558,186.02 1.41 7,699.76 MWD+IFR2+HDS+MS(6) 11,385.00 92.69 35.41 3,971.40 3,878.61 527.30 8,631.43 5,%D,212.32 558,203.29 1.21 7,725.23 MWD+IFR2+HDS+MS(6) 11,416.00 92.84 35.08 3,969.96 3,877.17 502.83 8,648.72 5,98.236.90 558,220.42 1.21 7,750.61 MWD+IFR2+HDS+MS(6) 11,446.00 92.70 34.75 3,968.51 3,875.72 578.26 8,665.87 5,98.%1.59 558,237.40 1.19 7,775.90 MWD+IFR2+HDS+MS(6) 11,476.00 92.20 34.41 3,967.23 3,874.44 553.58 8,682.88 5,980,286.37 558254.25 2.01 7,801.10 MWD+IFR2+HDS+MS(6) 11,506.00 92.20 34.OD 3,966.07 3,873.28 528.79 8,699.73 5,980,311.27 558,270.94 1.37 7,826.19 MWD+IFR2+HDS+MS (6) 11,536.00 92.23 33.58 3,964.91 3,872.12 503.87 8,716.40 5,980,316.29 558,28244 1.40 7,851.17 MWD+IFR2+HDS+MS(6) 11,566.00 92.22 33.14 3,963.75 3,870.96 A78.84 8,732.89 5,980,361.44 556,303.76 1.47 7,876.02 MWD+IFR2+HOS+MS(6) 11,596.00 92.19 32.35 3,%2.60 3,869.81 -053.62 8,749.10 5,980,386.76 558,319.80 2.63 7,00.59 MWD+IFR2+HDS+MS(6) 11,626.00 92.22 31.42 3,961.44 3,868.65 -426.17 8,764.94 5,980,412.31 558,335.47 3.10 7,925.10 MND+IFR2+HDS+MS (6) 11,656.W 92.71 30.49 3,960.15 3,867.36 402.46 8,780.36 5,98.438.11 558,350]1 3.50 7,949.22 MWD+IFR2+HDS+MS(6) 11,686.00 92.99 29.55 3,958.66 3,865.87 -376.52 8,795.35 5,980,464.15 558,365.53 3.27 7,973.04 MNID+IFR2+HDS+MS (6) 11,716.00 93.00 28.59 3,957.09 3,864.30 -350.34 8,809.90 5,900,490.43 558,379.91 3.20 7,996.55 MWD+IFR2+HDS+MS(6) 11,746.00 93.69 27.64 3,955.34 3,862.55 -323.92 8,824.01 5,900,516.94 558,393.85 3.91 8,019.74 MWD+IFR2+HDS+MS (6) 11,776.00 94.50 26.64 3,953.20 3,860.41 -297.29 8,837.66 5,980,543.65 558,407.32 4.28 8,042.59 MWD+IFR2+HDS+MS(6) 11,806.00 94.54 25.57 3,950.83 3,858.04 -270.44 8,850.62 5,980,570.59 558,420.30 3.56 8,065.07 MWD+IFR2+HDS+MS(6) 11,836.00 94.22 24.49 3,948.54 3,855.75 -243.34 8,863.48 5,9B0,597.77 558,432.77 314 8,087.18 MWD+IFR2+HDS+MS(6) 11,856.00 94.08 23.53 3,946.37 3,853.58 -216.00 8,875.65 5,980,625.18 558,444.77 3.23 8,108.94 MWD+IFR2+HDS+MS(6) 11,8%.00 94.40 22.79 3,944.15 3,851.35 -188.50 8,887.42 5,960,65216 558,456.35 2.68 8,130.38 MWD+IFR2+HDS+MS (6) 11,926.00 94.61 22.07 3,941.80 3,849.01 -160.85 8,898.83 5,980,680.48 558,467.58 2.49 8,151.55 MWD+IFR2+HDS+MS (6) 11,956.00 94.87 21.29 3,939.32 3,846.53 -133.07 8,909.88 5,980,708.33 558,478.44 2.73 8,172.49 MWD+IFR2+HDS+MS(6) 11,986.00 94.61 20.29 3,936.84 3,844.05 -105.12 8.920.49 5,900,736.35 558,488.86 3.43 8,192.99 MWD+IFR2+HDS+MS(6) 12,016.00 94.62 19.26 3,934.43 3,841.64 -76.96 8,930.61 5,980,764.55 558,498.79 3.42 8,213.16 MWD+IFR2+HDS+MS(6) 12,046.00 94.11 18.23 3,932.14 3,839.35 48.66 8,940.22 5,980,792.94 558,508.21 3.82 8,232.93 MWD+IFR2+HDS+MS(6) 12,076.00 93.61 17.26 3,930.12 3,837.33 -20.15 8,949.34 5,98.821.50 558,517.15 3.63 6,252.32 MWD+IFR2+HDS+MS(6) 12,106.00 92.52 16.32 3,928.52 3,835.73 8.53 8,957.99 5,980,850.24 558,525.61 419 8,271.34 MWD+IFR2+HDS+MS(6) 12,136.00 92.31 15.37 3,927.25 3,834.6 37.37 8,966.18 5,980,879.12 558,533.60 3.24 8,289.99 MWD+IFR2+HDS+MS(6) 12,166.00 92.63 14.38 3,925.96 3,833.17 66.33 8,973.87 5,980,908.14 558,541.10 3.47 8,308.24 MWD+IFR2+HDS+MS(6) 12,196.00 92.48 13.39 3,924.62 3,831.83 95.43 8,981.06 5,980,937.27 558,548.10 3.33 8,326.08 MWD+IFR2+HDS+MS(6) 12,226.00 92.77 12.39 3,923.25 3,830.46 124.64 8,07.75 5,98.966.53 558,554.59 3.47 8,343.49 MWD+IFR2+HDS+MS(6) 12,256.00 93.07 11.31 3,921.72 3,828.93 153.96 8,993.90 5,980,995.89 558,560.55 3.73 8,360.45 MND+IFR2+HDS+MS (6) 12,286.00 93.6 10.19 3,920.01 3,827.22 183.39 8,999.49 5,981,025.35 558,565.94 3.95 8,376.% MWD+IFR2+HDS+MS (6) 12,316.00 93.39 9.06 3,918.22 3,825.43 212.91 9,004.49 5,981,054.90 558,570.75 3.77 8,392.92 MWD+IFR2+HDS+MS(6) 12,346.W 92.90 7.95 3,916.55 3.823.76 242.53 9,008.92 5,981,089.55 558,574.99 3.94 8,408.41 MWD+IFR2+HDS+MS(6) 12,376.00 92.92 6.87 3,915.01 3,822.22 272.24 9,012.79 5,981,114.28 558,578.65 3.60 8,423.41 MWD+IFR2+HDS+MS(6) 12,406.W 92.89 5.79 3,913.49 3,820.70 302.02 9,016.09 5,981,144.08 558,581.76 3.60 8,437.92 MWD+IFR2+HDS+MS(6) 12,436.00 93.10 4.92 3,911.92 3,819.13 331.85 9,018.89 5,01,173.92 558,584.36 2.98 8,451.98 MND+IFR2+HDS+MS(6) 12,466.00 92.54 4.31 3,910.45 3,817.66 361.72 9,021.30 5,981,203.80 558,586.57 2.76 8,46510 MND+IFR2+HDS+MS(6) 12,496.00 91.36 3.71 3,909.43 3,816.64 391.63 9,023.39 5,981,233.72 558,588.47 4.41 8,479.14 MWD+IFR2+HDS+MS(6) 9/122018 7:15.5BAM Page 11 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 1 H-104 Project Kuparuk River Unit TVD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Site: Kupamk 1 H Pad MD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Wait: Rig: 1H-104 North Reference: True Wellbore: 1H-1041.1 Survey Calculation Method: Minimum Curvature D"lon: 1H-10411 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azl TVD TVDSS +NIS +E/ -A/ Northing Fasting DLS Section (uslt) 0 n (usfry (us(ry (uaft) (usft) (to (try r/100') (ft) Survey Tool Name 12,526.0 90.78 3.13 3,908.87 3,816.08 421.57 9,025.18 5,981,263.67 558,590.06 2.73 8,492.31 MWD+lFR2+HDS+MS(6) 12,556.00 89.87 2.70 3,908.70 3,815.91 451.53 9,026.71 5,981,293.63 558,591.39 3.35 8,505.25 MWD+IFR2+HDS+MS(6) 12,586.00 89.89 2.28 3,908.76 3,815.97 481.50 9,028.01 5,981,323.61 558,592.49 1.40 8,517.99 MWD+IFR2+HDS+MS(6) 12,616.00 89.93 1.89 3,908.81 3,816.02 511.48 9,029.10 5,981,353.60 558,593.38 1.31 8,530.54 MWD+IFR2+HDS+MS(6) 12,646.00 90.09 1.67 3,908.80 3,816.01 541.46 9,030.04 5,981,383.58 558,594.12 0.91 8,542.94 MWD+IFR2+HDS+MS(6) 12.676.00 90.45 1.49 3,908.66 3,815.87 571.45 9,030.86 5,981,413.57 558,594.75 1.34 8,555.24 M6VD+IFR2+HDS+MS (6) 12,706.00 90.44 1.32 3,908.43 3,815.64 601.44 9,031.60 5,981,443.56 558,595.28 0.57 8,567.46 MWD+IFR2+HDS+MS(6) 12,736.00 90.62 1.17 3,908.15 3,815.36 631.43 9,032.25 5,981473.56 558,595.74 0.78 8,579.60 MWDAFR2+MDS+MS(6) 12,766.00 90.52 1.04 3,907.85 3,815.06 661.43 9,032.83 5,981,503.55 558,596.12 0.55 8,591.68 MWD+IFR2+HDS+MS(6) 12,7%.0 90.60 0.90 3,907.55 3,814.77 691.42 9,033.34 5,981,533.54 %B,5%.43 0.54 8,603.69 MWD+IFR2+HDS+MS(6) 12,826.00 90.54 0.93 3,907.26 3,814.47 721.42 9,033.82 5,981,563.54 550,596.71 0.22 8,615.68 MWD+IFR2+HDS+MS (6) 12,856.00 90.56 1.11 3,906.97 3,814.18 751.41 9,034.35 5,981,593.53 558,597.04 0.60 6,627.71 MWD+IFR2+HDS+M5(6) 12,886.00 90.68 1.30 3,906.65 3,813.86 781.40 9,034.96 5,981,623.52 556,597.47 0.75 8,639.84 MWD+IFR2+HDS+MS (6) 12,916.0 90.41 1.35 3,906.36 3,813.57 811.39 9,035.67 5,981,653.52 558,597.97 0.92 8,652.02 MWD+IFR2+HDS+MS(6) 12,946.00 90.36 1.19 3,906.16 3,813.37 841.38 9036.34 5,981.683.51 558,598.44 0.% 8,664.18 MWD+IFR2+HDS+MS(6) 12,976.00 90.57 1.02 3,905.91 3,813.12 871.38 9,036.92 5,981713.50 558,598.82 0.90 8,676.25 MWD+IFR2+HDS+MS(6) 13,006.00 90.37 0.67 3,905.67 3,812.88 901.37 9,037.36 5,981,743.50 558,599.06 1.34 8,688.20 MWD+IFR2+HDS+MS(6) 13,036.00 90.15 359.76 3,905.53 3,812.74 931.37 9,037.47 5,981,773.49 558,598.97 3.12 8,699.85 MWD+IFR2+HDS+MS (6) 13,066.00 89.94 358.81 3,905.51 3,812.72 %1.37 9,037.10 5,961,803.49 558,598.40 3.24 8,711.05 MWD+IFR2+HDS+MS(6) 13,096.00 89.91 357.84 3,905.55 3,812.76 991.36 9,036.22 5,981,833.46 558,597.33 3.23 8,721.78 MWD+IFR2+HDS+MS (6) 13,126.00 89.47 356.74 3,905.71 3,812.92 1,021.32 9,034.80 5,981,863.42 558,595.71 3.95 8,732.01 MWD+IFR2+HDS+MS (6) 13,156.00 89.36 355.62 3,906.02 3,813.23 1,051.25 9,032.80 5,981,893.33 556,593.51 3.75 8,741.68 MWD+IFR2+HDS+MS(6) 13,186.00 89.48 354.55 3,906.32 3,813.53 1,081.14 9,030.23 5,981,923.20 558,590.75 3.59 8,750.81 MWD+IFR2+HDS+MS(6) 13,216.00 89.10 353.98 3,906.69 3,813.90 1,110.99 9,027.24 5,981,953.02 558,587.55 2.28 8,759.53 MWD+IFR2+HDS+MS(6) 13,246.00 87.91 353.55 3,907.48 3,814.69 1,140.80 9,023.98 5,981,982.81 558,584.10 4.22 8,768.0 MWD+IFR2+HDS+MS(6) 13,276.00 86.75 353.12 3,908.87 3,816.06 1,170.56 9,020.50 5,982,012.55 558,580.42 4.12 8,776.24 MWD+IFR2+HDS+MS(6) 13,306.00 85.79 353.01 3,910.82 3,818.3 1,200.28 9,016.89 5,982,042.23 558,576.61 3.22 8,764.34 MWD+IFR2+HDS+MS(6) 13,336.00 84.80 353.06 3,913.28 3,820.49 1,229.96 9,013.26 5,982,071.89 558,572.79 3.30 8,792.42 MWD+IFR2+HDS+MS (6) 13,366.00 84.04 353.10 3,916.20 3,823.41 1,259.60 9,009.66 5,982,101.50 558,569.00 2.54 8,800.50 MWD+IFR2+HDS+MS(6) 13,396.00 83.07 352.99 3,919.57 3,826.78 1,289.19 9,006.06 5,982,131.06 558,565.19 3.25 8,808.56 MWD+IFR2+HDS+MS(6) 13,426.00 82.66 352.77 3,923.30 3,830.51 1,318.73 9,002.37 5,982,160.57 558,%1.31 1.55 8,816.52 MWD+IFR2+HDS+MS(6) 13,456.00 83.16 352.56 3,927.0 3,834.21 1,348.25 8,996.56 5,982,190.07 558,557.31 1.81 8,824.38 MWD+IFR2+HDS+MS(6) 13,466.0 83.21 352.45 3,930.56 3,837.77 1,377.79 8,994.68 5,982,219.57 556,553.23 0.40 8,832.16 MWD+IFR2+HDS+MS(6) 13,516.0 83.07 352.3 3,934.14 3,841.35 1,407.31 8,990.76 5,982,249.07 558,649.12 0.47 8,839.90 MWD+IFR2+HDS+MS(6) 13,546.00 83.11 352.40 3,937.75 3,844.96 1,436.84 8,985.83 5,982,278.56 558,544.99 0.17 8,847.63 MWD+IFR2+HDS+MS(6) 13,576.0 82.% 352.39 3,941.39 3,848.60 1,466.35 8,982.89 5,982,308.05 558,540.86 0.50 8,855.36 MWD+IFR2+HDS+MS(6) 13,606.00 82.95 352.40 3,945.07 3,852.28 1,495.86 8,978.95 5,982,337.53 558,536.72 0.05 8,853.08 MWD+IFR2+HDS+MS(6) 13,636.00 83.13 352.41 3,948.70 3,855.91 1,525.38 8,975.01 5,982,367.02 558,532.59 0.60 8,870.80 MWD+IFR2+HDS+MS(6) 13.666+00 83.11 352.24 3,952.30 3,859.51 1,554.90 8,971.03 5,982,396.51 558,528.42 0.57 8,878.49 MWD+IFR2+HDS+MS(6) 13,696.00 83.07 351.78 3,955.91 3,863.12 1,584.39 8,9%.89 5,982,425.97 558,524.08 1.53 8,886.02 MV4D+IFR2+HDS+MS(6) 9/122018 7:15:58AM Page 12 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1H-104 Project: Kuparuk River Unit TVD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-104 actual @ 92.79us0 (Doyon 142) Well: Rig: 111-104 North Reference: True Wellborn: 1H -104L1 Survey Calculation Method: Minimum Curvature Design: 1H -104L1 Database: OAKEDMP2 Survey 9/12/2018 7:15:58AM Page 13 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easgng DLS Section (usR) r) r) (08111t) (usm (usR) (08111) (to t1t) P/100') (ft) Survey Tool Name 13,726.00 83.47 351.32 3,959.42 3,866.63 1,613.86 8,962.52 5,982,455.41 558,519.51 2.02 8,893.32 MWD+IFR2+HDS+MS(6) 13,756.00 83.56 350.72 3,962.81 3,870.02 1,643.30 8,957.86 5,982,484.81 558,514.66 2.01 8,900.36 MWD+IFR2+HDS+MS(6) 13,786.00 83.30 349.81 3,965.24 3,873.45 1,672.68 8,952.82 5,982,514.15 558,509.43 3.14 8,907.01 MWD+IFR2+HDS+MS(6) 13,816.00 84.02 348.76 3,969.56 3,876.77 1,701.97 8,947.28 5,982,543.41 558,503.69 4.23 8,913.17 MWD+IFR2+HDS+MS(6) 13,846.00 84.96 347.60 3,972.44 3,879.65 1,731.20 8,941.16 5,982,572.59 558,497.38 4.96 8,918.77 MWD+IFR2+HDS+MS(6) 13,876.00 85.70 346.51 3,974.88 3,882.09 1,760.34 8,934.47 5,982,601.68 558,490.49 4.38 8,923.80 MWD+IFR2+HDS+MS (6) 13,906.00 86.83 345.13 3,976.83 3,884.04 1,789.36 8,927.13 5,982,630.65 558,482.97 5.94 8,928.20 MWD+IFR2+HDS+MS(6) 13,936.00 88.30 343.36 3,978.11 3,885.32 1,818.21 8.918.99 5,982,659.44 558,474.64 7.67 8,931.79 MWD+IFR2+HDS+MS(6) 13,966.00 89.95 341.33 3,978.57 3,88578 1,846.79 8,909.90 5,982,687.96 558,465.36 8.72 8,934.40 MWD+IFR2+HDS+MS(6) 13,996.00 90.45 339.49 3,978.46 3,885.67 1,875.05 8,899.84 5,982,716.15 558,455.11 6.36 8,935.99 MWD+IFR2+HDS+MS(6) 14,026.00 90.25 337.78 3,978.28 3,885.49 1,902.99 8,888.91 5,982,744.01 558,444.00 5.74 8,936.65 MWD+IFR2+HDS+MS(6) 14,056.00 90.28 335.85 3,978.14 3,885.35 1,930.56 8,877.10 5,982,771.51 558,432.01 6.43 8,936.37 MWD+IFR2+HDS+MS(6) 14,086.00 90.62 333.89 3,977.90 3,885.11 1,957.72 8,864.36 5,982,798.58 558,419.09 6.63 8,935.06 MWD+IFR2+HDS+MS (6) 14,116.00 90.84 331.93 3,977.52 3,884.73 1,984.44 8,850.72 5,982,825.20 558,405.27 6.38 8,932.74 MWD+IFR2+HDS+MS(6) 14,146.00 91.17 330.48 3,977.00 3,884.21 2,010.73 8,836.28 5,982,851.39 558,390.65 5.15 8,929.54 MND+IFR2+HDS+MS(6) 14,176.00 91.69 329.03 3,976.25 3,883.6 2,036.64 8,821.18 5,982,877.19 558,375.39 5.13 8,925.57 MWD+IFR2+HDS+MS(6) 14,206.00 92.10 327.64 3,975.25 3,882.46 2,062.16 8,805.44 5,982,902.61 558,359.48 4.83 8,920.86 MWD+IFR2+HDS+MS(6) 14,236.00 92.91 326.84 3,973.94 3,881.15 2,087.36 8,789.22 5,982,927.70 558,343.10 3.79 8,915.59 MWD+IFR2+HDS+MS(6) 14,266.00 93.87 326.18 3,972.17 3,879.38 2,112.33 8,772.69 5,982,952.56 558,326.41 3.88 8,909.95 MWD+IFR2+HDS+MS(6) 14,296.00 94.02 325.46 3,970.11 3,877.32 2,137.09 8,755.88 5,982,977.21 558,309.44 2.45 8,903.96 MWD+IFR2+HDS+MS(6) 14,326.00 94.05 324.05 3,967.99 3,875.20 2,161.53 8,738.61 5,983,001.53 558,292.01 4.69 8,89743 MWD+IFR2+HDS+MS(6) 14,356.00 94.12 322.43 3,965.86 3,873.07 2,185.51 8,720.70 5,983,025.38 558,273.94 5.39 8,890.13 MWD+IFR2+HDS+MS(6) 14,386.00 94.05 320.83 3,963.72 3,870.93 2,208.97 8,702.13 5,983,048.72 558,255.22 5.32 8,882.01 MWD+IFR2+HDS+MS(6) 14,416.00 93.76 319.62 3,961.68 3,868.89 2,231.97 B,aa2.98 5,983,071.59 558,235.92 4.14 8,873.19 MWDAFR2+HDS+MS(6) 14,446.00 93.58 318.40 3,959.76 3,866.97 2,254.57 8,663.34 5,983,094.5 558,216.13 4.10 8,86376 MWD+IFR2+HDS+MS(6) 14,476.0 93.29 317.17 3,957.96 3,865.17 2,276.74 8,643.22 5,983,116.10 558,195.87 4.21 6,853.73 MWD+IFR2+HDS+MS(6) 14,506.00 93.07 316.33 3,956.29 3,863.50 2,298.56 8,622.70 5,983,137.78 558,175.20 2.89 8,843.18 MWD+IFR2+HDS+MS(6) 14,536.0 93.31 315.66 3,954.63 3,861.84 2,320.11 8,601.89 5,983,159.18 558,154.25 2.37 8,832.27 MWD+IFR2+HDS+MS(6) 14,566.00 93.19 314.99 3,952.92 3,850.13 2,341.41 8,580.83 5,983,180.34 558,133.06 2.27 8,821.3 MWD+IFR2+HDS+MS(6) 14,596.00 92.89 313.99 3,951.33 3,858.54 2,362.40 8,559.46 5,983,201.19 558,111.55 3.48 8,809.38 MWD+IFR2+HDS+MS(6) 14,626.00 92.89 312.82 3,949.82 3,857.03 2,382.99 8,537.69 5,983,221.63 558,089.65 3.90 8,797.21 MWD+IFR2+HDS+MS(6) 14,656.00 92.38 311.65 3,948.44 3,855.65 2,403.13 8,515.51 5,983,241.62 558,067.33 4.25 8,784.49 MWD+IFR2+HDS+MS(6) 14,686.00 92.38 311.57 3,947.20 3,854.41 2,423.04 8,493.09 5,983,261.38 558,044.79 0.27 8,771.46 MWD+IFR2+HDS+MS(6) 14,716.00 92.92 312.24 3,945.81 3,853.02 2,443.05 8,470.79 5,983,281.24 558,022.36 2.87 8,758.58 MWD+IFR2+HDS+MS(6) 14,746.00 92.75 312.92 3,944.33 3,851.54 2,463.32 8,448.73 5,983,301.37 558,000.16 2.33 8,746.02 MWD+IFR2+HDS+MS(6) 14,776.00 91.58 313.03 3,943.19 3,850.40 2,483.76 8,426.79 5,983,321.66 557,978.10 3.92 8,733.64 MWD+IFR2+HDS+MS(6) 14,806.00 90.49 312.60 3,942.65 3,849.86 2,504.14 8,404.79 5,983,341.09 557,955.96 3.91 8,721.17 MWD+IFR2+HDS+MS (6) 14,836.00 89.89 312.18 3,942.55 3,849.76 2,524.37 8,382.64 5,983,361.97 557,933.67 2.44 8,708.51 MWD+IFR2+HDS+MS(6) 14,856.00 89.74 311.20 3,942.65 3,849.86 2,549.32 8,360.23 5,983,381.77 557,911.14 3.30 8,695.51 MWD+IFR2+NDS+MS (6) 14,896.00 89.60 309.53 3,942.82 3,850.03 2,563.75 8,337.38 5,983,401.05 557,888.16 5.59 8.681.89 MWD+IFR2+HDS+MS(6) 9/12/2018 7:15:58AM Page 13 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: lH-104 Project: Kuparuk River Unit TVD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Sne: Kuparuk 1 H Pad MD Reference: 111-104 actual @ 92.79usn (Doyon 142) Wen: Rig: 1H-104 North Reference: True Wellbore: 1 H -1 04L1 Survey Calculation Method: Minimum Curvature Design: 1 H -1 04L1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Aal TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) r) 11 Not" Won) (usft) (-ft) (it) (ft) (°/100') (it) Survey Tool Name 14,926.00 89.81 307.86 3,942.97 3,850.18 2,582.51 8,313.96 5,983,419.64 557,864.62 5.61 8,657.50 MWD+IFR2+HDS+MS (6) 14956.00 911.03 306.44 3,943.02 3,850.23 2,600.62 8,290.05 5,983,437.60 557,840.60 4.79 8,652.40 MWD+IFR2+HDS+MS(6) 14,986.00 90.82 305.37 3,942.79 3,850.00 2,618.21 8,265.75 5,983,455.03 557,816.18 4.43 8,636.74 MWD+IFR2+11DS+MS(6) 15,016.00 90.91 304.31 3,942.34 3,849.55 2,635.35 8,241.13 5,983,472.00 557,791.45 3.55 8,620.61 MWD+IFR2+HDS+MS(6) 15,046.00 90.79 303.27 3,941.90 3,849.11 2,652.03 8,216.20 5,983,488.52 557,766.42 3.49 8,604.02 MWD+IFR2+HDS+MS (6) 15,076.00 90.78 302.27 3,941.48 3,848.69 2,668.27 8,190.98 5,983,504.58 557,741.09 3.33 8,586.99 MWD+IFR2+HDS+MS(6) 15,106.00 90.77 301.27 3,941.08 3,848.29 2,684.06 8,165.48 5,983,520.21 557,715.49 3.33 8,569.53 MWD+IFR2+HDS+MS(6) 15,136.06 90.88 300.24 3,940.65 3,847.86 2,699.40 8,139.70 5,983,535.37 557,689.61 3.45 8,551.64 MWD+IFR2+HDS+MS(6) 15,166.00 90.96 299.17 3,940.17 3,847.38 2,714.27 8,113.65 5,983550.06 557,663.46 3.58 8,533.32 MWD+IFR2+HDS+MS(6) 15,196.00 91.30 298.10 3,939.57 3,846.78 2,728.64 8,087.32 5,983,564.26 557,637.04 3.74 8,514.55 MWD+1FR2+HDS+MS(6) 15,226.00 92.10 297.34 3,938.68 3,845.89 2,742.59 8,060.78 5,961,578.03 557,610.41 3.68 8,495.42 MWD+IFR2+HDS+MS (6) 15,256.00 92.53 297.31 3,937.47 3,844.68 2,756.35 8,034.15 5,983,591.61 557,583.69 1.44 8,476.13 MWD+IFR2+HDS+MS(6) 15,286.00 92.26 297.29 3,936.22 3,843.43 2,770.10 8,007.51 5.983.605.16 557,556.97 0.90 8,456.84 MWD+IFR2+HDS+MS (6) 15,316.00 91.99 297.33 3,935.11 3,842.32 2,783.85 7,980.87 5,983,618.76 557,530.24 0.91 8,437.55 MWD+IFR2+HDS+MS (6) 15,346.00 92.03 297.52 3,934.05 3,841.26 2,797.66 7.954.26 5,983.632.39 557,503.54 0.65 8,418.30 MWD+IFR2+HDS+MS(6) 15,376.00 92.00 297.72 3,933.00 3,840.21 2,811.56 7,927.70 5,983,646.11 557,476.89 0.67 8,399.13 MWD+IFR2+HDS+MS(6) 15,406.00 91.39 297.78 3,932.11 3,839.32 2,825.52 7,901.16 5,983,659.90 557,450.26 2.04 8,380.01 MV4D+IFR2+HDS+MS(6) 15,435.00 90.40 297.37 3,931.64 3,838.85 2,839.41 7,874.57 5,983,673.61 557,423.58 3.57 8,360.81 MWD+IFR2+HDS+MS(6) 15,466.00 90.49 296.94 3,931.41 3,838.62 2,853.10 7,847.88 5,983,687.12 557.396.80 1.46 8,341.45 MWD+IFR2+HDS+MS(6) 15,496.00 90.37 296.55 3,931.18 3,838.39 2,866.60 7,821.09 5,983,700.44 557,369.93 1.36 8,321.91 MWD+IFR2+HDS+MS(6) 15,526.00 90.47 296.42 3,930.96 3,838.17 2,879.98 7,794.24 5,983,713.64 557,342.99 0.55 8,302.28 MWD+1FR2+HD8+M6(6) 15,556.00 91.04 296.31 3,930.57 3,837.78 2,893.30 7,767.36 5,983,726.78 557,316.03 1.94 8,282.60 MWD+IFR2+HDS+MS(6) 15,586.00 91.54 296.26 3,929.89 3,837.10 2,906.56 7,740.47 5,983,739.88 557,289.05 1.67 8,262.89 MWD+IFR2+11DS+MS(6) 15,616.00 91.54 296.59 3,929.09 3,836.30 2,919.93 7,713.61 5,983,753.05 557,262.11 1.10 8,243.24 MWD+IFR2+HDS+MS 16) 15,646.00 91.54 296.98 3,928.28 3,835.49 2,933.44 7,686.84 5,983,766.39 557,235.26 1.30 8,223.73 MWD+IFR2+HDS+MS(6) 15,676.00 91.56 297.33 3,927.47 3,83468 2,947.13 7,660.16 5,983,779.90 557,208.48 1.17 8,204.37 MWD+IFR2+HDS+MS(6) 15,706.00 91.55 297.41 3,926.66 3,833.87 2,960.91 7,633.53 5,983,793.50 557,181.76 0.27 8,185.10 MWD+IFR2+HDS+MS(6) 15,736.00 91.58 297.49 3,925.84 3,833.05 2,974.73 7,606.91 5,983,807.14 557,155.06 0.14 8,165.84 MWD+IFR2+HDS+MS (6) 15,766.00 92.04 297.48 3,924.89 3,832.10 2,988.55 7,580.30 5,983,820.79 557,128.36 1.54 8,146.61 MWD+IFR2+HDS+MS(6) 15,796.00 92.45 297.51 3,923.71 3,830.92 3,002.39 7,553.71 5,983,834.45 557,101.68 1.37 8,127.39 MWD+IFR2+HDS+MS(6) 15,826.00 92.53 297.59 3,922.41 3,829.62 3,016.24 7,527.13 5,983,848.12 557,075.02 0.28 8,106.19 MWD+IFR2+HDS+MS(6) 15,856.00 92.81 297.57 3,921.01 3,828.22 3,03D.11 7,500.56 5,983,861.81 557,048.36 0.94 8,089.00 MWD+IFR2+HD6+MS (6) 15,886.00 93.00 297.62 3,919.49 3,826.70 3,043.99 7,474.01 5,983,875.51 557,021.72 0.65 8,069.83 MWD+IFR2+HDS+MS (6) 15,912.02 93.02 297.89 3,918.13 3,825.34 3,056.09 7,451.02 5,983,887.46 556,998.65 1.04 8,053.27 MWD+IFR2+HDS+MS(6) 15,972.00 93.02 297.89 3,914.97 3,822.18 3,084.10 7,398.08 5,983,915.12 556,945.53 0.00 8,015.19 PROJECTED to TO 9/12/2018 7: 15.58AM Page 14 COMPASS 5000.14 Build 85 I Cement Detail Report 11-1-104 String: Conductor Cement Job: DRILLING ORIGINAL, 8/5/2018 09:00 Cement Details Description Conductor Cement Cementing Start Date 11/4/2016 06:00 Cementing End Date 11/4/2016 08:00 Wellbore Name 1H-104 Comment Cement Stages Stage # 1 Description Conductor Cement Objective Top Depth (ftKB) 0.0 Bottom Depth (ftKB) 118.5 Full Return? Yes Vol Cement...Top 0.0 Plug? No Btm Plug? No Q Pump Init (bbl/m...Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) 0.00 Rotated? Na Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) 113112 Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Surface Cement Fluid Description Estimated Top (ftKB) Co Est Btm (ftKB) 118.5 Amount (sacks) Class G Volume Pumped (bbl) 40.5 Yield (ft"/sack) Mix H2O Ratio (gal/sa... Free Water (Yo) Density (lb/gag Plastic Viscosity top) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 912412018 Cement Detail Report a 11-1-104 String: Surface Casing Cement Job: DRILLING ORIGINAL, 8/5/2018 09:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 18/712018 19:30 817/201823:30 1H-104 Comment Pump 5 bbls of CW100 & PT lines to 4000 psi, good. Pump 35 bbls of CW100 at 4.8 bpm, 120 psi. Pump 80 bills of 10.5 ppg MPI/ at 4 bpm, 115 psi. Drop bottom plug. Pump 300.9 bbls of 11.0 ppg Lead cement at 6 bpm, 175 psi. Observed bottom plug bump w/ 179 bbls away. Observed MPII at surface at 265 bbls away. Pump 67 bbls of 12.0 ppg Tail cement at 6 bpm, 270 psi. Drop top plug. Pump 10 bbls of fresh H2O at 5 bpm, 150 psi. Swap to rig & pump 165.1 bbls of 9.5 ppg spud mud to bump plug. Observe good 11.0 ppg cement back w/ 75 bbl mud pumped. Landed on hanger w/ 80 bbls of mud pumped. Pressure up to 784 psi & hold for 5 minutes. Check floats, good. CIP 23:22 firs. Total of 109 bbis of 11.0 ppg lead cement to surface. Cement Stages Stage 8 <Stage Numll DescriptionObjective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 42.4 1,906.0 Yes 109.0 Yes Yes O Pump Init (bbvm... O Pump Final (bbil... O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 5 6 280.0 780.0 Yes 10.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pump 5 bbls of CW100 & PT lines to 4000 psi, good. Pump 35 bbls of CW 100 at 4.8 bpm, 120 psi. Pump 80 bbls of 10.5 ppg MPII at 4 bpm, 115 psi. Drop bottom plug. Pump 300.9 bbls of 11.0 ppg Lead cement at 6 bpm, 175 psi. Observed bottom plug bump w/ 179 bbls away. Observed MPII at surface at 265 We away. Pump 67 bbls of 12.0 ppg Tail cement at 6 bpm, 270 psi. Drop top plug. Pump 10 bbls of fresh H2O at 5 bpm, 150 psi. Swap to rig & pump 165.1 bola of 9.5 ppg spud mud to bump plug. Observe good 11.0 ppg cement back w/ 75 bbl mud pumped. Landed on hanger w/ 80 bbls of mud pumped. Pressure up to 784 psi & hold for 5 minutes. Check floats, good. CIP 23:22 his. Total of 109 bbls of 11.0 ppg lead cement to surface. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btin (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 42.4 1,254.0 885 G 300.9 Yield (fVlsack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.91 6.76 11.00 74.1 5.75 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks)Class Volume Pumped (bbl) Tail Cement1,254.0 1,906.0 228 G 67.0 Yield (f'Isack) Mix H2O Ratio (gallsa... Free Water (%) Density (lb/gal) Plastic Viscosity (GP) Thickening Time (hr) CmprStr 1 (psi) 1.65 5.60 1 85.5 4.00 Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 9/24/2018 Cement Detail Report k 11-1-104 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 815/2018 09:00 Cement Details Description Cementing Start Date ementing End Date Wellbore Name Intermediate Casing Cement 8/141201814:00 8/14!20181&00 1=18 1H-104 Comment PJSM and RU cement hose PT lines to 4,000 PSI. (PASSED). Reciprocate pipe from 9,503' MD - 9,488' MD. UP WT = 211 K. DWN WT = tO1K. PUmp 41.3 BBLS MP II. @ 3 BPM 312 PSI, 12%F/0. Drop BTM Plug pump 250 BBLS of 15.8# Gass G cement stage up pumps to 6 BPM with ICP 400 SI. FCP 270 PSI. 22%F10. Drop top plug and chase with 10 BBLS H2O. followed with 9.2 PPG treated -SND @ 7 BPM icp 161 PSI, Obsereve DWN WT to 5OK - 10' high. Attempt to free pipe with no success. UP WT = 228K, DWN WT = 98k. continue to pump 7 BPM with FCP 1,265 PSI. tedum rate to 3 BPM @ 4,025 Stks. ICP 1,175 PSI. FCP 1,320 PSI. Bump plug with 422 STKS. CIP @ 1730 hrs. Increase pressure to 1,853 PSI and hold for 5 min. Bleed off and check floats. Holding. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth IRKS) Full Return? Vol Cement... Top Plug. in Plug? Intermediate Casing 4,775.0 9,514.0 Yes Yes Yes Cement O Pump Init (bbUm... O Pump Final (bbl/... O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 3 7 7 1,265.0 1,265.0 Yes 15.00 ND Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment PJSM and RU cement hose PT lines to 4,000 PSI. (PASSED). Reciprocate pipe from 9,503' MD - 9,488' MD. UP WT = 211K. DWN WT = 101 K. PUmp 41.3 BBLS MP II. @ 3 BPM 312 PSI, 12%F10. Drop BTM Plug pump 250 BBLS of 15.8# class G cement stage up pumps to 6 BPM with ICP 400 SI. FCP 270 PSI. 22% F/0. Drop top plug and chase with 10 BBLS H2O. followed with 9.2 PPG treated LSND @ 7 BPM icp 161 PSI, Obsereve DWN WT to 50K - 10' high. Attempt to free pipe with no success. UP WT = 228K, DWN WT = 98k. continue to pump 7 BPM with FCP 1,265 PSI. teduce rale to 3 BPM @ 4,025 Stks. ICP 1,175 PSI. FCP 1,320 PSI. Bump plug with 422 STKS. CIP @ 1730 hrs. Increase pressure to 1,853 PSI and hold for 5 min. Bleed off and check floats. Holding. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est also (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push 3,675.0 4,775.0 41.3 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (lb/gal) Plastic Viscosity lop) Thickening Time (hr) CmprStr 1 (psi) 12.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est etm (ftKB) JA-0 mount (sacks) Class Volume Pumped (bbl) Cement 4,775.0 9,515.0 1,401 G 250.0 Yield (Wisack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) IThickening Time (hr) Cmpstr 1 (psi) 1.16 5.12 15.80 163.0 14.22 Additives Additive Type Concentration Cone Unit label Page 111 Report Printed: 912412018 118085 29842 Schlumberger -Private STATE OF ALASKA Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.I. Suprylex-1(4A BOPE Test Report for: KUPARUK RIV U WSAK 1H-1041.1 Comm Contractor/Rig No.: Doyon 142 PTD#: 2180850 ' DATE: 9/5/2018 " Inspector Guy Cook - Insp Source Operator: CONOCOPHILLIPS ALASKA, INC. Operator Rep: Dave Coates Rig Rep: Johnny Newman Inspector Type Operation: DRILL Sundry No: Type Test: INIT MISC. INSPECTIONS: Test Pressures: Inspection No: bopGDC180905150530 Rams: Annular: Valves: MASP: 250/3500 250/3500 ' 250/3500 - 1323 - Related Insp No: TEST DATA P/F Location Gen.: P Housekeeping: P ' PTD On Location P Standing Order Posted P__ Well Sign P_'- Drl. Rig _P " Hazard Sec. P _ Misc NA Test Pressures: Inspection No: bopGDC180905150530 Rams: Annular: Valves: MASP: 250/3500 250/3500 ' 250/3500 - 1323 - Related Insp No: TEST DATA BOP STACK: MUD SYSTEM: System Pressure 3000 - P ' Visual Alarm P - Trip Tank P P " Pit Level Indicators P P Flow Indicator P P " Meth Gas Detector _P P H2S Gas Detector P FP MS Misc NA_ _- NA i ACCUMULATOR SYSTEM: BOP STACK: Time/Pressure P/F System Pressure 3000 - P ' Pressure After Closure 1750 P - 200 PSI Attained 6 P " Full Pressure Attained 50 P Blind Switch Covers: All Stations P - Nitgn. Bottles (avg): 6@2158 - P, ACC Misc 0 NA FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly P_ Stripper 0 NA No. Valves 14 -_ P Lower Kelly _1_=_ 1 P_- Annular Preventer _ 1 • 13 5/8" 5000 ' P .- Manual Chokes _ 1 P Ball Type 1 __P #1 Rams 1 '3.5"X6" VBR' P _ Hydraulic Chokes 1 - P Inside BOP 1 P #2 Rams 1 " Blinds P '_ CH Misc _ 0—.- NA" FSV Misc - 0 NA � #3 Rams 1 3.5"X6" VBR P #4 Rams 0 NA INSIDE REEL VALVES: #5 Rams 0 NA #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 . 3 1/8"5000 P " I Quantity P/F HCR Valves 2 " 3 1/8"5000 P Inside Reel Valves _0 NA Kill Line Valves 3 3 1/8"5000 ' P Check Valve 0 NA BOP Misc 0 NA Number of Failures: 1 ✓ Test Results Test Time 4 Remarks: 4.5' and 4" test joints were used for testing. The H2S detector in the its" the audible on initial and was recalibrated for a a pass. The choke and kill hoses on this rig are Continen ontitech an are API 16 -FSL2 compliant. V THE STATE o1 A L SKA GOVERNOR BILL WALKER G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. PO 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.alaska.gov Re: Kuparuk River Field, West Sak Oil Pool, KRU IH -104L1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-085 Surface Location: 5200.56' FNL, 772.31' FEL, SEC. 28, T12N, RIOE, UM Bottomhole Location: 2110.5' FNL, 3898.6.' FEL, SEC. 26, T12N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for the permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 218-084, API No. 50-029- 23610-00-00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. SL DATED this i day of August, 2018. Sincerely, r Hollis S. French Chair STATE OF ALASKA ALA( k OIL AND GAS CONSERVATION COMMIS )N PERMIT TO DRILL n7 lei 20 AAC 25.005 la. Types f Wor 4` 1 b. Proposed Well Class: Exploratory -Gas ❑ Service - WAG Ll Service - Disp F]1 c. Specify if well is proposed for: Drill 4 Lateral Stratigraphic Test ❑ Development - Oil E • Service - Winj ❑ Single Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ I Exploratory -Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone 0 ' Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑' • Single Well ❑ 11. Well Name and Number: ConocoPhillips Bond No. 59-52-180 • KRU 1H -104L1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 15917 TVD: 3826 Kupamk River Field West Sak Oil Pool ' 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 5200.56' FNL, 772.31' FEL, Sec 28, T 12N, ROtOE, UM ADL025639 & ADL025638 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 2050.34' FNL, 143.74' FEL, Sec 34, T 12N, R010E, UM 80-261 & 931695000 8/1/2018 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 2110.5 FNL, 3898.6' FEL, Sec 26, T 12N, ROt OE, UM 2560 &2560 2851' to ADL025637 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 93.1' 15. Distance to Nearest Well Open Surface: x- 549568.74. y- 5980782.43 Zone -4 GL / BF Elevation above MSL (ft): 54.1' to Same Pool: 518' t0 11-1-110 16. Deviated wells: Kickoff depth: 8367 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 95.45 degrees Downhole: 1707 psi Surface: 1323 psi 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 94# H-40 Welded 80 Surface Surface 118 118 Existing, cement to surface 13-1/2" 10-314" 45.5# L-80 Hyd 563 1864 Surface Surface 1918 • 1800 985 sx 11.0 Lead, 201 sx 12.0 Tail 9-7/8" 7-5/8" 29.7# L-80 Hyd 563 9414 Surface Surface 9468 4083 1169 sx 15.8 Class G 6-3/4" 4-1/2" 12.6# L-80 IBTM/TXP 7550 8367 3828 15917 . 3926 N/A: Un -cemented slotted liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (0): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (0): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes[] No ❑� ' 20. Attachments: Property Plat ❑ BOP Sketch Drilling Program B Time v. Depth PlotShallow Hazard Analysis e B Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements24 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be Kelsey Shumway deviated from without prior written approval. Contact Name: Authorized Name: G. Alvord Contact Email: kelsev shumwaynconocophillios.com Authorized Title: AlMa Drilling Manager Contact Phone: 1-907-265-1577 O / Authorized Signature: , , ALVa fLVDate: -7 is Commission Use Only Permit to Drill 77 _/'�,�� Co6 API Number: / 5f4'-16 Permit Approval See cover letter for other Number: d-elg ` 50-G'Z7 -Z ` IK C'C` Date: 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: No� Other. QO%� t%�%-lJiCyj //rG /5 35 G��5 /9 Samples req'd: Yes E] No Mudlogreq'd:Yes❑ /-s /'t t -lq ✓ rl ✓l✓/ �l� 4e -t- a rj - Hi measures: Yes ❑✓ No El Directional svy req'd: Yes [v]�No❑ %� Yes ❑ Nov / X55 Spaci g ex tion req'd: Yes ❑ No L� Inclination -only svy req'd: P.r�,/ �1 T (/V g / ✓f/- will ll eo" 5 ! fiC rf G1 / Y -i Post initial injection MIT req'd: Yes ❑ No n cd p©4c�vtd �JoSi'J�blr>^,porfi 5r�bn-t�'A dpto APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: V r 7-'L 8�l /70 Submit Form and Form 10.401 Revised 5/201 UU This permit is va ,{ t s r�k h of approval per 20 AAC 25.006(8) Attachments in uplicale .4�0 Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone(907)265-1577 Email: kelsev.shumway(cDconocophillips.com July 18, 2018 Alaska Oil and Gas Conservation Commission 333 West 7`t' Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Producer, 1H -104L1 Dear Commissioner: Application for Permit to Drill, Well 11-1-10411 Saved: 19 -Jul -18 C011000Phillips ConocoPhillips Alaska, Inc. hereby applies for a permit to drill a grass roots onshore producer, a tri -lateral horizontal well in the West Sak A2/A3, D/B and D sands. The expected spud date for this well is August 1, 2018. It is planned to use rig Doyon 142. A 13-1/2" surface hole will be drilled on diverter & 10-3/4" surface casing will be run to total depth and cemented to surface. The remaining intervals will utilize Doyon 142's 13-5/8" x 5000 psi BOP stack with required ram installations and tested on a 14 day cycle in accordance with COP and AOGCC policy. The intermediate hole section will drill a 9- 7/8" hole with 7-5/8" casing run to total depth & cemented in place. The second I H -104L1 6-3/4" production lateral will be geo-steered in the West Sak D and B sands and lined with 4-1/2" slotted liner. A separate PTD application will be submitted for each lateral: 1H-104, 1H -104L1, and 1H-1041-2 laterals. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Kelsey Shumway at 265-1577 (kelsev.shumwav na conocoohillips.com) or Chip Alvord at 265-6120. Si cerely, Kelse�waayyO Sr. Drilling Engineer Application for Permit to Drill Doci nlew Kuparuk Well 1H -104L1 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as KRU 1H -104L1 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file frith the commission and identified in the application: (2) a plat ident fying the properly and the property's miners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of tire well at the top of each objective jorniation and at total depth; Location at Surface 5200.56' FNL, 772.31' FEL, Sec 28, T 12N, ROME, UM NGS Coordinates Northings: 5980782.43' Eastings: 549568.74' RKBElevation 93.1'AMSL . Pad Elevation 54.1' AMSL Location at Surface Casing 138.71' FNL, 298' FEL Sec 33, T12N, ROI E, UM NGS Coordinates Northings: 5980567.48' E'astings. 550044.93 Measured De Sh, RKB: 1918' Total Vertical De th, RKB: 1800' Total Vertical Depth, SS: 1707' Location at Intermediate Casin —=7 4160.03' FEL, Sec 35, T12N, ROlOE, UM NGS Coordinates Northings: 5979011.08' Eastings: 556756.24' Measured De th, RKB: 9468' Total Vertical De th, RKB: 4083' Total Vertical Depth, SS: 1 3990' Location at Total Depth 2110.5 FNL, 3898.6' FEL, See 26, T 12N, ROIOE, UM NGS Coordinates Northings: 5983924.98' Eastings: 556974.3' Measured Depth,, RKB: 15917' Total Vertical De th, RKB: 3926' Total Vertical Depth, SS: 3833' and (D) other information required by 20 AAC 25.050(b): Requirements of 20 AAC 25.050(b) fa hell is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale. shoving the path of the proposed wellbore, including all adjacent wellbores within 200 feel of any portion of the proposed well: Please see Attachment: Directional Plan And (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells. to the extent that those names are known or discoverable in public records, and shoe that each named operator has been furnished a copy of dee application by certified mail: or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the follo.ving clews, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blovom prevention equipment (BOPS) as required by 20 AAC 25.035. 20 AAC 25.036, or 20 AAC 25.037, as applicable: Please reference BOP schematics on file for Doyon 142 & within this PTD application. Due to lower reservoir pressure in the West Sak a fixed stack ram placement will be utilized to fulfill all barrier requirements during well construction operations, graphic attached. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must he accompanied by each of the following items. except for an item already on file with the commission and ident f ed in the application: (4) information on drilling hazards, including (A) the marimuni downhole pressure that may be encountered. criteria used to determine it. and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 1H-104 is calculated using an estimated maximum reservoir pressure of 1707 psi (based on IH -05A pressure at a 4005.2' TVD reference datum), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Sak B sand at 3846' TVD: A2 Sand Estimated. BHP = 1,707 psi p X6.5 A2 Sand estimated depth = 3,846' TVD $�(p 0 Sy Gas Gradient = 0.10 psi/ft as7per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 384 psi (3,846' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 1,323 psi (1,707 psi — 384 psi) (B) data on potential gas -ones: The wellbore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and cones that have a propensity, for differential sticking: See attached 1H-104 Drilling Hazards Summary Reauirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill most be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.03069: A procedure is on file with the commission for performing FIT/LOT's. The FIT/LOT will be performed on the motherbore of the 1H-104 tri -lateral well (1 H-104). ConocoPhillips requests a waiver on subsequent laterals FIT/LOT (IH -104L1, and IH -104L2). Waiving the upper lateral FIT/LOT may be undertaken if the following criteria are met: 1. Primary cementjob pumped as per design with no issues. 2. Wel]View cement report submitted to AOGCC for review of job before 2nd lateral is drilled (1H-I04L1). 3. No abnormal pressure is discovered while drilling the motherbore well (lowest lateral). 4. Kill weight fluid is confirmed using a static flow check at the shoe post TD of the 1H-104 motherbore. If any of the above-mentioned criteria are not met, performing an FIT/LOT of the upper laterals will be undertaken. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the follmving items. except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030. and a description of any slotted liner, pre -perforated liner, or screen to be installed Casing and Cement Program 18. Casing Program Surface Specifications Production Top - Setting Depth - Bottom I Cerrent Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length tifl ND MD ND (including stage data) 42" 20" 94# H-40 Welded 80 Surface Surface 118 118 Existing, cement to surface 13-1/2" 10-3/4" 45.5# L-80 Hyd 583 1864 Surface Surface 1918 1800 985 sx 11.0 Lead, 201 sx 12.0 Tail 9-7/8" 7-5/8' 29.7# L -BO Hyd 583 9414 Surface Surface 9468 4083 1169 sx 15.8 Class G 6-3/4" 4-1/2" 12.6# L -BO �TMrTXP 7550 8367 3828 15917 3926 WA: Un -Cemented slotted liner Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application jar a Permit to Drill must be accompanied by each of the following items. except far ars item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 10 AAC 25.035, unless this requirement is waived by the rommission under 20 AAC 25.035(h)(2); Please reference attachment for diverter schematic. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and desorption cf the drilling fluid system, as required by 20 AAC 25033, Mud Program Summary Diagram of Doyon 142 Mud System is on file with AOGCC. Surface Intermediate Production 13-112" Hole 9-7/8" Hole 6-3/4" Hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner Mud System Spud (WBM) LSND WBM FloPro WBM Density 8.8-9.5 9.0-9.4 9.2-9.5 PV ALAP ALAP ALAP YP 30-80 20-30 15-30 Funnel Viscosity 250-300 Permafrost Base 100-150 to TD N/A N/A Initial Gel 30-50 8-15 5-10 10 minute Gel 30-50 < 30 6-15 API Filtrate NC <10 < 6 HTHP Fluid Loss at 120 F NIA N/A <10 H 9.0-10.0 9.0-10.0 9.0-9.5 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Reauirements of 20 AAC 25.005 (c)(13) An application jor a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program follows. Please refer to attachment for proposed well schematic. Note: Previous operations are covered under the 1H-104 Application for Permit to Drill. 1. With 6-3/4" bit, motor, GR/Res, and magnets, and drill —200' of new hole in the D sand. POOH. 2. Pick up 6-3/4" RSS lateral drilling assembly with GR, Res, periscope and RIH. 3. Drill lateral to S Sand, geosteering to the B sand and reach TD per directional plan. 4. BROOH to window and circulate clean before coming out and laying down BHA. 5. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 6. Run 4.5" slotted liner with hook hanger and MWD for orientation. POOH with running tools. 7. Make up and run in hole to install LEM (lateral entry module) with ZXP packer. POOH with running tools. 8. Run & set Baker whipstock system, placing the top of the window just below the top of the D sand orienting with MWD. 9. Mill 6-3/4" window until top mill across face & clean up window. 10. POOH with milling BHA. 11. PU 6-3/4" bit, motor, MWD (GR/Res), and magnets to perform a clean out run & land the well. 12. RIH, orient through window and tag bottom. 13. End IH -104L1 PTD & begin 1H -104L2 PTD. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling nail and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well at the 1B Facility. If needed, excess cuttings generated will be hauled to Milne Point or Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 BOP Ram Placement Attachment Well Schematic Attachment 3 Diverter Layout Diagram Attachment 4 Directional Plan Attachment 5 Drilling Hazards Summary ti v co0 2018 1 H -104L1 wp24 7 � P LL 10 3/4' WS_A3. UG_UUNa4 1k �YFtN r 5000 9000 12000 i Measured Depth 0.00 0.00-2080.35 Plan: 54.1+39 @ 93.10usft (Doyon 142) 0.00 0.00-2073.49 7.00 -16.50-2040.55 1 / <O O 3.00 -135.59-1948.15 o o p O 3.00 -134.90-1906.77 B7 O QQ� 0 m Co 0 M O i 3.00 -68.22-1751.02 o OC a m 7000^' m 12000 440 0 [R5/8- 7/8' parture 9 ".6-3/41 IH -1041.1 T03 W3018 RP 3.00 -113.77-132246 Start 3-11W DLS, -112,%° TF, for 512.07' 0.00 0.00-1144.03 3.00 -64.501058.41 1H -104L1 T04 W3018 RP 300 270 240 Hold for 264.55' 0.00 0.00 -729.90 3.00 -69.98 -584.95 111-1041.1 T05 063018 RP 3.00 -43.99 -371.77 Hold for 288.37' 0.00 0.00 -272.19 4.00 -114.31 30aft 1H -100L1 TW 063018 RP 4.00 -94.54 259.75 Adusl TF to 43.99°, for 25286' 0.00 0.00 662.95 4.00 -90,67 738.30 1H-10411 T07 W3018 RP 4.00 -90.00 914.51 9450 9800 10150 10500 10850 4.00 -153.51 1529.95 Hoid for 407.2' Start 4°1100' DLS, -90.67- TF, for 75.85! Measured Depth 4.00 -38.041807.20 114-10411 T09 063018 RP 401 -89.842495.21 Depth From Depth To SurvepPlan Tool 39.00 1400.00 1H-104wp261P1an: 11-1041 GYDGCSS 1400.00 1920.00 1H-f04wPZ51Plan: 11-104) MWD+IFR-AK-LAZ-ao 1920.00 8365.93 1H-104wp26(Plan: 11-104) MWD+IFR-AK-LAZ-a1. 836593 8700.00 1H' 04L1 P24 IN 1H-104UMWD-MC_ONLY 3700.0010200.00 1H-104L1wP24 Pla¢ 1H-10 1/4WD 8700 00 15916,76 1H-0O4L1wp24 (Plan: 1H-194L1)AWD+IFR-AK-CAZSC tec MD Inc A i 1 8365.93 79.11 78.43 2837893 81.06 77.70 3 8398.93 81.06 77.70 48538.67 90.45 74.94 5 8873.15 90.45 74.94 6 8893.96 90.00 74.50 7 9035.52 87.00 71.49 8 9431.65 87.00 71 49 9 9520.94 88.00 69.00 10 9702.29 91 89 65.20 11 9706.64 91.89 65.20 12021871 88.00 51.00 1310351.50 MAO 47.34 1410616.05 84.40 47.34 180739.01 8600 44.00 1610885.08 88.11 40.16 1711173.45 88.11 40.16 1811356.45 90.00 35.00 191609.31 95.45 29.72 2011724.49 95.45 29.72 2111991.22 91.W 20.00 2212291.32 90.04 803 2312698.52 90.04 8.03 2412774.38 90.W 5.00 2512947.76 90.94 358.06 2813215.48 90. W 358.0 273317.10 90.00 354.00 2813570.35 80.94 349.44 2913573.04 80.94 349.44 303857.54 89.95 34246 3114705.29 9005 30.44 304736.85 90.05 30844 3314738.03 90.08 308.47 Pad Elevation: 50.10 7 518" x 4 112" x SECTION DETAILS DieTFace VSect Target 0.00 0.00-2080.35 KOP: 16°1100' DL$, -20' TF, for 13' 16.00 -20.00-2077.70 0.00 0.00-2073.49 7.00 -16.50-2040.55 Start 7'/100' DLS, -16.5° TF, for 139.74' 0.00 0.00-1953.63 3.00 -135.59-1948.15 1H-1041.1 T01 W3018 RP 3.00 -134.90-1906.77 B7 0.000.00-1781.17 AdII'usl TF to -134 9°, far 141.56' 112dfor 3% 13' 3.00 -68.22-1751.02 1 H-1041.1 T02 M3018 RP 3.00 -44.37-168048 0.00 0.00-1678.65 3.00 -112.56-1408.95 IH -1041.1 T03 W3018 RP 3.00 -113.77-132246 Start 3-11W DLS, -112,%° TF, for 512.07' 0.00 0.00-1144.03 3.00 -64.501058.41 1H -104L1 T04 W3018 RP 3.00 -61.23 -950.17 Hold for 264.55' 0.00 0.00 -729.90 3.00 -69.98 -584.95 111-1041.1 T05 063018 RP 3.00 -43.99 -371.77 Hold for 288.37' 0.00 0.00 -272.19 4.00 -114.31 30aft 1H -100L1 TW 063018 RP 4.00 -94.54 259.75 Adusl TF to 43.99°, for 25286' 0.00 0.00 662.95 4.00 -90,67 738.30 1H-10411 T07 W3018 RP 4.00 -90.00 914.51 Stan 4°/100' DLS, -114.31° TF, for 266.73' 0.00 0,00 1179,09 4ol) -90.001280.44 1HANI-1 TO 03018 RP 4.00 -153.51 1529.95 Hoid for 407.2' Start 4°1100' DLS, -90.67- TF, for 75.85! 0.00 0.00 15M,57 UG C - 4.00 -38.041807.20 114-10411 T09 063018 RP 401 -89.842495.21 0.00 0.00 2514.83 " - 4.00 44.35 2515.56 iH-10411 T10 03018 RP Plan Summa 0 0 0 -'- 8308 0350 8560 0580 - 0750 0750 - 0940 0940 - 8130 8130 8320 8320 9510 9510 9700 9700 9880 9980 10230 10230 10490 10490 10750 10750 11010 roto 11 70 11270 11540 ttuo - 11800 11800 123M 12uo 12830 12830 13350 13350 13800 13860 143M 14380 14890 p26 ue90 15401180 15400 - 15917 Magnetic Model & Date: BGGM20101-Aug-18 North is 17.06° East of True North (Magnetic Declination) c Dip & Field Strength: 80.91° 57449nT Lithalogy Column Annotation Checked by: KOP: 16°1100' DL$, -20' TF, for 13' ccepted by Hold for 20' �repared V. Osara Start 7'/100' DLS, -16.5° TF, for 139.74' 9PFROST Hold for 334.49' Stan 3°1100• DLS, -135.59° TF, for 20.81' B7 AdII'usl TF to -134 9°, far 141.56' 112dfor 3% 13' T-3 Stan 3°1100• DLS, 68.22° TF, for 8929- e., Adjust TF to 34.37°, for 181.34' Hold for 4.36' Start 3-11W DLS, -112,%° TF, for 512.07' Adjust TF to -113.77°, for 132.79' Hold for 264.55' Start 3-11W DLS, 84.5° TF, for 122,97- Adjust TF to 61.23°, for 146 07' K-15 Hold for 288.37' Stan 3°11 W' DLS, 69.98° TF, for 183' Adusl TF to 43.99°, for 25286' Hoid for 115.18' Stan 4°/100' DLS, -114.31° TF, for 266.73' Ad'usl TF to -94.54°, for 3M. 1 V Hoid for 407.2' Start 4°1100' DLS, -90.67- TF, for 75.85! UG C - Adjust TFto-90°, for 173.38' Hold for 267.72' Start4°/100' DLS, -90° TF, for 101.82' a"1)G 8 J7'UG A Adjust TFto453.51°, for253.25' " - Hold for 2.69' Stan 4°/100• DLS, -38.04° TF, for 284,49- 84 49'Start Na Stan4.01 °/100' DLS, -89.84° TF, for 847.76 Hold for 31.56' Start 4°1109 DLS, 44.35° TF, for 1.17' Adjust TF to 83.7°, for 254.3T Hold for 924.37'11 °nne.rnrn - = 4 A9 '4f -A2 By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surrounding wells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.) teer�n approve it as the basis for the final well plan and wellsite drawings. I also acknowledge that unless nntifted ntherwise all taroets have a 100 feet lateral tolerance. by Checked by: ccepted by Approved by: �repared V. Osara Huy Bui Anh Erik Sterk 1 H-104L1wp24 Plan View While driffing production section staV within target poiVgon lateral/of plan, unless notified otherwise. Ip 0 3Q ti _ 0p 4 1/2" x 6-3/4"-- l 3000 1H- 11 063018 R Qb ^3 Oa 1H -104L1 0063018 2000 c_ 1H -104L1 T09 63018 N J 01000 20'x 42" 1H -104L1 T08 163018 0 + 1H-1041-1 T07 t63018 o9 r o z 0 0- 1 H -104L1 TA 063018 5 0 10 3/4" x 13 1/2" 1H-1 1 T05 063018 -1000 000 M -1041-1 T04 063018 1H-1041-1 T03 063018 -2000- x 9-7/ Li 11H-104LJI02 63018 P 1H -104L1 T01 063018 P 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 West( -)/East(+) (1000 usft/in) 1 H -104L1 wp24 Vertical Section at 0.00° (650 usft/in) 1 H -104L1 wp24 Section View 3600 x 7 5/ 'x 9-7/8" 'o A ' O ' O R 3750 a � p A 0 0 0 m O W o 4 1/2" x 6-314" '0 0 3900 %900- N 4) 04050- 4050m (a U r d 2 4200 4350- -1950 -1300 -650 0 650 1300 1950 2600 3250 Vertical Section at 0.00° (650 usft/in) ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 11-1-104 500292360600 Plan: 1H-1041-1 Plan: 1 H-104L1wp24 Standard Proposal Report 03 July, 2018 ConocoPhillips ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kuparuk River Unit Site: Kuparuk I Pad Well: Plan: 11-1-104 Wellbore: Plan: 1H-1041-1 Design: 1H-104Liwp24 Schlumberger Standard Proposal Report Local Co-ordinate Reference: Well Plan'. 1 H-104 TVD Reference: Plan: 54.1+39 Q 93.10usft (Doyon 142) MD Reference: Plan: 54.1+39 @ 93.10usft (Dayan 142) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor site Kupamk 1H Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.37 ° Well Plan: 11-1-104 Depth From Depth To Well Position -N/-S 811 26 usft Northing: Latitude: 1H-104Liwp24(Plan: 1H-1041-1) +E/ -W 376.91 usft Easting: Longitude: Position Uncertainty IH-104L1wp24(Plan: IH -1041-1) 0.00 usft Wellhead Elevation: Ground Level: 54.10 usft Wellbore Plan: 1H-104LI Magnetics Model Name Sample Date Declination Dip Angle Field Strength V) P) (0) BGGM2018 8/1/2018 17.06 80.91 57,449 Design 1H-104L1wp24 Audit Notes: Version: Phase: PLAN Tie On Depth: Vertical Section: Depth From (TVD) +NIS +E/ -W (usft) (usft) (usft) 39.00 0.00 Goo Plan Survey Tool Program Data 7/10/2018 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 6,365.93 8,700.00 1H-104Liwp24(Plan: 1H-1041-1) MWD-INC_ONLY MWD-INC—ONLY—FILLER 2 8,700.00 10,200.00 IH-104L1wp24(Plan: IH -1041-1) MWD MWD - Standard 3 8,700.00 15,916.76 IH-104Liwp24(Plan: IH -1041.1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,365.93 Direction (I 0.00 7/102018 11:36:53AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEOMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 11-1-104 Wellbore: Plan: 1H-1041-1 Design: 1H-104L1wp24 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Schlumberger Standard Proposal Report Well Plan: 11-1-104 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature Plan Sections Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth -NI-S +El -W Rate Rate Rate TFO 1 (usft) (°) (1) (usft) (usft) (usft) (°H00ul (°HOOusft) ('Moousft) (°) Target 8,365.93 79.11 78.43 3,828.10 -2,080.35 6,141.52 0.00 0.00 0.00 0.00 8,378.93 81.06 77.70 3,830.34 -2,077.70 6,154.05 16.00 15.04 -5.54 -20.00 8,398.93 81.06 77.70 3,833.45 -2,073.49 6,173.35 0.00 0.00 0.00 0.00 8,538.67 90.45 74.94 3,843.78 -2,040.55 6,308.58 7.00 6.72 -1.98 -16.50 8,873.15 90.45 74.94 3,841.18 -1,953.63 6,631.57 0.00 0.00 0.00 0.00 8,893.96 90.00 74.50 3,841.10 -1,948.15 6,651.64 3.00 -2.14 -2.10 -135.59 1H-10411 T01 063011 9,035.52 87.00 71.49 3,844.80 -1,906.77 6,786.93 3.00 -2.12 -2.13 -134.90 9,431.65 87.00 71.49 3,865.51 -1,781.17 7,162.06 0.00 0.00 0.00 0.00 9,520.94 88.00 69.00 3,869.40 -1,751.02 7,246.00 3.00 1.12 -2.79 -68.221H-1041-1 T02 06301i 9,702.29 91.89 65.20 3,869.57 -1,680.48 7,412.99 3.00 2.15 -2.10 -44.37 9,706.64 91.89 65.20 3,869.43 -1,678.65 7,416.94 0.00 0.00 0.00 0.00 10,218.71 86.00 51.00 3,878.90 -1,408.95 7,850.32 3.00 -1.15 -2.77 -112.561H-1041-1 T03063011 10,351.50 84.40 47.34 3,890.01 -1,322.46 7,950.42 3.00 -1.20 -2.76 -113.77 10,616.05 84.40 47.34 3,915.81 -1,144.03 8,144.03 0.00 0.00 0.00 0.00 10,739.02 86.00 44.00 3,926.10 -1,058.41 8,231.67 3.00 1.30 -2.71 -64.501H-10411 T0406301; 10,885.08 88.11 40.16 3,933.60 -950.17 8,329.40 3.00 1.45 -2.63 -61.23 11,173.45 88.11 40.16 3,943.09 -729.90 8,515.28 0.00 0.00 0.00 0.00 11,356.45 90.00 35.00 3,946.10 -584.95 8,626.82 3.00 1.03 -2.82 -69.98 IH -1041-1705063011 11,609.31 95.45 29.72 3,934.08 -371.77 8,761.92 3.00 2.16 -2.09 -43.99 11,724.49 95.45 29.72 3,923.14 -272.19 8,818.76 0.00 0.00 0.00 0.00 11,991.22 91.00 20.00 3,908.10 -30.88 8,930.49 4.00 -1.67 -3.64 -114.311H-10411 T0606301: 12,291.32 90.04 8.03 3,905.38 259.75 9,003.04 4.00 -0.32 -3.99 -94.54 12,698.52 90.04 8.03 3,905.12 662.95 9,059.95 0.00 0.00 0.00 0.00 12,774.38 90.00 5.00 3,905.10 738.30 9,068.56 4.00 -0.05 -4.00 -90.67 1H-10411 T07063011 12,947.76 90.00 358.06 3,905.10 911.51 9,073.19 4.00 0.00 -4.00 -90.00 13,215.48 90.00 358.06 3,905.10 1,179.09 9,064.15 0.00 0.00 0.00 0.00 13,317.10 90.00 354.00 3,905.10 1,280.44 9,057.12 4.00 0.00 -4.00 -90.001H-10411 T0806301; 13,570.35 80.94 349.44 3,925.09 1,529.95 9,020.88 4.00 -3.58 -1.60 -153.51 13,573.04 80.94 349.44 3,925.51 1,532.57 9,020.40 0.00 0.00 0.00 0.00 13,857.54 89.95 342.46 3,948.10 1,807.20 8,951.57 4.00 3.17 -2.45 -38.04 1H-10411709063011 14,705.29 90.05 308.44 3,948.13 2,495.21 8,477.80 4.01 0.01 -4.01 -89.84 14,736.86 90.05 308.44 3,948.10 2,514.83 8,453.08 0.00 0.00 0.00 0.00 14,738.03 90.08 308.47 3,948.10 2,515.56 8,452.16 4.00 2.86 2.80 44.351H-10411 T1006301! 14,992.39 91.19 298.36 3,945.28 2,655.44 8,240.13 4.00 0.44 -3.98 -83.70 15,916.76 91.19 298.36 3,926.10 3,094.36 7,426.64 0.00 0.00 0.00 0.00 1H-10411 T11 06301E 71102018 11.36:53AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Depth Company: ConocoPhillips (Alaska) Inc Project: Kuparuk River Unit -2,080.35 Site: Kuparuk 1H Pad 3,830.34 Well: Plan: 1H-104 -2,073.49 Wellbore: Pian: 1H-10411 3,843.21 Design: 1H-104L1wp24 -2,040.55 Planned Survey -2,024.61 3,842.53 I Measured 3,841.75 -1,972.64 Depth Inclination Azimuth 3,841.10 (usft) C) (') -1,946.52 8,365.93 79.11 78.43 KOP: 16°1100' DLS, -20' TF, for 13' -1,356.73 8,366.93 79.26 78.37 7 5/8" x 9-7/8" 3.00 -2.14 8,378.93 81.06 77.70 Hold for 20' 3.00 -2.12 8,398.93 81.06 77.70 Start 7'1100' DES, -16.5° TF, for 139.74' 8,400.00 81.13 77.68 8,500.00 87.85 75.70 8,538.67 90.45 74.94 Hold for 334,49' -2.77 8,600.00 90.45 74.94 8,700.00 90.45 74.94 8,800.00 90.45 74.94 8,873.15 90.45 74.94 Start 3'H00' DLS, -136.59' TF, for 20.81' 8,893.96 90.00 74.50 Adjust TF to -134.9', for 141.56' 3.00 8,900.00 89.87 74.37 9,000.00 87.76 72.25 9,035.52 87.00 71.49 Hold for 396.13' -1.20 -2.76 9,060.36 87.00 71.49 WS_B -2.76 9,100.00 87.00 71.49 9,200.00 87.00 71.49 9,300.00 87.00 71.49 9,400.00 87.00 71.49 9,431.65 87.00 71.49 Start 3'/100' DLS, -68.22' TF, for 89.29' 9,500.00 87.77 69.58 9,520.94 88.00 69.00 Adjust TF to -44.37', for 181.34' 9,600.00 89.70 67.34 9,700.00 91.84 65.24 9,702.29 91.89 65.20 Hold for 4.36' 9,706.64 91.89 65.20 Start 3'I100' DLS, -112.56' TF, for 512.07' 9,800.00 90.81 62.61 9,900.00 89.66 59.84 10,000.00 88.51 57.07 10,100.00 87.36 54.30 10,200.00 86.21 51.52 10,218.71 86.00 51.00 Adjust TF to -113.77', for 132.79' 10,298.10 85.04 48.81 WS -A4 10,300.00 85.02 48.76 10,351.50 84.40 47.34 YnW f , 1G6 FR' Local Co-ordinate Reference: . -Kup1 TVD Reference: MD Reference: North Reference: Survey Calculation Method: Vertical -1,886.33 Depth +N/ -S (usft) (usft) 3,828.10 -2,080.35 3,828.29 -2,080.15 3,830.34 -2,077.70 3,833.45 -2,073.49 3,833.61 -2,073.27 3,843.21 -2,050.35 3,843.78 -2,040.55 3,843.31 -2,024.61 3,842.53 -1,998.63 3,841.75 -1,972.64 3,841.18 -1,953.63 3,841.10 -1,948.15 3,841.11 -1,946.52 3,843.18 -1,917.81 3,844.80 -1,906.77 3,846.10 -1,898.89 3,848.17 -1,886.33 3,853.40 -1,854.62 3,858.63 -1,822.92 3,863.85 -1,791.21 3,865.51 -1,781.17 3,868.63 -1,758.42 3,869.40 -1,751.02 3,870.99 -1,721.64 3,869.65 -1,681.44 3,869.57 -1,680.48 3,869.43 -1,678.65 3,867.23 -1,637.60 3,866.81 -1,589.47 3,868.41 -1,537.17 3,872.02 -1,480.84 3,877.63 -1,420.63 3,878.90 -1,408.95 3,885.10 -1,357.98 3,885.26 -1,356.73 3,890.01 -1,322.46 Vertical +E/ -W Section (usft) (usft) 6,141.52 -2,080.35 6,142.48 -2,080.15 6,154.05 -2,077.70 6,173.35 -2,073.49 6,174.38 -2,073.27 6,271.19 -2,050.35 6,308.58 -2,040.55 6,367.81 -2,024.61 6,464.37 -1,998.63 6,560.93 -1,972.64 6,631.57 -1,953.63 6,651.64 -1,948.15 6,657.45 -1,946.52 6,753.21 -1,917.81 6,786.93 -1,906.77 Schlumberger Standard Proposal Report Well Plan: 1H-104 Plan: 54.1+39 Q 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature Dogleg Build Tum Rate Rate Rate ('/t00usft) ('/100usft) ('/100usft) 0.00 0.00 0.00 16.00 15.03 -5.58 16.00 15.04 -5.55 0.00 0.00 0.00 7.00 6.71 -2.01 7.00 6.72 -1.99 7.00 6.72 -1.97 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.00 -2.14 -2.10 3.00 -2.12 -2.13 3.00 -2.12 -2.13 3.00 -2.12 -2.13 6.810.46 -1.898.89 0.00 0.00 0.00 6,647.99 -1,886.33 0.00 0.00 0.00 6,942.69 -1,854.62 0.00 0.00 0.00 7,037.38 -1,822.92 0.00 0.00 0.00 7,132.08 -1,791.21 0.00 0.00 0.00 7,162.06 -1,781.17 0.00 0.00 0.00 7,226.42 -1,758.42 3.00 1.12 -2.79 7,246.00 -1,751.02 3.00 1.12 -2.79 7,319.37 -1,721.64 3.00 2.15 -2.10 7,410.91 -1,681.44 3.00 2.15 -2.10 7,412.99 -1,680.48 3.00 2.14 -2.10 7,416.94 -1,678.65 0.00 0.00 0.00 7,500.75 -1,637.60 3.00 -1.15 -2.77 7,588.39 -1,589.47 3.00 -1.15 -2.77 7,673.59 -1,537.17 3.00 -1.15 -2.77 7,756.12 -1,480.84 3.00 -1.15 -2.77 7,835.76 -1,420.63 3.00 -1.14 -2.78 7,850.32 -1,408.95 3.00 -1.14 -2.78 7,910.86 -1,357.98 3.00 -1.21 -2.76 7,912.29 -1,356.73 3.00 -1.20 -2.76 7,950.42 -1,322.46 3.00 -1.20 -2.76 7/102018 11:36:53AM Page 4 COMPASS 5000.14 Build 85 Schlumberger ConocoPhi I I i ps Standard Proposal Report Database: OAKEDMP2 Local Coordinate Reference: Well Plan: 1H-104 Company: ConowPhillips (Alaska) Inc. -Kup1 TVD Reference: Plan. 54.1+39 Q 93.10usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Site: Kuparuk 1 H Pad North Reference: True Well: Plan: 1 H-104 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-104L1 Design: 1 H-104L1 wP24 Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth -NIS +El-W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100uaft) (°1100usft) (°1100usft) 10,400.00 8440 47.34 3,894.74 -1,289.74 7,985.92 -1,289.74 0.00 0.00 0.00 10,500.00 8440 47.34 3,904.49 -1,222.30 8,059.10 -1,222.30 0.00 0.00 0.00 10,600.00 84.40 47.34 3,914.25 -1,154.85 8,132.29 -1,154.85 0.00 0.00 0.00 10,616.05 84.40 47.34 3,915.81 -1,144.03 8,144.03 -1,144.03 0.00 0.00 0.00 Start 3°1100' DLS, -64.5° TF, for 122.97' 10,700.00 65.49 45.06 3,923.21 -1,086.15 8,204.38 -1,086.15 3.00 1.30 -2.72 10,739.02 86.00 44.00 3,926.10 -1,058.41 8,231.67 -1,058.41 3.00 1.30 -2.71 Adjust TF to -61.23°, for 146.07' 10,800.00 86.88 42.39 3,929.89 -1,014.04 8,273.33 -1,014.04 3.00 1.45 -2.63 10,885.08 88.11 40.16 3,933.60 -950.17 8,329.40 -950.17 3.00 1.45 -2.63 Hold for 288,37' 10,900.00 88.11 40.16 3,934.09 -938.77 8,339.01 -938.77 0.00 0.00 0.00 11,000.00 88.11 40.16 3,937.38 -862.39 8,403.47 -862.39 0.00 0.00 0.00 11,052.24 88.11 40.16 3,939.10 -822.49 8,437.15 -822.49 0.00 0.00 0.00 WS-A3 11,100.00 88.11 40.16 3,940.67 -786.01 8,467.93 -786.01 0.00 0.00 0.00 11,173.45 88.11 40.16 3,943.09 -729.90 8,515.28 -729.90 0.00 0.00 0.00 Start 3°1700' DLS, -69.98° TF, for 183' 11,200.00 88.39 39.41 3,943.90 -709.51 8,532.26 -709.51 3.00 1.03 -2.82 11,300.00 89.42 36.59 3,945.81 -630.74 8,593.81 -630.74 3.00 1.03 -2.82 11,356.45 90.00 35.00 3,946.10 -584.95 8,626.82 -584.95 3.01 1.03 -2.82 Adjust TF to -63.99°, for 252.86' 11,400.00 90.94 34.09 3,945.74 -549.08 8,651.52 -549.08 3.00 2.16 -2.08 11,500.00 93.10 32.01 3,942.22 -465.32 8,706.01 -465.32 3.00 2.16 -2.09 11,600.00 95.25 29.91 3,934.94 -379.81 8,757.31 -379.81 3.00 2.15 -2.10 11,609.31 95.45 29.72 3,934.08 -371.77 8,761.92 -371.77 3.00 2.15 -2.10 Hold for 115.18' 11,700.00 95.45 29.72 3,925.46 -293.36 8,806.67 -293.36 0.00 0.00 0.00 11,724.49 95.45 29.72 3,923.14 -272.19 8,818.76 -272.19 0.00 0.00 0.00 Start 4°1100' DLS, -114.31° TF, for 266.73- 11,800.00 94.20 26.96 3,916.78 -205.96 8,854.46 -205.96 4.00 -1.65 -3.65 11,900.00 92.53 23.31 3,910.91 -115.61 8,896.85 -115.61 4.00 -1.67 -3.64 11,991.22 91.00 20.00 3,908.10 -30.88 8,930.49 -30.88 4.00 -1.68 -3.63 Adjust TF to 4W64°, for 300.11' 12,000.00 90.97 19.65 3,907.95 -22.62 8,933.47 -22.62 4.00 -0.32 -3.99 12,100.00 90.65 15.66 3,906.53 72.64 8,963.79 72.64 4.00 -0.32 -3.99 12,200.00 90.33 11.67 3,905.67 169.79 8,987.42 169.79 4.00 -0.32 3.99 12,291.32 90.04 8.03 3,905.38 259.75 9,003.04 259.75 4.00 -0.32 -3.99 Hold for 407.2' 12,300.00 90.04 8.03 3,905.37 268.34 9,004.26 268.34 0.00 0.00 0.00 12,400.00 90.04 8.03 3,905.31 367.36 9,018.23 367.36 0.00 0.00 0.00 12,500.00 90.04 8.03 3,905.25 466.37 9,032.21 466.37 0.00 0.00 0.00 12,600.00 90.04 8.03 3,905.19 565.39 9,046.18 565.39 0.00 0.00 0.00 12,696.52 90.04 8.03 3,905.12 662.95 9,059.95 662.95 0.00 0.00 0.00 Start 4°1100' DLS, -90.67° TF, for 75.85' 12,700.00 90.04 7.97 3,905.12 664.41 9,060.16 664.41 4.00 -0.05 4.00 12,774.38 90.00 5.00 3,905.10 738.30 9,068.56 738.30 4.00 -0.05 4.00 Adjust TF to -60°, for 173.38' 12,800.00 90.00 3.98 3,905.10 763.85 9,070.57 763.85 4.00 0.00 4.00 12,900.00 90.00 359.98 3,905.10 863.77 9,074.01 863.77 4.00 0.00 4.00 12,947.76 90.00 358.06 3,905.10 911.51 9,073.19 911.51 4.00 0.00 4.00 Hold for 267.72' 7/102018 11:36:53AM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kupamk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-104 Wellbore: Plan: 1H-10411 Design: 1H-1041-1wp24 Planned Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Measured Vertical Dogleg Vertical Tum Depth Inclination Azimuth Section Depth -NIS (usft) (°) (I (usft) (usft) 13,000.00 90.00 358.06 3,905.10 963.73 13,100.00 90.00 358.06 3,905.10 1,063.67 13,200.00 90.00 358.06 3,905.10 1,163.61 13,215.48 90.00 358.06 3,905.10 1,179.09 Start 4°/100' DLS, -00° TF, for 101.62' 9,058.81 1,263.42 4.00 13,300.00 90.00 354.68 3,905.10 1,263.42 13,317.10 90.00 354.00 3,905.10 1,260.44 Adjust TF to -163.61°, for 253.25' -1.79 9,032.88 1,461.30 13,400.00 87.03 352.52 3,907.25 1,362.73 13,500.00 83.46 350.72 3,915.54 1,461.30 13,570.35 80.94 349.44 3,925.09 1,529.95 Hold for 2.69' 3.15 -2.49 8,993.92 1,655.71 13,573.04 80.94 349.44 3,925.51 1,532.57 Start 4°1100' DLS, 48.04° TF, for 284A9' 3.17 -2.44 13,600.00 81.79 348.77 3,929.56 1,558.74 13,700.00 84.95 348.31 3,941.10 1,655.71 13,800.00 88.12 343.86 3,947.13 1,752.14 13,857.54 89.95 342.46 3,948.10 1,807.20 Start 4.01°1100' DLS, -89.84° TF, for 847.76' 2,118.30 4.01 13,900.00 89.95 340.76 3,948.14 1,847.49 14,000.00 89.97 336.74 3,948.20 1,940.67 14,100.00 89.98 332.73 3,948.25 2,031.09 14,200.00 89.99 328.72 3,948.28 2,118.30 14,300.00 90.00 324.70 3,948.29 2,201.87 14,400.00 90.01 320.69 3,948.28 2,281.40 14,500.00 90.02 316.68 3,948.25 2,356.49 14,600.00 90.03 312.66 3,948.20 2,426.78 14,700.00 90.05 308.65 3,948.13 2,491.92 14,705.29 90.05 308.44 3,948.13 2,495.21 Hold for 31.66' -3.96 8,240.13 2,655.44 4.00 14,736.86 90.05 308.44 3,948.10 2,514.83 Start 4°N00' DLS, 44.35° TF, for 1.17' 0.00 8,145.45 2,706.54 14,738.03 90.08 308.47 3,948.10 2,515.56 Adjust TF to -83.7°, for 264.37' 0.00 0.00 7,969.48 14,800.00 90.35 306.01 3,947.87 2,553.06 14,900.00 90.79 302.03 3,946.87 2,608.99 14,992.39 91.19 298.36 3,945.28 2,655.44 Hold for 924.37' 0.00 0.00 0.00 7,617.55 15,000.00 91.19 298.36 3,945.12 2,659.05 15,100.00 91.19 298.36 3,943.04 2,706.54 15,200.00 91.19 298.36 3,940.97 2,754.02 15,300.00 91.19 298.36 3,938.90 2,801.50 15,400.00 91.19 298.36 3,936.82 2,848.99 15,500.00 91.19 298.36 3,934.75 2,896.47 15,600.00 91.19 298.36 3,932.67 2,943.95 15,700.00 91.19 298.36 3,930.60 2,991.44 15,800.00 91.19 298.36 3,928.52 3,038.92 15,900.00 91.19 298.36 3,926.45 3,086.40 15,916.76 91.19 298.36 3,926.10 • 3,094.36 TD: 15916.76' MD, 3926.1' TVD .4 1/2" x 6-3/4" Schlumberger Standard Proposal Report Well Plan1 H-104 Plan: 54.1+39 @ 93.1rush (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 7/10/2018 11,36 53AM Page 6 COMPASS 5000.14 Build 65 Vertical Dogleg Build Tum +E/ -W Section Rate Rate Rate (usft) (usft) (°1100usft) (°/100usft) (°/100usft) 9,071.43 963.73 0.00 0.00 0.00 9,068.05 1,063.67 0.00 0.00 0.00 9,064.67 1,163.61 0.00 0.00 0.00 9,064.15 1,179.09 0.00 0.00 0.00 9,058.81 1,263.42 4.00 0.00 4.00 9,057.12 1,280.44 4.00 0.00 4.00 9,047.40 1,362.73 4.00 -3.58 -1.79 9,032.88 1,461.30 4.00 -3.58 -1.80 9,020.88 1,529.95 4.00 -3.57 -1.82 9,020.40 1,532.57 0.00 0.00 0.00 9,015.36 1,558.74 4.00 3.15 -2.49 8,993.92 1,655.71 4.00 3.16 -2.47 8,968.23 1,752.14 4.00 3.17 -2.44 8,951.57 1,807.20 4.00 3.17 -2.44 8,938.17 1,847.49 4.01 0.01 4.01 8,901.93 1,940.67 4.01 0.01 4.01 8,859.26 2,031.09 4.01 0.01 4.01 8,810.37 2,118.30 4.01 0.01 4.01 8,755.49 2,201.87 4.01 0.01 4.01 8,694.90 2,281.40 4.01 0.01 4.01 8,628.89 2,356.49 4.01 0.01 4.01 8,557.79 2,426.78 4.01 0.01 4.01 8,481.94 2,491.92 4.01 0.01 4.01 8,477.80 2,495.21 4.01 0.01 4.01 8,453.08 2,514.83 0.00 0.00 0.00 8,452.16 2,515.56 4.00 2.86 2.80 8,402.82 2,553.06 4.00 0.44 -3.96 8,319.96 2,606.99 4.00 0.44 -3.96 8,240.13 2,655.44 4.00 0.43 -3.98 8,233.43 2,659.05 0.00 0.00 0.00 8,145.45 2,706.54 0.00 0.00 0.00 8,057.47 2,754.02 0.00 0.00 0.00 7,969.48 2,801.50 0.00 0.00 0.00 7,881.50 2,848.99 0.00 0.00 0.00 7,793.52 2,896.47 0.00 0.00 0.00 7,705.53 2,943.95 0.00 0.00 0.00 7,617.55 2,991.44 0.00 0.00 0.00 7,529.57 3,038.92 0.00 0.00 0.00 7,441.58 3,086.40 0.00 0.00 0.00 7,426.84 3,094.36 0.00 0.00 0.00 7/10/2018 11,36 53AM Page 6 COMPASS 5000.14 Build 65 ConocoPhillips Database: OAKEDMP2 Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1H Pad North Reference: Well: Plan: 1 H-104 Survey Calculation Method: Wellbore: Plan: 1H -104L1 (usft) Design: 1H-104L1wp24 0.00 0.00 Design Targets Target Name - hit(miss target Dip Angle Dip Dir. TVD +NIS +El -W -Shape (^) (1) (usft) (usft) (usft) 1H -104L1 TOt 063018 F 0.00 0.00 3,841.10 -1,948.15 6,651.64 - plan hits target center - Circle (radius 100.00) 1H-10411 T01 063018 F 0.00 0.00 3,841.10 -1,948.15 6,651.64 - plan hits target center - Circle (radius 1,320.00) 1H -104L1 T02063018 F 0.00 0.00 3,869.40 -1,751.02 7,246.00 - plan hits target center - Circle (radius 100.00) 1H-104LI T03063018 F 0.00 0.00 3,878.90 -1,408.95 7,850.32 - plan hits target center - Circle (radius 100.00) 1H -104L1 T0806301 OF 0.00 0.00 3,905.10 1,280.44 9,057.12 - plan hits target center - Circle (radius 1,320.00) 1 H-1041-1 T08 063018 F 0.00 0.00 3,905.10 1,280.44 9,057.12 - plan hits target center - Circle (radius 100.00) 1 H-1041_1 707 063018 F 0.00 0.00 3,905.10 738.30 9,068.56 - plan hits target center - Circle (radius 100.00) 1 H -1 04L1 T06 063018 F 0.00 0.00 3,908.10 -30.88 8,930.49 - plan hits target center -Circle (radius 100.00) 1H-104LI T04063018 F 0.00 0.00 3,926.10 -1,058.41 8,231.67 - plan hits target center - Circle (radius 100.00) 1H-1041_1 T11 063018 R 0.00 0.00 3,926.10 3,094.36 7,426.84 - plan hits target center - Circle (radius 1,320.00) 1H-1041-1 T04063018 F 0.00 0.00 3,926.10 -1,058.41 8,231.67 - plan hits target center - Circle (radius 1,320.00) 1H-10411 T11063018 R 0.00 0.00 3,926.10 3,094.36 7,426.84 - plan hits target center - CirGe (radius 100.00) 1H -104L1 T05063018 F 0.00 0.00 3,946.10 -584.95 8,626.82 - plan hits target center - Circle (radius 100.00) 1 H-1041-1 T10 063018 F 0.00 0.00 3,948.10 2,515.56 8,452.16 - plan hits target center - Circle (radius 100.00) 1H-1041.1 T0O 063018 F 0.00 0.00 3,948.10 1,807.20 8,951.57 - plan hits target center - Cirde (radius 100.00) Schlumberger Standard Proposal Report Well Plan: 111-104 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 7/10/2018 11,36:53AM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips Database: Company: Project: Site: Well: Wellbore: Design: Casing Points OAKEDMP2 ConowPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1 H Pad Plan: 1H-104 Plan: 1H -104L1 1H-104L1wp24 Schlumberger Standard Proposal Report Local Co-ordinate Reference: Well Plan: 1 H-104 TVD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) MD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) North Reference: True Survey Calculation Method: asrnmueserJe -'.: Minimum Curvature . ._,........ ........ ._._..-........„. Measured Vertical Casing Hole Depth Depth Depth Diameter Diameter (usft) (usft) Name r) O 118.10 118.10 20” x 42" 20 42 1,918.25 1,800.00 10 3/4" x 13 1/2" 10-3/4 13-1/2 8,366.93 3,827.59 7 5/8" x 9-7/8" 7-5/8 9-7/8 15,916.76 3,926.10 41/2"x6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 1,724.87 1,641.10 Base Pfrost 1,936.03 1,814.10 T3 2,266.31 2,051.10 K15 5,414.37 3,053.10 UG -C 6,489.58 3,360.10 UG_B 6,832.81 3,458.10 UG_A 7,169.03 3,554.10 Na 8,128.88 3,783.10 WS_D 8,352.33 3,825.10 WS_C 9,060.36 3,846.10 WS_B / 10,298.10 3,885.10 WS_A4 11,052.24 3,939.10 WS -A3 7/10/2018 1136: 53AM Page 8 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Local Coordinate Reference: Company: ConowPhillips(Alaska) Inc.-Kupl TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kupamk 1 H Pad North Reference: Well: Plan: 1H-104 Survey Calculation Method: Wellbore: Plan: 1H-10411 (usft) Design: 1H-104Ltwp24 3,828.10 Schlumberger Standard Proposal Report Well Plan: 1H-104 Plan. 54.1+39 ®93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +EI -W (usft) (usft) (usft) (usft) Comment 8,365.93 3,828.10 -2,080.35 6,141.52 KOP: 16"/100'DLS,-20'TF, for 13' 8,378.93 3,830.34 -2,077.70 6,154.05 Hold for 20' 8,398.93 3,833.45 -2,073.49 6,173.35 Start 7°/100' DLS, -16.5° TF, for 139.74' 8,538.67 3,843.78 -2,040.55 6,308.58 Hold for 334.49' 8,873.15 3,841.18 -1,953.63 6,631.57 Start 3'/100' DLS, -135.59° TF, for 20.81' 8,893.96 3,841.10 -1,948.15 6,651.64 Adjust TF to -134.9", for 141.56' 9,035.52 3,844.80 -1,906.77 6,786.93 Hold for 396.13' 9,431.65 3,865.51 -1,781.17 7,162.06 Start 3°/100' DLS, -68.22° TF, for 89.29' 9,520.94 3,869.40 -1,751.02 7,246.00 Adjust TF to -44.37°, for 181.34' 9,702.29 3,869.57 -1,680.48 7,412.99 Hold for4.36' 9,706.64 3,869.43 -1,678.65 7,416.94 Start 3"/100' DLS, -112.56° TF, for 512.07' 10,218.71 3,878.90 -1,408.95 7,850.32 Adjust TF to -113.77°, for 132.79' 10,351.50 3,890.01 -1,322.46 7,950.42 Hold for 264.55' 10,616.05 3,915.81 -1,144.03 8,144.03 Start 3"/100' DLS, -64.5° TF, for 122.97' 10,739.02 3,926.10 -1,058.41 8,231.67 Adjust TF to -61.23°, for 146.07' 10,885.08 3,933.60 -950.17 8,329.40 Hold for 288.37' 11,173.45 3,943.09 -729.90 8,515.28 Start 3'/100' DLS, -69.98° TF, for 183' 11,356.45 3,946.10 -584.95 8,626.82 Adjust TF to 43.99', for 252.86' 11,609.31 3,934.08 -371.77 8,761.92 Hold for 115.18' 11,724.49 3,923.14 -272.19 8,818.76 Start 4°/100'DLS,-114.31' TF, for 266.73' 11,991.22 3,908.10 -30.88 8,930.49 Adjust TF to -94.54°, for 300.11' 12,291.32 3,905.38 259.75 9,003.04 Hold for 407.2' 12,698.52 3,905.12 662.95 9,059.95 Start 4°/100'DLS,-90.67°TIF, for 75.85' 12,774.38 3,905.10 738.30 9,068.56 Adjust TF to -90', for 173.38' 12,947.76 3,905.10 911.51 9,073.19 Hold for 267.72' 13,215.48 3,905.10 1,179.09 9,064.15 Start 4"/100' DLS, -90' TF, for 101.62' 13,317.10 3,905.10 1,280.44 9,057.12 Adjust TF to -153.51°, for 253.25' 13,570.35 3,925.09 1,529.95 9,020.88 Hold for 2.69' 13,573.04 3,925.51 1,532.57 9,020.40 Start 4"/100'DLS, -38.04"TF, for 284.49' 13,857.54 3,948.10 1,807.20 8,951.57 Start 4.01 °/100' DLS, -89.84° TF, for 847.76' 14,705.29 3,948.13 2,495.21 8,477.80 Hold for 31.56' 14,736.86 3,948.10 2,514.83 8,453.08 Start 4°/100' DLS, 44.35' TF, for 1.17' 14,738.03 3,948.10 2,515.56 8,452.16 Adjust TF to -83.7°, for 254.37' 14,992.39 3,945.28 2,655.44 8,240.13 Hold for 924.37' 15,916.76 3,926.10 3,094.36 71426.84 TD: 15916.76' MD, 3926.1' TVD 7/102018 11.36.53AM Page 9 COMPASS 5000.14 Build 85 ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad Plan: IH -104 Plan: IH -104L1 500292360600 1H-104L1wp24 ConocoPhillips Clearance Summary Anticollision Report 03 July, 2018 Truly. cylinder Norm Proximity Scan on current Suryey Data (Nonh Reference? Reference Design: he pa n,k 1H Pad - Plan: IH -104 -Plan: 1 H-104Lt-1H 104Ltwp24 Datum Height: Plan: 54.1,39 @ 93.10usft(Ooyan 1421 Scan Range: 8.360.00 to 15,916]6 ash. Measured Depth. Scan Radius is 1,]8].78 usf1, clearance FactorcutoH is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 85 Scan Type: GLOBAL FILTER APPLIED. All we11,ma-thin 200'+ 10011000 of reference Scan Type: 25 00 ConocoPhillips ConocoPhillips Anticollision Report for Plan: 1 H-104 -1 H-104L1wp24 ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Tray. Cylinder Norah Proximity Scan on Current Survey Data (North Reference) 1,173.40 15,910.64 947.09 Reverence Design: KupamklH Pad -Plan: 1M -104 -Plan: 1H-10411-1H-T04L1wp24 5.185 Clearance Factor Pass - Major Risk Scan Range: 8,360.00 to 15,916.76 usn. Measured Depth. 1,184.77 15,912.30 960.77 Scan Radius is 1,787.78 son. Clearance Factor cutoff Is Ungraded. Max Ellipse Separation Is Unlimited 5,289 Clearance Factor Pass - Measured Minimum awasured Ellipse jaMeasured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum separation Warning Comparison Well Nam. - Wel@ore Name -Oesi9n (un) (ush) lush) (us") usn Kuparuk 1H Pad 1H -103 -1H -103-1H-103 1H -103 -1H -10311 -1H -103L1 1H -103 -1H -10312-1H-10312 1H -103 -1H -10313-1H-10313 1H -103 -1H -10314-1H-1031_4 1H -108 -1H -108A -1+108A 1 H-100 -1 H-108 A -1 +108A 1H.108 -Plan iH-108B -1 H-1088 wp04 111 -108 -Plan iH-108B - lH-1080 wp04 111 -100 -Plan. iH-10813-1H-108Bvg04 111 -108 -Plan 1 H-108 B -1 H-1080 wp04 1H -110 -1H -110-1H-110 1H -113 -1H -113-1H-113 Plan: 111-104 - Wan: 1H -104-1H-104"26 Plan: 111 -104 -Plan: 1H -104-1H-104"26 Rig: 1H-115 -IH-115- 111-115e,;,22 15,910.64 1,173.40 15,910.64 947.09 11,650.40 5.185 Clearance Factor Pass - Major Risk 15,912.30 1,184.77 15,912.30 960.77 11625.00 5,289 Clearance Factor Pass - Major Risk 8,385.44 1,247.58 8.305.44 1044A9 8,200.00 6.143 Clearance Factor Pass - Major Risk 8,361.09 1,250.73 8,381.09 1034.05 8,200A0 5.772 Clearance Factor Pass - Major Risk 8,360.00 1,296.14 8,360.97 1.082.22 8.200A0 6.059 Clearance Factor Pass - Major Risk 6,369.28 430.43 8,369.28 229.57 9,225.00 2.099 Clearance Factor Pass - Major Risk 8.36928 438.43 8,359.28 229.57 9,225.00 2.099 Clearance Factor Pass - Major Risk 9,889.29 850.39 9,889.29 623.44 10950.00 3.747 Clearance Factor Pass - Major Risk 10,208.53 845.77 10,208.53 681.97 11,400.00 4602 Centre Distance Pass - Major Risk 9,889.29 850.39 9,889.29 623.44 10,950.00 3.747 Clearance Factor Pass - Major Risk 10,208.53 845.77 10,208.53 661.97 11,400.00 4.602 Centre Distance Pass - Major Risk 8.360.00 529.73 8,360.00 312.67 8,175.00 2.440 Clearance Factor Pass - Major Risk 12,891.02 655.40 12,B91.02 549.07 10,475.00 5601 Clearance Factor Pass - Major Risk 8,668.59 49.97 8,668.59 42.99 8.675.00 7.161 Centre Distance Pass - Major Risk 13,611.45 84.39 13,611.45 7.39 13,875.00 1.0% Clearance Factor Pass - Major Risk 14,721.69 570.76 14,72169 374.51 10,725.00 2.833 Clearance Factor Pass - Major Risk 033Wy. 2018 - 13:18 Page 205 COMPASS ConocoPhillips Anticollision Report for Plan: 1 H-104 -1 H-1O4L1wp24 Survey fool nroorand From To Survey/Plan Survey Tool lush) luso) 39.00 1,400.00 GYD-GC-S5 1,400.00 1,920.00 MWD -OFR -AK -O SC 1 920.00 0,365.93 MWDHFR-AK-CA -SO 8,365.93 8,900.00 111-10411wp24 MN INC ONLY 8,700.00 10,200.00 111-1041.1"24 MWD 8,700.00 15.916.16 lHA041-1,a24 MWD«IFR-AK-CA2 C Ellipse error terns are consisted across surrey tool tie -on points. Calculated ellipses incemorate surface mors. Separation is the actual distance beMeen ellipsoids. Distance Sesseen centres is the straight line desires baNreen viafbom centres. Clearance Factor= Distance Between profiles 1(Distance BeMeen profiles- Ellipse Separation). All station ceordnates were calculated using Me Minimum Curvature method. ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit 0 July, M18 - 13. 18 page 3 ofs COMPASS 13:19, July 03 "Is 1 H-104L1wp24 Ladder View 300 — o ma m200 I O. o N C/) I S y U 0 x100 c v U 0 9000 10000 11000 12000 13000 14000 15000 1600 Measured Depth SURVEY PROGRAM CASTNG DETAILS Depth FroDepth To Survey/Plan Tool TVD MD Name 39.00400.00 1H-104wp26 (Plan: 1H©V9J GC -SS 3827.8366.937 5/8" x 9-7/8" 1400.00920.00 1 H-104wp26 (Plan: 1 HMVQ+IFR-AK-CAZ-SC 39289016.764 1/2" x 6-3/4" 1920.03365.93 1H-104wp26 (Plan: 1HMSQ+IFR-AK-CAZ-SC 8365.93700.00 1H-104L1wp24 (Plan: MWD4UQ_ONLY 8700.00200.00 1H-104L1wp24 (Plan: T• WID4L1) 8700.00916.76 1H-104L1wp24 (Plan: MWlD4LF11R-AK-CAZ-SC N a 3 e 0 x cc60 — — _.___.._ _ o. N U) I C 0 0 w U I Equivalent Magnetic Distance 8400 8750 9100 9450 9800 10150 10500 10850 Partial Measured Depth 13:24, Jury W 2018 / 1 H-104L1wp24 TC View SURVEY PROGRAM MD Inc Azi TVD Dleg TFace Target Annotation epth Frol®epth To TOOT 365.93 79.11 78.43 3828.10 0.00 0.00 KOP: 16'/100' OLS, -20' TF, for 13' 39.001400.00 GYD-GC-SS 378.93 81.06 77.70 3830.34 16.00 -20.00 Hold for 20' 398.93 81.06 77.70 3833.45 0.00 0.00 Start 7'/100' DLS, -16.5° TF, for 139.74' 1400.001920.00 MWD+IFR-AK-CAZ-SC 538.67 90.45 74.94 3843.78 7.00 -16.50 Hold for 334.49' 1920.003365.93 MWD+IFR-AK-CAZ-SC 873.15 90.45 74.94 3841.18 0.00 0.00 Start 3°1100' DLS, -135.59° TF, for 20.81' 893.96 90.00 74.50 3841.10 3.00 -135.59 1HAD41.1701063016 RP Adjust TF to-134.9', for 141.56' 8365.933700.00 MWD-INC 035.52 87.00 71.49 3844.80 3.00 -134.90 Hold for 396.13' _ONLY 8700.007200.00 MWD 31.65 87.00 71.49 3865.51 0.00 0.00 Start 3°/100'DLS,-68.22°TIF, for 89.29' 20.94 800 69.00 3869.40 3.00 -68.22 1H-104L1 702063018 RP Adjust for 181.34' 8700.0[6916.76 MWD+IFR-AK-CAZ-SC 702.29 9889 65.20 3869.57 3.00 -44.37 Hold or4to-44.37°, 706.64 91.89 65.20 3869.43 0.00 0.00 Start 3°/100' DLS, -112.56° TF, for 512.0 218.71 86.00 51.00 3878.90 3.00 -112.56 1H-104L1 T03063018 RP Adjust TF to-113.77', for 132.79' 351.50 84.40 47.34 3890.01 3.00 -113.77 Hold for 264.55' 616.05 84.40 47.34 3915.81 0.00 0.00 Start 3°1100' DLS, -64.5° TF, for 122.97' 739.01 86.00 44.00 3926.10 3.00 -64.50 IH-1041_1 T04 063018 RP Adjust TF to -61.23", for 146.07' 885.08 88.11 40.16 3933.60 3.00 -61.23 Hold for 288.37' 173.45 88.11 40.16 3943.09 0.00 0.00 Start 3°/100' DLS, -69.98° TF, for 183' 356.45 90.00 35.00 3946.10 3.00 -69.98 IH-104LI 705063018 RP Adjust TF to .43.99', for 252.86' 09.31 95.45 29.72 3934.08 3.00 -43.99 Hold for 115.18' 724.49 99122 95.45 29.72 91.00 20.00 3923.14 3908.10 0.00 4.00 0.00 -114.31 1H-104L1 T06063018 RP Start 4°/100' DLS, -114.31' TF, for 266.7 Adjust TFto-94.54', for 300.11' CASING DETAILS 291.32 698.52 90.04 8.03 90.04 8.03 3905.38 3905.12 4.00 0.00 -94.54 0.00 Hold for 407.2' Start 4.1100' DLS, -90.67" TF, for 75.85' TVD MD Name 77438 90.00 5.00 3905.10 4.00 -90.67 1H-10411 T07063018 RP Adjust TF to-90', for 173.38' 215 4,e 358.06 90.00 3905.10 0.00 90.00 Hold for 7 3827.598366.93 7 5/8" x 9-7/8" 358.06 Start 4°/100DLS, -90" TF, for 101.62' 3926.105916.76 41/2"x6-3/4" 317.10 90.00 354.00 3905.10 4.00 -90.00 1H-1041_1 708063018 RP Adjust TF to-153.51', for253.25' 570.35 80.94 349.44 3925.09 4.00 -153.51 Hold for 2.69' 573.04 80.94 349.44 3925.51 0.00 0.00 Start 4.1100' DLS, -38.04° TF, for 284.49' 857.54 89.95 342.46 3948.10 4.00 -38.04 111-10411 T09 063018 RP Start 4.01'/100' OLS, -89.84° TF, for 847. 705.29 90.05 308.44 3948.13 4.01 -89.84 Hold for 31.56' 736.85 90.05 308.44 3948.10 0.00 0.00 Start 4.1100' DLS, 44.35' TF, for 1.17' 738.03 90.08 308.47 3948.10 4.00 44.35 11-4-10411 710 063018 RP Adjust TF to -83.7', for 254.3T 992.39 91.19 298.36 3945.28 4.00 -83.70 Hold for 924.37' 916.76 91.19 298.36 3926.10 0.00 0.00 111-10411 T11 063018 RP TD: 15916.76' MD, 3926.1' TVD 0 330 30 150 0 8366 12 8366 -8560 8560 - 8750 300 90 60 8750 - 8940 8940 - 9130 1H-104Wp2 9130 - 9320 60 9320 - 9510 9510 - 9700 3 9700 - 9960 1 9960 10230 l % 10230 - 10490 270 90 10490 - 10750 ////l!� {9 10750 - 11010 _ - �a4z - 11010 11270 �s 11270 - 11540 �\\ E 11540 - 11800 `�� 3 11800 - 12320 €' a 12320 - 12830 240 120 12830 13350 13350 - 13860 13860 14380 1 111 �,tr yl, ili A hl%q� m �, 14380 14890 i/ r % 14890 15400 210 150 15400 - 15917 ./o 180 o n. amius zo is 1H-104L1wp24 18360.00 To 15916.76 AC Wells Only 1H-0086 wp04 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 11-1-104 500292360600 Plan: 1 H -1 04L1 Plan: 1 H-104L1wp24 Error Ellipse Survey Report 03 July, 2018 Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-104 Wellbore: Plan: 1H-104LI Design: 1H-104L1wp24 Schlumberger Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1 H-104 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 Q 93.10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kupamk 1H Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.37 ° I Wellbore Magnetics Design Audit Notes: Version: Vertical Section: Plan 1H-10411 Model Name BGGM2018 1H-104Liwp24 Sample Date 8/1/2018 Declination Dip Angle Field Strength (°) (°1 (nT) 17.06 80.91 57,449 Phase: PLAN Te On Depth: 8,365.93 Depth From (TVD) +NIS +E/ -W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 0.00 Survey Tool Program Date 7/3/2018 From To (usft) (usft) Survey (Wellbore) 39.00 1,400.00 1 H-104wp26 (Plan: 1 H-104) 1,400.00 1,920.00 1 H-104wp26 (Plan: 1 H-104) 1,920.00 8,365.93 1 H-1 04wp26 (Plan: 1 H-104) 8,365.93 8,700.00 1H-10411wp24(Plan: 1H-10411) 8,700.00 10,200.00 1H-104L1wp24(Plan: iH-10411) 8,700.00 15,916.76 1H-104L1wp24(Plan: 1H-1041-1) Tool Name Description GYD-GC-SS Plan IH -104 MWD+IFR-AK-CAZ-SC ,. MWD+IFR-AK-CAZ-SC Well Position +N/S 0.00 usft Northing: Latitude: MWD+IFR-AK-CAZ-SC +E/ -W 0.00 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level: 54.10 usft I Wellbore Magnetics Design Audit Notes: Version: Vertical Section: Plan 1H-10411 Model Name BGGM2018 1H-104Liwp24 Sample Date 8/1/2018 Declination Dip Angle Field Strength (°) (°1 (nT) 17.06 80.91 57,449 Phase: PLAN Te On Depth: 8,365.93 Depth From (TVD) +NIS +E/ -W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 0.00 Survey Tool Program Date 7/3/2018 From To (usft) (usft) Survey (Wellbore) 39.00 1,400.00 1 H-104wp26 (Plan: 1 H-104) 1,400.00 1,920.00 1 H-104wp26 (Plan: 1 H-104) 1,920.00 8,365.93 1 H-1 04wp26 (Plan: 1 H-104) 8,365.93 8,700.00 1H-10411wp24(Plan: 1H-10411) 8,700.00 10,200.00 1H-104L1wp24(Plan: iH-10411) 8,700.00 15,916.76 1H-104L1wp24(Plan: 1H-1041-1) Tool Name Description GYD-GC-SS Gyrodata gyro single shots MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD-INC—ONLY MWD-INC_ONLY_FILLER MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/3/2018 121'48PM Page 2 COMPASS 5000.14 Build 85 Schlumberger Error Ellipse Report Company: ConowPhillips(Alaska) Inc.-Kupt Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1H Pad MD Reference: Well: Plan: 1H-104 North Reference: Wellbore: Plan: 1H -104L1 Survey Calculation Method: Design: 1 H-104L1wp24 Output errors are at 1H-10411 MWD Database: Plan Survey Tool Program Date 7/3/2018 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.00 1r400.00 1 H-1 04wp26 (Plan* 11-1-104) GYD-GC-SS BMs &Bies Gyrodata gyro single shots 2 1,400.00 1,920.001H-104wp26(Plan: 1H-104) MWD+IFR-AK-CAZ-SC (usa/ (°) MWD+IFR AK CAZ SCC 3 1,920.00 8,365.93 IH-104wp26 (Plan: 1H-104) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 8,365.93 8,700.00 IH-104L1wp24(Plan: IH -104L7 MWD-INC_ONLY Indiwllon ALmutn wmN .l MWD -INC ONLY FILLER 5 8,700.00 10,200.001H-104L1wp24(Plan: 1H-10411 MWD SemNnator Bemlminor MWD - Standard 6 8,700.00 15,916.76 1H-104L1wP24(Plan: 1H-1041-1 MWD-IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Well Plan: 1 H-104 Plan: 54.1+39 @ 93.1 Ousft (Doyon 142) Plan: 54.1+39 @ 93.10us%(Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and bias at survey station Mosured Indiwllon ALmutn wmN .l n199side Lateral Veru./ M ... "de SemNnator Bemlminor DepM Oeptb Error Bus Ertor Binz E. BMs &Bies Ertor Error A wnuM Tod (usa/ (°) r) (ose) (use) (usftl (usa) (ush) (usn) (usa) loam loan) W-10 PI 836593 79.11 78.43 3,828.10 11.63 -am 31.52 1.79 10.50 1.51 3.93 36,35 4.59 109,65 MN INC _ONLY (1. 4) 8,366.93 79.26 78.37 3,028.29 1183 4.96 3152 1.79 10.50 1.51 3.93 36.95 4.59 109.65 MN INC _ONLY (1. 4) 8,378.93 81.06 77.70 3,830.34 11.55 -1.00 31.45 1.80 10.50 1.51 3.93 36.95 159 109.65 MN41NC_ONLY(1, 4) 8,398.93 81.06 77.70 3,833A5 11.55 -1.00 31.47 1.00 10.50 151 3.94 36.96 4.63 109.63 MWD -INC _ONLY (1, 4) 8,400.00 81.13 77.68 31833.81 11,64 4.03 31.46 1.80 10.50 1.51 3.94 36.97 4,63 109.63 MW INC ONLY(1, 4) 8,500.00 87.65 75]0 9,843.21 10.72 -1.39 31.20 1.91 10.51 1.51 3.99 37.21 5.38 109.13 MN INC _ONLY (1, 4) 8.538.67 90.45 74.94 3,843.78 10.48 -1.54 31.37 1.96 10.52 1.51 4.01 37.47 6.09 100.61 Mw INC ONLY(1. 4) 8.600.00 90.45 74.94 3.643.31 10,50 -1.54 32.62 1.96 10.54 1.51 4.03 38.23 7.75 107.10 6 JNC ONLY (t,q 8,700.00 90.45 74.94 3,842.53 10.52 -1.54 34.48 2,20 10.56 1.51 4.19 39.49 9.32 105.06 MM (1, 5) 8,800.00 90.45 74.94 3.841.75 10.53 4.54 3413 369 10.57 1.51 4.50 40.06 9.31 104.56 MM (1. 5) 8.873.15 90.45 74.94 3,841.18 10.55 -1.54 35.65 3.04 10.59 1.51 4.75 40.51 9.34 104.17 MWD (1, 5) 8,893.96 90.00 74.50 3,841.10 10.59 -1.51 35.65 3.17 10.59 1.51 4.82 40.64 9.35 104.05 MM (1, 5) 8,900.00 89.87 74.37 3.841.11 10.61 -1.51 35.66 3.21 10.80 1.51 4.85 40.68 9.36 104.02 M vo (1, 5) 91000.00 87.76 72.25 3,843.18 10.86 -1.39 35,69 3.81 10.63 1.51 5.21 41.32 9.44 103.42 MM (1, 5) 9,035.52 87.00 71.49 3,844.80 10.97 -1.35 35.71 4.02 10.65 1.51 5.35 41.55 9.49 103.18 MM (1. 5) 9,100,00 87.00 71.49 3,648.17 11.01 -1.35 36.24 4.32 10.68 1.52 5.60 41.99 9.59 102.74 MM (1. 5) 9,200.00 87.40 71.49 3.853.40 11.07 4.35 37.11 4.79 10.75 1.52 6.00 42.70 9.79 102.03 MM (1. 5) 9,232.54 87.00 71.49 3,855.10 11.14 -1.35 38.03 5.25 10.82 1.52 6.41 43.45 10.02 10130 MM (1, 5) 9,300.00 87.40 71.49 3.858.63 11.14 -1.35 3883 5.25 10.82 1.52 6.41 43.45 10.02 101.30 MWD (1, 5) 9.40000 87.00 71.49 3.863.85 11]2 -1.35 39.00 5.72 10.91 1.53 6.83 44.24 10.28 100.54 MWO(1, 5) 9,431.65 87.00 71.49 3,865.51 11.25 -1.35 39.32 5.87 10.94 1.53 8.98 44.50 10.37 100.29 mm (1, 5) 9.500.00 87.77 69.58 3.860.83 11.23 -1.40 39.32 6.29 11.01 1.53 7.25 45.07 10.56 99.75 MWD(1. 5) 952094 88.00 89,00 3,869.40 11.23 -1.42 39.32 6.42 11.03 1.53 7.34 45.24 10.63 99.58 MWD(1, 5) 9,600.00 89.70 67.34 3,870.99 11.14 -1.51 39.51 6.87 11.11 153 7.67 45.90 10.88 98.93 MWD(1, 5) 9.700.00 91.84 65.24 3.889.85 11.10 .1.62 39.76 7.41 11.23 1.53 8.08 46.75 11.24 98.05 MM (1. 5) 9,70239 91.89 65.20 3,869.57 11.10 -1.62 3937 7.42 11.24 1,53 8.09 48.77 11.24 98.03 MM (1. 5) 9.706.64 91.89 65.20 3.869.43 11.10 -1.62 39.82 7.44 11.24 1.53 8.11 46.81 11.26 97.98 MM (1. 5) 9,800.00 90.81 62.61 3,867.23 11.30 -1.56 39.74 7.95 11.36 1.53 8.49 47.59 11.59 97.16 MM (1, 5) 7/32018 1:21:48PM Page 3 COMPASS 5000.14 Build 85 Company: ConowPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: Plan: 1H-104 Wellbore: Plan: 1H-1041-1 Design: 1H-104L1wp24 Position uncertainty and bias at survey station Schlumberger Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1H-104 Plan: 54,1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93, 10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Measured Ind..i. Avmulh WnJc.l Hi9hslde Laleml w"Ical Magnitude Semi+na)or Semlaninor Depth Minh Error Bks Error Bias Emor Bias areia: Error Error Azimulh Tod (.00 (1) 19 (uaftl (uat0 (usm (ast!) (uah) (ucu) (us0) (um1 (daft lush) r) 9,90000 89.85 59.84 3,86681 14.54 -1.51 3961 8.47 11.51 1.53 8.88 48.42 11.96 96.26 Mwo(1, 5) 10,000.00 80.51 57.07 3,068,41 11.01 .1.48 39.43 885 11.66 1.53 9.26 49.25 12.37 95.30 MWD(1, 5) 10,10000 87.36 54.30 3,872.02 12.13 -1.46 39.22 9.38 11.82 1.53 9.61 50.07 12.81 94,32 MWo(1, 5) 10,200.00 08.21 51.52 3,077.83 11.44 -134 27.75 3.29 10.91 1.53 4.68 41.92 10.03 102.04 MM+IFR-AK-CP -SC (2, 5) 10,218.71 06.00 51.00 3,070.90 11.49 -1.33 27.54 3.32 10.92 1.53 4.69 41.95 10.05 101.99 MWn+1FR-AK-CA2-SC(2. 5) 10.300.00 85.02 48.76 3.885.26 11.74 -1.28 26.61 3.43 10.96 1.54 4.72 42.08 10.17 101.72 MND+IFR-AK-CA2-SC (2, 5) 10,351.50 84,40 47.34 3.890.01 11.92 -1.26 26.01 3.50 10.99 1.54 4.74 42.16 10.25 101.55 MWD+1FR-AK-CAZ-SC(2, 5) 10,400.00 84.40 47.34 3894.74 11.% -1.26 26.15 3.50 11.01 1.54 4.76 42.23 10.31 101.40 MWWIFR-AK-GAZ-SC(2. 5) 10.500.00 84.40 4234 3,904.49 11.99 -1.26 26.43 3.50 11.06 1.55 4.80 42.37 10.43 101.08 MWD+IFR-AK-CAZ-SC (2, 6) 10,60000 04.40 0.34 3,914.25 12.04 -1.26 28.72 3.50 11.12 1.56 4.85 42.52 10.56 100.76 MWD+IFR-AR-CAZ-SC (2,5) 10,616.05 04.40 0.34 3,915.81 12.05 -1.26 26.76 3.50 11.13 1.58 4.55 42.54 10.58 100.71 MWD+IFR-AK-CAZ-SC (2,5) 10,700.00 85.49 45.06 3,923.21 11.87 -1.33 25.80 3.62 11.17 1.56 4.89 4267 10.71 100.43 MAD+IFR-AK-CAZSC(2, 5) 10,739.02 09.00 4400 3.928.o 11.79 -1.36 25.35 3.67 11.20 1.56 4.90 42.73 10.78 100.29 MWD+1FR-AK-CP -SC (2 5) 10,800.00 86.80 4239 3,929.89 11.66 -1.41 24.67 3.75 1123 1.57 4.92 42.82 10.88 100.08 MVM+IFR-AK-C -60(2,5) 10,885.08 88.11 40.16 3.933.60 11.51 -140 23.72 3.06 11.29 1.57 4.95 42.93 11.05 99.77 MWD+1FR4K-CP -SC (2, 5) 10,900.00 80.11 40.16 3,93409 11.52 -1.48 23.77 3.86 11.30 1.57 4.95 42.95 11.07 99.72 MWD+IFR-AK-CA-S",5) 11,owoo 80.11 40.16 3,937.30 11.58 -1.48 24.00 3.08 11.35 1.57 4.99 43.09 11.25 99.35 MWD+1FR-AK-CA-SC(2. 5) 11,100.00 88.11 40.16 3,940.87 1165 -1.48 24.41 3.86 11.43 1.57 5.02 43.22 11.44 99.01 MM+IFR-AK-CAZ-SC(2,5) 11,173.45 88.11 40.16 3,943.09 11.70 -1.40 24.65 3.86 11.48 1.57 5,04 43.32 11.58 98.74 MWD+IFR-AK-CAZ-SC(2,5) 11,200.00 88.39 39.41 3.943.90 11.68 -1.50 24.33 3.90 11.50 1.57 5.05 43.36 11.64 90.64 MWD+IFR-AK-CAZ-SC (2,5) 11,300.00 89,42 Use 3,945.81 11.63 -1.55 23.14 4.03 11.57 158 5.08 43.49 11.86 90.25 MN +IFR-AK-CAZ-SC (2,5) 11,356.45 90.00 35.00 3,946.10 11.61 -1.58 22.0 4.10 11.61 1.50 5.09 4157 1200 90.03 MWD+IFR-AK-CAZ-SC(2. 5) 11,463.00 9094 3409 3945.74 11sa -162 22.13 4.14 11.65 1.58 5.11 43.62 12.11 97.86 MWD+IFR-AR-CAZ-SC(2, 5) 11,500.00 93.10 32.01 3,942.22 11.68 -1.70 21 38 4.23 11.72 1.57 5.13 43.74 12.38 97.45 MW IFR-AK-CAZSC (2, 5) 11.600.00 95.25 29.91 3,934.94 11.93 -1.78 20.66 4.32 11.80 1.57 5.14 43.05 12.67 97.03 MM+IFR-AK-CAZ-SC(2, 5) 11.ars.31 95,45 29.72 3,934.09 11.96 -1.78 20.80 4.33 11.81 1.57 5.15 43.86 12.70 06.99 MWD+IFF-AK-CAZSC(2, 5) 11,700.00 95AS 29.72 3,925.46 12,04 -1.78 20.95 4.33 11.08 1.57 5.16 43.98 12.95 96.83 MWD+IFR-MKq -SC (2, 5) 11.724.49 95.45 29.J2 3.923.14 1205 -1.78 21.04 4.33 11.90 1.57 5.16 43.99 13.00 96.53 MWD+1FR-AK-CP -SC (2, 5) 11,800.00 94.20 26.96 3,916.78 12,00 -1.72 19.05 4.44 11.96 1,56 5.18 44.05 13.15 96.25 MWD+IM-AK-CAZ-SC (2,5) 11,900.00 92.53 23.31 3,9ID.91 1200 -1.65 10.32 4.57 12.05 1.56 5.19 44.14 13.30 95.09 MW0+1FR-AK-CP-8C(2, 5) 11,991.22 9100 2000 3,908.10 1208 -1.59 1708 4.67 12.13 1.56 5.21 44.21 13.45 95.56 MWD+1FR-AK-CP-SC(2,5) 12,000.00 90.97 19.65 3,907.95 12.09 -1.59 16.94 4.88 12.14 1.56 5.21 44.21 13.47 95.53 MWD+1FR-AK-CAZ-SC(2.5) 12,10000 Was 15.86 3,906.53 12.19 Ass 15.71 4.79 12.23 1.58 5.22 44.27 13.71 95.15 MWD+IFR-AK-CAZ-SC(2, 5) 12,200.00 90.33 11.67 3,905.67 12.30 -1.57 14.04 4.87 12.32 1.56 5.23 44.31 13.96 94.76 MW0+1FR-AK-GAZ-SL(2. 5) 12,29132 90.04 0.03 3,905.38 12.40 -1.66 14.43 4.93 12.40 1.56 5.24 44.33 14.19 94.42 MND+1FR.AK-DAZ-SG(2,5) 1230000 90.04 8.03 3.905.37 12.41 -1.56 14.45 4.93 12.41 1.56 5.24 44.33 1420 94.39 MM+IFR-AK-CAZ-SC(2,5) 1240000 90.04 0.03 3,905.31 12.50 -1.56 14.69 4.93 12.51 1.56 5.25 44.35 14.39 94.03 MWD+1FR-AK-GAZ-SC(2,5) 1250000 90.01 8.03 3.905.25 12.60 -1.56 14.94 4.93 12.60 1.56 5.26 44.37 14.60 93.67 MMWR-AK-CAZ-SC(2,5) 12,60000 90.04 8.03 3,905.19 12.70 -1.56 15.21 4.93 12.70 1.58 5.27 44.39 14.82 93.30 MWWIFR-AK-CAZ-SC(2,5) 12,698.52 90.04 0.03 3,905.12 12.00 -1.56 15.50 4.93 12.00 1.56 5.28 44A1 15.05 92.94 MM+IFR-N(-CAZ-SC(2, 5) 12,700.00 90.04 7.97 3,905.12 12.80 -1.56 15.49 4.94 12.80 1.56 5.28 "Al 15.05 92.93 MWWIFR-AK-CAZSC(2, 5) 12,774.38 90.00 5.00 3,905.10 12.88 -1.56 15.34 4.90 12.aB 1,58 5.29 44.42 45.24 92.65 MWD+IFR-AK-CAZSC(2, 5) 12,800.00 90.00 3.98 3,905.10 12.90 -1.56 15.35 5.00 12.90 1.56 5.29 44.42 15.31 92.56 MWD+IFR-AR-CAZSC(2, 5) 12,900.00 90.00 359.98 3,905.10 13.01 -1.58 15.88 5.04 13.01 1.55 5.29 46,42 15.58 92.19 MWD+IFR-AK-CAZSG(2,5) 12.97.76 90.00 358.06 3.905.10 13.06 -1.56 15.97 5.05 1306 1.55 5.29 44.42 15.71 92.02 MWD+IFR-AK-C -SC (2, 5) 13,000.00 90.00 358.06 3,905.10 13.11 -1.56 18.07 5.05 13.11 1.56 530 44.41 15.83 91.84 MWD+IFR-AK-CAZ-SC(2, 5) 13,100.00 90,00 358.06 3,905.10 13.22 -1.56 16.25 5.05 1322 1.56 5.30 44.40 18.06 91.50 MWD+IFR-MK- -SC (2, 5) 13,200.00 90.00 358.05 3.905.10 13.33 -1.56 16.45 5.05 13.33 1.56 5.30 44.30 16.30 91.16 MWD+IFR-AK-CA -SC (2, 5) 13.215.40 90.00 35806 3,905.10 13.35 -1.56 16.48 5.05 1335 1.56 5.30 44.38 16.34 91.10 MWD+IFR-AK-C -SC (2. 5) 13,300.00 90.00 3MAS 3,905.10 13.44 -1.56 17.13 5.97 13.4" 1.56 5.31 44.37 16.55 90.81 MWD+1FR-AK-CAZ-SC(2,5) 13,317.10 90.00 354.00 3,905.10 13.46 -1.56 17.29 5.07 13.18 1.56 5.31 44.36 1660 90+75 MWD+1FR-AK-CA-SC (2,5) 13,400.00 07.03 352.52 3,907.25 13.84 -1.56 17.67 5.07 13.55 1.56 5.31 44.34 18.72 90.50 MwD+IFRdK-CAZ-SC(2. 5) 13,500.00 83.48 350.72 3,915.54 14.69 .1.56 18.00 5.07 13.66 1.57 5.31 44.31 16.76 90.25 MM+1FR-AK-CAZ-SC(2. 5) 13,570.35 00.94 349.44 3,925.09 15.50 -1.57 10.41 507 13,74 1.57 5.31 44.29 16.79 90.00 MM+IFR-AK-CAZ-SG(2, 5) 7!32018 1:21:48PM Page 4 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kupamk River Unit Site: Kuparuk 1 H Pad Well: Plan: 11-1-104 Wellbore: Plan: 1H-1041-1 Design: 1H-104L1wp24 Position uncertainty and bias at survey station Schlumberger Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1 H-104 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usfi (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Measured ImBmtlon Avmulh Vertical Hi9fiside Lateral Vertical M,niNde semimalor semiminor OepM Depth Eno, alas Error sial Etor alas oreus E., Error Azimuth Tod ihsn) 0 PI luso) (ust) (Veal lust) (ustl (-s57 (uetl (uso) (-ft) (usn) r) 13,573.04 8094 34944 3,925.51 15.50 -1.57 18.42 5.07 13.75 1.57 5.31 44.29 16.79 90.07 MW IFR-AK-CAZ C(2, 5) 13,800.00 81.79 348]7 3.929.50 15.25 -1.50 18.65 5.07 13.70 1.58 5.31 44.28 16.07 89.98 MWD+IFR-AK-CA -SC (2, 5) 13700.00 MA5 346.31 3,941.10 14.51 -1.60 19.59 5.05 13.89 1.59 5.31 44,23 17.17 89.67 MWD+11FR-AK-CA -SC (2, 5) 13,800.00 08.12 343.86 3.947.13 14.12 -1.80 20.58 5.04 14.01 1.59 5.31 44.17 17.49 89.37 MVO -IFR -AK -CA -=(2,5) 13,857.54 89.95 342.46 3,948.10 14,08 .1.59 21.18 5.03 14.08 1.59 530 44.14 17.67 09.20 MVM+IFR-AK-cP -W(2, 5) 13.90000 ease 34076 3,948.14 14.13 -1.59 21.86 5.01 14.13 1.59 5.30 44.11 17.79 Wile MND+IFR-MG -&C(2, 5) 14,00000 89.97 336.74 3,948.20 14.25 -159 23.55 4.98 14.25 1.59 5.29 44.04 18.06 88.84 MWD+IFR-AK4-SC (2. 5) 14,100.00 89.98 33273 3,94&.25 14.37 .1.59 25.30 4.88 14.37 1.59 5.28 43.95 18.32 88.62 MWD -IFR -M -CA -SC (2,5) 14200.00 89.99 32072 3,948.28 14.49 -1.59 27.00 478 14.49 1.59 527 43.85 18.58 8644 MV JFR-AK-CAZSC(2.5) 14,300.00 90.00 324.70 3.940.29 14.61 -1.59 28.84 466 14.61 1.59 525 4377 10.82 8829 MWD+IFR-AK-CA-SC(2, 5) 14,400.00 90.01 320.69 3,948.28 14.74 -1.59 30.57 453 14.74 1.59 5.23 43.66 19.05 88.17 MWDNFR-AK-CA-SC(2, 5) 14,50000 90.02 316.68 3,948.25 14.86 -1.59 32.23 4.37 14.86 1.59 5.21 4356 19.28 88.09 MMM -IFR -AK -CA -SC (2.5) 14,600A0 90.03 31288 3.948.20 14.99 -1.59 33.81 4.20 14.99 1.59 5.19 43.45 19.46 88.04 MM -IFR -AK -CA -SC (2, 5) 14,700.00 90.05 308.65 3,946.13 15.12 -1.59 35.30 4.01 15.12 1.59 5.16 43.34 19.64 88.03 MND+IFR-AK-CALSC(2,5) 14705.29 90.05 M8,44 3.948.13 15.12 -1.59 35.37 4.00 15.12 1.59 5.16 4334 less 88.03 MWD+IFR-AK-CA-SC(2. 5) 14,736.86 90.05 308.44 3948.10 15.16 -1.59 35.36 4.00 15.16 1.59 5.15 43.30 19.70 00.02 MWD+IFR-AK-CAZSC(2, 5) 14,738.03 90.08 308.47 3,948.10 15.17 -1.59 35.35 4.00 15.16 1.59 5.15 43.30 19.70 08.02 MWD+IFR-MK- -SC R5) 14,80000 90,35 306.01 3,947,87 1525 -1.57 36.19 3.87 15.24 1.59 5.13 4324 19.78 88.01 MV.U+IFR-AK-CA-SC(2, 5) 14.900.00 90.79 302.03 3,94fi.87 15.40 -1,55 37.47 3.66 15.37 1.59 5.10 43.14 19.94 8805 MW IFR-AK-CASC(2, 5) 14,992.39 9119 290.36 3,945.28 15.54 -1.52 30.54 3.45 15.50 1.59 5.07 43.04 20.06 88.12 MWD+IFR-AK-CA -SC (2,5) 15,000.00 91.19 29&36 3,945.12 15.55 -1.52 38,53 3.45 15.51 1.59 5.07 43.04 20.07 88.12 MWWIFR-AK-CAZSC(2,5) 15.100.00 91.19 298.36 3,943.04 15.68 -1.52 38.49 3.45 15.64 1.59 5.04 42.94 23.10 88.18 MV IFR -AK -CA -SC (2, 5) 15.200.00 91.19 290.36 3.940.97 15.81 -1.52 38.45 3.45 1577 1.59 5al 42.85 20.30 88.25 MW IFR -AK -CA -SC (2. 5) 15,300.00 91.19 298.36 3,930.90 15.94 -1.52 38.42 345 1590 1.59 4.90 42.77 20.42 80.35 MWD+IFR-AK-CA-SC(2, 5) 15.400.00 91.19 290.36 3,936.02 16.08 -1.52 38.40 3.45 16.04 1.58 4.95 42]0 20.54 88.45 MWD+IFR-AK-CA -8C(2, 5) 15,500.00 91.19 298.36 3,934.75 18.21 -1.52 38.39 3.45 16.17 1.58 4.91 42.62 20.67 00.57 MVO -IFR -AK -CA -SC (2, 5) 15.600.00 91.19 298.36 3,932.67 16.35 4.52 38.39 3.45 16.31 1.58 4.00 42.56 20.79 00.70 MVO -IFR -AK -CA -SC (2, 5) 15,700.00 917,9 298.36 3,930.60 16.48 -1.52 38.40 3.45 16AS 1.58 4.05 42+60 20.92 88.84 MWD+IFR-AR-CA -SC(2, 5) 15,80000 91.19 29&.36 3,928.52 15.82 -1.52 38.41 3.45 18.58 1.50 4.83 4245 21.06 09.00 MW0+1FR-McC -SC (2,5) 15.900.00 91.19 298.36 3,926.45 16.76 -1.52 38.44 3.45 16.72 1.68 4.80 42.40 21.19 09.18 MWD+IFR-PJ( -Sc (2.5) 15,91676 91.19 29835 3926.10 16.78 -1.52 38.44 3.45 1675 1.58 679 42.40 21.22 89.21 MND+1FR-AM-CA-SC(2,5) 7!3/2018 1:21:48PM Page 5 COMPASS 5000.14 Build 85 Schlumberger Error Ellipse Report Company: ConccoPhillips (Alaska) Inc. -Kupi Local Coordinate Reference: Well Plan: 11-1-104 Project: Kupawk River Unit TVD Reference: Plan. 54.1+39 @ 93.10usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Well: Plan: 1H-104 North Reference: True Wellbore: Plan: 11-1-10411 Survey Calculation Method: Minimum Curvature Design: 1 H-104Liwp24 Output errors are at 1.00 sigma 42 1,918.25 Database: OAKEDMP2 Design Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD -NIS +•E/ -W -Shape (') (1) (usft) (usft) (usft) 1H-10411 T01 063018 F 0.00 0.00 3,841.10 -1,948.15 6,651.64 - plan hits target center f') 1") 118.10 118.10 20" x 42" - Circle (radius 100.00) 42 1,918.25 1,800.00 10 3/4" x 13 1/2" 10-314 1H -104L1 702063018 F 0.00 0.00 3,869.40 -1,751.02 7,246.00 - plan hits target center 3,926.10 41/2"x6-3/4" 4-1/2 6-3/4 - Circle (radius 100.00) iH-10411 T03063018 F 0.00 0.00 3,878.90 -1,408.95 7,850.32 - plan hits target center - Circle (radius 100.00) 1H-1041-1 T08063018 F 0.00 0.00 3,905.10 1,280.44 9,057.12 - plan hits target center - Circle (radius 100.00) 1 H-104LI T07 063018 F 0.00 0.00 3,905.10 738.30 9,068.56 - plan hits target center - Circle (radius 100.00) 1H-10411 T06063018 F 0.00 0.00 3,908.10 -30.88 8,930.49 - plan hits target center - Circle (radius 100.00) 1H-1041-1 T04063018 F 0.00 0.00 3,926.10 -1,058.41 8,231.67 - plan hits target center - Circle (radius 100.00) 1H-1041-1 T11063018 R 0.00 0.00 3,926.10 3,094.36 7,426.84 - plan hits target center - Circle (radius 100.00) 1 H-1 04L1 T05 063018 F 0.00 0.00 3,946.10 -584.95 8,626.82 - plan hits target center - Circle (radius 100.00) 1H-1041-1 710 063018 F 0.00 0.00 3,948.10 2,515.56 8,452.16 - plan hits target center - Circle (radius 100.00) iH-104L1 T09063018 F 0.00 0.00 3,948.10 1,807.20 8,951.57 - plan hits target center - Circle (radius 100.00) Casing Paints Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name f') 1") 118.10 118.10 20" x 42" 20 42 1,918.25 1,800.00 10 3/4" x 13 1/2" 10-314 13-V2 8,366.93 3,827.59 7 5/8" x 9-7/e" 7-5/8 9-7/8 15,916.76 3,926.10 41/2"x6-3/4" 4-1/2 6-3/4 7/3/2018 1: 2148PM Page 6 COMPASS 5000.14 Build 85 Schlumberger Error Ellipse Report Company: ConowPhillips (Alaska) Inc. -Kupl Local Coordinate Reference: Project: Kupawk River Unit TVD Reference: Site: Kupamk I Pad MD Reference: Well: Plan' 1H-104 North Reference: Wellbore: Plan: iH-1041-1 Survey Calculation Method: Design: 1 H-104L1wp24 Output errors are at KOP. 16"/100' DLS, -20° TF, for 13' 8,378.93 Database: Formations 6,154.05 Hold for 20' 8,398.93 Measured Vertical -2,073.49 6,173.35 Depth Depth 8,538.67 3,843.78 (usft) (usft) Name Lithology Hold for 334.49' 9,232.54 3,855.10 WS -A2 3,841.18 Plan Annotations Well Plan: 1H-104 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan, 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Dip Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 8,365.93 3,828.10 -2,080.35 6,141.52 KOP. 16"/100' DLS, -20° TF, for 13' 8,378.93 3,830.34 -2,077.70 6,154.05 Hold for 20' 8,398.93 3,833.45 -2,073.49 6,173.35 Start 7'!100' DLS, -16.5" TF, for 139.74' 8,538.67 3,843.78 -2,040.55 6,308.58 Hold for 334.49' 8,873.15 3,841.18 -1,953.63 6,631.57 Start 3-/100' DLS, -135.59° TF, for 20.81' 8,893.96 3,841.10 -1,948.15 6,651.64 Adjust TF to -134.9', for 141.56' 9,035.52 3,844.80 -1,906.77 6,786.93 Hold for 396.13' 9,431.65 3,865.51 -1,781.17 7,162.06 Start 3°/100' DLS, -68.22° TF, for 89.29' 9,520.94 3,869.40 -1,751.02 7,246.00 Adjust TF to -44.37°, for 181.34' 9,702.29 3,869.57 -1,680.48 7,412.99 Hold for4.36' 9,706.64 3,869.43 -1,678.65 7,416.94 Start 31100' DLS, -112.56° TF, for 512.07' 10,218.71 3,878.90 -1,408.95 7,850.32 Adjust TF to -113.77% for 132.79' 10,351.50 3,890.01 -1,322.46 7,950.42 Hold for 264.55' 10,616.05 3,915.81 -1,144.03 8,144.03 Start 3-1100'DLS, -84.5°TF, for 122.97' 10,739.02 3,926.10 -1,058.41 8,231.67 Adjust TF to -61.23°, for 146.07' 10,885.08 3,933.60 -950.17 8,329.40 Hold for 288.37' 11,173.45 3,943.09 -729.90 8,515.28 Start 3°/100' DLS, -69.98° TF, for 183' 11,356.45 3,946.10 -584.95 8,626.82 Adjust TF to 43.99°, for 252.86' 11,609.31 3,934.08 -371.77 8,761.92 Hold for 115.18' 11,724.49 3,923.14 -272.19 8,818.76 Start 4'/100' DLS, -114.31° TF, for -266.73' 11,991.22 3,908.10 -30.88 8,930.49 Adjust TF to -94.54", for300.11' 12,291.32 3,905.38 259.75 9,003.04 Hold for 407.2' 12,698.52 3,905.12 662.95 9,059.95 Start 4'/100' DLS, -90.67° TF, for 75.85' 12,774.38 3,905.10 738.30 9,068.56 Adjust TF to -90', for 173.38' 12,947.76 3,905.10 911.51 9,073.19 Hold for 267,72' 13,215.48 3,905.10 1,179.09 9,064.15 Start4°/100'DLS, -90`TF, for 101.62' 13,317.10 3,905.10 1,280.44 9,057.12 Adjust TF to -153.51', for 253.25' 13,570.35 3,925.09 1,529.95 9,020.88 Hold for 2.69' 13,573.04 3,925.51 1,532.57 9,020.40 Start 4°/100' DLS, -38.04° TF, for 284.49' 13,857.54 3,948.10 1,807.20 8,951.57 Start 4.01"/100'DLS, -89.84°TF, for 847.76' 14,705.29 3,948.13 2,495.21 8,477.80 Hold for 31.56' 14,736.86 3,948.10 2,514.83 8,453.08 Start 4°/100' DLS, 44.35" TF, for 1.17' 14,738.03 3,948.10 2,515.56 8,452.16 Adjust TF to -83.7", for 254.37' 14,992.39 3,945.28 2,655.44 8,240.13 Hold for 924.37' 15,916.76 3,926.10 3,094.36 7,426.84 TD: 15916.76' MD, 3926.1' TVD Checked By: Approved By: Date: Dip Direction 1°1 71312018 1:21:48PM Page 7 COMPASS 5000.14 Build 85 Pool Report 13:31, July 032018 1 H-104L1wp24 nMwL *w snm°`Iwe� IPo.oq Quarter Mile View INtOeLiMXXIBRR �iWLI TO]PoUIO RP 3#9.N 30]B.N CINe (PMiue'.IW WI Gree (WCluv:iPoPol IWIWLI RP .m0.10 Code (RMrva:IW WI m] !GRP IX�f 01LI TAO IB PP OM ms ]9X.10 Ne 1PWlu5:1]N.WI IX�109LI lfb CFMIB R> 388.10 Cimb lWemS:IN.W1 yysfC IX�100.1 TMCSi410 RP °M J936.10 Curie lPeeiue:1 W.WI AC IX.IWII iT11Po 1j1 ]9]0.10 LYde lRa3ue:IW.W1I OBYXB#P43M.... 11p CW Np i090X19PP B.10 I. IR ede lR+euv IroW Cvtle lRe6ve 1W �1 LbdelReOrsIW�, i 1!{-102b1 4500 T x 9'^ I Q� �i000 N 1 H414 7 O O —1500 '. Y 1X-109 9 f N 3 Z ^ 0 is r 3,, O >> ry Qo/ 1500 -1500- -3000 -3000- -1500 -1500 0 1500 3000 4500 6000 7500 9000 10500 West( -)/East(+) (1500 usft/in) I 13:31, July OJ 4(N8 1H-104L1wp24 `a• wm• 0 IMiaLI T°I W.1e RP .W.1 �° crcie lR,eu.:1WW1 Quarter Mile View IN.I041IDIWID19RR0M IX�1 WLI l WO1. I a RV INTI WLI TP)6a1010 RP ]%°.tl IPZJuv:1W.W) Ctrb W.W1 V IN�IOKI TO)Ofi]OIB P.10 9Y0 .1. lRabva:l Cvtle (Ratix:I W.WI G� N�IWLI T'R W0010 RP_OH M00001B 0 RP BB9H10 9.810 NVIRVM ISA.WI G.eb (RaWa:IR.WI Y .IOJLI TOIWTIRP 41610 GrtM (Ratirt lW.Wl PN1O RP OM IOILI OtYll PP IYt8.10 9iB.10 Grtk lRaJu I AW Q MIRaPd W W) 6000 »I4 Rw IM P8 WJ99PP R Grd. IW 1KI00LIT003W1BPP 9908.1° 9004.10 (PM GNa lPaeua IW GA ,H -,03L2 0.'a 1H-102bJ'I iM-10Zr an 4500 QN w C 000 OIH Q -114 mm S LO \ 8 500- 00 0 Z L 0- i1, mm� 0 2hg0j 38mm-. i8-- 38 m -1500-- 1500 -3000--- -3000 — n - 0 1500 3000 4500 6000 7500 9000 10500 12000 West( -)/East(+) (1500 usft/in) 1H-104L1wp24 Surface Location fa CPAI Coordinate Converter From: --- - To: ---------------- _. - i Datum: NAD83 Region: alaska Datum: NAD27 Region: jalaska C Latitude/Longitude IDecimaiDegtees —� r Latitude/Longitude IDecimalDegrees r UTM Zone: F— F South C UTM Zone: True r South r C•' State Plane Zone: q Units: us -ft fi State Plane Zone: q Units: us -ft . C Legal Description (NAD27 only) C Legal Description (NAD27 only) Starting Coordinates: - X: 11689600.36 Ending Coordinates: X: F549568.736474514 Y: 5980534.24 Y: 5980782.43086254 Transform Quit Help 1H-104L1wp24 Surface Casing CPAICoordinate Comrerte ,. From: To: Datum: NAD83 Region: alaska wl Datum: NAD27 . Region: alaska • Latitude/Longitude IDecimal Degrees r Latitude/Longitude IDecimalDegrees • UTM Zone: F— r• South r UTM Zone: True r- South C� State Plane Zone: �� Units: us -ft C• State Plane Zone: q Units: us -ft r Legal Description (NAD27 only) r Legal Description (NAD27 only) Starting Coordinates: X: 1690076.56 Endmg Coordinates: X: 550044.927833547 Y: 5980319.29 Y: 5980567.47692271 11.77.77Transform j Quit Help 1H-104L1wp24 Top of Window CPAI Coordinate Converter —e_ e From: To: Datum: NAD83 Region: alaska Datum: NAD27 Region: Fal—ask—a--3 r Latitude/Longitude IDecimalDegFees r Latitude/Longitude IDecimalDegrees C UTM Zone: �— r South f UTM Zone: True r South C•` State Plane Zone: q Units: us -ft . F State Plane Zone: q „ Units: us -ft t" Legal Description (NAD27 only) i Legal Description (NAD27 only) -Starting Coordinates: X 1695527.14 Ending Coordinates: X: F555495.411490119 Y: 5978446.26 Y: r5978694.3883668 t.................Transform...___........; Quit Help 1H-104L1wp24 Top of Production Horizon d, CPAP Coordinate Converter: ..a.�,. From: __.-- -- --- -_-_. To: Datum: NAD83 Region: alaska Datum: NAD27 Region: alaska • Latitude/Longitude (Decimal Degrees C Latitude/Longitude Decimal Degrees • UTM Zone: F— r South f UTM Zone: True r- South G State Plane Zone: q w Units: us -Ft R State Plane Zone: I" J Units: us -ft . C Legal Description (NAD27 only) I r Legal Description (NAD27 only) Starting Coordinates: Ending Coordinates: X: 1694712.06 X 554680.344082698 Y: 5978454.11 Y: 5978702.25354768 _I r Transform ! Quit Help 1H-104L1wp24 TD ® CPA: Coordinate Converter, From: ---------- Datum: NADB3 7, Region: afaska C Latitude/Longitude IDecimalDegrees C UTM Zone: r' South C� State Plane Zone: qUnits: us -ft {" Legal Description (NAD27 only) OICHI IP 5—C To: Datum:NAD27 Region: alaska C Latitude/Longitude IDecimalDegrees f UTM Zone: True r South (� State Plane Zone: q - Units: us -ft t-' Legal Description (NAD27 only) r Starting Coordinates: -- Ending Coordinates: X 11697006 X: 556974.287841876 Y: —F5983924.97577649 Y: 5983677 .................. ........... ._... ............ ..._........ .Transform Quit Help 1H-104L1wp24 Surface Location Q CPA] Coordinate Converter From: To: Datum: NAD83 Region: alaska . Datum: NAD27 Region: alaska . r Latitude/Longitude IDecimalDegrees 71 r Latitude/Longitude (Decimal Degrees f UTM Zone: (— South r UTM Zone: True r South G State Plane Zone: q Units: us -ft r State Plane Zone: q Units: us -ft C Legal Description (NA.D27 only) C•" Legal Description (NAD27 only) �- Starting Coordinates: Legal Description X: 1689600.36 Township: 012 N . Range: 010 I` _j Y: 5980534.24 Meridian: U Section:28 IL FNL5200.5597 FEL 772.31441 _Transform Quit Help 1H-104L1wp24 Surface Casing Q. CPAI Coordinate Converts[. From: -- To: Datum: NAD83 flegion: alaska Datum: NAD27 Region: alaska 1 C Latitude/Longitude IDecimalDewees, . r Latitude/Longitude Decimal Degrees C UTM Zone: F— r South r UTM Zone: True r South f• State Plane Zone: q Units: us -ft C- State Plane Zone: q Units: us-tt f Legal Description (NAD27 only) C• Legal Description (NAD27 only) Starting Coordinates: Legal Description X: 11690076.56 Township: 012 N . Range: 010 E -. Y: 15980319.29 Meridian: U Section:33 FNL . 138.71385 FEL 1297.99407, Transform Quit Help 1H-104L1wp24 Top of Window M CPAI Coordinate Converter " Wor Datum: NAD83 Region: alaska + • Latitude/Longitude IDecimalDegrees • UTM Zone: r— r' South F State Plane Zone: q Units: us -ft + r Legal Description [NAD27 only) r- Starting Coordinates: - X 11695754.81 Y: 5978494.46 Datum: NAD27 Region: alaska + • Latitude/Longitude IDecimalDegrees + r UTM Zone: True r- South • State Plane Zone: q Units: us -ft + R Legal Description (NAD27 only) -Legal Township: 012 F-3 Range: 010 1` J Meridian: U Section:35 FNL 2003.8243 FEL5195.6325 i Transform . ,,. Quit Help I 1 H-104L1wp24 Top of Production Horizon I n CPA! Coordinate Converter From: Datum: NAD83 Region: alaska + ' Latitude/Longitude IDecimalDegrees + r UTM Zone: F— r- South r State Plane Zone: q Units: us -ft: -3 r Legal Description (NAD27 only) -Starting Coordinates: X: 11695527.14 Y: 15978446.26 MIM Datum: NAD27 Region: alaska + {" Latitude/Longitude Decimal Degrees C UTM Zone: True r South C State Plane Zone: 4 Units: us -ft _j- * G Legal Description (NAD27 only) Township: 012 N + Range: 010 E + Meridian: U Section:34 FNL 2050.3399 FEL + 143.73658 (�Trmisform Quit Help r._._._.. ......................_..._.._._.._. 1H-104L1wp24 TD B, CPAi Coordinate Datum: NAD83 D Region: alaska r Latitude/Longitude IDecimal Degrees r UTM Zone: F— r South f• State Plane Zone:q : Units: us -ft C Legal Description (NAD27 only) r- Starting Coordinates: X: 1697006 Y: 5983677 Datum: NAD27 Region: alaska C Latitude/Longitude IDecimalDegrees • UTM Zone: True r South C State Plane Zone: F-':-:1 Units: us -ft C•' Legal Description (NAD27 only) Description Township: 012 [—N—,l Range: 010 E Meridian: rU------,l Section F26 FNL 2110.4736 FEL - 3898.5570 T ..._._._........raa . ns ..._................ _..... ....., ........_.......ormQuit Help ................) Tollerable Collision Risk Worksheet As -built ;EV I DATE I BY ICK APP DESCRIPTION IREV DATE BY Cn I APP DESCRIPTION 1. 1 12/05/01 MRT I CC I IRev. Per K05014ACS 12 02/01/14 JAH I LGM I Rev. Per K170005ACS N25 COORDINATES SHOWN ARE ALASKA STATE 30 29 26 27�A 25 0 3. ELEVATIONS ARE B.P.M.S.L. 36 31 1H ALL CONDUCTORS ARE LOCATED WITHIN •14 KCS 32 33 34 35 36 TOWNSHIP 12 NORTH, RANGE 10 EAST, X20 T12NE10E E, UMIAT MERIDIAN, ALASKA. 919 •22 o11 5. T11NR IGE 010 1-31-17 FIELD BOOKS L16-35, L16-40, •17 5 6 4 3 2 1 *16 0120 `" ld! o13 ASP GRID NORTH 0118 2 7 CPF1 ybi 10 c •2 •7 8 9 it NFO 2 ®117 GRAPHIC SCALE 0116 0 100 200 400 08 0115 •4 18 7 16 15 14 13 0114 1 inch = 200 ft. >B LEGEND 0113 IF IDL 0112 24 is 20 z1 z 23 0 AS—BUILT CONDUCTOR ®111 8110 VICINITY MAP • EXISTING CONDUCTOR 0109 SCALE: 1" = 2 MILES ®104 0108 0103 28 27 33 34 0102 0106 0101 SEE SHEET 2 & 3 FOR COORDINATE TABLE LOUNSBURY & ASSOCIATES, INC. SURVE YORS ENGINEERS PLNNERS AREA: 1H MODULE: XXXX UNIT: D1 ConocoPhillips DS1H WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD nLE NO. DRAWING NO. PART: REV: LK6108d31 2/05/05 CEA—D1HX-610SD31 1 OF 3 2 NOTES: 1. BASIS OF LOCATION AND ELEV. IS DS1H MONUMENTATION PER LOUNSBURY & ASSO DS1H 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 3. ELEVATIONS ARE B.P.M.S.L. •UGNU 01 4. ALL CONDUCTORS ARE LOCATED WITHIN •14 PROTRACTED SECTIONS 28 AND 33, •5 TOWNSHIP 12 NORTH, RANGE 10 EAST, X20 X12 UMIAT MERIDIAN, ALASKA. 919 •22 o11 5. DATES OF SURVEY: 12-26-16 THRU 010 1-31-17 FIELD BOOKS L16-35, L16-40, •17 06 L17-02 & L17-03. *16 •21 •15 o13 6. ALL DISTANCES SHOWN ARE GROUND. 91 •9 •2 •7 •3 •18 GRAPHIC SCALE 0 100 200 400 08 •4 1 inch = 200 ft. SEE SHEET 2 & 3 FOR COORDINATE TABLE LOUNSBURY & ASSOCIATES, INC. SURVE YORS ENGINEERS PLNNERS AREA: 1H MODULE: XXXX UNIT: D1 ConocoPhillips DS1H WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD nLE NO. DRAWING NO. PART: REV: LK6108d31 2/05/05 CEA—D1HX-610SD31 1 OF 3 2 1 1 102/01/171 JAH I LGM I (Create Per K170005ACS I I I I I I CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 28, T. 12 N., R. 10 E., UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geo ra hic Coordinates Section Offset. Elev. Y I X Lot. Long. F.S.L F.E.L.O.G. PAD *103 5,980,722.55' 549,573.20' N 70' 21' 29.220" W 149' 35' 50.536" 19' 768' 48.0' 54.1' *104 5,980,782.43' 549,568.74' N 70' 21' 29.809" W 149' 35' 50.655" 79' 772' 48.0' 54.1' *108 5,980,752.52' 549,570.98' N 70' 21' 29.515" W 149' 35' 50.595" 49' 770' 48.0' 54.0' *109 5,980,812.20' 549,566.50' N 70' 21' 30.102" W 149' 35' 50.714" 109' 774' 48.0' 54.0' *110 5,980,842.21' 549,564.40' N 70' 21' 30.398" W 149' 35' 50.770" 139' 776' 48.0' 54.0' *111 5,980,872.05' 549,562.21' N 70' 21' 30.691" W 149' 35' 50.828" 169' 778' 48.0' 54.1' *112 5,980,902.08' 549,559.94' N 70' 21' 30.987" W 149' 35' 50.889" 199' 780' 48.0' 54.0' *113 5.980,932.00' 549,557.76' N 70' 21' 31.281" W 149' 35' 50.947" 229' 782' 48.0' 54.0' *114 5,980,961.86' 549,555.50' N 70' 21' 31.575" W 149' 35' 51.006" 259' 784' 48.0' 54.1' *115 5,980,991.68' 549,553.43' N 70' 21' 31.868" W 149' 35' 51.062" 289' 786' 48.0' 54.1' *116 5,981,021.61' 549,551.58' N 70' 21' 32.163" W 149' 35' 51.110" 319' 787' 48.0' 54.1' *117 5,981,051.73' 549,548.80' N 70' 21' 32.459" W 149' 35' 51.185" 349' 790' 48.0' 54.0' *118 5,981,081.22' 549,546.95' N 70' 21' 32.750" W 149' 35' 51.234" 378' 791' 48.0' 54.0' *119 5,981,111.42' 549,544.52' N 70' 21' 33.047" W 149' 35' 51.299" 408' 794' 48.0' 54.2' *120 5,981,141.33' 549,542.48' N 70' 21' 33.341" W 149' 35' 51.353" 438' 1 795' * CONDUCTOR ASBUILT THIS SURVEY 49th ................................................. c * JEREMIAH F. CORNELL �i Ji LS -12663 •••,:i AIV ♦♦♦iC,'4�41111�-FESSIONA� ��••/ SURVEYOR'S CERTIFICATE 1 HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION ARE CORRECT AS OF JANUARY 31, 2017. LOUNSBURY x ASSOCUTES, INC. :VBYORS 6NCINEnS PWNNER9 AREA: IH MODULE: XXXX UNIT: D1 ConocoPhilli SDS1H WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS PART: Fixed BOP configuration for West Sak Operations Ann Fixed Blind O r 13 InsWaed Conductor 1u5!g 2 '7 KSix34",0312' +1-134• MD hAEi 10.3/4",4954, L -M, HYd563 Wellhead / Tubing Head / Tree, U -3/8"x4 -'h". 3.1100 Lai 1H-104 Producer Schematic Planned wo26 Tubing SOin, 0.12". 126k 1.60 TXP Gu Lin Mandrel, 112". P ,I dam., valve Gas Lift Mandrel. 4.112" s I" m/dummy valve GU Lift MaWrel, 4-IP"al"nd SOV 0.'A"SSD a0h 3.812• DB NiPPk p.file 1918' MD / 180V TVD Pemanent Davn Hole Gauge Tubing Seal Assembly L4 ZXP Packer C' 375" DP Nipple Pro01e n S aF Sm Q 2 Stacked Baker Hook Hanger $. di Level 3 Junction Systems r' ZXP U IY'Sand UPP Lobe WWdauw8142'MDl3]85'TVD Pmktt '•.- 6-3/4" Dead (L2) Weial 15]]]' MD/3843'WD� J-Ih"Slatted Liner and Blank pipe 12.6M 480 TXPABTM/SLHT ............ . ..............-----------------....................................... •.... ............ M.,Aig ................................................ LI "D" SarW Lover Lobc Windoss 2 836Y MD 13X28' TVD 6.316' Did eaW (L I) IaarW Literal Envy M �,-'•.M�0.12"Slotted Linzr end Blvnk pip1264"OTXPABTWSLHT ` .._.__..................................................................... 1591]'MD/3926'TVD� Tubing Seal Assemb___--___________________________________________________ ly •.... .... .........................................................................% 3,562- DP Nipple Pmfle6-3If' A2IA3 smd (mainborcl J ,'_" Slaued Lam and Glad Pl I' IXPSLHTIxn IA ZXP pxkcr --------- -- Ilan) M04 \'11 ' __....___6.. ]-MX. 29. ]4, L80, HYd563, Cs --.__ --- --------- 8— __ - _ -__ _ _-. .. .. 9469'MDI4083'---------------------- ................. ...................: .. 1H-104 Drilling Hazards Summary 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Miti tion Strate Broach of Conductor _ Low _ Monitor cellar continuously during interval. Gas Hydrates Moderate Reduced pump rates, Reduced drilling fluid temperatures, Additions of ScreenKleen Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use oftrip sheets), pumping out Washouts /Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible Anti -Collision Moderate Follow real time surveys very closely, shut in nearby wells that we have collision concerns with, gyro survey to ensure survey accuracy. 9-7/8" Open Hole 17-5/8" Casing Interval Hazard Risk Level Mi' tion Strategy Running Sands and Gravels Low Maintain planned mud parameters, increase mud weight, use weighted sweeps. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate . Reduced pump rates, mud rheology, LCM. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out. 6-3/4" Open Hole/ 4-1/2" Liner Intervals Hazard Risk Level Mitigation Strate Abnormal Reservoir Pressure Low Stripping drills shut-in drills increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud wei if ossible if pipe does get stuck. Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid • stored on location during completion urn. Differential Sticking Moderate Follow mud program, keep pipe moving when able. Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out or backreamin . Fault Crossings and Concretions Moderate Use developed best practices for concretion drilling. Anti -Collision Moderate Follow real time surveys very closely, shut in nearby wells that we have collision concerns with. Utilize periscope to maintain geological certainly to stay within zone. Casing wear Moderate Maintain low dog legs in the surface interval and utilize super sliders for drilling, milling, and liner running operations to minimize casing wear. Consider logging casing thickness to calibrate casing wear model. Getting Liner to Bottom Moderate Properly clean hole on the trip out with the BHA, perform clean out run if necessary, utilize super sliders for weight transfer, monitor torque and Whipstock Retrieval Moderate A dedicated clean out urn prior to attempting to pull whipstock can be used to reduce the risk of fishing operations._ 1H-104 Dril@ng Hazards Summary.doc 5/152018 4:42:08 PM v Drill Site 1 H DRAWN BY: ALKET MICi o 0 T ConocophillipS TALE: DS1H LAYOUT DRAWING Alaska, Ina DRAWN BY: ALKET MICI I OAw. m, lata aar t TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: Development —Service —Exploratory _ Stratigraphic Test —Non -Conventional FIELD: rt,,k f POOL: vt/e J`�d� bJi l Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit 1s for new wellbore segment of existing well Permit LATERAL No. API No. 50-6- 731616 -6e-> -Cxa f (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be 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, 1j 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, WEST SAK OIL - 490150 PTD#:2180850 Company CONOCOPHILLIPS ALASKA INC. Initial Class/Type DEV Weil Name: KUPARUK RIV U WSAK 1H -104L1 Program DEV Well bore seg I PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven, gas conforms to AS31.05.030Q. 1.A).U.A-D) _ _ NA 1 Permit fee attached _ NA 2 Lease number appropriate _ Yes Surf Loc & Top Prod Int lie in ADL0025639; TO lies in ADL0025638. 3 Unique well. name and number Yes _ Yes - Previous application for 1H-1041_1 (PTD #218-062) was. cancelled. per email from S. Brunswick, 4 Well located in defined pool _ _ _ Yes CPA], rescinding permit. Kuparuk River, West.Sak Oil Pool - 490150, governed by CO 406C 5 Well located proper distance from drilling unit. boundary. Yes CO 406C, Rule 3; no restrictions as to well spacing except that no pay shall be opened in a. well closer (6 Well located proper distance from other wells _ _ _ _ _ _ _ _ _ _ Yes than 500 feet toan external. property line where ownership or landownership changes... 7 Sufficient acreage available in drilling unit. _ Yes As planned, well conforms to spacing requirements. 8 If. deviated, is wellbore plat. included _ _ _ _ Yes '9 Operator only affected party..... _ _ Yes 10 Operator has appropriate bond in force _ Yes Appr Date 11 Permit can be issued without conservation order... _ _ _ Yes 12 Permit can be issued without administrative approval ... Yes SFD 7/23/2018 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 i NA 15 All wellswithtn 114 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 1 H-104... Engineering 19 Surface casing_ protects all. known USDWs _ _ .. NA. Surface casing will be set for KRU1H-104.. 20 CMT. vol adequate to circulate on conductor. & surfcsg _ _ _ _ _ _ _ _ _ _ _ NA Surface casing will be set and fully cemented 21 CMT. vol adequate to tie-in long string to surf csg.... _ _ _ No 22 CMT will cover all known_ productive horizons. _ No Productive. interval will be completed with uncemented slotted liner 123 Casing designs adequate for C, T, B & permafrost. _ _ _ _ _ Yes 124 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 1.707 psig(8.5 ppg EMW); will drip w/ 8.8-9.5 ppg EMW VTL 8/1/2018 I29 BOPEs,. do they meet regulation _ _ _ _ _ _ _ _ _ _ _ Yes...... 30 BOPE.press rating appropriate; test to (put prig in comments)... _ _ _ Yes MPSP is 1323 psig; will test BOPS to 3500 psig 31 Choke. manifold complies w/API. RP -53 (May 84) _ _ _ _ .. _ Yes 32 Work will occur without operation shutdown.... _ _ _ _ _ .. Yes 33 Is presence of H2$ 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 H2$ measures required. Well 1H-102 measured 20 ppm H2S on. November 20, 2017. Geology 36 Datapresented on potential overpressure zones _ _ _ _ _ _ _ Yes Expected reservoir pressure is -8.4 ppg EMW; will be drilled with 9.2 - 9.5 ppg mud...... Appr Date 37 Seismic. analysis of shallow gas zones _ _ _ _ _ NA _ _ Moderate potential for lost circulation, differential sticking, swabbing, and fault crossing. issues.. SFD 7/23/2018 38 Seabed condition survey (if off -shore) ... _ _ NA ..... Mitigation measures discussed. in Drilling. Hazards Summary... 39 Contact name/phone for weekly. progress reports. [exploratory only] _ _ _ _ _ _ _ _ NA. Geologic Engineering Pub' Commissioner: Date: Commissioner: Date p C issloner Date 1-I r.-�-S 811111 1 I r le�
