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217-105
DATA SUBMITTAL COMPLIANCE REPORT 1/22/2018 Permit to Drill 2171050 Well Name/No. KUPARUK RIV UNIT 1H-10214 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23580-63-00 MD 14670 TVD 3780 Completion Date 10/20/2017 Completion Status 1-0I1 Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Lag No Samples No Directional V Survey Yes DATA INFORMATION List of Logs Obtained: GR/Res (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type MedlFrmt Number Name Scale Media No Start Stop P CH Received Comments ED C 28752 Digital Data _ 32 1776 10/26/2017 Electronic Data Set, Filename: CPAI 1H -102L4 - Scope Resistivity_RM_LW D001.1as ED C 28752 Digital Data 1776 8094 10/26/2017 Electronic Data Set, Filename: CPAI 11-1-1021-4 Scope Resistivity_RM_LWD002.las ED C 28752 Digital Data 7360 14670 10/26/2017 Electronic Data Set, Filename: CPAI 11-1-1021-4 Scope Resistivity_RM_LWD026.las ED C 28752 Digital Data 28 14670 10/26/2017 Electronic Data Set, Filename:. CPAI 11-1-1021-4 Scope Resistivity RM.las ED C 28752 Digital Data 32 14670 10/26/2017 Electronic Data Set, Filename: CPAI 1H -102L4 - Scope Resistivity Customer Channel LAS.Ias ED C 28752 Digital Data 10/26/2017 Electronic File: CPAI 11-1-1021-4 Scope Resistivity , RM LWD002 DLIS.dlis ED C 28752 Digital Data 10/26/2017 Electronic File: CPAI 1H-10214 Scope Resistivity' RM LWD002 DLIS.html ED C 28752 Digital Data 10/26/2017 Electronic File: CPAI 11-1-10214 Scope Resistivity RM LWD0026 DLIS.dlis ED C 28752 Digital Data 10/26/2017 Electronic File: CPAI 1H -102L4 Scope Resistivity - RM LWD0026 DLIS.html ED C 28752 Digital Data 10/26/2017 Electronic File: CPAI 11-1-10214 Scope Resistivity' RM LW D001 DLIS.dlis ED C 28752 Digital Data 10/26/2017 Electronic File: CPAI 1H -102L4 Scope Resistivity - RM LWD001 DLIS.html ED C 28752 Digital Data 10/26/2017 Electronic File: CPAI 11-1-1021-4 Scope Resistivity RM DLIS.dlis ED C 28752 Digital Data 10/26/2017 Electronic File: CPAI 1H-1021-4 Scope Resistivity . RM DLIS.html AOGCC Page 1 of 3 Monday, January 22, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/22/2018 Permit to Drill 2171050 Well Name/No. KUPARUK RIV UNIT 11-1-1021-4 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23580.63-00 MD 14670 TVD 3780 ED C 28752 Digital Data ED C 28752 Digital Data ED C 28752 Digital Data ED C 28752 Digital Data ED C 28752 Digital Data ED C 28752 Digital Data ED C 28752 Digital Data Completion Date 10/20/2017 ED C 28752 Digital Data ED C 28752 Digital Data ED C 28752 Digital Data ED C 28752 Digital Data ED C 28752 Digital Data ED C 28752 Digital Data ED C 28752 Digital Data ED C 28752 Digital Data Log C 28752 Log Header Scans Well Cores/Samples Information Name INFORMATION RECEIVED Interval Start Stop Completion Status 1 -OIL Current Status 1 -OIL UIC No Electronic File: CPAI_1H- H- ♦10/26/2017 1021_4 — 1021_4_ Scope_Resistivity_2in_MD.Pdf • 10/26/2017 Electronic File: CPA11H- F 102L4_Scope_Resistivity_2in_TVD.Pdf ' 10/26/2017 Electronic File: CPAI_1H- n 010/26/2017 1021-4_ Scope_Resistivity_5in_MD.Pdf ' Electronic File: CPAI_1H- 12 102L4_Scope_Resistivity_5in_TVD.Pdf 10/26/2017 Electronic File: 1H-10214 Final , PrintSurveyList.csv 10/26/2017 Electronic File: 1H-1021.4 NAD27 EOW + Compass Survey.pdf 10/26/2017 Electronic File: 1H-1021-4 NAD83 EOW - Compass Survey.pdf 10/26/2017 Electronic File: 1 H-1021-4 [Canvas] NAD27.txt 10/26/2017 Electronic File: 1H-10214 [Canvas] NAD83.txt 10/26/2017 Electronic File: 11-1-1021.4 [Macro] NAD27.txt 10/26/2017 Electronic File: 1H -102L4 [Macro] NAD83.txt 10/26/2017 Electronic File: 1H -102L4 [Petrel] NAD27.txt 10/26/2017 Electronic File: 1H-1021_4 [Petrel] NAD83.txt 10/26/2017 Electronic File: 11-1-1021.4 [Surveys] NAD27.txt ' 10/26/2017 Electronic File: 1H-1021-4 [Surveys] NAD83.txt 0 0 2171050 KUPARUK RIV UNIT 1H-1021_4 LOG HEADERS Sample Set Sent Received Number Comments Page 2 of 3 Monday, January 22, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/22/2018 Permit to Drill 2171050 Well Name/No. KUPARUK RIV UNIT 1H -102L4 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23580-63-00 MD 14670 TVD /3780 Completion Report 'N 1 Production Test InformationONA Geologic Markers/Tops 0 COMPLIANCE HISTORY Completion Date: 10/20/2017 Release Date: 7/26/2017 Description Comments: Compliance Review B : Completion Date 10/20/2017 Completion Status 1 -OIL Current Status 1 -OIL Directional / Inclination Data 0 Mud Logs, Image Files, Digital Data Y Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files YO Daily Operations Summary l9 Cuttings Samples Y / NA) Date Comments UIC No Core Chips y / Core Photographs Y / Laboratory Analyses y / A Date: 1I v�' M)G(C Parc 3,,13 Monday_ January 22, 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION HLULIVtu NOV 2 0 2017 �eNe% t-� 1-% WELL COMPLETION OR RECOMPLETION REPORT A 1a. Well Status: Oil❑+• Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20MC 25.105 20AAC 2s.110 GINJ❑ WINJ❑ WAGE] WDSPL❑ No. of Completions: ib. Well Class: Development ❑� • Exploratory ❑ Service ❑ Stratigraphic Test❑ 2. Operator Name: ConocoPhillips Alaska, Inc. ' 6. Date Comp., Susp., or Abend.: 10/20/2017 14. Permit to Drill Number/ Sundry: 217-105 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 10/9/2017 15. fppLlJus �O - -C� 4a. Location of Well (Governmental Section): Surface: 40.52' FNL, 764.65' FEL, Sec 33, T12N, R10E, UM Top of Productive Interval: 633' FNL, 1684' FEL, Sec 34, T12N, R1 OE, UM Total Depth: 4454' FNL, 3027' FEL, Sec 22, T12N, R1 OE, UM 8. Date TD Reached: 10/14/2017 , 16. Well Name and Number: KRU 11-1-1021-4 9. Ref Elevations: KB:92.62 GL: 54 - BF: 17. Field / Pool(s): Kuparuk River FieldM/est Sak Oil Pool , 10. Plug Back Depth MDrrVD: N/A 18. Property Designation: ADL 25639, ADL 25636 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 549577.46 y- 5980662.56 Zone- 4 TPI: x- 553943 y- 5980100 Zone- 4 Total Depth: x- 552540 y- 5986828 Zone- 4 11. Total Depth MDrrVD: 14670/3780 19. DNR Approval Number: LO/NS 80-261 12. SSSV Depth MDrrVD: N/A 20. Thickness of Permafrost MD/TVD: 1699/1630 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 1 21. Re-drill/Lateral Top Window MD/TVD: 7377/3738 . 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 CASING' PER SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT.TOP BOTTOM TOP BOTTOM PULLED 20 78.67 40 119 40 119 42 Existing Cement to Surface dR1,A 103/4 45.5 40 1771 40 1691 13.5 876 sx 11.0 ppg Lead Cement 211 x 1 Tail C75/8 29.7 37 8593 37 3991 9.875 1155 sx 15.8 ppg, Class G 41/2 11.6 7374 14670 3737 3780 6.75 Uncemented Slotted Liner 24. Open to production or injection? Yes El No ❑ If Yes, list each interval open (MDrrVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER @ 7513 - 14608 MD and 3766-3781 TVD 20NIPLL T OI, r).4 rF 1CV7,0/t' - /FRIFIFG Lc 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/ VD) 41/2 7289 n/a 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No R] Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 1114/2017 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 11/15/2017 Hours Tested: 13 fire, 7 min Production for ITest Period Oil -Bbl: 3058 bbis I Gas -MCF: 1154 MSCF Water -Bbl: 1 bbl Choke 62% Gas -Oil Ratio: 416 SCF/STB Flow Tubinq Press. 334 PSI Casinq Press: 1 PSI Calculated 24 -Hour Rate Oil -Bbl: TBI Gas -MCF: 227 M CTI Water -Bbl: 2 TB/d Oil Gravity -API (torr): 20.7 PI Form 10407��Re 1 `i 7� 0]; A 1/2/y � CONTINUED ON PAGE 2 RE3P- ��, l - NOV 2 L 25upqut ORIGINIAL gnly 28. CORE DATA Conventional Core(s): Yes ❑ No El Sidewall Cores: Yes ❑ No (] If Yes, list formations and intervals cored (MD/TVD, Fromrro), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1699 1630 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7377 3738 information, including reports, per 20 AAC 25.071. Formation @ TPI -West Sak D TD 14670 3780 Formation at total depth: West Sak D 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematics Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, naleontoloa cal report, production or well test results. r 7. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G. L. Alvord Contact Name: Kelsey Hallford Authorized T le: Alaska Drilling Manager Contact Email: kelsev.hatford0cop.com ��y% Authorized �� r t (LVO�).� Contact Phone: 265-1577 Signature: Date: —� INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item tb: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only (� G �� Wellhead / TuNng Head /Tree, In4Naled Conduces 13-3/B"x0.K", S,000ksi 1H-102 Producer Schematic Casng,20 KSSx34^,0.312" Tubing Sving: 4-12, 1242, LSO TXP Finel-As Run µrT® Wutor Sed Auwbly@R5998'b� H-Btl MD Borom of Mule SM1ac®]289.08'MD Gm LIRMmdml, 4-12"x l" w/dununyv41ve2668.56'MD/2288'TVD 6ss LiR Mmtlrel, 0.]2' x 1" w/dmnmy valve 5515.1' b10 /3199' TVD 10.Y4', 45.SY, G Lift Mmdr J,4-12"xl"w/SOV709.49'MD/344TTVD Hyd563 4-W=wi$3812"DB Nipple pm lc 712680 MD 1TIl'14D/1691'TVD Pem int Down Hole Gaup 7193,231 MD TuNng Seal Assembly IA ZXP Packer@=,23'MD 3.75- DP Nipple Me@130825'MD ],l "W Sand Willow®]3]]'MD/ BOW: 7390.6T 63/4"D sand lererul m S ••, Swell Pmkem 144>0'MD/ 3789IVD d•`•, s c 4-12', 11.62 IBTM LSO, SIotted❑n ,4-K'"Blink __.. .. .. pipe-...#: 'SOTXP LinmiD�N652.5'MD� _______________—__— _.••.......................................................•.,,•••....,,,,.__......,..........................._ _______ m C O Snicked Baker Hook Hanger L3"B"Sind Window®]64T MD/BOW: ]460.T kdD 63/4"Bm dlalcml ca LeN3Junmim $yy4em4 •,`. 14686'MD/31,1,t D r 4_12"SIWId Linea IL621BTML80; 0.K"Blink' 1262 L80 T](P Lim, TD®14668'MD� ZKP Pecker Depdu:L2"A4"Seed Window®Td45'144D/BOW: ]8wldO 63/4"A4�l al L3®]460AX 75.57o inc L2®TI18.39I&D `., Limr, 11621BTMLBO,aK_BBN: pipe 12.62 LBOTXP 1343Y MD/39VWD Liner __._.4-12_S1omd L1 @]912.54'19ID - .•,,._,.•..__..,,•••,•..____••.............. LI "A3" Smd Window® NN MD MOW 7993'MD •,•412"Slowed TD (�13200_MD� , ,,.., 63/4'A3 seed Nmral Laeral Enay MAW.`•�/—• Limr, I1mlBTM LBR 0.K"Blink 12,0 LSO TXP 13126n/.3388'TVD Liom'Rl 1309T KID TuNng Sed AxmnblY---------------- ,`.... ............. ........... g 3.56T DP Nipple Profile®8244.36l,fD 6-3/4"A2a ]mein" 5� LO ZXP packer ®6249.5'MD •,/-4-12"$lotld Liner and Blink Pipe, 11.4NIBTM L80 12%0'MD/4W2'TVD TD®12790'MD� eg 3 ].5/%", 29 )N, L80. HYd563. Cs8 .•__________________________________________ operations Summary (with Timelog uepths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Srarr Time End Tie 13-rhd Phase Op Gads Activity Code Time P -T -X Ope ion siert OepN (flxB) End Depth (flKB) 8/22/2077 8/23/2017 6.00 MIRU MOVE MOB P Move rig f/ 1H-118 to 1H-102 ('417). 18:00 00:00 A12300 spot over conductor. 8/23/2017 8/23/2017 0.75 MIRU MOVE MOB P Spot Pits 00:00 00:45 8/23/2017 8/23/2017 0.75 MIRU MOVE MOB P Spot pump Mod 00:45 01:30 8/23/2017 8/23/2017 0.50 MIRU MOVE MOB - P !Spot motor complex 01:30 02:00 8/23/2017 8/23/2017 0.50 MIRU MOVE MOB P Spot Rock washer 02:00 02:30 8/23/2017 8/23/2017 1.25 MIRU MOVE MOB P Spot pipe shed and drop landings. 02:30 03:45 8/23/2017 8/23/2017 5.25 MIRU MOVE RURD P Hook up all service connections and 03:45 09:00 comms. Continue with derrick board installation. 8/23/2017 8/23/2017 3.00 MIRU MOVE NUND P NU Annular/ Diverter, install pitchin 09:00 12:00 nipple,and riser, take on water to pits and build spud mud. Load 10 3/4" casing into pipe shed. Rig ACCEPTED at 0900. 8/23/2017 8/23/2017 6.00 MIRU MOVE NUND P Install mouse hole, NU surface arm / 12:00 18:00 Divert. 8 GE starting head. build spud mud, C/O saver sub. Install bushings / and elevators to dg floor. Swap to high line power at 1730 HRS. 8/23/2017 8/23/2017 0.75 MIRU MOVE BOPE P PU stand of 5" DP and perform 18:00 18:45 diverter test. Ann close time 26 sec. Knife valve opening time = 8 sec. 3000 PSI on koomy. 1,500 PSI on manifold, 1,950 after function with 7 sec to build 200 PSI, 44 sec full recovery. with two electric pumps and 2 air pumps. average 2,004 PSI on 6 N2 bottles. Jeff Jones waived witness of diverter test. 8/23/2017 8/23/2017 2.25 MIRU MOVE RURD P Send BHA componets to rig floor while 18:45 21:00 working smart tools in the pipe shed. Work and inspect 5" DP on sills outside. load 5" DP in shed. 8/23/2017 8/23/2017 2.00 MIRU MOVE BHAH P MU surface BHA. RIH with same to 105.0 21:00 23:01 1 tag at 105' 8/23/2017 8/24/2017 1.00 MIRU MOVE SEQP P Make up top drive and surface test to 105.0 105.0 23:00 00:00 3,500 PSI for 15 min. Shallow hole test GPM 450 GPM @ 424 PSI, F/O = 32%. 8/24/2017 8/24/2017 6.00 SURFAC DRILL DDRL P Drill 13 1/2" surface hole from 105'- 105.0 491.0 00:00 06:00 491' MD 491' TVD. 500 GPM, 800 PSI DPP. 44% F/O 40 RPM, 3K TO with 20K WOB. UP WT = 74K. DWN WT = 79K. 5K TO, off BTM pressure = 730 PSI. Maz gas units = 35. AST .66 , ART = 2. ADT = 2.66// Total bit hours = 13.3. Total jar hrs = 92.98 - Page 7/79 Report Printed: 10/30/2017 uperations Summary (with Timelog uepths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tme End Tme Our hr l) Phase O Code p Activity Code ty Time P- - T x Operation slat Depth (10®) End Depth MKa) 8/24/2017 8/24/2017 6.00 SURFAC DRILL DDRL P D611 13 1/2" surface hole from 491- 491.0 1,008.0 06:00 12:00 1,008' MD 1,006' TVD. 500 GPM, 1,090 PSI DPP. 44% F/O 60 RPM, 5K TQ with 27K WOB. UP WT = 93K. OWN WT = 94K. 1 K TO, off BTM pressure = 875 PSI. Max gas units = 160. AST 1.43 , ART = 3.21. ADT = 4.64// Total bit hours = 17.94. Total jar hrs =97.62 8/24/2017 8/24/2017 6.00 SURFAC DRILL DDRL P Drill 13 1/2" surface hole froml,008' 1,008.0 1,558.0 12:00 16:00 MD - 1,558' MD 1,506' TVD. 500 GPM, 1,121 PSI DPP. 44%F/060 RPM, 5K TO with 28K WOB. UP WT - =100K. DWNWT=99K. 1KTQ,off BTM pressure = 943 PSI. Max gas units = 8658. AST 2.21 , ART = 2.11. ADT = 4.32// Total bit hours = 22.26. Total jar hrs = 101.94 8/24/2017 8/24/2017 3.25 SURFAC DRILL DDRL P Drill 131/2" surface hole froml,558' 1,558.0 1,777.0 18:00 21:15 MD - 1,777' MD 1,694' TVD. 500 GPM, 982 PSI DPP. 41 % F/O 60 RPM, 4K TQ with 15K WOB. UP WT = 105K. DWN WT= 100K. 2K TO, off BTM pressure= 950 PSI. Max gas units= 827. AST 1.59 , ART= .44. ADT = 2.03// Total bit hours = 24.29. Total jar hrs = 103.97 8/24/2017 8/24/2017 0.75 SURFAC CASING CIRC P Rotate and circulate from 1,775' MD to 1,777.0 1,777.0 21:15 22:00 1,718' MD with 500 GPM, 960 PSI DPP. 40% F/O. 60 RPM, 2K Q UP WT=105K. DWN WT=100K. ROT = 103K 2K TO total slits pumped 2,872. 8/24/2017 8/24/2017 0.50 SURFAC CASING OWFF P OWFF. Hydrates noted breaking out. 1,777.0 . 1,777.0 22:00 22:30 slowed down significantly. Continue to POOH as planned. 8/24/2017 8125/2017 1.50 SURFAC CASING BKRM P BKRM OOH from 1,777'to 1,292' MD. 1,777.0 1,292.0 22:30 00:00 550 GPM Q 1,128 PSI DPP. RPM =- 60. 2K TO. UP WT=95K. DWN WT = 92K. ROT= 95K. 8/25/2017 8/25/2017 2.25 SURFAC CASING BKRM P Continue to BKRM OOH from 1,292- 1,292.0 398.0 00:00 02:15 398' MD. 500 GPM @ 730 PSI DPP. 33% F/O. 60 RPM, 2K TO. 8/25/2017 8/25/2017 0.75 SURFAC CASING BKRM P BKRM with CBU from 398' to 305' MD 398.0 305.0 02:15 03:00 500 GPM @ 680 PSI DPP. 33% F/O. 40 RPM, 1 K TO, total strokes pumped = 2,200. BD top drive. monitor well for 10 min. static with slight gas breakout. UPWT=68K. DWN WT=71K. 8/25/2017 8/25/2017 2.00 SURFAC CASING BHAH P RB stand 1 and break / LD 305.0 0.0 03:00 05:00 Schlumberger directional tools as per DD. 8/25/2017 8125/2017 0.75 SURFAC CASING BHAH P Clean and clear rig floor of all handling 0.0 0.0 05:00 05:45 equip etc. 8/25/2017 8/25/2017 2.00 SURFAC CASING RURD P RU all 10 3/4" handding equipment for 0.0 0.0 05:45 07:45 10 3/4" casing. slips / Volant / elevators and empty pipeshed of BHA, and load shoe track. 8/25/2017 8/25/2017 0.25 SURFAC CASING SFTY P Pre -job safety meet for running 10 3/4" 0.0 0.0 07:45 08:00 HYD 563. Page '2179 Report Printed: 1013012017 Uperations Summary (with Timelog uepths) IH-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tune End Time Dur (hr) Phase Op Cade Activity Code Time P-T-X Opealinn Start Deph (NCB) End Deptli(N(6) 8/25/2017 8/25/2017 1.00 SURFAC CASING PUTS P RIH with 10 3/4" shoe track to 105' 0.0 105.0 08:00 09:00 MD. Baker lock shoe track and install cent / stop rings as per pipe detail. Check floats & pump through at 8 BPM = 24% F/O. 4 BPM = 17% F/O. 2 BPM = 11 % F/0. 8/25/2017 8/25/2017 5.25 SURFAC CASING PUTB P RIH from 105'- 1,725' MD. monitor 105.0 1,725.0 09:00 14:15 disp via pits 3-6. Fill on the fly every 5 joints. TO all conn to 23K FT/LBS. install cent on all connections. 8/25/2017 8/25/2017 0.50 SURFAC CASING HOSO P MU casing hanger and land joint. 1,725.0 1,771.0 14:15 14:45 Remove slips and wash down to landing ring with 4 BPM @ 215 PSI DPP. Set on hngr with 103K UP WT - 114K. A # 41 last joint with a centralizer, 43 centralizers and 4 stop rings were run. 8/25/2017 8/25/2017 0.50 SURFAC CEMENT SFTY P PJSM with all crews on cement 1,771.0 1,771.0 14:45 15:15 program. RU on cement hose B/D top drive. 8/25/2017 8/25/2017 7.00 SURFAC CEMENT CMNT P Stage pumps up to 8 BPM 290 PSI 1,771.0 1,771.0 15:15 22:15 DPP with 268 PSI FDPP. 23% F/O. While recip from 1,740-1770' MD. Pump maker sweep and observe back at 3,650 STKS. 12,000 Total stks pumped @ 8 BPM. UP WT = 117K OWN WT =I 09K. Lineup SLB pump 5 BBLS CWto PT lines & chart 3,500 - PSI test. Pump remainder CW for total BBLS of 40 @ 3.1 BPM 75 PSI DPP. 15% F/O. Batch up and pump 77.4 BBLS 10.5 PPG Mud Push. @ 3.5 BPM 115 PSI DPP. 19% F/O. Drop BTM plug. Batch and pump 298 BBLS of 11# cement @ 5.6 BPM 180 PSI DPP, 21 % F/O. Batch and pump 61.9 BBLS 12# tail cement and pump at 4 BPM 164 PSI DPP with 19% F/O. Drop top ;iug and pump with 10 BBLS H2O, UP WT = 11 K-DWN WT = 95K. Chase cement with rig pumps utilizing 9.6# mud @ 5 BPM 330 PSI 31-55% F/O. from 1356 STKS reduce rate to 3 BPM 300 PSI FCP 56% F/O. Bump plug at 1,502 STKS at 2207. increase pressure to 1,082 PSI and hold for 5 min. Bleed off pressure and check floats. GOOD. Cement in place at 2207 hrs. Recip until last 30 bbls pumped. Circulated contaminated cement to surface 67.7 bbls prior to bumping the plug, circulated 9 bbis of good 11. ppg cement to surface. CIP 2207 hrs 8/25/2017. 8/25/2017 8/26/2017 1.75 SURFAC CEMENT RURD PRD cement equipment B/D cement 1,771.0 0.0 22:15 00:00 lines. B/O landing joint and lay down . Clean pits and flow box. Drain stack , - PU 5" lest joint to wash stack. Page 3179 Report Printed: 10/30/2017 Operations Summary (with Timelog Liepths) Aeft 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our Thar) Phase Op Cade Activity Cade Time P -T -X Operation Start Depth (ftKB) End DepN(ftKB) 8/26/2017 8/26/2017 1.50 SURFAC CEMENT WWWH P Clean dg floor of casing equipment. 0.0 0.0 00:00 01:30 Flush stack and set black water pill in place. Rinse out same. Suck out cellar and UD test jt. 8/26/2017. 8/26/2017 4.00 SURFAC CEMENT NUND P ND surface annular, Tee / starting 0.0 0.0 01:30 05:30 head. Remove riser and flange. PUII back diverter line. Measured cement in conductor, 2' below starting head at the 4" drain outlets. 8/26/2017 8/26/2017 1.75 SURFAC WHDBOP NUND P Clean hanger neck, install Vetco grey 0.0 0.0 05:30 07:15 MB222 wellhead. Test seal sub to 2000 psi f/ 10 min (good). Test witnessed by Granville Rizek. 8/26/2017 8/26/2017 4.75 SURFAC WHDBOP NUND P NU hi pressure riser and BOPE stack. - 0.0 0.0 07:15 12:00 Install choke and kill lines. Install riser / flange install 1502 unionson tbg. IA/OA valves. Install test plug and MU dart / TIW valves, RU test pump. 8/26/2017 8/26/2017 1.25 SURFAC WHDBOP NUND P DNL valve IA & OA, Plug seocndary 0.0 0.0 12:00 13:15 IA, install safety slings on choke & kill, air up boots. 8/26/2017 8/26/2017 8.75 SURFAC WHDBOP BOPE P Flush and fill stack and choke. TEst 0.0 0.0 13:15 22:00 BOPE all test to 250 low / 3,500 PSI high for 5 min each with exception of man operated and super chokes to 25/2000 \PSI for 5 min. Tested with 4 1/2" - 5 "- 7 5/8" . Tested LPR's, 1-12S, and combustible gas alarms. Test witness waived by Chuck Scheve. Drawdown initial = 1,550 man, 3,000 ACC. 800 Ann. 1850 PSI after function of Ann, 3 rams. & 2 HCR's. 200 PSI build = 11 sec. Full press = 51 sec. 6 BTL average = 1,925 PSI. BD and RD test equipment. Pull test plug set wear bushing. 8/26/2017 8/27/2017 2.00 SURFAC CEMENT SLPC P Hang blocks cut 59' DL. Slip on 0.0 0.0 22:00 00:00 ssame. 8/27/2017 8/27/2017 1.00 SURFAC CEMENT SLPC P Unhang blocks and recalibrate 0.0 0.0 00:00 01:00 totoo/amphion system for block height. 8/27/2017 8/27/2017 1.00 SURFAC CEMENT SVRG P Service topdrive. 0.0 01:00 02:00 8/27/2017 8/27/2017 2.50 SURFAC CEMENT BHAH P MU BHA #2. as per DD. RIH to 829' 0.0 829.0 02:00 04:30 MD. Monitor displacement via pill. 8/27/2017 8/27/2017 0.75 SURFAC CEMENT PULD P RIH to 1,583' MD. Monitor DISP via 829.0 1,583.0 04:30 05:15 pit 1. Change out joint number 20 and kick out as it is bent. 8/27/2017 8/27/2017 0.50 SURFAC CEMENT DHEQ P Circulate at 500 GPM / 915 PSI DPP. 1,583.0 1,583.0 05:15 05:45 32% F/O. Shallow hole test MWD (GOOD) total stks pumped = 1,400. MW-in=9.5, MW -cut =9.6.. UP WT =104K DWN WT=99K. ROT - 101k. 8/27/2017 8/27/2017 1.25 SURFAC CEMENT PRTS P RU test OA valve and casing to 3,000 1,583.0 1,583.0 05:45 07:00 PSI charted (GOOD) RD test equip. 26 slks t / pressure up. 2.7 BBLS bleed back. Page 4/79 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1H-102 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 Operation mKS) End Depth(MKB) 8/27/2017 8/27/2017 0.50 SURFAC CEMENT COCF P Wash down from 1,583'to 1,670' MD. 1,583.0 1,670.0 07:00 07:30 400 GPM @ 600 PSI. 26% F/O. UP WT=106K. DWN WT=98K. ROT= 100K. 8/27/2017 8/27/2017 2.25 SURFAC CEMENT DRLG P Drill out cement plugs to float collar 1,670.0 1,777.0 07:30 09:45 with 380 GPM 555 PSI DPP. 25% F/O. 60-70 RPM 2-6K TO. 3-18K WOB. Continue to drill cement R shoe with 500 GPM 890 PSI DPP. 33% 1`/0. 3K WOB, 60 RPM. 2-5K TQ. TOC @ 1,670' MD. TOP plugs @. 1,683.4 TOP F/C @ 1,683'. Top F/C@ 1,685.5' BTM FIC, 1,686.7'. Top shoe @ 1,768.84' BTM Shoe @ 1,770.12 MD. Drill rathole out to 1777' MD. 8/27/2017 8/27/2017 0.25 SURFAC CEMENT DDRL P Drill 20'of new hole from 1777'- 1,777.0 1,797.0 09:45 10:00 1,797' MD W/500 GPM w 500 GPM 910 PSI 33% F/O. 60 RPM. 4K TO. 3K WOB. ADT .26 total bit hours = .26 Total jar hours = 50.81 8/27/2017 8/2712017 1.00 SURFAC CEMENT CIRC P Circulate bottoms up while rotating 1,797.0 1,797.0 10:00 11:00 and recip from 1,796 - 1,713' MD with 500 GPM @ 900 PSI. 32% F/O 60 RPM 3.5K TQ.. Total STKS pumped = 5,824. 9.6 MW IN/OUT. 10 min gel = 14. 8/27/2017 8/27/2017 1.00 SURFAC CEMENT FIT P R/U flood lines for FIT/LOT to 12.5 1,797.0 1,797.0 11:00 12:00 PPG. 40 STKS pumped. 0 BBLS bleed back. STBY for orders. 8/27/2017 8/2712017 1.00 SURFAC CEMENT WAIT T Wait on orders from town for plan 1,797.0 1,797.0 12:00 13:00 forward. 8/27/2017 8/27/2017 1.00 SURFAC CEMENT FIT T RU for FIT. Obtained LOT 12.6 1,797.0 1,797.0 13:00 14:00 PPGEMW w/ 9.6 ppg mud weight, 262 psi and 1691.1 TVD. 24 STKS were pumped (2.4 bbls) 0 BBLS returned. RD. 8/27/2017 8/27/2017 3.75 SURFAC CEMENT COND T Begin making up LCM pill as per 1,797.0 1,779.0 14:00 17:45 program. Mix up number 2 FINE 10 PBL, #2 MED 20# PBL, Nut plug fine 5 PBL, Nut Plug Med 5# PBL. mix 50 BBLS to pump 35. perform dg maintenance during mixing. 8/27/2017 8/27/2017 0.25 SURFAC CEMENT CIRC T Pump 35 BBLS of 40# LCM at max 1,779.0 1,779.0 17:45 18:00 rate displacing with 34 bbis 9# LSND. 8/27/2017 8/2712017 1.25 SURFAC CEMENT TRIP T Trip OOH from 1779'-1397' MD to 1,779.0 1,397.0 18:00 19:15 begin squeeze LCM operations. Monitor disp via TT. 8/27/2017 8/28/2017 4.75 SURFAC CEMENT SQEZ T Circulate 8 BBLS at 2 BPM to ensure 1,397.0 1,397.0 19:15 00:00 no LCM left in DP. RU circ equipment with ANN closed to SQZ LCM @.6 BPM. 264 PSI, Shut in and monitor/bleed off. Repeat 10X with gradual increasing pressure to 320 PSI. SQZ total of 4 BBLS into formation. Ending pressure of SQZ sessions = 1. 144 PSI 2. 206 PSI, 3. - 278 PSI, 4. 286 PSI 5.270 PSI, 6. 292 PSI, 7.305 PSI, 8.316 PSI, 9.326 PSI, 10. 324 PSI. Page 5179 Report Printed: 10130120171 . Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sta Stan Toe End Time omr its) Phase Op Cotle Activity Code lime P -Lx Operation Start Depth (rt De End Depth take) 8/28/2017 8/28/2017 0.50 SURFAC CEMENT SQFZ T Perfom SQZ push #11 to 306 PSI. 1,397.0 1,397.0 00:00 00:30 1 hold for tem min. 8/28/2017 8/28/2017 0.50 SURFAC CEMENT SVRG P Service rig. 1,397.0 1,397.0 00:30 01:00 8/28/2017 8/28/2017 1.00 SURFAC CEMENT WASH T Wash down to 1,770' MD. @ 5 BPM 1,397.0 1,770.0 01:00 02:00 140 PSI, 18% F/O UP WT = 110K, DWN WT = 102K. 8/28/2017 8/28/2017 0.50 SURFAC CEMENT CIRC T Circulate bottoms up while rotating / 1,770.0 . 1,770.0 02:00 02:30 . circulating from 1,276'- 1,680' MD. With 500 GPM, 545 PSI, 31 % F/O. 60 RPM, 3K TQ. 9.0 MW in/out. total STKS pumped = 2,260. UP WT = 110K. DWNWT=106K. 8/28/2017 8/28/2017 1.00 SURFAC CEMENT LOT T Perform last FIT to 12.6 PPG EMW 1,770.0 1,770.0 02:30 03:30 and call town. 10 stks to 320 PSI. 10 min bleed off 320 - 245 PSI. 12.6 PPG pic. Discussed pressures, LCM squeezed away and timing. 8/28/2017 8/28/2017 2.50 INTRMI DRILL DDRL P Make connection and downlink to 1,770.0 1,961.0 0330 06:00 EXCEED. DIM 9 7/8" hole from 1,770' - 1,961" MD 1,847" TVD. 550 GPM @ 665 PSI DPP. 35% F/O, 60 RPM 3.5K TO, 1K WOB. ECD's 9.8 PPG. Off bottom 665 PSI DPP. UP WT = 110K DWN WT = 102K. ROT = 106K. 2K TQ. ADT- 1.67, Bit hrs 1.93, Jar hrs 52.48. 8/28/2017 8/28/2017 6.00 INTRMI DRILL DDRL P Dtill 9 7/8" hole from 1,961"MID - 1,961.0 2,594.0 06:00 12:00 2,594' MD 2,253' TVD. 550 GPM @ 735 PSI DPP. 34% F/O, 120 RPM 4K TO, 4.5K WOB. ECD's 9.86 PPG. Off bottom 730 PSI DPP. UP WT = 119K DWN WT=105K. ROT =112K. 3.5K TO. ADT- 4.6, Bit hrs 6.27, Jar hrs 56.82. MAx gas 220 units. SPR's 2,245' MD 2,050 TVD MW = 9.1 PPG @ 0900 hrs MP1) 30 SPM 120 PSI 40 SPM 140 PSI MP2) 30 SPM 120 PSI 40 SPM 140 PSI 8/28/2017 8/28/2017 6.00 INTRMI DRILL DDRL P Dtill 9 7/8" hole from 2,594' MD - 2,594.0 3,193.0 12:00 18:00 3,193' MD 2,510' TVD. 595 GPM @ 890 PSI DPP. 34% F/0, 100 RPM 6- 9K TQ, 10K WOB. ECD's 9.86 PPG. Off bottom 885 PSI DPP. UP WT = 131KDWNWT=91K. ROT=110K. 4K TQ. Max gas 220 units. SPR's 2,813' MD 2,363 TVD MW = 9.0 PPG @ 1400 hrs MP1) 30 SPM 140 PSI 40 SPM 160 PSI MP2) 30 SPM 130 PSI 40 SPM 150 PSI Page- 6179 Report Printed: 10130120171 Operations Summary (with Timeiog Depths) 111-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Mme End Time Dur(hr) Phase Op Code A vky Corte Tune P -T -X Operation start Depth (MB) End Depth(ItKB) 8/28/2017 8/29/2017 6.00 INTRMI DRILL DDRL P DIM 97/8" hole from 3,193' MD- 3,193.0 3,750.0 18:00 00:00 3,750' MD 2,672' TVD. 650 GPM @ ' 1135 PSI DPP. 35% F/O, 100 RPM 6- 9K TO, 8K WOB. ECD's 10.04 PPG. Off bottom 1135 PSI DPP. UP WT = 125KDWNWT=96K. ROT=110K. 6K TO. Max gas 96 units. ADT 8.92, Bit hrs 15. 19, Jar hrs 65.74 SPR's 3,571' MD 2,620' TVD MW = 9.0 PPG @ 2200 hrs MP1) 30 SPM 160 PSI 40 SPM 180 PSI MP2) 30 SPM 150 PSI 40 SPM 180 PSI 8/29/2017 8129/2017 6.00 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 3,750.0 4,424.0 00:00 06:00 hole from 3750'to 4424' MD, 2867' TVD. Pump at 700 gpm, 1430 psi on- btm, 1430 psi off-btm, 36% F/0, ECD 10.36 ppg. Rotate at 120 rpm with 5- 13k Tq on-btm, 7k off-btm. 9k WOB. PUW 132k, SOW 92k, ROT 111 k. Max gas of 122 units. ADT 4.93 hrs, Bit 20.12 hrs, Jars 70.67 hrs. Pump hi - vis sweep with 4 ppb Nut Plug Medium every 4 x stands. - SPRs @ 4045' MD 2757' TVD, MW=9.0 ppg, 02:30 hours MP#1: 30 spm=160 psi, 40 spm=200 psi. MP #2: 30 spm=160 psi, 40 spm=200 psi. 8/29/2017 8129/2017 6.00 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 4,424.0 5,010.0 06:00 12:00 hole from 4424'to 5010' MD, 3042' TVD. Pump at 675 gpm, 1410 psi on- blm, 1405 psi off-blm, 35% F/O, ECD 10.22 ppg. Rotate at 150 rpm with 10k Tq on-btm, 7.5k Tq off-btm. 11k WOB. PUW 139k, SOW 96k, ROT 113k. Max gas of 146 units. ADT 4.31 hrs, Bit 24.43 hrs, Jars 74.98 hrs. Continued seeing high stick slip, increased lubes by 0.5% Lo-Torq, total concentration in mud at 1.5% Lo-Torq. Pump hi -vis sweep with 4 ppb Nut Plug Medium every 4-5 stands. SPRs @ 4610' MD 2921' TVD, MW=9.05 ppg, 07:58 hours MP#1: 30 spm=180 psi, 40 spm=220 psi. MP #2: 30 spm=180 psi, 40 spm=220 psi. Page 7179 Report Printed: 10/3012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Suit Time End Time O pv) Phase Op Code Activity Code Time P44 Operation Start Depth rt De End Depth (tIKB) 8/29/2017 8/29/2017 6.00 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 5,010.0 5,384.0 12:00 18:00 hole from 5010'to 5384' MD, 3160' TVD. Pump at 603 gpm, 1200 psi on- btm, 1200 psi off-btm, 34% F/O, ECD 10.07 ppg. Rotate at 100 rpm with 9- 11 k Tq on-btm, 7.5k Tq off-btm. 6k WOB. PUW 139k, SOW 99k, ROT 117k. Max gas of 132 units. ADT 4.5 hrs, Bit 28.93 hrs, Jars 79.48 hrs. Pump hi-vis sweep with 4 ppb Nut Plug Medium every 5 x stands. SPRs @ 5084' MD 3065' TVD, MW=9.05 ppg, 12:40 hours MP#1: 30 spm=190 psi, 40 spm=230 psi. MP #2: 30 spm=190 psi, 40 spm=230 psi. 8/29/2017 8/30/2017 6.00 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 5,384.0 5,835.0 18:00 00:00 hole from 5384'to 5835' MD, 3297' TVD. Pump at 603 gpm, 1295 psi on- btm, 1295 psi off-btm, 35% F/O, ECD 10.24 ppg. Rotate at 130 rpm with 11- 13k Tq on-btm, 9k Tq off-btm. 11k WOB. PUW 147k, SOW 95k, ROT 121 k. Max gas of 327 units. ADT 4.42 hrs, Bit 33.35 hrs, Jars 83.9 hrs. Encountered hard spot at 5455' - 5460' MD. SPRs @ 5655' MD 3065' TVD, MW=9.05 ppg, 12:40 hours MP#1: 30 spm=190 psi, 40 spm=230 psi. MP #2: 30 spm=190 psi, 40 spm=230 psi. Total downhole losses for past 24 hours = 68 bbls. 8/30/2017 8/30/2017 6.00 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 5,835.0 6,339.0 00:00 06:00 hole from 5835' to 6339' MD, 3433' TVD. Pump at 600 gpm, 1335 psi on- btm, 1330 psi off-btm, 35% F/O, ECD 10.23 ppg. Rotate at 140 rpm with 11- 12k Tq on-btm, 9k Tq off-btm. 4k WOB. PUW 152k, SOW 98k, ROT 121 k. Max gas of 590 units. ADT 4.76 hrs, Bit 38.11 hrs, Jars 88.68 hrs. Pump 50 bbl hi-vis sweep at -6000' MD and observe -20% increase in cuttings, it came back -600 strokes early. Drill through hard spots @ 5861' - 5867', 6081'- 6087', and 6161'- 6164'. SPRs @ 6313' MD 3424' TVD, MW=9.10 ppg, 05:35 hours MP#1: 30 spm=220 psi, 40 spm=260 psi. MP #2: 30 spm=220 psi, 40 spm=260 psi. Page 8179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slert Depth De Sled Tone End Tune Our (hr) Phase Op Code Activity Code Time P -T -x Operation (rt Oeptll (nom) 8/30/2017 8/30/2017 6.00 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 6,339.0 -End 6,837.0 06:00 12:00 hole from 6339' to 6837' MD, 3585' TVD. Pump at 550 gpm, 1150 psi on- btm, 1145 psi off-btm, 34% F/O, ECD 10.16 ppg. Rotate at 120 rpm with 7- 16k Tq on-btm, 10k Tq off-btm. 3k WOB. PUW 167k, SOW 93k, ROT 1261k. Max gas of 250 units. ADT 4.98 hrs, Bit 43.09 hrs, Jars 93.64 hrs. Increase lubes to 2.0% Lo-Torq to try and help with continued high stick -slip. Drill hard spot @ 6483'. Pump hi -vis sweep at 6600' and observe -10% increase in cuttings, it came back -800 strokes early. 8/30/2017 8/30/2017 6.00 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 6,837.0 7,176.0 12:00 18:00 hole from 6837' to 7176' MD, 3682' TVD. Pump at 510 gpm, 1055 psi on- btm, 1055 psi off-btm, 31 % NO, ECD 10.09 ppg. Rotate at 100 rpm with 10- 15k Tq on-btm, 9.5k Tq off-btm. 18k WOB. PUW 164k, SOW 99k, ROT 126k. Max gas of 737 units. ADT 3.73 hrs, Bit 46.82 his, Jars 97.37 hrs. Drill hard spots at 6929'- 6931', 7173'- 7176'. SPRs @ 6885' MD 3598' TVD, MW=9.10 ppg, 12:30 hours MP#1: 30 spm=230 psi, 40 spm=280 psi. MP #2: 30 spm=230 psi, 40 spm=280 psi. 8/30/2017 8/31/2017 6.00 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 7,176.0 7,421.0 18:00 00:00 hole from 7176'to 7421' MD, 3750' TVD. Pump at 697 gpm, 1800 psi on- btm, 1800 psi off-btm, 35% IF/O, ECD 10.19 ppg. Rotate at 120 rpm with 13k Tq on-btm, 9.5k Tq off-btm. IOk WOB. PUW 164k, SOW 99k, ROT 126k. Max gas of 161 units. ADT 5.26 hrs, Bit 52.08 hrs, Jars 102.63 his. Observe fault at 7211' MD with -50' down -to -south throw. Drill hard spots from 7176'- 7180' and 7404'- 7415'. Pump 50 bbls hi -vis sweep at 7260' and observe -10% increase in cuttings, it came back -900 strokes early. Downhole losses for past 24 hours = 21 bbis. Page 9179 Report Printed: 10130/2017 Operations Summary (with Timelog Depths) IH-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan T Toe End Time Dur (hr) Phase Op Cotle Activity Code Time P-T-% Operation Start Depth (n De Emf Depth (flKa) 8/31/2017 8/31/2017 6.00 INTRM1 DRILL DDRL P Directionally drill 9-7/8" intermediate 7,421.0 7,673:0 00:00 06:00 hole from 7421'- 7673' MD, 3817' TVD. Pump at 700 gpm, 1860 psi on- trim, 1655 psi off-btm, 35% F/O, ECD 10.39 ppg. Rotate at 110 rpm with 14k Tq on-btm, 11 k Tq off-btm. 1 Ok WOB. PUW 164k, SOW 97k, ROT 128k. Max gas of 480 units. ADT 3.97 hrs. Bit 56.05 hrs. Jars 106.6 hrs. Drill through concretions at 7427' - 7436', 7467' - 7469', 7557' - 7561', and 7664'- 7673' MD. SPRs @ 7450' MD 3758' TVD, MW=9.10 ppg, 01:00 hours MP#1: 30 spm=230 psi, 40 spm=260 psi. MP #2: 30 spm=230 psi, 40 spm=260 psi. 8/31/2017 8/31/2017 6.00 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 7,673.0 8,142.0 06:00 12:00 hole from 7673'- 8142' MD, 3943' TVD. Pump at 700 gpm, 1990 psi on- btm, 1985 psi off-btm, 35% F/O, ECD 10.62 ppg. Rotate at 150 rpm with 14k Tq on-btm, 11 k Tq off-btm. 7k WOB. PUW 171 k, SOW 99k, ROT 129k. Max gas of 620 units. ADT 4.84 hrs, Bit 60.89 hrs, Jars 111.44 hrs. Drill through concretions at 7673' - 7677', 7771'- 7773', 7809'- 7813', and 7963'- 7967', 8/31/2017 8/31/2017 6.75 INTRM1 DRILL DDRL P Directionally drill 9-7/8" intermediate 8,142.0 8,598.0 12:00 18:45 hole from 8142' to TO of 8698' MD, 3991' TVD. Pump at 697 gpm, 2015 psi on-bim, 2010 psi off-btm, 36% F/O, ECD 10.65 ppg. Rotate at 130 rpm with 12-16k Tq on-btm, 12.4k Tq off-blm. 1O WOB. PUW 173k, SOW 92k, ROT 131 k. Max gas of 1048 units. ADT 4.43 hrs. Bit 65.32 hrs. Jars 115.87 hrs. Pump 70 bbl hi-vis sweep just prior to TD and observe it bring back -10% increase in cuttings, at surface -900 strokes early. Drill through concretion at 8342' - 8344' MD. SPRs @ 821 VMD 3961' TVD, MW=9.30 ppg, 12:55 hours MP#1: 30 spm=300 psi, 40 spm=360 psi. MP #2: 30 spm=300 psi, 40 spm=360 psi. Downhole losses for past 18:45 his = 39 bbls Total downhole losses while drilling Interval = 128 bbls. Page 10179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Tfine Log S1ad Time End Time Dur(hr) Phase Op Code Activity Cade Time P -T -X Operation Siad Depth (ftKB) End DepM(ftKB) 8/31/2017 8/31/2017 1.00 INTRMI CASING BKRM P Obtain final T&D paramters, SPR'9, 8,598.0 8,500.0 18:45 19:45 and survey at TD, Downlink Xceed to neutral. PUW 173k, SOW 921k, ROT 131k w/ 12.4k Tq. Backream out stand to 8500' MD with 697 gpm, 2030 psi, 35% F/O, 120 rpm, 11-16k Tq, ECD 10.62 ppg SPRs @ 8598' MD 3991' TVD, MW=9.25 ppg, 19:05 hours MP#1: 30 spm=310 psi, 40 spm=360 psi. MP #2: 30 spm=310 psi, 40 spm=360 psi. 8/31/2017 8/31/2017 0.50 INTRMI CASING OWFF P Monitor well for flow for 30 minutes- 8,500.0 8,500.0 19:45 20:15 observe fluid level drop -1 ft in riser over 30 minutes, calculated to -0.5 bbl/hr static loss rate. 8/31/2017 9/1/2017 3.75 INTRM1 CASING BKRM P Backream OOH from 8500'to 7362' 8,500.0 7,362.0 20:15 00:00 MD with 697 gpm, 1905 psi, 35% F/0, ECD 10.45 ppg. Rotate at 120 rpm with 11-16k Tq, ROT 123k. Monitor displacement via pits #1-5. Lay down 5" DP via mousehole. Calculated displacement = 8.4 bbls. Actual displacement = 23 bbls. 9/1/2017 9/1/2017 6.00 INTRMI CASING BKRM P Backream OOH from 7362'- 4849' 7,362.0 4,849.0 00:00 06:00 MD with 700 gpm, ICP 1910 psi, FCP 1660 psi, 36% F/O, Initial ECD 10.45 ppg, Final ECD 10.46 ppg. Rotate at 120 rpm with 7k Tq. PUW 135k, SOW 92k. Monitor displacement via pits #1- 5. Increase pulling speed up to 1000 f thr. MW 9.3 ppg. SIMOPS: Floorhands lay out 5" DP stands using mousehole while backreaming out. At 1000 ft/hr pulling speed, floorhands finish laying out stand by the time driller reaches top of next stand. 9/1/2017 9/1/2017 6.00 INTRM1 CASING BKRM P Backream OOH from 4849'- 3010' 4,849.0 3,010.0 06:00 12:00 MD with 698 gpm, ICP 1660 psi, FCP 1470 psi, 35% F/O, Initial ECD 10.48 ppg, Final ECD 10.30 ppg. Rotate at 120 rpm with 5k Tq. Pull at -700 R/hr from 4849'to 3120'then drop pulling speed to 200 R/hr as ECD increased, up to a 10.70 ppg highest seen @ -3240' MD. MW 9.3 ppg. SIMOPS: Floorhands lay out 5" DP stands using mousehole while backreaming out. Page 11/79 ReportPrinted: 10/30/2017 Operations Summary (with Timelog Depths) } IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log StartTime FSA Time Our (hr) Phase Op Cetle Atlivity Code Time P -T-% Operation Start oefxh (flKS) End Depth(fiKa) 9/1/2017 9/1/2017 5.50 INTRMI CASING BKRM P Backream OOH from 3010' - 1771' 3,010.0 1,771.0 12:00 17:30 MD with 697 gpm, ICP 1470 psi, FCP 1290 psi, 36% F/O, Initial ECD 10.30 ppg, Final ECD 9.96 ppg. Rotate at 120 rpm with 2.5k Tq. Pull at 200-500 Whir with max ECD of 10.88 ppg seen - at -2350' MD. MW 9.3 ppg. Observed ECD drop -0.3 ppg as we pulled the BHA into casing. SIMOPS: Floorhands layout 5" DP stands using mousehole while backmarring out. 9/1/2017 9/1/2017 0.25 INTRMI CASING OWFF P Monitor well for flow at the shoe - well 1,771.0 1,771.0 17:30 17:45 static. 9/1/2017 9/1/2017 1.25 INTRM1 CASING BKRM P Backream OOH from 1771'- 1397' 1,771.0 1,397.0 17:45 19:00 MD with 697 gpm, 1215 psi, 34% F/O, ECD 9.83 ppg. Rotate at 100 rpm, 21k Tq. Observe hole unload at -1550' MD and then shakers cleaned up. SIMOPS: Floorhands lay out 5" DP stands using mousehole while backreaming out. 9/1/2017 9/1/2017 1.00 INTRMI CASING PULD P Pull OOH on elevators from 1397'- 1,397.0 829.0 19:00 20:00 829' MD, laying out 5" DP sideways and monitoring displacement via trip tank. 911/2017 9/1/2017 0.25 INTRMI CASING OWFF P Monitor well for flow at top of BHA - 829.0 829.6- 20:00 20:15 well static. 9/1/2017 9/1/2017 2.50 INTRMI CASING BHAH P Pull OOH on elevators from 829'to 829.0 0.0 20:15 22:45 surface, laying out BHA #2 per DD. Observe large amount of wear on upper NM integral blade stabilizer with unusual wear pattern, significant wear on 8-3/8" sleeve stabilizer with only -2" of blades remaining and stabilizer loose from original position, and minimal wear on the two NM stabs on - the Xceed. The bit had multiple broken teeth and chipped teeth but was in - gauge. 9-7/8" Smith MSi516 PDC Bit grade: 2 3 -BT -A -X -0 -CT -TD Upper 9-3/4" NM Integral Blade Stabilizer: 1-5/16" undergauge 8-3/8" NM Straight -blade sleeve stabilizer: minimal amount of stabilizer remaining Upper Xceed 9-3/4" NM Integral Blade Stabilizer: In -gauge Lower Xceed 9-3/4" NM Integeral Blade Stabilizer: 1/16" undergauge Calculated displacement for trip = 90.9 bbls Actual displacement for trip = 126.0 bbis 9/1/2017 9/1/2017 0.50 INTRM1 CASING SHAH P Clean and clear floor of BHA 0.0 0.0 22:45 23:15 1 equipment. Page 12179 Report Printed: 1 013 0/2 01 7 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Siad Tune EM Time Dur (hr) Phase Op Code A fivity Code Time P.T-x Opendsm Stan Depth (fiKa) End Depth (RKe) 9/1/2017 9/1/2017 0.50 INTRMI CASING WWWH P Make up 2 x 5" DP singles, XO, and 0.0 0.0 23:15 23:45 stack washer. Jet stack and wellhead with 819 gpm. 9/1/2017 9/2/2017 0.25 INTRMI CASING RURD P Lay out stack washer and make up 0.0 0.0 23:45 00:00 wearbushing retrieval tool. 91212017 9/2/2017 0.50 INTRMI CASING RURD P Pull Vetco Grey wearbushing with 0.0 0.0 00:00 00:30 retrieval tool. Lay down both. 9/2/2017 9/2/2017 1.50 INTRMI CASING RURD P Rig up Volant casing running tool. Pick 0.0 0.0 00:30 02:00 up spiders and side door elevators. Install bail extensions. Stage 7-5/8" casing pups on the rig floor. Load top row of casing in the shed (16 its). 9/2/2017 9/2/2017 4.50 INTRMI CASING PUTB P Make up jt # 1 with the Weatherford 0.0 1,771.0 02:00 06:30 float shoe ((2) 7-518" x 9-3/8" OD centralizers & total of 4 stop rings. Centralizer 1 O' f/ each end). Jt # 2 centralzied the same as above, and it 3 with the Davis Lynch double valve float collar (no centralizers on it #3). MU joint #4 (pin end of #4 and all below are baker locked).Check floats, OK. Continue to run 7-5/8" 29.7# L-80 Hydril 563 dopeless casing per tally to jt # 41. PU wt 86k, SO wt 88k. Fill pipe on the fly and top off every 10 its. Install centralizers per tally. Install pups per tally. Make up with 14k Tq to make-up mark. NO CENTRALIZERS ON THE WINDOW JOINTS, OR JOINT ABOVE AND BELOW. 9/2/2017 9/2/2017 0.50 INTRMI CASING CIRC P Circulate at the 10-3/4" shoe. Stage 1,771.0 1,771.0 06:30 07:00 pumps up to 6 bpm w/ 110 psi. Circulate bottoms up @ 1771'. 9/2/2017 9/2/2017 3.75 INTRMI CASING PUTB P Contiinue to run in w/ 7-5/8" 29.7 ppf L 1,771.0 3,780.0 07:00 10:45 -80 Hyd 563 dopeless casing f/ 1771' to 3780' installing 7-518" x 9-3/8" Volant centralizers floating on jts up to it 105. 90 joints in the hole at this depth. Average MU torque 14k ft lbs. Fill pipe on the fly and top off every 10 its. Install centralizers per tally.. 9/2/2017 9/2/2017 0.75 INTRMI CASING CIRC P Stage pumps up to 6 bpm w/ 200 psi. 3,780.0 3,780.0 10:45 11:30 Once at full rate, circulate bottoms up at 3780'. 9/2/2017 9/2/2017 0.50 INTRM1 CASING PUTB P Contiinue to run in w/ 7-5/8" 29.7 ppf L 3,780.0 4,024.0 11:30 12:00 -80 Hyd 563 dopeless casing fl 3780' to 4024' installing 7-5/8" x 9-3/8" Volant centralizers floating on jts up to jt 105. 96 joints in the hole at this depth. Average MU torque 14k ft lbs. PU wt 120k, SO wt 96k. Fill pipe on the fly and lop off every 10 jts. Install centralizers per tally.. Calculated mud losses -17-19 bbls. E:Z: Page 13/79 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slav Time End'nme Dur (hr) Phase Op CodeAtlivily Code Time P -T -X Operation Start Depth (flKB) End Depth(RKB) 9/2/2017 9/2/2017 2.75 INTRM1 CASING PUTB P Contiinue to run in w/ 7-518" 29.7 ppf L 4,024.0 5,429.0 12:00 14:45 -80 Hyd 563 dopeless casing f/ 4024' to 5429' installing 7-5/8" x 9-3/8" Volant centralizers floating on jts up to it 105. 130 joints in the hole at this depth. Average MU torque 14k If lbs. Fill pipe on the Fly and top off every 10 jts. Install centralizers per tally.. 9/2/2017 9/2/2017 1.25 INTRMI CASING CIRC P Circulate, reciprocate from 5429'to 5,429.0 5,480.0 14:45 16:00 5480', Stage pumps up to 9 bpm w/ 395 psi 27% flow out. After circulating PU wt 155k, SO wt 100k. 9/2/2017 9/212017 2.75 INTRMI CASING PUTS P Contiinue to run in w/ 7-518" 29.7 ppf L 5,480.0 6,873.0 16:00 18:45 -80 Hyd 563 dopeless rasing f/ 5480' to 6873'. 165 joints in the hole at this depth. SOW = 75k Average MU torque 14k it lbs. Fill pipe on the fly and top off every 10 jts. 9/212017 9/2/2017 0.25 INTRM1 CASING RURD T Change out cup on volant tool. 6,873.0 6,873.0 18:45 19:00 9/2/2017 912/2017 1.25 INTRM1 CASING CIRC P Circulate/ reciprocate from 6873'to 6,873.0 6,908.0 19:00 20:15 6908', Stage pumps up to 8 bpm w/ ICP 530 psi, FCP 440 psi, 24% F/O and circulate 1 x bottoms up. After circulating, observe 9.2ppg MW vs 43 going in, 9.35 ppg MW Vis 59 coming out, PUW 178k, SOW 101k. 9/2/2017 9/2/2017 3.50 INTRMI CASING PUTB P RIH w/ 7-5/8" 29.7# L-80 Hyd 563 6,908.0 8,550.0 20:15 23:45 dopepless casing per tally from 6908' to 8550' MD. MUT 14k Calculated displacement = 90.72 bbls Actual displacement = 63.50 bbls 9/2/2017 9/3/2017 0.25 INTRMI CASING HOSO P Make up Vetco 7-5/8" casing hanger 8,550.0 8,550.0 23:45 00:00 using single -stack tongs. Pick up and make up landing joint to hanger. 9/312017 9/3/2017 0.50 INTRM1 CASING HOSO P Finish making up landing joint, run in 8,550.0 8,591.0 00:00 00:30 hole and land off hanger. 9/3/2017 9/3/2017 1.00 INTRMI CEMENT CIRC - P Stage up to 342 gpm and circulate / 8,591.0 8,591.0 00:30 01:30 condition mud with reciprocation, 470 psi, 24% F/O, PUW 184k, SOW 82k. MW in 9.3ppg Vis 50, MW out 9.35ppg Vis 63. 9/3/2017 913/2017 1.50 INTRMI CEMENT CIRC P Rig up cement hose and continue 8,591.0 8,591.6- 01:30 03:00 circulating / conditioning mud at 254 gpm, 480 psi. Hold PJSM for cement job and dg up cementers. Page 14179 ReportPrinted: 10/30120V Operations Summary (with Tirrtelog Depths) i 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Blert fine EM Time Dur (hr) Phase Op Cotla Activity Code Time P -T -X Operation Start Depth (W) Ertl Depth (rtl(B) 9/3/2017 9/3/2017 2.00 INTRMI CEMENT CMNT P Pump cement job as follows: SLB 8,591.0 8,591.0 03:00 05:00 _ pump 5 bbls freshwater and pressure test lines to 400 / 3500 psi - good test. Pump 50 bbls 12.5ppg Mudpush at 3 bpm, ICP 450 psi, FCP 210 psi. Drop Davis Lynch anti -rotational bottom plug. Batch mix cement, cement wet at 03:46 hrs. SLB pump total of 239.3 bbls 15.8ppg Class G cement. Pumped 170 bbls at 6 bpm, ICP 459 psi, FCP 315 psi. Then observe "H" pump fail so swap to "G" pump which has slightly lower rate capacity. Did not have to stop pumping but rate briefly dropped to -3 bpm. Continue pumping additional cement at -4.5 bpm, ICP 230 psi, FCP 190 psi. Drop Davis Lynch anti -rotational top plug. SLB pump 10 bbls freshwater at 4 bpm, 120 psi. Reciprocate pipe -15 it, PUW 220k, SOW 95k. 9/3/2017 9/3/2017 1.25 INTRMI CEMENT CMNT P Swap to rig mud pump #1 and 8,591.0 8,591.0 05:00 06:15 displace cement with 9.3ppg LSND at 8 bpm for 3250 strokes, ICP 242 psi, FCP 1587 psi. Drop rate to 3 bpm and continue displacing cement, ICP 1120 psi. Bump plug at 3797 strokes, FCP 1423 psi. Pressure up to 2000 psi and hold for 5 minutes. Bleed off and check floats - floats holding. Cement in place @ 06:10 hrs. Calculated TOC 4250' MD. Note: Total downhole losses throughout cement job = 11 bola 9/3/2017 9/3/2017 0.75 INTRMI CEMENT PRTS P Pressure up to 3500 psi and hold for 8,591.0 0.0 06:15 07:00 30 minutes to test 7-5/8" casing - good test. Pump 5.6 bbls, returned 5.6 bbls. 9/3!2017 9/3/2017 1.50 INTRMI CEMENT RURD P Rig down and blow down cement line 0.0 0.0 07:00 08:30 and test equipment. Lay down Volant tool and casing handling equipment. 9/3/2017 9!3/2017 1.50 INTRMI CEMENT W WSP P Make up packoff running tool and 0.0 0.0 08:30 10:00 install packoff. Run in lock down screws and lay down running assembly. Inject packoff with packing and pressure test to 5000 psi / 10 min, witnessed by CPAI - good test. SIMOPS: Start rigging in E -line. 9!3/2017 9/3/2017 2.00 INTRMI EVALWB ELOG P Rig up SLB E -line. Pick up Welllec 0.0 0.0 10:00 12:00 tractor and USIT logging tools and Function test at surface. 9/3/2017 9/3/2017 2.50 INTRMI EVALWB ELOG P RIH on E -line from surface to 3000' 0.0 0.0 12:00 14:30 MD and then utilize tractor to run in from 3000' to 7500', average of 57 ft/min with tractor. Page 15179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) IH-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stanne End Time Dor(hr) Phase Op Code Atlmty Cede Time P-T-X Operation sten Depth (N(B) Entl Depth (11101)7s 9/3/2017 9/3/2017 6.00 INTRMI EVALWB ELOG P Pull up and get stretch out of string 0.0 0.0 14:30 22:30 and confirm tool working. Pull OOH on E-line, logging from top of D-sand at 7450' MD to surface at 15 ft/min pulling speed for high-definition resolution. 9/3/2017 9/3/2017 0.75 INTRMI EVALWB ELOG P Rig down E-line equipment. 0.0 0.0 22:30 23:15 9/3/2017 9/4/2017 0.75 INTRM1 CEMENT RURD P Change out saver sub to XT39. 0.0 0.0 23:15 00:00 9/4/2017 9/4/2017 1.00 INTRMI CEMENT TURD P Change out saver sub to XT39. 0.0 0.0 00:00 01:00 Change out die blocks and install bell guide. 9/4/2017 9/4/2017 1.50 INTRMI WHDBOP -ITU—RD P Rig up to test ROPE. Assemble floor 0.0 0.0 01:00 02:30 valves and install ported sub on top drive. Makeup 4-1/2" test joint and test plug. Troubleshoot inability to suck out stack through A. Page 16/79 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Tune End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Opemtion Sled DePM (110) End Depm (ftKB) 9/4/2017 9/4/2017 5.50 INTRMI WHDBOP BOPE P Test BOPE with 4" and 4-1/2" test joint 0.0 0.0 02:30 08:00 to 250/3500 psi 5/5 min, witness waived by AOGCC rep Bob Noble. Test Sequence as follows: 1) 4" XT39 Dart valve and Upper IBOP 2) 4" XT39 FOSV and Lower IBOP 3) Choke valves #12, 13, & 14 4) Choke valves # 9 and 11 5) Choke valves #8 and 10 6) Super and manual chokes Install 4-1/2" test joint 7) Annular, Floor Kill, Choke valves #1, 2, and 5 8) HCR choke and Mezzanine Kill 9) Lower 3-1/2" x 6" pipe rams Install 4" test joint 10) Annular, Manual choke, Manual Kill, and HCR 11) Lower 3-1/2" x 6" pipe rams Pull test joint 12) Blinds, Manual Kill, Choke valves #6 and 7 13) Choke valves #3 and 4. Perform koomey drawdown test: System Pressure = 3,000 psi PSI after closure = 1,900 psi 200 psi Attained with 2 x electric pumps = 8 seconds Full Pressure attained with 2 x electric and 2 x air pumps = 47 seconds N2 = 6 each @ 2,033 psi Tested all gas and 1-12S sensors, PVT and Flow alarms both audio and visual, and functioned primary and remote BOP controls - all good. Upper 7-5/8" casing rams not tested. Note: Started testing surface equipment while finishing up troubleshooting difficulty draining stack through IA valve. Drain stack _ through the production wing port and observe muddy material around top of packoff. Close blind rams, hook up air to one side of IA and blow air through and out the other IA port and clear out packoff ports. Fill stack up with water and confirm no issues draining out through both IA ports. Move forward with installing test plug. 9/4/2017 9/4/2017 1.00 INTRMI WHDBOP RURD P Blow down and dg down test 0.0 0.0 08:00 09:00 equipment. Pull test plug and install Vetco short wearbushing with 9" ID. Page 17179 Report Printed: 10/30/2017 r Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Siert Tme EM Tme Dur(hr) phase Op Code Adivty Code Time P-T-Xstat Operation Depth (ftKB) End Depth(ftKB) 9/4/2017 9/4/2017 1.25 INTRMI CEMENT LOT P Rig up to perform OA leak off test prior 0.0 0.0 09:00 10:15 to freeze protecting. Using mud pump #1, pressure up OA to 740 psi at 7 spm with no indication of leak -off. Kill - pump and shut in. Observe pressure drop to 282 psi after 10 minutes and 210 psi after 45 minutes. Discuss path forward with town. 9/4/2017 9/4/2017 1.25 INTRMI CEMENT BHAH P Make up 6-3/4" production "A2" drilling 0.0 118.0 10:15 11:30 BHA to 118' MD per DD, monitoring displacement via trip tank. SIMOPS: Pressure up on OA with mud pump #1 to 700 psi at 7 spm - observe erratic pressure buildup. Swap to mud pump #2 and continue pressuring up to 960 psi at 7 spm with no indication of leak off. Kill pump and shut in. Observe pressure fall to 300 psi after 40 minutes. Discuss path forward with town. 9/4/2017 9/4/2017 1.00 INTRMI CEMENT LOT P Pressure up on OA with mud pump #2 118.0 118.0 11:30 12:30 to 1460 psi at 7 spm and observe pressure break over and drop to -800 psi. Bullhead total of 80 bbls freshwater, increasing rate to 3 bpm and observe injection pressure stabilize - 470 psi. 9/4/2017 9/4/2017 1.50 INTRMI CEMENT FRZP P Rig up Little Red and pressure test 118.0 118.0 12:30 14:00 lines to 2000 psi. Little Red freeze protect OA with 82 bbls IsoTherm at -1.5 bpm, ICP 335 psi, FCP 1050 psi. Rig down Little Red. After shut in for - 10 minutes, OA pressure = 550 psi. SIMOPS: Service topdrive and blocks. 9/4/2017 9/4/2017 0.75 INTRMI CEMENT BHAH P Continue making up 6-3/4" drilling 118.0 302.0 14:00 14:45 BHA from 118'to 302' MD per DD, monitoring displacement via trip tank. 9/4/2017 9/4/2017 2.50 INTRMI CEMENT PULD P Single in hole on 4" DP singles from 302.0 2,196.0 14:45 17:15 302'- 2196' MD, monitoring displacement via trip tank. 9/4/2017 9/4/2017 0.50 INTRMI CEMENT DHEQ P Fill pipe and shallow hole test MWD 2,196.0 2,196.0 17:15 17:45 tools at 240 gpm, 1100 psi, 19% F/O - good test. 9/4/2017 9/4/2017 3.50 INTRMI CEMENT PULD P Single in hole on 4" DP singles from 2,196.0 5,797.0 17:45 21:15 2196'- 5797' MD, monitoring displacement via trip tank and filling pipe every 20 x stands. Page 18179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log StartTone End Time Ow hr ( ) Phase Op Code Activity Cafe Tinea P -T -X Ope2llon Stall Oeptlt (flKe) FSG OepM (Po(B) 9/4/2017 9/5/2017 2.75 INTRMI CEMENT PULD P Single in hole on 4" DP with super 5,797.0 7,881.0 21:15 00:00 sliders pre-installed from 5797'- 7881' MD, monitoring displacement via trip lank and filling pipe every 20 x stands. Note: Super sliders installed 58" above pin -end on each joint. OA pressure at midnight = 330 psi 9/5/2017 9/5/2017 1.00 INTRMI CEMENT PULD P Single in hole on 4" DP with super 7,881.0 8,433.0 00:00 01:00 sliders pre-installed from 7881' - 8433' MD, monitoring displacement via trip tank. 9/5/2017 9/5/2017 0.25 INTRM1 CEMENT WASH P Make up stand in mousehole and 8,433.0 8,451.0 01:00 01:15 wash down on stand #90 with 221 gpm, 1550 psi, 23% F/O. Tag up on cement stringer at 8451' MD with —4k weight. 9/5/2017 9/5/2017 0.50 INTRMI CEMENT COCF P Ream down from 8451' to 8501' MD 8,451.0 8,501.0 01:15 01:45 and tag top of plugs with 235 gpm, 1850 psi, 24% F/0, 40 rpm, 8-10k Tq, 1-4k WOB. 9/5/2017 9/5/2017 2.75 INTRMI CEMENT DRLG P Drill out plugs, float collar, shoetrack 8,501.0 8,598.0 01:45 04:30 cement, shoe, and rathole from 8501'- 8598' MD with 222 gpm, 1760 psi, 24% F/O, 40-60 rpm, 8-10k Tq, 2-14k WOB. 9/5/2017 9/5/2017 0.25 INTRMI CEMENT DDRL P Drill 20' of new formation from 8598'to 8,598.0 8,618.0 04:30 04:45 8618' MD with 270 gpm, 2280 psi, 26% F/O, 60 rpm with 9k Tq on btm, 6k Tq off btm. 2k WOB. PUW 145k, SOW 62k, ROT 94k. MW 9.3ppg. ADT 0.33 hrs, Bit 0.33 hrs, Jar 0.33 hrs: 9/5/2017 9/5/2017 0.75 INTRMI CEMENT CIRC P Pull up inside shoe to 8588' MD and 8,618.0 8,588.0 04:45 05:30 circulate / condition mud with 240 gpm, 1916 psi, 22% F/0, 60 rpm, 8.5k Tq until even in/out 9.3ppg MW observed. 9/5/2017 9/5/2017 0.75 INTRMI CEMENT FIT P Rig up and perform FIT to 13.0 ppg 8,588.0 8,588.0 05:30 06:15 EMW. Pump down drill pipe and annulus with mud pump #1 to 768 psi with 9.3ppg LSND at 3991' TVD. Shut in and monitor, observe pressure drop to 635 psi after 10 minutes. Pump 1.8 bbis, Return 1.7 bbls. 915/2017 9/5/2017 0.25 PROD1 DRILL WASH P Wash down to bottom from 8588' to 8,588.0 8,618.0 06:15 06:30 861 8'MD with 276 gpm, 2430 psi, 80 rpm, 9k Tq. 9/5/2017 9/5/2017 0.25 PROD1 DRILL DDRL P Drill 6-3/4" production "A2" lateral from 8,618.0 8,636.0 06:30 06:45 8618' to 8636' MD with 276 gpm, 2100 psi, 80 rpm, 9k Tq, 2K WOB. ADT 0.2 hrs, Bit 0.53 hrs, Jar 0.53 hrs. Pump 30 bbl hi -vis spacer and start displacing to 9.2ppg FloPro on the fly. Page 19179 Report Printed: 10130/2017 . Operations Summary (with Timelog Depths) IH-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Thine Log Start Time End Time Dw(hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (N(a) End DepM(M) 9/5/2017 9/5/2017 1.00 PROD1 DRILL DISP P Circulate / reciprocate from 8636' to 8,636.0 8,636.0 06:45 07:45 8607' MD with 276 gpm, 2050 psi, 24% F/O, 80 rpm, 7k Tq and finish displacing well to new 9.2ppg FIDPro ' WBM. Obtain new SPR's. SPRs @ 8631' MD 3992' ND, MW=9.20 ppg, 07:30 hours MP#1: 20 spm=520 psi, 30 spm=720 psi. MP #2: 20 spm=520 psi, 30 spm=700 psi. 9/5/2017 9/5/2017 4.25 PROD1 DRILL DDRL P Directionally drill 6-3/4" production 8,636.0 9,011.0 07:45 12:00 "A2" lateral from 8636' to 9011' MD, 3990' TVD. Pump at 271 gpm, 1906 psi, 23% F/O, ECD 10.95 ppg, MW 9.2 ppg. Rotate at 140 rpm with 8k Tq on-btm, 6k Tq off-btm. 3k WOB. PUW 140k, SOW 70k, ROT 96k. ADT 3.61 hrs, Bit 4.14 hrs, 4.14 hrs. Observe shakers start blinding off throughout section. Quadco troubleshoot gaswatch system. 9/5/2017 9/5/2017 6.00 PRODt DRILL DDRL P Directionally drill 6-3/4" production 9,011.0 9,554.0 12:00 18:00 "A2" lateral from 901 V to 9554' MD, 3986' TVD. Pump at 280 gpm, 1950 psi, 23% F/O, ECD 11.18 ppg, MW 9.2 ppg. Rotate at 150 rpm with Sk Tq on-btm, 8k Tq off-btm. 5k WOB. PUW 143k, SOW 65k, ROT 95k. Max gas of ,. 277 units. ADT 4.56 hrs, Bit 8.7 hrs, Jar 8.7 hrs. Continue controlling ROP at -100 ft/hr from 9113'- 9304' MD due to shakers blinding off and then from 9304'- 9554' MD for directional work. Did not see first fault that was prognosed at -9000' MD. SPRs @ 9206' MD 3993' TVD, MW=9.20 ppg, 14:00 hours MP#1: 20 spm=560 psi, 30 spm=740 psi. MP #2: 20 spm=540 psi, 30 spm=730 psi. Page 20179 Report Printed: 1013012017 Operations Summary (with Tlmelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dor(hr) Phase Op Code Activity Cade Time P -T -X operation Start Depth (MKB) End Depth(WEI) 9/5/2017 9/6/2017 6.00 PRODt DRILL DDRL P Directionally drill 6-3/4" production 9,554.0 .9,960.0 18:00 00:00 "A2" lateral from 9,554'to 9960' MD, 3999' ND. Pump at 275 gpm, 2000 psi on-btm, 1990 psi off-btm, 22% F/O, ECD 11.43 ppg. MW 9.2 ppg. Rotate at 170 rpm with 8.5k Tq on- btm, 8k Tq off-btm. 5k WOB. PUW 148k. SOW - Lose ability to obtain slackoff weight at 9945' MD. ROT 92k. Max gas of 177 units. ADT 4.34 his, Bit 13.04 hrs, Jars 13.04 hrs. Change out all 24 x shaker screens prior to midnight due to wear. Observe "greasing" of sand/safecarb coming out over shakers throughout the day, partial blinding off 170 mesh screens. Lubes have not been increased, kept at initial 1% concentration of Lo-Torq. OA pressure at midnight = 460 psi Downhole losses over past 24 hours = 31 bbls. 9/6/2017 9/6/2017 6.00 PRODt DRILL DDRL P Directionally drill 6-3/4" production 9,960.0 10,512.0 00:00 06:00 "A2" lateral from 9960' MD to 10512' MD, 4005' TVD. Pump at 275 gpm, 2140 psi, 23% F/0, ECD 11.48 ppg, MW 9.2 ppg. Rotate at 170 rpm with 9k Tq on-btm, 8k Tq off-btm. 3-6k WOB. PUW 160k, unable to slack off, ROT 107k. Max gas of 30 units. ADT 4.68 hrs, Bit 17.72hm, Jar 17.72 his. Observe slightly less "greasing" at shakers and less blinding off of shaker screens. SPRs @ 10051' MD 4005' TVD, MW=9.20 ppg, 01:00 hours MP#1: 20 spm=640 psi, 30 spm=860 psi. MP #2:20 spm=640 psi, 30 spm=860 psi. 9/6/2017 9/6/2017 6.00 PRODt DRILL DDRL P Directionally drill 6-3/4" production 10,512.0 11,225.0 06:00 12:00 "A2" lateral from 10512' MD to 11225' MD, 4026' TVD. Pump at 275 gpm, 2350 psi, 23% F/O, ECD 11.91 ppg, MW 9.2 ppg. Rotate at 170 rpm with 9k Tq on-btm, 8k Tq off-btm. 3-6k WOB. PUW 170k, unable to slack off, ROT 99k. Max gas of 577 units. ADT 4.5 hrs, Bit 22.22 hrs, Jar 22.22 hrs. Control drilled as needed for directional control. No further "greasing" observed at shakers. Changed 4 x 170 mesh screens over past 12 hours due to wear. Faulted out of zone at 11,047' and observed 27' DTN throw. Total of 221' out of zone. Page 21179 Report Printed: 10/30/2017 Operations Summary (with Timeiog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sled Tune End rime Dur (hr) Phase Op Code ActivityCode rima P -T -X operation Stan Depth (flKe) End Depth (MB) 9/6/2017 9/6/2017 6.00 PROD1 DRILL DDRL P Directionally drill 6-3/4" production 11,225.0 11,800.0 12:00 18:00 "A2" lateral from 11,225'to 11,800' MD, 4,033' TVD. Pump at 275 gpm, 2530 psi, 22% NO, ECD 12.17 ppg, MW 9.2 ppg. Rotate at 170 rpm with 9k Tq on-btm, 8.5k Tq off-btm. 5k WOB. PUW 172k, unable to slack off, ROT 106k. Max gas of 177 units. ADT 3.95 hrs, Bit 26.17 hrs, Jars 26.17 hrs. SPRs @ 11 340'MD 4033' TVD, MW=9.20 ppg, 12:45 hours MP#1: 20 spm=780 psi, 30 spm=980 psi. MP #2:20 spm=760 psi, 30 spm=980 psi. 9/6/2017 9/7/2017 6.00 PROD1 DRILL DDRL P Directionally drill 6-3/4" production 11,800.0 - 12,260.0 18:00 00:00 "A2" lateral from 11800' to 12260' MD, 4020' TVD. Pump at 275 gpm, 2535 psi, 22% F/O, ECD 11.96 ppg, MW 9.2 ppg. Rotate at 170 rpm, 9k Tgon- btm, 9k Tq off-btm. 3k WOB. PUW 186k, unable to slack off, ROT 110k. Max gas of 226 units. ADT 4.01 hrs, Bit 30.18 hrs, Jars 30.18 hrs. Perform 290 bbl dump/dilute at 12,170' MD. OA pressure at midnight = 400 psi Downhole losses for past 24 hours = 8 bbls 9/7/2017 9/7/2017 6.00 PROD1 DRILL DDRL P Directionally drill 6-3/4" production 12,260.0 12,814.0 00:00 06:00 "A2" lateral from 12260'to 12814' MD, 4020' TVD. Pump at 275 gpm, 2646 psi, 22%f/0, ECD 12.04 ppg, MW 9.2 ppg. Rotate at 170 rpm with 10k Tq on -btm, 9k Tq off-btm. 3k WOB. PUW 190k, unable to slackoff, ROT 110k. Max gas of 300 units. ADT 4.49 hrs, Bit 34.67 hrs, Jars 34.67 hrs. 9/7/2017 9/7/2017 1.00 PROD1 DRILL DDRL P Directionally drill 6-3/4" production 12,814.0 12,960.0 06:00 07:00 "A2" lateral from 12814'to TO of 12960' MD, 4022' TVD. Pump at 275 gpm, 2720 psi, 22% F/O, ECD 12.04 ppg, MW 9.2 ppg. Rotate at 170 rpm with 10k Tq on-btm, 9k Tq off-btm. 3k WOB. PUW 190k, Unable to slackoff, ROT 110k. ADT 0.88 hrs, Bit 35.55 hrs, Jars 35.55 hrs. Did not see at 12,845' MD. Page 22179 Report Printed: 1 013 012 01 7 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slad Tune End Time Ow(hr) Phase Op Code Activity Code Time P-T-X Operation Sled Depth (flKB) End Oaptlt (tlKa) 9/7/2017 9/7/2017 1.75 PROD1 CASING CIRC P Circulate bottoms up at TD with 275 12,960.0 12,960.0 07:00 08:45 gpm, 2686 psi, 170 rpm, 9k Tq. Obtain final surveys, parameters, and SPR's. PUW 190k, Unable to slack off, ROT 110k. SPRs @ 12960' MD 4022' TVD, MW=9.20 ppg, 07:00 hours MP#1: 20 spm=810 psi, 30 spm=1020 psi. MP #2: 20 spm=810 psi, 30 spm=980 psi. 9/7/2017 9/7/2017 0.50 PROD1 CASING OWFF P Monitor well for flow -well static. 12,960.0 12,960.0 08:45 09:15 Service top drive and traveling equipment. 9/7/2017 9/7/2017 2.75 PROD1 CASING BKRM P Backream out of hole from 12960'to 12,960.0 11,987.0 09:15 12:00 11987' MD with 275 gpm, ICP 2700 psi, FCP 2500 psi, ECD 11.63 ppg, 170 rpm, 6k Tq, monitoring displacement via pits 1-5. Note: Regained slackoff weight 11,986' MD, PUW 170k, SOW 82k 9/7/2017. 9/7/2017 6.00 PROD1 CASING BKRM P Backream out of hole from 11987'to 11,987.0 10,055.0 12:00 18:00 10055' MD with 277 gpm, 1995 psi, 20% F/0, ECD 10.98 ppg, 170 rpm, 4- 5k Tq, PUW 145k, SOW 83k, ROT 100k, monitoring displacement via pits 1-5. Ream stand #109 twice through 5.64° DLS at 10543' MD and re- survey. 9/7/2017 9/7/2017 4.00 PROD1 CASING BKRM P Backream out of hole from 10055'to 10,055.0 8,546.0 18:00 22:00 8546' MD with 277 gpm, 1845 psi, 21% F/O, ECD 10.8 ppg, 170 rpm, 4- 5k Tq. monitoring displacement via pits 1-5. Decrease rotary to 120 rpm as BHA entered shoe. 9/7/2017 9/7/2017 1.00 PROW CASING CIRC P Circulate hole clean inside casing with 8,546.0 8,546.0 22:00 23:00 2 x bottoms up at 277 gpm, 1800 psi, 21% F/O, 120 rpm, 4-5k Tq, ECD 10.66 ppg. Drop 2.12" OD hollow rabbit with 102' of wire on stand #87. PUW 117k, SOW 80k, ROT 100k. 9/7/2017 9/7/2017 0.25 PROD1 CASING OWFF P Monitor well for flow -well static. 8,546.0 8,546.0 23:00 23:15 9/7/2017 9/7/2017 0.50 PROD1 CASING SVRG P Service topdrive and blocks. 8,546.0 8,546.0 23:15 23:45 Electrician inspect MCWS and change out encoder. 9/7/2017 9/8/2017 0.25 PROD1 CASING RURD P Blow down topdrive and line up for 8,546.0 8,546.0 23:45 00:00 pulling out of hole on elevators. Downhole losses for past 24 hours = 41 bbls OA pressure at midnight = 380 psi 9/8/2017 9/8/2017 4.00 PROD? CASING TRIP P POOH on elevators f/ 8540' MD to 8,546.0 123.0 00:00 04:00 123' MD standing back 4" DP and 4" HWDP in derrick. Actual displacement= 60.4 bbls, Calculated displacement= 55.2 bbls. 5.2 bbls lost to formation. Page 23/79 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur(hQ Phase Op Code Activity Code Time P -T -x Opersuon Start Depth (ftKB) End Depth jM(e) 9/8/2017 9/8/2017 1.50 PRODt CASING SHAH P L/D BHA as per SLB DD. Bit was in 123.0 0.0 04:00 05:30 good shape with only 1 x broken cutter. Smith 6-3/4" X516 bit grade= 0- 1 -BT -G -X -0 -NO -TD. All stabilizers came out of hole in -gauge. 9/8/2017 9/8/2017 1.00 COMPZ1 CASING RURD P Rig up GBR casing equipement, 0.0 0.0 05:30 06:30 power tongs and make up XO on floor valve. 9/8/2017 9/8/2017 6.00 COMPZ1 CASING PUTS P Make up 4-1/2" Ray Oil tools float 0.0 4,483.0 06:30 12:30 shoe and run in hole with 4-1/2" slotted liner per tally to 4483' MD, monitoring displacement via trip tank. Use JetLube Run-nSeal dope and torque to -4000 ft -lbs. Install 4-1/2" x 6-1/8" Tesco thin-walled centralizers every joint free floating. Run total of 3 x 6-3/8" swell packers, 87 xjoints 4-1/2" 11.6# L-80 IBT-m slotted liner, and 18 xjoints 4-1/2" 12.6# L-80 IBT-m blank liner, 106 x 4- 1/2" by 6-1/8" Tesco hydroform centralizers, and 1 x 4-1/2" by 6-1/2" Volant hydroform centralizer. No remakes. Rejected 1 xjoint (#58 = 41.77') prior to torquing up as centralizer would not easily go onto pipe -replaced with #101 = 42.15'. 9/8/2017 9/8/2017 1.00 COMPZ1 CASING OTHR P Make up Flex -Lock Liner hanger and 4,483.0 4,553.0 12:30 13:30 HRD-E liner top packer w/ pusher tool per Baker to 4553' MD. Fill tieback sleeve with Xan-Plex D. PUW 79k, SOW 72k. 9/8/2017 9/8/2017 0.50 COMPZ1 CASING CIRC P RIH with 1 x stand 4" DP to 4647' MD. 4,553.0 4,647.0 13:30 14:00 Circulate -12 bbls through finer assembly and confirm no obstructions. Blow down top drive. 9/8/2017 9/8/2017 2.00 COMPZ1 CASING RUNL P Run 4-1/2" liner on 4" DP from derrick 4,647.0 8,591.0 14:00 16:00 from 4647'to 8591' MD, monitoring displacement via trip tank. Obtain. parameters at shoe - PUW 112k, SOW 83k 9/8/2017 9/8/2017 3.25 COMPZ1 CASING RUNL P Run 4-1/2" liner on 4" DP and 4" 8,591.0 12,790.0 16:00 19:15 HWDP from derrick to 12790' MD, monitoring displacement via trip tank. PUW 174k, SOW 97k. Calculated displacement = 82.3 bbls Actual displacement = 87.8 bbls (pipe self -filling, not full) Note: 12 x stands 4" DP slick, 43 x stands 4" DP with super sliders, 30 x stands 4" HWDP with super sliders, and 3 x stands 4" HWDP slick. 9/8/2017 9/8/2017 0.50 COMPZ1 CASING CIRC P Circulate 1 x drill pipe volume per 12,790.0 12,790.0 19:15 19:45 Baker, staging up to 3 bpm, 544 psi, 13% F/O. Page 24179 Report Printed: 11013012017 Operations Summary (with Timelog Depths) IH-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slad Imre End Tvne Our(hr) Pham Op Code Activity Cade Time P-T-X Operation Start Depth (ftKB) End Depth(nKB) 9/8/2017 9/8/2017 0.75 COMPZI CASING PACK P Drop 1.625" phenolic ball. Pump down 12,790.0 12,790.0 19:45 20:30 at 4 bpm, 738 psi, 15% F/O for 500 strokes. Slow rate to 2.5 bpm, 451 psi, 11 % F/O after 500 strokes. Ball on seat at 590 strokes. Pressure up to 1840 psi and hold to set liner hanger. Slack off to block weight (stacking —55k on hanger) and confirm hanger set. Pressure up to 2600 psi and hold - observe pusher tool shear at 2250 psi. Increase pressure up to 4000 psi, observing pusher tool neutralize at 3500 psi. 9/8/2017 9/8/2017 1.00 COMPZ1 CASING PRTS P Line up to IA, close annular, and 12,790.0 8,249.5 20:30 21:30 pressure test liner top packer to 3500 psi / 30 minutes, charted - goad test. Use mud pump #1. Pumped 4.0 Wis. Returned 4.0 bbls. Liner top packer set at 8249.5' MD 9/8/2017 9/8/2017 0.75 COMPZ1 WELLPR CIRC P Pick up and expose dogs. PUW 153k, 8,249.5 8,249.5 21:30 22:15 SOW 116k. Slack off to block weight, observing dog sub shear at 50k hookload. Pressure up to 200 psi and pull out of RS packoif. Once pressure dropped, roll pump at 1 bpm and continue pulling up into tieback sleeve. Pump 28 bbls of Corrosion-inhibited brine at 4 bpm, 620 psi, 15% F/O and spot with 67 bbis of 9.2ppg Flo-Pro at 4 bpm, 590 psi, 15% F/O. 9/8/2017 9/8/2017 0.25 COMPZ1 WELLPR TRIP P Pull OOH with running tools to 8246' 8,249.5 8,246.0 22:15 22:30 and rack back stand #88. Blow down kill line. 9/8/2017 9/8/2017 0.50 COMPZ1 WELLPR OWFF P Monitor well for flow -well static. 8,246.0 8,246.0 22:30 23:00 9/8/2017 9/9/2017 1.00 COMPZ1 WELLPR TRIP P Pull OOH on elevators from 8246'to 8,246.0 6,775.0 23:00 00:00 6775' MD, racking back 4" HWDP in derrick, monitoring displacement via trip tank. PUW 126k, SOW 102k. OA pressure at midnight = 280 psi 9/9/2017 9/9/2017 3.00 COMPZ1 WELLPR TRIP P POOH w/ Baker liner running tools f/ 6,775.0 0.0 00:00 03:00 6775' MD to surface. Inspect running tools, oberserved dog sub sheared. Calculated displacement = 62.1 bbls Actual displacement = 71.91 bbls 9/9/2017 9/9/2017 0.75 COMPZ1 WELLPR SHAH P Service break Baker liner running 0.0 0.0 03:00 03:45 tools and UD tools via beaver slide. 9/9/2017 9/9/2017 1.00 COMPZ1 WELLPR SLPC P Cut and slip 73' of drilling line. 0.0 0.0 03:45 04:45 9/9/2017 9/9/2017 1.00 PROD2 WHPST SHAH P Mobilize Baker BHA components to dg 0.0 0.0 04:45 05:45 floor: string mills, magnets, whip stock and misc BHA tools. Page 25179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 IN Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log SWrt Time End Time Dur (hr)Phase Op Code A Activity Cade Time e P -T-% Operation slaa Depth (fixe) End Depth(ftKa) 9/9/2017 9/9/2017 4.25 PROD2 WHPST BHAH P Make up milling BHA. M/U MWD, 1 0.0 404.0 05:45 10:00 joint HWDP, XO, Upper mill, Flex joint, Lower mill and Window mill. Obtain tool face offset of 294.82 deg. Stand back in derrick. M/U and RIH w/ seals, unloader, 7 joints of 4" DP, string magnet and Anchor assembly. Whipstock assembly weight = Sk. M/U milling BHA stand to whip stock using 35K brass shear screw and RIH w/ 4 string magnets on top. 9/9/2017 9/9/2017 1.00 PROD2 WHPST TRIP P Run in hole on 4" DP stands from 404.0 1,533.0 10:00 11:00 derrick from 404' to 1533' MD, monitoring displacement via trip tank. 9/9/2017 9/9/2017 0.25 PROD2 WHPST DHEQ P Shallow hole test MWD at 1533' MD 1,533.0 1,533.0 11:00 11:15 with 235 gpm, 590 psi. 9/9/2017 9/9/2017 4.75 PROD2 WHPST TRIP P Trip in hole on 4" DP / 4" HWDP string 1,533.0 8,189.0 11:15 16:00 with super sliders installed to 8189' MD, running speed 60 ft/min, filling pipe every 20 stands, monitoring displacement via trip tank. 9/9/2017 9/9/2017 0.25 PROD2 WHPST PULD P Pick up 1 x4" DP single (31.63 it) and 8,189.0 8,221.0 16:00 16:15 RIH to 8221'. 9/9/2017 9/9/2017 0.25 PROD2 WHPST WPST P Kelly up to stand # 84, establish 8,221.0 8,221.0 16:15 16:30 circulation at 230 gpm, 1278 psi, 18% F/O and orient whipstock to 22" left of highside. PUW 141k, SOW 106k. 9/9/2017 9/9/2017 0.25 PROD2 WHPST WPST P Wash down w/ 233 gpm, 1300 psi, 8,221.0 8,249.5 16:30 16:45 18% F/O and tag liner top at 8249.5' MD with no-go. Confirm orientation at 22" left of highside. Slack off 18k and set anchor. Pick up 7k overpull and confirm anchor set. 9/9/2017 9/912017 1.00 PROD2 WHPST WPST T Attempt to shear 35k window mill bolt - 8,249.5 8,249.5 16:45 17:45 unsuccessful. PUW 141k, SOW 106k. Work up and down to weaken bolt, setting down -65k weight on it and pulling 20k weight max overpull with no indication of shear. Kill pump and continue working with no success. Note: Anchor pinned to shear at 60k overpull 9/9/2017 9/9/2017 2.50 PROD2 WHPST WPST T Work down torque in 500 ft -Ib 8,249.5 8,249.5 17:45 20:15 increments up to max of 8000 ft -lbs (3- 1/2" REG make-up torque at 8000 ft - lbs, anchor slips good to 15000 ft -lbs) and continue working pipe up/down, setting down -65k weight on it and pulling 20k max overpull with no indication of shear. Establish circulation at 234 gpm, 1285 psi, 20% F/O and confirm orientation hasn't changed once trapped torque let out. Discuss path forward with town. Page 26179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Tice Write) (� Phase O Code P Ad, Cafe N Time P -T- X Operation Start DepN (8' Fntl Depth 9/9/2017 9/9/2017 0.50 PR0D2 WHPST WPST T Work out all trapped torque and pull to 8,249.5 8,249.5 20:15 20:45 195k hookload (54k overpull) and .5) observe good indication of shear. Observe new PUW —145k. Pull up, rack back stand # 84 and lay down 31.63' drill pipe single, and blow down top drive. 9/9/2017 9/1012017 3.25 PROD2 WHPST TRIP T Pull OOH racking back 4" HWDP and 8,249.5 3,210.0 20:45 00:00 4" DP to 3210' MD, monitoring displacement via trip tank. OA pressure at midnight = 390 psi No downhole losses observed for past 24 hours. 9/10/2017 9/10/2017 1.50 PROD2 WHPST TRIP T Cont POOH f/ 3215' MD to surface. 3,210.0 0.0 00:00 01:30 Observed bolt at window mill/ whipstock sheared. The shear bolt sheared in the correct location on the bolt, no issues could be visual observed on shear bolt. The decision was made to RIH w/ retrieval hook. Caculated displacement = 57.1 bbls Actual displacement = 57.1 bbls 9/10/2017 9/10/2017 0.50 PROD2 WHPST BHAH T UD milling BHA as per Baker rep. 0.0 0.0 01:30 02:00 9/10/2017 9/10/2017 1.00 PROD2 WHPST BHAH T Make up whipstock retrieval BHA, 0.0 90.0 02:00 03:00 hook, HWOP, MWD and oil jars. Scribe MWD to jet, 171' toolface offset. 9/10/2017 9110/2017 4.00 PROD2 WHPST TRIP T RIH w/ whipstock retrival BHA f! 90' 90.0 7,970.0 03:00 07:00 MD to 7970' MD. Obtain parameters, PN= 136K, S/0= 107K, Pump @ 237 gpm= 1130 psi. 9/10/2017 9/10/2017 3.25 PROD2 WHPST FISH T Orient retrieval hook to 20 deg L and 7,970.0 7,986.0 07:00 10:15 hook up into retrieval slot. Set down 1 O @ 7986.5' MD. Pick up and overpull 15K to confirm hook up, observed toolface @ 19 deg L. Stage up P/U to 235K ( 95K over) and attempt to release anchor without jarring, no success. Set down 10K to cock jars, P/U to 175K ( 40K over) and fire jars, straight pull to 235K ( 95K over) No success. Slowly stage up jar firing overpull f! 40K over to 95K over while pulling to 235K ( 95K over) post jar fire. Able to jar free when firing jars 235K (95K overpull) Picked up 16' to stand back DP and observed 12K drag. 9/10/2017 9/10/2017 0.25 PROD2 WHPST OWFF T OWFF, static. 7,986.0 7,970.0 10:15 10:30 9/10/2017 9/10/2017 0.50 PROD2 WHPST TRIP T POOH 5 stands f/ 7970' MD to 7602' 7,970.0 7,602.0 10:30 11:00 MD,P/U=147K, 11K drag. 9/10/2017 9/10/2017 0.50 PROD2 WHPST SFTY T Perform postjarring derrick inspection 7,602.0 7,602.0 11:00 11:30 as per DDI, all good. 9/10/2017 9/10!2017 4.75 PROD2 WHPST TRIP T Pull OOH on elevators from 7602'to 7,602.0 268.0 11:30 16:15 268'to bring whipstock to surface, monitoring displacement via trip tank. Page 27179 ReportPrinted: 1 013 0/207 7 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Opennion Start Depth (ftKB) End Depm (flKB) 9/10/2017 9/10/2017 1.75 PROD2 WHPST BHAH T Lay down whipstock retreival BHA and 268.0 0.0 16:15 18:00 whipstock assembly per Baker. The shear bolt sheared in the correct location on the bolt, no issues were visually observed on shear bolt. Overall condition of BHA was good with no wear. Observed moderate amount of metal on magent below whipstock. Lay down assembly and rack back 4" DP spaceout pipe. Calculated displacement = 58.4 bbls Actual displacement = 59.7 bbls 9/10/2017 9!10/2017r1.50 PROD2 WHPST SHAH T Clean and clear rig floor and mobilize 0.0 0.0 18:00 19:30 new whipstock components to dg floor. 9/10/2017 9/10/2017 2.50 PROD2 WHPST BHAH T Make up milling BHA. M/U MWD, 1 0.0 404.0 19:30 22:00 joint HWDP, XO, Upper mill, Flex joint, Lower mill and Window mill. Obtain tool face offset of 227° from MWD highside to jet. Stand back in derrick. M/U and RIH w/ seals, unloader, 7 joints of 4" DP, string magnet and Anchor assembly. Whipstock assembly weight = 5k. M/U milling BHA stand to whip stock using 35K brass shear screw and RIH w/ 4 string magnets on top to 404' MD. PUW 49k, SOW 55k. Note: Used prior milling BHA components that were in good condition and changed out anchor, disconnect, whipstock, and window mill. Re -confirmed correct gauges on mills. Added in a 2.05' spacer sub to ensure anchor is set above previous set point. Anchor pinned with 4 x screws, -14k shear and shipping bolt removed. Unloader re -pinned with 3 x screws, -18k shear. Length of new slide = 13.67', retrieval slot 5.25' down. Whipstock pinned with 35k brass shear screw from different batch then prior shear screw. 9/10/2017 9/10/2017 1.00 PROD2 WHPSTTRIP T Trip in hole on 4" DP stands from 404.0 2,006.0 22:00 23:00 derrick from 404'to 2006' MD, monitoring displacement via trip tank, running speed 60 it/min. 9/10/2017 9/10/2017 0.25 PROD2 WHPST DHEQ T Shallow hole test MWD with 235 gpm, 2,006.0 2,006.0 23:00 23:15 540 psi, 20% F/O. Blow down top drive. 9/10/2017 9/11/2017 0.75 PROD2 WHPST TRIP T Trip in hole on 4" DP stands from 2,006.0 3,144.0 23:15 00:00 derrick from 2006' to 3144' MD, monitoring displacement via trip tank, running speed 60 ft(min. OA pressure at midnight = 325 psi No downhole losses for past 24 hours Page 28/79 Report Printed: 1 013 0/2 01 7 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stmt Time Ertl Time Dur (Ar) Phax Op Code ActiWty Cetle Time P -T -X Operztlon Start Dep" (fIKB) EW Depth (flKB) 9/11/2017 9/11/2017 3.25 PROD2 WHPST TRIP T Trip in hole on 4" DP / 4" HWDP with 3,144.0 8,219.0 00:00 03:15 super sliders from 3144'to 8219' MD, confirming pipe fill at 5000' and monitoring displacement via trip tank. Make up 31.63'4" DP single above stand #83. Calculated displacement = 56.6 bbls Actual displacement = 58.6 bbls 9/11/2017 9/11/2017 0.50 PROD2 WHPST WPST T Establish circulation, obtain PUW 8,219.0 8,249.5 03:15 03:45 137k, SOW 106k with 238 gpm, 1234 psi. Orient to 22' left of highside. RIH and tag liner top at 8249.5' MD with —5k. Confirm orientation at 22° left of highside. Slack off to 92k HL (14k on it) and observe good indication of anchor shear. Pick up to 148k HL (11 k overpull) and confirm anchor set. 9/11/2017 9/11/2017 1.00 PROD2 WHPST WPST T Slack off to block weight (-65k on it) to 8,249.5 8,249.5 03:45 04:45 shear 35k shear bolt - no sign of shear. Start working pipe up/down to fatigue bolt, 238 gpm, 1240 psi, 20% F/O, pulling up to 15k overpull (152k HL) and slacking off down to 75k on it (31k HL) - no sign of shear. 9/11/2017 9/11/2017 0.25 PROD2 WHPST WPST T Slack off to block weight, killpumps, 8,249.5 8,249.5 04:45 05:00 and start using rig's rocker system with 3-5k torque limit. Observe hookload increase from 45k to 52k. 9/11/2017 9/11/2017 0.25 PROD2 WHPST WPST T With rocker system engaged and 3k 8,249.5 7,979.1 05:00 05:15 torque limit, start working pipe up/down to fatigue bolt, no pumps. Work up to 20k overpull (157k HL) and down to 68k weight slacked off (38k HL). Observe good indication of bolt shear on downstroke and HL increase from 38k to 52k. Top of window @ 7979.13' MD Btm of window @ 7992.80' MD 9/11/2017 0.25 PROD2 WHPST WPST P Obtain parameters with 238 gpm, 7,979.1 7,979.1 19/11/2017 05:15 05:30 1225 psi, 19% F/O, PUW 1341k. Engage rotary at 80 rpm, 4k Tq, ROT 114k. 9/11/2017 9111/2017 11.50 PROD2 WHPST MILL P Mill 6-3/4" window for Ll Lateral from 7,979.1 8,014.3 05:30 17:00 7979.1' to 8014.3' MD with 238 gpm, 1460 psi, 20% NO, 80 rpm, 5-9k Tq, starting with 1-3k WOB and ending with 4-8k WOB. Pump super sweeps as each mill passed the slide with minimal metal shavings observed at surface. Mill out on pit #1 only, keeping other FloPro isolated. Note: 5 ft of gauge 6-3/4" hole to 7997' MD, rathole to 8014.3' MD Page 29179 Report Printed: 10/30/2017 ► Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log alertTime EM Time Our (hr) Phase Op Cotle grdivity Code Time P -T -X Operation start Depth (ftKB) End Depth (MB 9/11/2017 9/11/2017 1.00 PROD2 WHPST REAM P Pump super sweep at TD with 238 8,014.3 7,975.0 17:00 18:00 gpm, 1464 psi, 20% VO, 80 rpm, 5-9k Tq and ream through window twice and wash down through window once. With pump on, PUW 133k, SOW t 00k, ROT 122k. Once sweep turned corner, pull pipe from TD back up into cased hole and circulate sweep to surface reciprocating from 7975'to 7950' MD w/ 238 gpm, 1464 psi, 20% F/O - total strokes pumped = 3392. Minimal metal shavings observed at surface. MW in/out 9.3 ppg 9/11/2017 9/11/2017 0.25 PROD2 WHPST TRIP P Kill pumps and obtain parameters - 7,975.0 7,975.0 18:00 18:15 PUW 150k, SOW 105k. Work pipe up and down through window to TD, observing 1-3k drag - confirm window smooth and in good shape. 9/11/2017 9/11/2017 0.75 PROD2 WHPST FIT P Blow down top ddve, rig up and 7,975.0 7,975.0 18:15 19:00 perform FIT for L1 lateral to 13.Oppg EMW with 9.3ppg FloPro at 3900' ND. Close bag, pump down ddllpipe - and IA with mud pump #1, and pressure up to 750 psi. Shut in and monitor, observing pressure drop to 635 psi over 10 minutes. Pumped 1.4 bbls, bled back 0.5 bbls. Rig down lest equipment and blow down lines. 9/11/2017 9/11/2017 4.00 PROD2 WHPST TRIP P Pull OOH on elevators from 7975'to 7,975.0 133.0 19:00 23:00 133' MD racking back 4" DP / HWDP stands, monitoring displacement via trip tank. Note: Laid down the 31.63' DP single we installed between stand #83 & 84 that allowed us to mill window on full stand 9/11/2017 9/12/2017 1.00 PROD2 WHPST BHAH P Lay down milling assembly per Baker. 133.0 0.0 23:00 00:00 Observe pockets full of metal shavings on all 4 x magnets. Clean off magnets and lay down MWD tool and mills. - 6-314" window mill was 1/4" undergauge, - 6-5/8" lower mill was 118" undergauge. - 6-3/4" upper mill was in -gauge Calculated displacement = 55.4 bbls Actual displacement = 55.0 bbls OA pressure at midnght = 465 psi No downhole losses observed over past 24 hours 9/12/2017 9/12/2017 1.00 PROD2 WHPST W W WH P M/U stack washing tool on stand of 0.0 0.0 00:00 01:00 HWDP, wash and flush stack/ wellhead of swarf from milling operations. 9/12/2017 9/12/2017 1.50 PROD2 WHPST BHAH P Make up clean out BHA, Mud motor, 0.0 639.0 01:00 02:30 impulse w/ 4 Baker string magnets to 639' MD as per SLB. Page 30179 ReportPrinted: 10(30!2017 Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start rime End Time our (hr) Phase Op Cotle Activity Code Time P -T -X Operefion 5182 Depth (fIKB) End Depth (flKa) 9/12/2017 9/12/2017 4.00 PROD2 WHPST TRIP P RIH w/ clean out BHA f/ 639' MD to 639.0 7,845.0 02:30 06:30 7845' MD. Shallow hole test MWD @ 1500' MD, good. 9/12/2017 9/12/2017 1.00 PROD2 WHPST TRIP P Establish circulation @ 7845' MD, 7,845.0 8,014.0 06:30 07:30 pump @ 253 gpm= 1920 psi. P/U= 128K, S/0= 96K. Orient motor to 20 deg L. Trip down thought window with no pumps, TOW @ 7979' MD, BOW @ 7993' MD. Observed small 4K bobble @ 7992' MD. Trip down to bottom of rat hole @ 8014' MD and set 5K down. 9/12/2017 9/12/2017 4.50 PROD2 DRILL DDRL P DDrill 6-3/4" L1 hole f/ 8014' MD to 8,014.0 8,299.0 07:30 12:00 8299' MD, TVD= 3934'. Pump @ 234 gpm= 1650 psi. on, 1600 psi off 19% FO. Rotate @ 40 rpm's W 6K Tq on, 51K Tq off. WOB= 2-14K. P/U= 133K, S/0= 99K, ROT= 106K. 9.2 ppg MW. AST= 2.0, ART= 1.47. ADT= 3.47, Bit hours= 3.47, Total jar hours= 39.02. At 8299' MD 33' of separation from 1H -102 main bore. Displace out milling fluid on the fly to new/used 9.2 ppg Flo -Pro NT @ 8110' MD Obtain SPRs @ 8299' MD, 3944' TVD w/ 9.2 ppg mud MP #1: 20 spm= 480 psi, 30 spm= 660 psi MP#2: 20 spm- 480 psi, 30 spm= 660 psi 9/12/2017 9/12/2017 0.50 PROM DRILL OWFF P OWFF- Static 8,299.0 8,299.0 12:00 12:30 9/12/2017 9/12/2017 0.75 PROM DRILL TRIP P POOH on elevators from 8,299'- 8,299.0 7,935.0 12:30 13:15 8,121' MD then orient to 20 DEG left high side from 8,121'- 8,029'- 7,935' MD UP WT 135-150K off BTM and through window. OWN WT = 99K. 9/12/2017 9/12/2017 4.25 PROD2 DRILL TRIP P Pump heavy sweep and POOH to 101' 7,935.0 101.0 13:15 17:30 MD monitoring displacement via TT. Prep to lay down BHA. 9/1212017 9/12/2017 1.00 PROD2 DRILL BHAH P LD BHA. Monitor disp via TT. 101.0 0.0 17:30 18:30 9/12/2017 9/12/2017 1.50 PROD2 WHDBOP RURD P Clean rig floor and wash out stack. 0.0 0.0 18:30 20:00 Set test plug and pull wear bushing. Page 31/79 Report Printed: 1 013 0/2 01 7 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EM TNne Our(hr) phase Op Code Attivity Coda Tme P -T -X Operation Start Depth (%B) Ertl Depth (flKS) 9/12/2017 9/13/2017 4.00 PROD2 WHDBOP BOPE P Test SOPE with 4" and 4-1/2" test joint 0.0 0.0 20:00 00:00 to 250/3500 psi 5/5 min, witness waived by AOGCC rep Jeff Jones. Test Sequence as follows: 1) 4" XT39 Dart valve and Upper IBOP 2) 4" XT39 FOSV and Lower MOP 3) Choke valves #12, 13, & 14 4) Choke valves # 9 and 11 5) Choke valves #8 and 10 6) Super and manual chokes Install 4" lest joint 7) Annular, Floor Kill, Choke valves #1, 2, and 5 8) HCR choke and Mezzanine Kill 9) Lower 3-1/2" x 6" pipe rams Install 4 1/2" test joint 10) Annular, Manual choke, Manual Kill, and HCR 11) Lower 3-1/2" x 6" pipe rams Pull test joint 12) Blinds, Manual Kill, Choke valves #6 and 7 13) Choke valves #3 and 4. Perform koomey drawdown test: System Pressure = 3,000 psi PSI after closure = 1,800 psi 200 psi Attained with 2 x electric pumps = 9 seconds Full Pressure attained with 2 x electric and 2 x air pumps = 47 seconds N2 = 6 each @ 2,033 psi Tested all gas and H2S sensors, PVT and flow alarms both audio and visual, and functioned primary and remote BOP controls - all good. Upper 7-5/8" casing rams not tested. Note: While installing test plug first PT failed. Pulled test plug seal missing, Replace test plug seal and retest _ GOOD 9/13/2017 9/13/2017 0.50 PROD2 WHDBOP BOPE -FF-- Cont to test BOPE w/ 4-1/2" TJ to 0.0 0.0 00:00 00:30 250/3500 psi. Test pit level sensors and flow out alarm. Test H2S and combustible gas alarms. Witness of BOP test waived by Jeff Jones of the AOGCC. 9/13/2017 9/13/2017 1.00 PROD2 WHDSOP RURD P Rig down testing equipment, remove 0.0 0.0 00:30 01:30 test plug; blow down choke/kill lines, top drive and choke manifold. R/D floor valves from testing equipment. Install wear bushing. 9/13/2017 BHAH M/U BHA as per SLB, X516 PDC bit, 0.0 302.0 19/13/2017DRILL. 01:30 02:30 PowerDrive, PeriScope, Impulse, JP NMFC, Jars and 4" HWDP to 302' MD. Page 32179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Our (hr) Phase Op Code Activity Case Time P -T -X Operation Star) Depth Wa) End Depth MKS) 9/13/2017 9/13/2017 4.25 PROD2 DRILL TRIP P RIHw/drilling BHA f/302'MD to TOW 302.0 8,093.0 02:30 06:45 @ 7979' MD. Shallow hole lest tools 1500, tools in neutral. Slowly trip down thought window Q 7979' MD to 7993' MD. Cont RIH U 8093' MD. P/U= 117K. S/0= 82K. 9/13/2017 9/13/2017 0.75 PR002 DRILL DLOG P MAD pass down f/ 8093' MD to 8300' 8,093.0 8,300.0 06:45 07:30 MO. Pump @ 236 gpm= 1460 psi, Rotate Q 40 rpms w/ 4K Tq. 9/13/2017 9/13/2017 4.50 PROD2 DRILL DDRL P DDRL from 8,300' MD - 8,636' MD 8,300.0 8,636.0 07:30 12:00 3,929' TVD. 271 GPM 1,844 PSI DPP. 21% F/O. 120 RPM with 5K TO. 2-5K WOB along with ECD's of 10.64 EMW. Off BTM 1,830 PSI DPP, UP WT = 114K, OWN WT = 79K. ROT = 94K. 4K TO. MW = 9.2 PPG. Max gas = 50 units. ADT -3 Bit hrs - 3 Jar hrs - 42.02 SPR 7,870' MD 2,930' TVD Q 0600 hrs MP 1) 20 SPM - 440 PSI 30 SPM - 620 PSI MP 2) 20 SPM - 420 PSI 30 SPM - 600 PSI 9/13/2017 9/13/2017 6.00 PROD2 DRILL DDRL P DDRL from 8,636' MD 3,929 TVD - 8,636.0 9,430.0 12:00 18:00 9,430' MD 3,948' TVD. 271 GPM 1,947 PSI DPP. 23% F/O. 120 RPM with 6K TQ. 4-5K WOB along with ECD's of 10.82 EMW. Off BTM 1,931 PSI DPP, UP WT= 121 K, OWN WT= 70K. ROT = 94K. 6K TO. MW = 9.2 PPG. Max gas = 171 units. ADT -4.25 Bit hrs - 7.24 Jar hrs - 45.79 SPR 8,825' MD 3,941' TVD @ 1330 hrs MP 1) 20 SPM - 420 PSI 30 SPM - 600 PSI MP 2) 20 SPM - 420 PSI 30 SPM - 620 PSI 9/13/2017 9/14/2017 6.00 PROD2 DRILL DDRL P DDRL from 9,430' MD 3,948' -TVD- 9,430.0 10,215.0 18:00 00:00 10,215' MD 3,957' TVD. 271 GPM 2,090 PSI DPP. 22% F/O. 120 RPM with 6K TO. 2-5K WOB along with ECD's of 11.16 EMW. Off BTM 2,064 PSI DPP, UP WT = 125K, OWN WT = 68K. ROT = 92K. 6K TO. MW = 9.2 PPG. Max gas = 222 units. ADT -4.18 Bit hrs - 11.42 Jar hrs - 49.97 9/14/2017 9/14/2017 6.00 PROD2 DRILL DDRL P DDRL from 10,215' MD 3,957' TVD - 10,215.0 11,070.0 00:00 06:00 11,070' MD 3,970' TVD. 271 GPM 2,300 PSI DPP. 22% F/O. 120 - 135 RPM with 8K TO. 2-5K WOB along with ECD's of 11.5 EMW. Off BTM 2,264 PSI DPP, UP WT = 136K, DWN WT=73K. ROT= 101 K. 6K TO. MW = 9.2 PPG. Max gas = 60 units. ADT -4.72 Bit hrs - 16.14 Jar hrs - 54.69 Page 33179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 114-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Tme End Tme Dor (h') Phase Op Code Activity Cotle Time P-T-XSWO Operation Depth End Depth (MB)9/14/2017 9/14/2017 6.00 PROD2 DRILL DDRL P DDRL from 11,070' MD 3,970' TVD - 11,070.0 11,716.0 06:00 12:00 11,716' MD 3,986' TVD. 271 GPM 2,595 PSI DPP. 22% F/O. 120 - 135 RPM with 81K TO. 2-61K WOB along with ECD's of 12.05 EMW. Off BTM . 2,550 PSI DPP, UP WT = 125K, DWN WT=76K. ROT =117K. 71K TQ. MW = 9.2 PPG. Max gas = 65 units. ADT -4.16 Bit hrs - 20.3 Jar hrs - 58.85 SPR 10,333" MD 3,955' TVD @ 00:30 hrs MP 1) 20 SPM - 550 PSI 30 SPM - 760 PSI MP 2) 20 SPM - 540 PSI 30 SPM - 740 PSI 9/14/2017 9/14/2017 6.00 PROD2 DRILL DDRL P DDRL from 11,716' MD 3,986' TVD - 11,716.0 12,362.0 12:00 18:00 12,362' MD 3,974' ND. 272 GPM 2,601 PSI DPP. 22% F/O. 110-120 RPM with 9K TO. 2-6K WOB along with ECD's of 11.76 EMW. Off BTM 2,590 PSI DPP, UP WT= 164K, DWN WT = 63K. ROT = 108K. 81K TO. MW = 9.2 PPG. Max gas = 150 units. ADT -4.6 Bit hrs - 24.63 Jar hrs - 63.18 SPR 11,803" MD 3,985' TVD @ 13:33 hrs MP 1) 20 SPM - 750 PSI 30 SPM - 960 PSI MP 2) 20 SPM - 740 PSI 30 SPM - 950 PSI 9/14/2017 9/15/2017 6.00 PROD2 DRILL DDRL P DDRL from 12,362' MD 3,974' TVD - 12,362.0 12,719.0 18:00 00:00 12,719 MD 3,970' TVD. 271 GPM 2,653 PSI DPP. 22% F/O. 110-120 RPM with 9K TQ. 2-5K WOB along with ECD's of 11.82 EMW. Off BTM 2,644 PSI DPP, UP WT= 173K, DWN WT=63K. ROT =11 OK. 8K TQ. MW = 9.2 PPG. Max gas = 150 units. ADT -3.75 Bit hrs - 28.38 Jar hrs - 66.93 9/15/2017 9/15/2017 3.25 PROD2 DRILL DDRL P DDRL from 12,719 MD 3,970' TVD - 12,719.0 13,126.0 00:00 03:15 13,126' MD 3,988' TVD. 271 GPM 2,653 PSI DPP. 22% F/O. 110-135 RPM with 9K TO. 2-51K WOB along with ECD's of 11.95 EMW. Off BTM 2,700 PSI DPP, UP WT = 175K, DWN WT=63K. ROT =106K. 8K TQ. MW = 9.2 PPG. Max gas = 150 units. ADT -2.7 Bit hrs - 31.08 Jar hrs - 69.63 Page 34179 Report Printed: 10130/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Thne Dur (hr) Phase Op Code AciiWty Catle Time P -T -X Operation Stat Depth (ItKB) End Depth (i1K6) 9/15/2017 - 9!15/2017 1.75 PROD2 CASING CIRC P TD called by Anch Geo / Rack bak 13,126.0 13,126.0 03:15 05:00 stand and pump BU. rotate 140 RPM, 81K TQ. Recip 13126-13030' MD 270 GPM 2,668 DPP. 9/15/2017 9/15/2017 0.50 PROD2 CASING OWFF P OWFF. (STATIC) 13,126.0 13,126.0 05:00 05:30 9/15/2017 9/15/2017 3.00 PROD2 CASING BKRM P BKRM OOH from 13,126'- 12,086' 13,126.0 12,086.0 05:30 08:30 1 MD. 130 RPM 270 GPM. 9/15/2017 9/15/2017 0.50 PROD2 CASING SVRG P Inspect top drive and service same. 12,086.0 12,086.0 08:30 09:00 9/15/2017 9/15/2017 9.75 PROD2 CASING BKRM P BKRM OOH from 12,086'- 8,356' MD 12,086.0 8,356.0 09:00 18:45 272 GPM Q 2310-1,950 PSI DPP. RPM 130-80 with UP WT 145K. DWN WT=69K. ROT= 101K. 9/15/2017 9/15/2017 0.50 PROD2 CASING TRIP P POOH on elevators from 8,356'- 8,356.0 7,882.0 18:45 19:15 7,882' MD with Baker rep on site through window. - 10K bobble. UP WT=128K. DWN WT=80K. 9115/2017 9/15/2017 1.50 PROD2 CASING CIRC P Rotate and circulate from 7,882'- 7,882.0 7,882.0 19:15 20:45 7,785' MD total of 5,003 STKS. 240 GPM @ 1,450 PSI DPP. RPM @ 60. 180K. 4.5 TQ. UP WT=120K. DWN WT= RT = 93K. 9/15/2017 9/15/2017 0.50 PROD2 CASING OWFF P OWFF (Static) Pump slug and install 7,882.0 7,882.0 20:45 21:15 wiper rubber. 9/15/2017 9/16/2017 2.75 PROD2 CASING TRIP P POOH on elevators from 7,882'-1,155' 7,882.0 1,155.0 21:15 00:00 MD. Monitor disp via TT. UP WT = 118K. DWNWT=80K. 9/16/2017 9/16/2017 0.75 PROD2 CASING TRIP P Continue to POOH from 1, 155'-302' 1,155.0 302.0 00:00 00:45 MD monitoring disp via TT. REmove strippin rubber. 9/16/2017 9/16/2017 0.25 PROD2 CASING OWFF - P OWFF. PJSM for laying down BHA. 302.0 302.0 00:45 01:00 9/16/2017 9/16/2017 1.25 PROD2 CASING SHAH P Lay down BHA #9 as per DD from 302.0 0.0 01:00 02:15 302' MD to surface. Monitor disp via TT. 9/16/2017 9/16/2017 0.25 PROD2 CASING SHAH P Clean rig floor. 0.0 0.0 02:15 02:30 9/1612017 9/16/2017 1.25 PROD2 CASING SLPC P SLPC 73' drill line. 0.0 0.0 02:30 03:45 9/16/2017 9/16/2017 0.50 PROD2 CASING SVRG P Service top drive and blocks. 0.0 0.0 03:45 04:15 9/16/2017 9/16/2017 1.75 COMPZ2 FISH SHAH P MU BHA # 10 and scrib as per BOT 0.0 230.0 04:15 06:00 rep to 230' MD 9/16/2017 9/16/2017 1.25 COMPZ2 FISH TRIP P RIH from 230'- 2,209' MD monitoring 230.0 2,209.0 06:00 07:15 Disp via TT. UP WT = 70K DWN WT= 70K 9/16/2017 9/1612017 0.25 COMPZ2 FISH DHEQ P Shallow test MWD (PASSED). 2,209.0 2,209.0 07:15 07:30 9/16/2017 9/16/2017 3.00 COMPZ2 FISH TRIP P Continue to Trip in hole from 2,209' - 2,209.0 7,904.0 07:30 10:30 7,904' MD. Fill pipe every 30 stnds. Page 35/79 Report Printed: 1 013 0/2 01 7 '- Operations Summary (with Timelog Depths) 77 IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Time End Time Our (hr) phase Op Code Activity Code Time P -T -X Operation Start Depth (Wil) End Depth (id(B) 9/16/2017 9/16/2017 1.50 COMPZ2 FISH JAR P Wash down from 7,904' - 7,991' MD 7,904.0 7,991.0 10:30 12:00 @ 5.5 BPM 1,650 PSI DPP. 20% F/O. Up WT=120K, OWN WT=77K. Orient 22 DEG. Latch into whipstock and work up to 100K overpull with no success with straight overpull. Jar 3X at 40K / 4X at 60K, Whipstock free after 2 80K hits with straight pulls to 100K. 127K UP WT with 10K drag. 9/16/2017 9/16/2017 1.50 COMPZ2 FISH CIRC P Circulate bottoms up X2 @ 268 GPM, 7,991.0 7,960.0 12:00 13:30 1,284 PSI DPP. 21% F/O. 4,862 STKS pumped. 9/16/2017 9/16/2017 0.50 COMPZ2 FISH OWFF P OWFF. (STATIC). PUH to 7,904' MD. 7,960.0 7,904.0 13:30 14:00 UP WT = 125K. Blow down top drive. 9/16/2017 9/16/2017 5.00 COMPZ2 FISH TRIP P POOH with Whipstock assym on 7,904.0 230.0 14:00 19:00 elevators. from 7,960'- 230' MD. UP WT = 125K. Monitor disp via TT. Drop 2.115 OD rabbit. 9/16/2017 9/16/2017 2.00 COMPZ2 FISH BHAH. P Lay down BHA #10 and whipstock as 230.0 0.0 19:00 21:00 per Baker rep. Monitor disp via TT. 9/16/2017 9/16/2017 1.00 COMPZ2 FISH BHAH P Clean rig floor and LD running tools. 0.0 0.0 21:00 22:00 9/16/2017 9/16/2017 1.50 COMPZ2 CASING RURD P Rig up to run liner., Bring GBR 0.0 0.0 22:00 23:30 equipment to rig floor, centrilizers, etc. 9/16/2017 9/17/2017 0.50 COMPZ2 CASING PUTB P PJSM / pick up 4 1/2" 11.6# IBTM 0.0 290.0 23:30 00:00 slotted liner as per tally to 290' MD. UP WT = 47K, OWN WT = 47K. 9/17/2017 9/17/2017 7.25 COMPZ2 CASING PUTS P RIH with 41/2" 11.6# L-801BTM 290.0 5,097.0 00:00 07:15 slotted liner as per tally from 290' - 5,097' MD. Monhor disp via TT. Install centralizer on every joint. TO connections to 5K FT/LB. 9/17/2017 9/17/2017 1.00 COMPZ2 CASING OTHR P Change out elevators and make up 5,097.0 5,130.0 07:15 08:15 hook hanger assym + Impulse and scribe. UP WT=82K. DWN WT= 69K. 9/17/2017 9/17/2017 0.50 COMPZ2 CASING RUNL P RIH with DP fro 5,130'-5,687'MD. 5,130.0 5,687.0 08:15 08:45 Monitor Disp via TT. 9/17/2017 9/17/2017 0.25 COMPZ2 CASING DHEQ P Shallow hole test MWD with 100 GPM 5,687.0 5,687.0 08:45 09:00 320 PSI DPP, 10% F/O (PASSED) Blow down top drive. 9/17/2017 9/17/2017 4.50 COMPZ2 CASING RUNL P RIH with 4" DP from 5,687'- 10,431' 5,687.0 13,040.0 09:00 13:30 MD then HWDP to 13,040' MD UP WT 168K, OWN WT 91 K. 9/17/2017 9/17/2017 1.25 COMPZ2 CASING RUNL P Kelly up and wash down from 13,040 - 13,040.0 13,110.0 13:30 14:45 13,090' MD. Stage pumps up to 3 1/2 BPM ICP - 920 PSI, FCP -1,134 PSI with 14% F/O. Tool face 150 DEG left on high side wash down to 13,110' MD P/U orient 22 DEG left highside to set - hood hanger on depth with 30K dwn wt. Page 36179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sian Tme End Time Dur(hr) Phase Op Code AcU%*Code rime P -T -X O p makem elart Depth (kl®) End Depth (kKa) 9/17/2017 9/17/2017 0.75 COMPZ2 CASING CIRC P Drop 29132" ball and pump down Q 4 13,110.0 13,110.0 14:45 15:30 BPM 170 GPM, 1,350 PSI DPP. 14% F/O. Decrease rate to 42 GPM - 350 PSI DPP. 5% F/O. Ball on seat at 667 STKS. Pressure up to 3,300 PSI. Pick up to confirm release observe 145K UP WT. Pressure up to 4,362 PSI to shear out ball seat. 9/17/2017 9/17/2017 0.50 COMPZ2 WELLPR OWFF P OWFF (Static) 13,110.0 13,110.0 15:30 16:00 9/17/2017 9/17/2017 3.50 COMPZ2 WELLPR TRIP P POOH on elevators from 7,952 to 75' 7,952.0 75.0 16:00 19:30 MD. 9/17/2017 9/17/2017 0.50 COMPZ2 WELLPR BHAH P LD liner running BHA from 7545' MD 75.0 45.0 19:30 20:00 9/17/2017 9/17/2017 1.00 COMPZ2 WELLPR BHAH P Lay down and flush SLB MWD tools. 45.0 0.0 20:00 21:00 9/17/2017 9/17/2017 1.00 COMPZ2 WELLPR SHAH P Clean dg floor and remove BHA from 0.0 0.0 21:00 22:00 floor. Service TD, 9/1712017 9118/2017 2.00 COMPZ2 WELLPR RGRP T Begin traction motor replacement on 0.0 0.0 22:00 00:00 top drive. 9/18/2017 9/18/2017 15.00 COMPZ2 WELLPR RGRP T Continue to change out top drive 0.0 0.0 00:00 15:00 motors 9/18/2017 9/18/2017 0.50 COMPZ2 WELLPR SFTY T Perform DROPS inspection. 0.0 0.0 15:00 15:30 9/18/2017 9/18/2017 1.00 COMPZ2 RWRID RURD P Bring tools to rig floor to run LEM / 0.0 0.0 15:30 16:30 ZXP. GBR set to Torque turn TXP treads. 9/18/2017 9/18/2017 2.50 COMPZ2 RWRID PUTB P MU and RIH with LEM /ZXP assym to 0.0 399.0 16:30 19:00 399'MD. Up WT=47K DWN WT= 53K. Monitor disp via TT. Utilizing GBR to make up torque on TXP threads. 9/18/2017 9/19/2017 5.00 COMPZ2 RWRID RCST P RIH with LEM / ZXP ASSYM from 399' 399.0 5,645.0 19:00 0000 - 5,645' MD. Monitor disp via TT. UP WT=107K DWN WT=87K. Shallow hole test MWD at 870' MD with 80 GPM 210 PSI 8% F/O (PASSED). 9/19/2017 9/19/2017 2.00 COMPZ2 RWRID RCST P Continue to RIH from 5,645-8,270' 5,645.0 8,270.0 00:00 02:00 MD. Monitor disp via TT 9/19/2017 9/19/2017 1.75 COMPZ2 RWRID PACK P Bring on pumps and orient to 90 DEG 8,270.0 8,299.0 02:00 03:45 L. Set LEM with 15K DWN and confirm latched with 5K overpull. Work pipe to turn to 28 DEG left and drop 1 3/4" ball. Bring pumps on line at 80 GPM with ball going on seat at 558 STKS. Pressure up to 2,800 PSlfor 5 min. Increase pressure to 3,700 PSI to set isolation tool and PKR. Bleed off pressure. Pressure test PKR for 10 min at 3,500 PSI. (PASSED). UP WT = 145K. DWN WT= 106K 9/19/2017 9/19/2017 1.00 COMPZ2 RWRID CIRC P PUH to 7,907' MD and circulate in 28 8,299.0 7,907.0 03:45 04:45 BBLS of 9.3 PPG Cl pill with 140 GPM at 440 PSI DPP. 12% F/O. UP WT = 147K. 9/19/2017 9/19/2017 0.75 COMPZ2 RWRID OWFF P PUH to 7,849' MD OWFF. Blow down 7,907.0 7,849.0 04:45 05:30 top drive. Fluid level dropped 2" Page 37179 Report Printed: 1 0/3 012 01 7 Operations Summary (with Timelog uepths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Ow(.5 Phase Op Code Activity Code Time P -T -X OpenNion SAW Depth (tyke) EM Capri take) 9!19/2017 9/19/2017 4.50 COMPZ2 RWRID TRIP P POOH from 7,849'- 74' MD 7,849.0 74.0 05:30 10:00 monitoring disp via TT. Up WT = 145K 9/19/2017 9/19/2017 0.75 COMPZ2 RWRID SHAH P LD LEM assym BHA 74.0 0.0 10:00 10:45 9/19/2017 9/19/2017 0.50 COMPZ2 RWRID SHAH P Clean dg floor and perp for next run. 0.0 0.0 10:45 11:15 9/19/2017 9/19/2017 2.75 PROD3 WHPST SHAH P PU Baker Whipstock BHA as per 0.0 305.0 11:15 14:00 Baker rep. Monitor Disp via TT. Own WT = 53K 9/19/2017 9/19/2017 5.25 PROD3 WHPST TRIP P RIH with BHA #12 on 4" DP and 305.0 7,511.0 14:00 19:15 HWDP from 305'-7,811' MD. Monitor disp via TT. UP WT = 137K. DWN WT= 105K. Shallow hole test of MWD at 2,192' MD with 220 GPM 688 PSI DPP with 17% F/O. 9/19/2017 9/19/2017 1.25 PROD3 WHPST WPST P Kelly up and fill pipe @ 7,811' MD. 7,511.0 7,915.0 19:15 20:30 Wash DWN and orient 125 DEG Left high side @ 220 GPM, 1,177 PSI DPP. 16% F/O. 7,915' MD UP WT = 137K. DWN WT= 105K. 9/19/2017 9/19/2017 0.75 PROD3 WHPST WPST P Locate liner top @ 7,915'MD with 7,915.0 7,831.8 20:30 21:15 5KDWN and set ancot with 15K DWN. PUI IOK over to check set. Shear off and slide with 40K DWN WT. 9/19/2017 9/20/2017 2.75 PROD3 WHPST MILL P Mill window as per BOT 7,831.8 7,848.0 21:15 00:00 recomendations with 300 GPM, 1,906 PSI DPP with 20% F/O. 80 RPM with 4K TO. UP WT=137K. DW WT= 105K. ROT = 120K. to 7,848' MD. 9/20/2017 9/20/2017 6.00 PROD3 WHPST MILL P Mill Window and new hole as per 7,848.0 7,865.9 00:00 06:00 Baker rep. From 7,848' MD - 7,865.87' MD. At 296 GPM, 2,050 PSI DPP, F/O = 22% 4K WOB with 3-7K TO. PUUmp 25 BBLS high vis super sweeps at 7,852', 7,855', 7,866' MD. 9/20/2017 9/20/2017 3.50 PROD3 WHPST MILL P Continue to mill from 7,865'- 7,865.9 7,880.0 06:00 09:30 7,880'MD. 296 GPM @ 2,260 PSI DPP, 21% F/O, 8K WOB, 120 RPM, 4K TO and pumped 21 BBLS high vis at 7,880' MD. Work through window 2X wl pump and rotary (GOOD) 2X w/o pump and rotary (GOOD) UP WT = 148K, DWN WT = 106K. 9/20/2017 9/20/2017 0.25 PROD3 WHPST CIRC P Circulate BU at 200 GPM. 7,880.0 7,880.0 09:30 09:45 9/20/2017 9/20/2017 1.25 PROD3 WHPST FIT P Perform FIT Tto 12.9 EMW. 8 STKS 7,880.0 7,880.0 09:45 11:00 to pressure up to 720 PSI. .8 BBLS bled back. RD and BD test equip. 9/20/2017 9/20/2017 0.25 PROD3 WHPST OWFF P OWFF(GOOD). 7,880.0 7,880.0 11:00 11:15 9/20/2017 9/20/2017 4.75 PROD3 WHPST TRIP P POOH monitoring disp via TT. Strap 7,880.0 231.0 11:15 16:00 OOH and inspect all SS. No correction. 9/20/2017 9/20/2017 1.25 PROD3 WHPST SHAH P LD Milling BHA as per Baker Rep from 231.0 0.0 16:00 17:15 1 231'to Surface. Upper mill was full guage. Page 38179 Report Printed: 1 013 012 01 7 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slap Time Entl Time Da phase Op Activity Cotle Time P -T -X 0,embon Slat Depth (MB) End Depth (flKB) 9/20/2017 9/20/2017 1.7 1.75 PRODS WHPSTT W W WH P MU / BOP stack washer and cycle 0.0 0.0 17:15 19:00 rams. 470 GPM with 20 RPM. F/O 20 %. BD lop drive. SIMOPS with I/S Mill BHA via Beaver Slide clean and wash floor. 9/20/2017 9/20!2017 1.00 PRODS WHPST RGRP T Change out lights of derrick. 0.0 0.0 19:00 20:00 9/20/2017 9/20/2017 0.50 PROD3 WHPST EQRP P Change out SLB stand pipe 0.0 0.0 20:00 20:30 transducer. 9/20/2017 9/20/2017 1.75 PROD3 WHPST BHAH P PU/MU clean out BHA as per SLB DD. 0.0 887.0 20:30 22:15 to 887' MD /IUP WT = 53K, OWN WT = 58K. Monitor disp via TT. 9/20/2017 9/20/2017 1.00 PROD3 WHPST TRIP P Trip in hole with 4" DP form 887'- 887.0 1,558.0 22:15 23:15 1,558' MD. UP WT 67K, DWN WT= 71K. Perform shallow test @ 250 GPM 1,048 PSI DPP 20% F/O. (FAILED) 9/20/2017 9/21/2017 0.75 PROD3 WHPST EQRP T Troubleshoot Faulty SLB pressure 1,558.0 1,558.0 23:15 00:00 transducer equip. Replace transducer wire system and re -test @ 220 GPM 831 PSI DPP. 18% F/O (PASSED) 9/21/2017 9/21/2017 4.00 PROD3 WHPST TRIP P Comtinue to trip in hole from 1,558'- 1,558.0 7,718.0 00:00 04:00 7,718' MD. Change out Super Sliders as per W WT rep. Fill pipe every 20 Stands. UP WT= 125K, DWN WT= 78K. 9/21/2017 9/21/2017 0.75 PROD3 WHPST TRIP P Orient to 18 DEG L and RIH from 7,718.0 7,874.0 04:00 04:45 7,718' - 7,874' MD with 230 GPM. 1,560 PSI DPP. 20% F/O. 9/21/2017 9/21/2017 7.25 PROD3 DRILL DDRL P DDRL63/4" hole from 7,880'-8,283' 7,874.0 8,283.0 04:45 12:00 MD 3,878' TVD. 230 GPM 1,560 PSI DPP. 18% F/O. 40 RPM, 8K TO, 17K WOB. Off BTTM - 1,300 PSI, UP WT =124K, DWN WT=74K. Max gas= 40 Units. ADT 4.24, AST -2.17, ART, 2.07, Bit hrs 7.71, Jar HR 4.24 1 SPR's @ 7,997' MD 3,916 TVD - MW 9.2 PPG Time 07:45 MP 1) 20 SPM = 430 PSI 30 SPM = 590 PSI MP 2) 20 SPM = 400 PSI 30 SPM = 570 PSI 9/21/2017 9/21/2017 1.00 PRODS DRILL DDRL P DDRL63/4'hole from 8,283'-8,331' 8,283.0 8,331.0 12:00 13:00 MD 3,877' TVD. 230 GPM, 1,370 PSI DPP, 18% F/O, 40 RPM. 7K TQ, with 3K WOB. Off BTM 1,305 PSI, UP WT =127K, DWN WT=72K, ROT WT - 94K. Max gas 81 units. ADT .65, AST .20, ART .45, Bit hrs 8.36, Jar hrs. 4.89. SPR's @ 8,373' MD 3,873 TVD - MW 9.2 PPG Time 13:00 MP 1) 20 SPM = 450 PSI 30 SPM = 620 PSI MP 2) 20 SPM = 450 PSI 30 SPM = 620 PSI Page 39179 Report Printed: 10130120171 Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tne EM Tme Dur(hr) Phase Op Cade Activity Cade Time P -T -X Operation Start Depth (ftKB) End Depth (flKB) 9/21/2017 9/21/2017 0.75 PROD3 DRILL CIRC P Rotate and reciprocate from 8,331'- 8,331.0 8,331.0 13:00 13:45 8,285' MD at 230 GPM, 1,310 PSI, 18% F/O. 40 RPM, with 6K DWN WT --UP WT=72K. ROT WT=94K, 2,580 STKS pumped. 9/21/2017 9/21/2017 0.50 PROD3 DRILL OWFF P OWFF (Static) 8,331.0 8,331.0 13:45 14:15 9/21/2017 9/21/2017 0.50 PROD3 DRILL TRIP P POOH on elevators from 8,331'- 8,331.0 7,905.0 14:15 14:45 7,905' MD. Monitor disp via TT. UP WT = 135K, DWN WT = 74K. 9/21/2017 9/21/2017 0.75 PROD3 DRILL TRIP P Kelly up and orient to 25 DEG Left7905.0 7813.0 14:45 15:30 highside for Whipstock pull through , , with Baker rep on site. UP WT 138K. 9/21/2017 9/21/2017 3.50 PROD3 DRILL TRIP P Pump heavy slug and blow down top 7,813.0 895.6- 15:30 19:00 drive. POOH on elevators from 7,813' -895'MD. UP WT=135K. DWN WT = 74K. Monitor disp via TT. 9/21/2017 9/21/2017 1.50 PROD3 DRILL BHAH P LO BHA as per SLB rep from 895' MD 895.0 0.0 19:00 20:30 to surface monitoring disp via TT. 9/2112017 9/21/2017 0.50 PROD3 DRILL WWWH P Make up BOP stack washer tool and 0.0 0.0 20:30 21:00 jet ram cavities. 9/2112017 9/21/2017 0.50 PROD3 WHDBOP RURD P Pull wear bushing and install test plug 0.0 0.0 21:00 21:30 9/21/2017 9/22/2017 2.50 PROD3 WHDBOP NOPE P MU BOPE testjoint and dart valve. 0.0 0.0 21:30 00:00 flush all lines, fill stack and body test. PJSM and Perform BOPE test with AOGCC rep Matt Herrera on site to witness. Low 250 High 3500 for 5 min each, Test #1-4 JNT, ANN, CV1,12,13,14,4" Kill line on mud manifold, 4:" Dart valve. Test #2 CV 9,11 Mez Kill ine 4" FOSV. 9/22/2017 9/22/2017 3.00 PROD3 WHDBOP ROPE P Continue to test BOPE. All test to 0.0 0.0 00:00 03:00 250/ 3,500 PSI 5 min charted. Except super chokes to 1,500 PSI. Test choke valves 1-14 UPR & LWR IBOR XT 39 dart and TIW valve. Man choke and kill valves. 4" Kill valve & Mez Kill ' valve. with 4" & 4 1/2" test joints. AN & 3 1/3" X6" VBR's. Blind rams Koomey draw down = 3050 PSI. 1850 after functions. 7 sec for 200 PSI, with 2 elect pumps 44 sec for total build up with 2 electric pumps and 2 air pumps. aver of 6 bit[ back up 2,020 PSI. Matt - Herrera with AOGCC witnessed test, Perform derrick inspection. 9/22/2017 9/22/2017 1.00 PROD3 WHDBOP RURD P RID test equipment BD top drive. 0.0 0.0 03:00 D4:00 Drain stack and pull test plug. Install wear bushing. grease upper IBOP. 9/22/2017 9/22/2017 0.25 PROD3 DRILL SFTY 5 PJSM for upcoming BHA work 0.0 0- 04:00 04:15 9/22/2017 9/22/2017 1.50 PROD3 DRILL SHAH P PU/MU BHA # 14 as per DD / MWD. 0.0 306.0 04:15 05:45 Monitor disp via TT 9/22/2017 9/22/2017 0.75 PROD3 DRILL TRIP P RIH from 306' MD to 2,105' MD. 306.0 2,105.6- 05:45 06:30 Monitor disp via TT UP WT = 75K, DWN WT = 75K. Page 40179 Report Printed: 1 013 0/2 01 7 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log SIN Tone End Tim D (hd Phew Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth Mot) /20 9/2217 9/22!2017 0.25 PROD3 DRILL DHEQ P Shallow hole test MWD with 220 GPM 2,105.0 2,105.0 06:30 06:45 @ 920 PSI DPP. 17% F/O 9.2 PPG (GOOD) 9/22/2017 9/22/2017 3.75 PRODS DRILL TRIP P Continue to RIH from 2,105'- 7,945' 2,105.0 7,945.0 06:45 10:30 MD. Monitor disp via TT. UP WT = 132K. DWN WT= 79K. Fill pipe every 20 stands. 9/22/2017 9/22/2017 1.50 PROD3 DRILL DLOG P Perform MAD PASS from 7,945' - 7,945.0 8,290.0 10:30 12:00 8,290' MD w@ 390 FPM. 250 GPM @ 1,545 PSI DPP. F/O = 19%. UP WT=130K, OWN WT 72K. ROT= 92K 6K TQ. 9/22/2017 9/22/20170.50 PROD3 DRILL DLOG P Continue MAD pass form 8,290' - 8,290.0 8,377.0 12:00 12:30 8,377' MD. with 250 GPM, 1,600 PSI, 20% F/O, 80 RPM, 5.51K TO. 9/22/2017 9/22/2017 5.50 PROD3 DRILL DDRL P Drill 6 3/4" hole from 8,377'- 8,926' 8,377.0 8,926.0 12:30 18:00 MD 3,878' TVD, 272 GPM at 1,880 PSI DPP. 22% F/O 150 RPM, 7K TO, with 3-3K WOB. ECD's 10.73 PPG EMW, Off BTM 1,880 PSI DPP, UP WT=137K DWN WT=37K. ROT= 96K. 7K TQ. Max gas = 80 units. ADT - 4.20, Bit HRS = 4.20 Jars = 9.09 9/22/2017 9/23/2017 6.00 PROD3 DRILL DDRL P Drill 3/4" hole from 8,926' MD 3,878' 8,926.0 9,780.0 18:00 00:00 TVD - 9,780' MD 3,887' TVD, 272 GPM at 2,005 PSI DPP. 22% F/O 150 RPM, 8K TO, with 4-51K WOB. ECD's 10.98 PPG EMW, Off BTM 2,000 PSI DPP, UP WT=137K DWN WT= 63K. ROT = 98K. 7.8K To. Max gas = 223 units. ADT - 4.31, Bit HRS = 8.51 Jars = 13.4 9/23/2017 9/23/2017 6.00 PROD3 DRILL DDRL P Drill 6 3/4" hole from 9,780' MD 3,887' 9,780.0 10,439.0 00:00 06:00 TVD - 10,439' MD 3,893' TVD, 272 GPM at 2,185 PSI DPP. 21% F/O 150 RPM, 8K TO, with 3K WOB. ECD's 11.52 PPG EMW, Off BTM 2,180 PSI DPP, UP WT = 125K OWN WT = 60K. ROT = 99K. 7.5K TQ. Max gas = 580 units. ADT - 4.15, Bit HRS = 12.66 Jars = 17.55 SPR's @ 9,870' MD 3,885 TVD - MW 9.2 PPG Time 00:53 MP 1) 20 SPM = 480 PSI 30 SPM -= 670 PSI MP 2) 20 SPM = 470 PSI 30 SPM = 640 PSI 9/23/2017 9/23/2017 6.00 PRODS DRILL DDRL P Drill 6 3/4" hole from 10,439' MD 10,439.0 11,188.0 06:00 12:00 3,893' MD -11,188' MD 3,922' TVD, 270 GPM at 2,360 PSI DPP. 21 % F/O 150 RPM, 8K TQ, with 5K WOB. ECD's 11.8 PPG EMW, Off BTM 2,355 PSI DPP, UP WT = 143K OWN WT=61 K. ROT =99K. 7.7K TQ. Max gas = 450 units. ADT - 4, Bit HRS = 16.66 Jars = 21.55 Begin 290 BBLS dump and dilute @ 10,987'MD Page 41/79 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EM Time our ft) Phase Op Code ActiNy Time me P -T -X Operation Slart Depth (Po(B) Ery Depth(RKa) 9/23/2017 9/23/2017 6.00 PROD3 DRILL DDRL P Drill 6 3/4" hole from 11,188' MD 11,188.0 11,758.0 12:00 18:00 3,922' TVD- 11,758' MD 3,922' TVD, 271 GPM at 2,425 PSI DPP. 21 % F/O 150 RPM, 9K TO, with 5K WOB. ECD's 11.48 PPG EMW, Off BTM 2,420 PSI DPP, UP WT= 148K OWN WT=67K. ROT =101 K. 8.3K TO. Max gas = 7,736 units. ADT - 4.41, Bit HRS = 21.07 Jars = 25.96 SPR's @ 11,266" MD 3,930' TVD - MW 9.2 PPG Time 12:30 MP 1) 20 SPM = 650 PSI 30 SPM = 860 PSI MP 2) 20 SPM = 640 PSI 30 SPM = 820 PSI 9/23/2017 9/24/2017 6.00 PROD3 DRILL DDRL pi— Drill 6 3/4" hole from 11,758' MD 11,758.0 12,003.0 18:00 00:00 3,922' TVD - 12,003' MD 3,909' TVD, 271 GPM at 2,440 PSI DPP. 21% F/O 150 RPM, 9K TO, with 5K WOB. ECD's 11.30 PPG EMW, Off BTM 2,420 PSI DPP, UP WT = 154K DWN WT=63K. ROT =101 K. 8.5K TO. Max gas = 3,458 units. ADT - 4.95, Bit HRS = 26.02 Jars = 30.91 9/24/2017 9/24/2017 6.00 PROD3 DRILL DDRL P Drill 6 3/4" hole from 12,003' MD 12,003.0 12,517.0 00:00 06:00 3,909' TVD -12,517' MD 3,903' TVD, 270 GPM at 2,500 PSI DPP. 21% F/O 140 RPM, 8K TO, with 2.5K WOB. ECD's 11.43 PPG EMW, Off BTM 2,495 PSI DPP, UP WT= 160K DWN WT=74K. ROT =IIOK. 8K TO. Max gas = 140 units. ADT - 4.02, Bit HRS = 30.04 Jars = 34.93 SPR's @ 12,095" MD 3,909" TVD - MW 9.2 PPG Time 00:55 MP 1) 20 SPM = 520 PSI 30 SPM = 750 PSI MP 2) 20 SPM = 520 PSI 30 SPM = 740 PSI 9/24/2017 9/24/2017 6.00 PROD3 DRILL DDRL P Drill 3/4" hole from12,517' MD 3,903' 12,517.0 13,177.0 06:00 12:00 TVD -13,177' MD 3,934' TVD, 270 GPM at 2,705 PSI DPP. 21% F/O 120 RPM, 8.5K TO, with 5K WOB. ECD's 10.71 PPG EMW, Off BTM 2,700 PSI DPP, UP WT= 175K DWN WT= 68K. ROT= 120K. 8.2K TO. Max gas = 65 units. ADT - 3.78 Bit HRS = 33.82 Jars = 38.71 Page 42179 Report Printed: 10/30/2017 DOYON 142 Operations Summary (with Timelog Depths) IH -102 Job: DRILLING State Time 9/24/2017 End Time 9/24/2017 Dia(m) 3.00 PhaseOp PROD3 Code Activity Cade Time P -T -X OP eradon Start Depth (ftKB) End Depth(XKB) 12:00 15:00 DRILL DDRL P Drill 6 3/4" hole from 13,177' MD 3,934' 13,177.0 13,435.0 TVD - 13,435' MD 3,924' TVD, 270 GPM at 2,820 PSI DPP. 21% F/O 140 RPM, 8.51K TO, with 5K WOB. ECD's 11.81 PPG EMW, Off BTM 2,810 PSI DPP, UP WT=177K OWN WT= 67K. ROT= 117K. 8.4K TQ. Max gas = 200 units. ADT - 1.84 Bit HRS = 35.66 Jars = 40.55 SPR's @ 13,199" MD 3,935" TVD - MW 9.2 PPG Time 12:10 MP 1) 20 SPM = 620 PSI 30 SPM = 870 PSI MP 2) 20 SPM = 620 PSI 30 SPM = 860 PSI 9/24/2017 15:00 9/24/2017 1.25 PRODS CASING CIRC P Obtain survey and SPR's. CBU and 13,435.0 13,430.0 16:15 recip from 13,430 MD - 13,379' MD. @ 270 GPM 2,790 PSI DPP, 21% F/O, 150 RPM, 8K TO, 4,500 STKS pumped. SPR's @ 13,435" MD 3,924" TVD - MW 9.2 PPG Time 15:00 MP 1) 20 SPM = 680 PSI 30 SPM = 920 PSI MP 2) 20 SPM = 660 PSI 30 SPM = 900 PSI 9/24/2017 9/24/2017 0.50 PROD3 CASING OWFF P OWFF 13,430.0 13,430.0 16:15 16:45 9/24/2017 16:45 9/25/2017 7.25 PROD3 CASING BKRM P BROOH form 13,430' MD -10,900' 13,430.0 10,900.0 00:00 MD at 270 GPM 2,265 PSI DPP. 20% F/O, 150 RPM, 6.5K TO. 11.41 ECD EMW. UP WT= 137K, DWN WT = 756K Monitor disp via TT. 9/25/2017 9/25/2017 7.50 PROD3 CASING BKRM P Continue to BKRM OOH from 10,900' 10,900.0 8,169.0 00:00 07:30 MD - 8,169' MD. 270 GPM @ 1,880 PSI DPP. 150 RPM with 5K TO. ECD = 10.57, UP WT = 130, DWN WT = 75K. 9/25/2017 9/25/2017 0.50 PRODS CASING TRIP P POOH on elevators from 8,169' MD - 8,169.0 7,788.0 07:30 08:00 7,788' MD UP WT= 126K, DWN WT = 80K 9/25/2017 9/25/2017 1.50 PROD3 CASING CIRC P Circulate while rotating from 7,783' 7,788.0 7,788.0 08:00 09:30 MD - 7,700' MD. 270 GPM @ 1,850 PSI DPP. 19% F/O. 120 RPM, with 5K TQ. 9.25 PPG MW. 5,400 STKS pumped. UP WT = 118k, DWN TWT = 86K = 86K 9/25/2017 9/25/2017 0.50 PRODS CASING OWFF P PJSM for SLIP / CUT 7,788.0 7,788.0 09:30 10:00 9/25/2017 9/25/2017 0.75 PRODS CASING SLPC P SLPC 73' 7,788.0 7,788.0 10:00 10:45 9/25/2017 9/25/2017 10:45 0.25 PROD3 CASING SVRG P Service top drive, Blocks and crown. 7,788.0 7,788.0 11:00 9/25/2017 9/25/2017 0.25 PROD3 CASING CIRC P Pumpwieghted slug. 7,788.0 7,788.0 11:00 11:15 Page 43/79 Report Printed: 10/30/2017 DOYON 142 Operations Summary (with Timelog Depths) 1H-102 Job: DRILLING Start Time I EM Time I Dur(ho I peas _ I Op Co. I A.WNCMa Ilime P -T -XI I SW Do PM 38'- 306' MD. Monitor Disp via TT. WT=121K OWN WT=83K. poi iv uvu men ie sown 15:30 16:45 RHC ae nor ci R - 9/25/2017 9/25/2017 0.50 PROD3 CASING SHAH ean rig floor and clear all tools. 0.0 0.0 16:45 17:15 9/25/2017 9/25/2017 0.25 COMPZ3 FISH SF ff SM for BHA handling. 0.0 0.0 17:15 17:30 9/25/2017 17:30 9/25/2017 1.50 50MPZ3 FISH BHAH 4PM1U whipstock retrieving assym as per 0.0 230.0 19:00 ker rep. 9/25/2017 19:00 9125/2017 1.00 COMPZ3 FISH TRIP H with BHA# 15 to retrieve 2300 1,6380 20:00 ipstock. monitor disp via TT. 9/25/2017 20:00 9/2512017 0.50 COMPZ3 FISH DHEO P Shallow pulse test SLB BHA for 1,638.0 1,638.0 20:30 communications. 250 GPM @ 1,060 PSI DPP. 18% F/O. UP WT = 67K. OWN WT 70K. 9/25/2017 20:30 9/25/2017 3.00 C0MPZ3 FISH TRIP P Continue to RIH from 1,638' MD to 1,638.0 7,828.0 23:30 7,828' MD. Monitor lisp via #5. Fill pipe every 20 STNDS. 9/25/2017 23:30 9/26/2017 0.50 50MPZ3 FISH FISH P7-- Mousehole botm single stand 82. 7,828.0 7,848.0 00:00 obtain toolface orientation with 250 GPM 1,440 PSI, 19% F/O. wash whipstock slot then orient 180 degrees and latch hook. UP WT = 136K OWN WT = 105K 9/26/2017 00:00 9/26/2017 0.50 COMPZ3 FISH FISH P Pull whipstock free per Baker. Jar as 7,848.0 7,750.0 00:30 follows: 2 x times with 40k overpull, 4 x times with 60k overpull, 3 x times With 70k overpull, and 1 x time with 80k overpull. Observe whipstock come free when jarring with 80k overpull. Pick up to 7750' MD. PUW 147k. 9/26/2017 00:30 9/26/2017 02:00 1.50 50MPZ3 FISH CIRC P Circulate 2 x bottoms up at 253 gpm, 7,750.0 7,750.0 1395 psi, 18% F/O. Observe initial loss of 40 bbls downhole and then dynamic losses of 13 bbl/hr. Total of 4700 strokes pumped. 9/26/2017 02:00 9/26/2017 02:30 0.50 C0MPZ3 FISH OWFF P Monitor well for flow -observe fluid 7,750.0 7,750.0 level drop -1 ft over 30 minutes. Drop 2.1" OD hollow drift on stand #80. 9/26/2017 02:30 9/26/2017 5.00 50MPZ3 FISH TRIP P Pull out of hole on elevators racking 7,750.0 231.0 07:30 back 4" DP and HWDP from 7750' to 231' MD, monitoring displacement via trip tank. 9/26/2017 07:30 9/26/2017 2.25 COMPZ3 FISH BHAH P Lay down whipstock retrieval BHA #15 231.0 0.0 09:45 and whipstock per Baker from 231' to surface. Observe whipstock wear pattern -33` right of center at bottom of slide. Observe small amount of gas trapped below whipstock, no issues breaking out. 9/26/2017 9/26/2017 0.75 COMP23 FISH,' BHAH P Clean and clear rig Floor of whipstock 0.0 0.0 09:45 10:30 equipment. 9/26/2017 9/26/2017 1.50 COMPZ3 CASING RURD P Rig up casing tools to mn 4-1/2" lower 0.0 0.0 10:30 12:00 - completion. Page 44179 ReportPrinted: 1 013 0/2 01 7 Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Steil Tune EM Tune our ( Phase Op Activity Code Time P-T-X Openmon Start Depth (flKB) End Depth(11KB) 9/26/2017 9/26/2017 0.7.7 5 COMPZ3 CASINGG RURD P Mobilize pups to rig floor, confirm pipe 0.0 0.0 12:00 12:45 count, and hold PJSM for running liner. 9/26/2017 9/26/2017 8.75 COMPZ3 CASING PUTB P Pick up bent shoe and run in hole with 0.0 5,338.0 12:45 21:30 4-1/2" 11.6# L-80 IBTm slotted liner with 4-1/2" 12.6# L-80 blank joints and 6" OD swell packers to 5338' MD per tally. Run total of 1 x bent shoe joint, 109 x 4-1/2" 11.6# L-80 IBTm slotted liner, 14 x 4-1/2" 12.6# L-80 TXPm blank liner, and 3 x 6" OD Baker swell packers with —2.7' long elements. Run total of 130 x 6-1/8" thick-walled Volant hydroform centralizers. Install 1 x free-floating on every joint and install above and below each swell packer element. MUT for 4-1/2" IBTm of —4500 fl-lbs. MUT for 4-1/2" TXPm of —7000 fl-lbs. No remakes / no rejects. Monitor displacement via trip tank. 9/26/2017 9/26/2017 1.00 COMPZ3 CASING OTHR P change out handling equipment, rig 5,338.0 5,368.0 21:30 22:30 - up false bowl, and install SLB slimpulse in suing. Make up Baker "B- 3" Flanged Hook Hanger assembly and scribe. 130° toolfaoe offset measured MWD highside to 180° off from hook. 9/26!2017 9/26/2017 0.25 COMPZ3 CASING CIRC P Make up stand of 4" DP and break 5,368.0 5,368.0 22:30 22:45 circulation, staging up pump to 2.5 bpm, 340 psi, 11% F/O. With pumps off, obtain PUW 87k, SOW 74k. 9/26/2017 9/2612017 0.25 COMPZ3 CASING RUNL P Run 4-1/2" lower completion in on 4" 5,368.0 5,835.0 22:45 23:00 DP from 5368'to 5835' MD 9/26/2017 9/26/2017 0.50 COMPZ3 CASING DHEQ P Shallow hole test SLB Slimpulse at 90 5,835.0 5,835.0 23:00 23:30 gpm, 290 psi, 9% F/O - good test. Blow dow topddve. 9/26/2017 9/27/2017 0.50 COMPZ3 CASING RUNL P Run 4-1/2" lower completion in on 4" 5,835.0 6,792.0 23:30 00:00 DP from 5835' to 6792' MD, monitoring displacement via trip tank. PUW 97k, SOW 77k. OA pressure at midnight = 20 psi Total downhole losses for past 24 hours = 101 bbls 9/27/2017 9127/2017 0.50 COMPZ3 CASING RUNL P Run 4-1/2" lower completion in on 4" 6,792.0 7,829.0 00:00 00:30 _ DP from 6792'to 7829' MD, monitoring displacement via trip tank. 9/27/2017 9/27/2017 0.50 COMPZ3 CASING 'CIRC P Break circulationabove window with 7,829.0 7,829.0 00:30 01:00 88 gpm, 358 psi, 9% F/O, PUW 109k, SOW 82k. Blow down topdrive. 9/27/2017 9/2712017 3.00 COMPZ3 CASING RUNL P Run 4-1/2" lower completion in on 4" 7,829.0 13,153.0 01:00 04:00 DP and 4" HWDP from 7829'to 13153' MD, monitoring displacement via trip tank. No issues running bent joint through window. Calculated displacement = 81.8 bbls, Actual displacement = 42.2 bbls. Page 45179 Report Printed: 10130/2017 Operations Summary (with Timelog Depths) IH -102 lip( Rig: DOYON 142 Job: DRILLING ORIGINAL rime Log Start Time End Time Dur (hr) Phase Op Code AclivM1y Code Time P -T -X Opere4on Stan Depm MKB) End Depth (WS) 9/27/2017 9/27/2017 1.00 COMPZ3 CASING RUNL P Kelly up and pump at 90 gpm, 590 psi, 13,153.0 13,204.2 04:00 05:00 9% F/O. Orient to 154" right and run in hole 60' on stand #84 to 13213' MD, putting hook 10' past window - no issues. Pick up and orient to 20° left. Run in hole and engage hook hanger 50.5' in on stand #84. Set down 20k weight and confirm orientation 20` left. Pick up 15', run back in, see slight bobble of weight 50.5' in on stand #84 then engage hook at 52' in on stand #84. Set down 20k and confirm orientation 20° left. Total of 717 strokes pumped. 9/27/2017 9/27/2017 1.25 COMPZ3 CASING CIRC P Drop 29/32" phenolic ball and pump 13,204.2 7,835.0 05:00 06:15 - down, 139 gpm, 990 psi, 12 % F/O for 350 strokes, then 85 gpm, 540 psi, 9% F/O for 150 strokes, then 66 gpm, 429 psi, 7% F/O for 100 strokes, then 44 gpm, 328 psi, 4% F/O to seat ball. Ball on seat at 645 strokes. Pressure up to 3300 psi and hold to release liner running tool. Continue pressuring up to 4450 psi with mud pump to shear ball seat- no shear observed. Bleed off pressure, line up test pump, pressure up with mud pump to 4100 psi, and continue pressuring up with test pump to shear ball seat. Observe shear at 4850 psi (pinned for 4000 psi shear). Pick up above hook hanger to 7835' MD, PUW 1421k. Top of L2 hook hanger set at 7840.0' MD L2 Shoe set at 13204.2' MD 9/27/2017 9/27/2017 0.50 COMPZ3 WELLPR OWFF P Monitor well for flow -observe fluid 7,835.0 7,835.0 06:15 06:45 level drop 6 inches over 30 minutes. - Blow down topdrive. 9/27/2017 927/2017 3.75 COMPZ3 WELLPR TRIP 5 Trip out of hole on elevators, racking —T8-35 0 0.0 06:45 10:30 back 4" HWDP and 4" DP from 7835' to surface, monitoring displacement via trip tank. Calculated displacement = 57 bbls. Actual displacement = 69.9 bbls. 9/27/2017 9/272017 0.50 COMPZ3 WELLPR BHAH P Lay down Baker hook hanger conning 0.0 0.0 10:30 11:00 tools and SLB SlimPulse. 9/2712017 927/2017 0.25 COMPZ3 WELLPR SHAH P Clean and clear rig floor of running 0.0 0.0 11:00 11:15 tools. 927/2017 9/27/2017 0.50 COMPZ3 RWRID KURD P Rig up to run L2 LEM / ZXP assembly 0.0 0.0 11:15 11:45 with GBR torque tum and hold PJSM. Page 46179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 11-1-102 lipf Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Time End Tone our (hr) —2 Phase Op Coda Activity Code Time P -T -X Operation stint Depth (1009) End Depth(RKe) 9/27/2017 9/27/2017 75 COMPZ3 RWRID PUTB P Make up LEM I ZXP assembly for L2 0.0 242.0 11:45 14:30 lateral to 242' MD with SLB Slim Pulse installed. GBR utilize torque turn while making up TXP connections to 7000 ft -lbs, no issues observed. Scribe MWD offset to 177.56°. Had issue stinging in . seal assembly but eventually got it installed. 9127/2017 9/27/2017 0.75 COMPZ3 RWRID CIRC P Run in hole —0n1 x stand 4" DP to 337' 242.0 337.0 14:30 15:15 MD and break circulation at 2 bpm, 310 psi, 9% F/O, no issues observed. Blow down topdrive. 9/27/2017 9/27/2017 1.50 COMPZ3 RWRID RCST P Run in hole with L2 LEM / ZXP 337.0 2,137.0 15:15 16:45 assembly on 4" DP from 337' to 2137' MD, monitoring displacement via trip tank. 9/27/2017 9/27/2017 —0 25 50MPZ3 ffWRID RWRIDDHEQ P Shallow hole testMWD SIimPulse with 2,137.0 2,137.0 16:45 17:00 92 gpm, 320 psi, 10°h F/O. PUW 73k, SOW 75k. Blow down topdrive. Note: Low end at 70 gpm, high end at 150 gpm for tool. 9/27/2017 9/27/2017 3.25 COMPZ3 RWRID RCST P Run in hole with L2 LEM / ZXP 2,137.0 7,838.0 17:00 20:15 assembly on 4" DP and 4" HWDP from 2137'to 7838' MD, monitoring displacement via trip tank. PUW 143k, SOW 109k 9/27/2017 9/27/2017 1.00 COMPZ3 RWRID PACK P Establish circulation at 90 gpm, 550 7,838.0 7,948.0 20:15 21:15 psi, 9% FlO. Wash down from 7838' and orient LEM to 80° left. No issues running muleshoe through hook hanger or entering L1 LTP. Run in and bury stand #82 to 7930.48' MD. Make up 4" DP single and continue washing in hole. Locate LEM in hook hanger 17.5' in on single. Slack off to 90k HL (19k set down) and observe toolface roll to 26" left. Confirm orientation at 26° left, Pick up to 155k (12k overpull) and confirm latched. 9127/2017 9127/2017 1.25 COMPZ3 RWRID PACK P Drop 1.625" frac ball and pump down 7,948.0 7,948.0 21:15 22:30 at 3 bpm, 780 psi, 13% F/O for 350 strokes, then 2 bpm, 490 psi, 10% F/O for 150 strokes, then 1.5 bpm, 385 psi, 8% F/O. Ball on seat at 558 strokes. Increase pressure to 2300 psi and hold for 1 minute, observing pusher tool shear at 2300 psi. Stage up pressure to 4000 psi, observing pusher tool neutralize at 3600 psi. Bleed off pressure and pick up to 146k. Slack off to 90k and pick up to 150k - not released. Slack off to 90k and pressure up to 4400 psi with mud pump. Slack off to 80k HL. Bleed off pressure and pick up, observing breakover at 147k - confirm released. Page 47/79 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Siad Time End Diu ( Ph op Cotle ACGvity Code Time P -T -X Opereuan Sart Depth (W13) End Depth(tIKB) 9/27/2017 9/27/2017 17 0.5.5 0 COMPZ3 Z3 RWRID PRTS P Close bag and pump down IA with 7,948.0 7,948.0 22:30 23:00 mud pump #1 to pressure test L2 liner top packer. Pressure up to 3500 psi and hold for 10 minutes, charted - good test. Pumped 3.6 bbls, returned 3.6 bbls. Bottom of seal assembly at 7947.98' MD - spaced out 4.24' off no-go Top of L2 Liner Top Packer at 7718.30' MD 9/27/2017 9/27/2017 0.50 COMPZ3 RWRID CIRC P Lay down single and continue pulling 7,948.0 7,718.0 23:00 23:30 up to place ports at top of liner tieback sleeve for high circulation rate. Pump 26 bbls corrosion inhibited brine and spot with 73 bbls of 9.3ppg FloPro at 213 gpm, 665 psi, 17% F/O. Note: Circulation port is above the SlimPulse 9/27/2017 9/28/2017 0.50 COMPZ3 RWRID OWFF P Rack back stand to 7642' MD, blow 7,718.0 .7,642.0 23:30 00:00 down topdrive, and monitor well for 30 minutes. OA pressure at midnight = 30 psi Downhole lasses for past 24 hours = 53 bbls. 8/28/2017 9/28/2017 0.25 50MPZ3 RWRID OWFF P Finish monitoring well for flow and 7,642.0 7,642.0 00:00 00:15 blow down kill line. 9/28/2017 9/28/2017 5.75 60MPZ3 RWRID TRIP P Trip out of hole on elevators from 7,642.0 87.0 00:15 06:00 7642'to 87', racking back 4" HWDP and 4" DP and adjusting supersliders per W WT as needed. 9/28/2017 9/28/2017 0.75 COMPZ3 RWRID BHAH P Lay down LEM / Z (P running tools 87.0 0.0 06:00 06:45 and SLB Slimpulse. 9/28/2017 9/28/2017 0.50 COMPZ3 RWRID BHAH P Clean and Gear rig floor of running 0.0 0.0 06:45 07:15 tools. 9/28/2017 9/28/2017 1.25 PROD4 WHPST BHAH P Mobilize whipstock BHA to rig floor, 0.0 0.0 07:15 08:30 confirm spaceout, and mobilize spaceout pups to rig floor. Hold PJSM. 9/28/2017 9/28/2017 3.00 PROD4 WHPST BHAH P Make up 6-3/4" milling assembly with 0.0 307.0 08:30 11:30 Slimpulse MWD and scribe, 242.11 ° TFO. Rack back milling assembly. Make up 7-5/8" Gen II whipstock assembly and bolt up milling assembly with 25k shear bolt. RIH to 307' MD. SOW 57.5k 9/28/2017 9/28/2017 1.50 PROD4 WHPST TRIP P Trip in hole with whipstock assembly 307.0 2,197.0 11:30 13:00 on 4" DP from 307' to 2197' MD, monitoring displacement via trip tank. 9/28/2017 9/28/2017 0.50 PROD4 WHPST DHEQ P Shallow hole test MWD with 213 gpm, 2,197.0 2,197.0 13:00 13:30 605 psi, 16% F/0 - no issues. Note: Flow range is 175 - 330 gpm 9/28/2017 9/28/2017 4.25 PROD4 WHPST TRIP P Trip in hole with whipstock assembly 2,197.0 7,625.0 13:30 17:45 on 4" DP and 4" HWDP from 2197' to 7625' MD,filling pipe every 20 x stands and monitoring displacement via pit #1. Page 48179 Report Printed: 1 013 0/2 01 7 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slav none End none Dur(hr) Phase Op Code Activity Code none P -T -X Operation atan Depth (IIKa) End Depth (WS) 9/28/2017 9/28/2017 0.50 PROD4 WHPST WPST P Establish circulation at 200 gpm, 1000 7,625.0 7,625.0 17:45 18:15 psi, 15% F/O and orient whipstock to 22° left. PUW 142k, SOW 111k 9/28/2017 9/28/2017 0.50 PROD4 WHPST WPST P Wash in hole from 7625', SOW 110k. 7,625.0 7,647.0 18:15 18:45 Observe -1k drag as seals entered top of liner. Locale top of liner at 7719.09' MD (0.79' deep, -amount that pusher tool compress LTP). Slack off to 105k HL (6k set down) and observe good indication of anchor shear. Confirm whipstock orientation at 22° left. Kill pump and pick up to 150k HL (8k overpull) - confirm anchor set. Slack off to 80k HL (30k set down) and observe good indication of bolt shear. Pick up and observe free travel at PUW 142k. Top of window @ 7647.0' MD Blm of window @ 7660.7' MD 9/28/2017 9/28/2017 0.25 PROD4 WHPST WPST P Establish parameters with 200 gpm, 7,647.0 7,647.0 18:45 19:00 1000 psi, 16% F/O, 20 rpm, 4.5k ft -lbs off-btm torque. 017 9/29/2017 5.00 PROD4 WHPST MILL P Mill 6-3/4" window for L3 lateral from 7,647.0 7,657.0 19:00 19:00 00:00 7647' to 7657' MD per Baker with 300 gpm, 1880 psi, 21% F/O, 100 rpm, 3- 5k Tq, 3K WOB, 9.3ppg in/out MW with 65 vis in / 59 vis out. Pump 25 bbl hi -vis super sweep at 7652' MD, observe moderate increase in metal cuttings over shakers. Mill out on pit #1 only, keeping other RoPro isolated. Downhole losses for past 24 hours = 24 bbls OA pressure at midnight = 360 psi 9/29/2017 9/29/2017 7.75 PROD4 WHPST MILL P Mill 6-3/4" window for L3 Lateral from 7,657.0 7,685.0 00:00 07:45 7657' to 7685' MD with 300 gpm, 1850 psi, 21 % F/O, 100 rpm, 3-7k Tq, 5-12k WOB. Pump super sweeps per Baker rep. Mill out on pit #1 only, keeping other FloPro isolated. Note: -7 ft of gauge 6-3/4" hole to 7668' MD, rathole to 7685' MD TOW @ 7647.0' MD BOW @ 7660.7' MD 9/29/2017 9/29/2017 0.50 PROD4 WHPST REAM P Pump super sweep at TD with 300 7,685.0 7,637.0 07:45 08:15 gpm, 1850 psi, 21 °h VO, 100 rpm, 3- 4k Tq and ream through window - no issues. Kill rotary, drop flow to 86 gpm, 618 psi, 11 % F/O and wash up and down through window- no issues. Pumps on PUW 140k, SOW 104k. Rack back stand to 7637' MD. Page 49179 Report Printed: 1013-0/20-171 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Da(hr) ase Phase Op Code Activity Cade Time P -T-% Operation Depth (ItKB) End Depth (nKB) 9/29/2017 9/29/2017 0.50 PROD4 WHPST CIRC P Circulate sweep out while staying 7,637.0 7,637.0 08:15 08:45 above window with 300 gpm, 1800 psi, 21 % F/O, MW in/out 9.3ppg. Moderate amount of metal cuttings observed once sweep at surface. Obtain SPR's. Total 3400 strokes pumped. SPRs @ 7633' MD 3806' TVD, MW=9.30 ppg, 08:39 hours - MP#1: 20 spm=610 psi, 30 spm=780 psi. MP #2: 20 spm=600 psi, 30 spm=740 psi. 9/29/2017 9/29/2017 1.00 PROD4 WHPST FIT P Rig up and perform FIT for L3 window 7,637.0 7,637.0 08:45 09:45 to 12.9 ppg EMW. Close annular, pump down drill pipe and IA with mud pump #1. Pressure up to 715 psi and shut in, observe pressure drop to 595 psi after 10 minutes. Pumped 0.9 bbl, returned 0.9 bbl. Rig down and blow down equipment. 9/29/2017 9/29/2017 0.50 PROD4 WHPST OWFF P Monitor well for flow -observefluid 7,637.0 7,637.0 09:45 10:15 level drop —3 inches. 9/29/2017 9/29/2017 0.25 PROD4 WHPST TRIP P Trip OOH from 7639' to 7436' MD, 7,637.0 7,436.0 10:15 10:30 racking back 4" HWDP stands, monitoring displacement via trip tank. Note: Lay down top single of stand #77 to switch breaks on the stands. 9/29/2017 9/29/2017 0.25 PR0D4 WHPST CIRC P Pump dry job, install stripping rubbers, 7,436.0 7,436.0 10:30 10:45 and blow down topdrive. 9/29/2017 9/29/2017 4.00 PROD4 WHPST TRIP P Trip OOH from 7436' to 231' MD, 7,436.0 231.0 10:45 14:45 racking back 4" DP and 4" HWDP, monitoring displacement via trip tank. 9/29/2017 9/29/2017 1.00 PROD4 WHPST SHAH P Lay down milling BHA from 23V to 231.0 0.0 14:45 15:45 surface. Clean off metal from each magnet - pockets mostly full on each magnet. Lay down MWD tool and gauge mills. Upper 6-3/4" Mill - In Gauge Lower 6-5/8" Mill - 1/4" undergauge Window 6-3/4" Mill - 1/2" undergauge 9/29/2017 9/292017 0.50 PROD4 WHPST BHAH P Clean and clear dg floor of BHA tools. 0.0 0.0 15:45 16:15 1 9/29/2017 9/29/2017 0.75 PROD4 WHPST WWWH P Make up stack washer and jet stack 0.0 0.0 16:15 17:00 with 21 bpm, 150 psi. SIMOPS - mobilize motor BHA to rig floor. 9/292017 9/29/2017 2.00 PROD4 WHPST BHAH P Make up 6-3/4" motor BHA with 1.5" 0.0 896.0 17:00 19:00 motor and run in hole to 896' MD. Monitor displacement via trip tank. Note: Re -run 6-3/4" milltooth bit and 1.5" motor as they are both in good shape and low hours. 9/2912017 9/29/2017 1.00 PROD4 WHPST TRIP P Trip in hole on 4" DP from 896'to 896.0 2,087.0 19:00 20:00 1 2087' MD, monitoring displacement via trip lank. Page 50179 Report Printed: 1 013 0/2 01 7 Tim. 20:30 DOYON 142 Operations Summary (with Timeiog Depths) 1 H-102 Job: DRILLING 1270 gpm, 1235 psi, 21 % F/O - tPSt. Rinw down inn dri%< 9/29/2017 20:30 9/29/2017 23:15 2.75 PROD4 WHPST TRIP P Trip in hole on V DP and 4" HWDP 2,087.0 7,556.0 from 2087'to 7556' MD, monitoring displacement via trip tank and filling pipe every 20 x stands, PUW 148k, SOW 108k. Note: Replace 4" HWDP single on top of same stand it was removed from. 9/29/2017 23:15 9/29/2017 23:45 0.50 -FR—OD-4— WHPST CIRC p and orient motor to 22° left 7,556.0 7,675.0 5 gpm, 2010 psi, 22% F/O. Kill nd trip in from 7556'to 7675' drag observed tripping T5, window. Observed string start -2k drag at 7668'MD, end of ole. Continue tripping in and 5-6k weight at 7675' MD. Pick nd trip in, setting down 5-6k weight at 7675' MD. 9/29/2017 23:45 9/30/2017 00:00with 0.25 PROD4 Wash down from 7675'to 7685' MD 7,6750 7,685.0 250 gpm, 1760 psi, 18% F/O, 4- 7k WOB. Observe hard spot between TWHPSTWASHP 7675'- 7677'MD. OA pressure at midnight = 0 psi Downhole losses for past 24 hours20 bbls 9/30/2017 00:00 9/30/2017 03:00 3.00 PROD4 RL P Directionally drill 6-314" production L3 7,685.0 7,918.0 lateral from 7685' to TD of 7918' MD, 3882' TVD. TO called early per Geo as we obtained higher than expected motor yield (15° versus 12°) that put us in pay zone quicker. Pump at 250 gpm, 1850 psi on-btm, 1750 psi off- btm, 19% F/O. Rotate at 30 rpm, 5k Tit on-btm, 3.5k Tq off-btm. 5-8k WOB. Max gas 39 units. PUW 138k, SOW 110k, ROT 114k. ADT 1.43 hrs, AST 0.67 hrs, Bit 9.79 hrs, Jar 41.98 hrs. Displace wellbore to new/used 9.2ppg Flo -Pro on the fly on first full stand and put on full active system, dumping all milling fluid. Note: Observed flow -out reading drop & gas unit reading rise once started dumping milling fluid returns to rockwasher. Actual flow out did not change, nor did gas units increase. Rig is investigating the issue with the sensors when we dump fluid to rockwasher. SPRs @ 7822' MD 3851' TVD, MW=9.20 ppg, 01:40 hours MP#1: 20 spm=440 psi, 30 spm=620 psi. MP #2: 20 spm=430 psi, 30 spm=610 psi. Page 51179 Report Printed: 1 013 0/2 01 7 t, Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stag Time End Time Dm ( Phase Op Cade Actively Cade Time P -TX Operation start Depth (ftKI fi End Depth (f K13) 9/30/2017 8/30/2017 0.5.5 0 PROD4 DRILL CIRC P Obtain final survey and circulate hole 7,918.0 7,824.0 03:00 03:30 clean around BHA, backreaming stand from 7918'to 7824' with 270 gpm, 1955 psi, 50 rpm, 4.5k Tq. Orient to 16' left and rack back stand. 9/30/2017 9/30/2017 0.50 PROD4 DRILL OWFF P Blow down topdrive and monitor well 7,824.0 7,824.0 03:30 04:00 for flow - observe fluid level drop -6 inches over 30 minutes 9/3012017 9/30/2017 0.50 PROD4 DRILL TRIP P Trip out of hale from 7824'to 7550' 7,824.0 7,550.0 04:00 04:30 MD. PUW 143k, SOW 111 k. Observed 3-5k drag in open hole. No drag observed pulling BHA through window. 9/30/2017 9/30/2017 0.25 PROD4 DRILL CIRC P Pump dry job with 170 gpm, 760 psi. 7,550.0 7,550.0 04:30 04:45 Blow down top drive. 9/30/2017 9/30/2017 3.25 PROD4 DRILL TRIP P Trip out of hole from 755010 895' MD, 7,550.0 895.0 04:45 08:00 racking back 4" HWDP and 4" DP, monitoring displacement via trip tank. 9/30/2017 9/30/2017 0.25 PROD4 DRILL OWFF P Monitor well for flow at top of BHA- 895.0 895.0 08:00 08:15 1 well static. 9/30/2017 9/30/2017 2.25 PROD4 DRILL BHAH P Pull out of hole from 895' to surface. 895.0 0.0 08:15 10:30 Cleani off magnets and lay down. Rack back jar stand and lay BHA per SLB. Bit was in good shape, graded 0- O -NO -A -E -0 -NO -BHA. 9130/2017 9/3012017 0.50 PROD4 DRILL BHAH P Clean and Gear rig floor of BHA and 0.0 0.0 10:30 11:00 mobilize RSS BHA to floor. 9/30/2017 9/30/2017 0.75 PROD4 DRILL W W WH P Make up slack washer and jet stack 0.0 0.0 11:00 11:45 with 20 bpm, 130 psi, 38% F/O, 10 rpm. 9/30/2017 9/30/2017 0.75 PROD4 DRILL RURD P Pull wearbushing, clean off, and re- 0.0 0.0 11:45 12:30 install same. 9/30/2017 9/30/2017 1.00 PROD4 DRILL BHAH P PJSM. Make up RSS BHA to 306' with 0.0 306.0 12:30 13:30 6-3/4" Smith AxeBlade PDC bit, X6 Powerdrive, 4-3/4" Periscope, 4-3/4" ImPulse, 6-5/8" NM stabilizer, 4-3/4" flex NMDC, 4" HWDP, and 4-3/4" hydraulic jars. Monitor displacement vita pit #5. 9/30/2017 9/30/2017 1.00 PROD4 DRILL TRIP P Trip in hole from 306'to 2195' MD on 306.0 2,195.0 13:30 14:30 4" DP stands slick, monitoring displacement via pit #5.hall 9/30/2017 9/30/2017 0.25 PROD4 DRILL DHEQ P Fill pipe and sow hole test MWD 2,195.0 2,195.0 14:30 14:45 with 200 gpm, 760 psi, 16°h FIO - good test. Blow down top drive. 9/30/2017 9/30/2017 1.50 PR0D4 DRILL TRIP P Trip in hole from 2195' to 5044' MD on 2,195.0 5,044.0 14:45 16:15 4" DP stands slick, monitoring displacement via pit #5 and filling pip every 20 x stands. 9/30/2017 9/30/2017 1.25 PROD4 DRILL PULD P Run in hole from 5044' to 6370' MD 5,044.0 .6,370.0 16:15 17:30 picking up 4" DP singles from shed, PUW 106k, SOW 86k. Monitor displacement via pit #5 and fill pipe every 20 x stands. 9/30/2017 9/30/2017 0.50 PROD4 DRILL TRIP P Trip in hole from 6370'to 7124' MD on 6,370.0 7,124.0 17:30 18:00 4" DP stands slick, monitoring displacement via pit #5, filling pipe every 20 x stands. Page 52179 Report Printed: 11573012 01 7 Operations Summary (with Timeiog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL rime Lug SIAM Thee End Time our (hr) Phese Op Code Achv.ty Code ➢me P -T -X Operation StaMDepth I (ftKB) End Depth (MKB) 9/30/2017 9/30/2017 1.50 PROD4 DRILL SVRG P Service lopddve. Inspect saver sub 7,124.0 7,124.0 18:00 19:30 and decision made to change out due to wear. 9/30/2017 9/30/2017 0.75 PROD4 DRILL TRIP P Trip in hole from 7124'to 7601' MD on 7,124.0 7,601.0 19:30 20:15 4" DP stands slick, monitoring displacement via pit #5. Fill pipe. 9/30/2017 9/30/2017 0.25 PROD4 DRILL TRIP P Run in hole from 76 V to 7670' MD, 7,601.0 7,670.0 20:15 20:30 picking up 4" DP stands with super sliders. PUW 115k, SOW 85k. Observe bit tagging up on top of whipstock at 7647' MD, max 5k set down. Attempt to trip past several times with no luck. Pick up above whipstock and put in 1.5 wraps and work down. Attempt to trip past with no luck. Pick up above whipstock, engage pump at 128 gpm, 510 psi, 12% F/O, put in 5 wraps, and attempt to wash past, no luck, still tagging up on top of whipstock, max 5k set down. Pick up above whipstock, increase rate to 212 gpm, 1140 psi, 16% F/O to help engage powerdrive pads to rock bit past top of whipstock, put in 5 wraps, and wash down across window successfully. Once bit past top of whipstock, no drag observed across window. 9/30/2017 9/30/2017 0.25 PROD4 DRILL DLOG P Perform MAD pass from 7670' to 7,670.0 7,677.0 20:30 20:45 7677' MD with 242 gpm, 1430 psi, 18% F/O at 300 ft/hr per MWD. 9/30/2017 9/30/2017 1.75 PROD4 DRILL DLOG P Observe bit tagging up at 7677' on 7,677.0 7,918.0 20:45 22:30 concretion. Attempt to wash past several times, setting down 15k weight, no success. With bit and stabilizer in open hole (below window), engage rotary at 15 rpm, 3-4k Tq and ream down to 7692', logging per MWD at 214 gpm, 1172 psi, 16% F/O. Make up stand, engage pumps, and observe ability towash down without needing anymore rotary. Continue washing down at 242 gpm, 1440 psi, 20% F/O from 7692' to 7918' MD, logging per MWD at 300 ft/hr. Stop and cycle pumps for surveys per DD. Take SPRs. SPRs @ 7878' MD 3828' TVD, MW=9.20 ppg, 22:14 hours MP#1: 20 spm=360 psi, 30 spm=520 psi. MP #2: 20 spm=340 psi, 30 spm=510 psi. Page 53/79 ReportPrinted: 10130120171 0130/2 017 DOYON 142 Operations Summary (with Timelog Depths) 1H-102 Job: DRILLING startTime 9/302017 End Time 10/1/2017 drr 1.50 Phase PROD4 op Code DRILL Activity cede DDRL Time P -T -x P Operation SWA Depth (ftKB) End Depth (nKB) 22:30 00:00 Directionally drill 6-3/4" production L3 7,918.0 8,043.0 lateral from 7918'10 8043' MD, 3823' TVD. Pump at 267 gpm, 1740 psi, 21% F/O, ECD 10.36 ppg, MW 9.25 ppg. Rotate at 130 rpm with 4.5k Tq on-btm, 4k Tq off-btm. Max gas 115 units. 1k WOB. PUW 107k, SOW 84k, ROT 95k. ADT 1.24 hrs, Bit 1.24 hrs, Jars 43.22 hrs. OA pressure at midnight = 220 psi. Downhole losses for past 24 hours = 10 bbls. 10/12017 00:00 10/1/2017 06:00 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 8,043.0 8,357.0 lateral in WestSak B sand from 8043' ' to 8357' MD, 3818' TVD. Pump at 269 gpm, 1729 psi, 21% F/O, ECD 10.34 ppg, MW 9.25 ppg. Rotate at 130 rpm with 5.5k Tq on-btm, 4k Tq off-btm. 2- 3k WOB. PUW 111 k, SOW 80k, ROT 92k. Max gas 229 units. ADT 5.03 hrs, Bit 6.3 hrs, Jars 48.28 hrs. Concretions drilled at 8089' - 80961, 8125' - 8140', 8190'- 8204', and 8331' - 8343'. SPRs Q 8066' MD 3822' TVD, MW=9.20 ppg, 00:23 hours MP#1: 20 spm=360 psi, 30 spm=540 psi. MP #2: 20 spm=360 psi, 30 spm=540 psi. 10/1/2017 06:00 10/1/2017 12:00 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" Production L3 8,357.0 8,871.0 lateral in WestSak B sand from 8357' to 8871' MD, 3817' TVD. Pump at 272 gpm, 1837 psi, 22% F/O, ECD 10.6 ppg, MW 9.25 ppg. Rotate at 130 rpm with 6k Tq on-btm, 5.5k Tq off-btm. 2k WOB. PUW 112k, SOW 77k, ROT 95k. Max gas 238 units. ADT 4.16 hrs, Bit 10.46 hrs, Jars 52.44 hrs. Concretions drilled at 8361'- 8365', 8373'- 8375', and 8473' - 8476'. Page 54179 Report Printed: 10/30/2017 Summary (with Timelog Depths) IH-102 IgoOperations Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Tone Our (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (71x13) End Depth (f K13) 10/1/2017 10/1/2017 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 8,871.0 9,700.0 12:00 18:00 lateral in WestSak B sand from 8871' to 9700' MD, 3836' TVD. Pump at 280 gpm, 2130 psi, 23% F/O, ECD 11.08 ppg, MW 9.25 ppg. Rotate at 180 rpm with 7k Tq on-btm, 6k Tq off-btm. 2k WOB. PUW 118k, SOW 81k, ROT 93k. Max gas 226 units. ADT 4.54 hrs, Bit 15.0 hrs, Jars 56.98 hrs Concretions drilled at 9027'- 9033' and 9116'- 9125' SPRs @ 8925' MD 3819' TVD, MW=9.20 ppg, 12:17 hours MP#1: 20 spm=440 psi, 30 spm=630 psi. MP #2: 20 spm=440 psi, 30 spm=590 psi. 10/1/2017 10/2/2017 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 9,700.0 10,200.0 18:00 00:00 lateral in WestSak B sand from 9700' to 10,200' MD, 3836' TVD. Pump at 272 gpm, 2100 psi, 21% F/O, ECD 11.21 ppg, MW 9.20 ppg. Rotate at 180 rpm with 8k Tq on-btm, 7k Tq off- btm. 2-3k WOB. Max gas 150 units. PUW 121k, SOW 62k, ROT 92k. ADT 4.48 hrs, Bit 19.48 hrs, Jars 61.46 hrs. Concretions drilled at 9713'- 9716', 97261- 97481, 9770' - 9796', 9812' - 9815', 98241- 98341, 98591- 98761, 9900'- 9904', 9973'- 9974', and 101851- 101911. OA pressure at midnight = 345 psi Downhole losses for past 24 hours = 42 bbls 10/2/2017 10/2/2017 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 10,200.0 10,861.0 00:00 06:00 lateral in WestSak B sand from 10,200' to 10,861' MD, 3846' ND. Pump at 281 gpm, 2254 psi, 21% F/O, ECD 11.2 ppg, MW 9.25ppg. Rotate at 180 rom with 8k on-btm Tq, 7.5k off- trim Tq. 2k WOB. Max gas 296 units. PUW 126k, SOW 60k, ROT 93k. ADT 4.7 hrs, Bit 24.18 hrs, Jars 66.16 hrs. SPRs @ 10245' MD 3837' TVD, MW=9.20 ppg, 00:15 hours MP#1: 20 spm=580 psi, 30 spm=780 psi. MP #2: 20 spm=580 psi, 30 spm=800 psi. Concretions drilled at 10548' - 10552', 10567'- 10571', 10667'- 10674', 10680y- 10687', 10712'- 10716', and , 10723'-10727'. Page 55/79 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stad Time EndnM Our (h(hr)hase P Op Cate Activity Code Time P -T -X Operation start Depth (flK6) End Depth(fIKB) 10/2/2017 10/2/2017 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 10,861.0 11,582.0 06:00 12:00 lateral in WestSak B sand from 10,861' to 11,582' MD, 3875' TVD. Pump at 272 gpm, 2310 psi, 21 % F/O, ECD 11.58 ppg, MW 9.25 ppg. Rotate at 180 rpm with 8.5k on-btm Tq, 81k off -btm Tq. 2-5k WOB. Max gas 207 units. PUW 129k, SOW 55k, ROT 93k. ADT 3.94, Bit 28.12 hrs, Jars 70.1 his. Note: Crossed fault at 10971' with 20' throw. Concretions drilled at 11021'- 11027' and 11347'- 11353'. 10/2/2017 10/2/2017 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 11,582.0 12,360.0 12:00 18:00 lateral in WestSak B sand from 11,582'to 12,360' MD, 3855' TVD. Pump at 270 gpm, 2340 psi, 21% F/O, ECD 11.37 ppg, MW 9.2ppg. Rotate at 180 rp with 9k on-btm Tq, 7k off-btm Tq. 3-4k WOB. PUW 148k, unable to slack off after 12215' MD. ROT 89k. Max gas 180 units. ADT 4.68 hrs, Bit 32.8 hrs, Jars 75.78 hrs. SPRS @ 11673' MD 3868' TVD, MW=9.20 ppg, 12:26 hours MP#1: 20 spm=620 psi, 30 spm=840 psi. MP #2: 20 spm=610 psi, 30 spm=780 psi. Note: At -11,600' MD, observed formation losses increase to -15 bbl/hr and then fluctuate from 5-20 bbls/hr onward. Perforated dump/dilute at -11700'- still seeing issue with flow % and gas reading - continue troubleshooting. Concretions drilled at 11586'- 11592', 11848' -11864',12164- - 12173', 12260'- 12281', and 12284'- 12287'. Page 56179 ReportPrinted: 10/30/2017 r Operations Summary (with Timeiog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start 7me 10/212017 End Time 10/312017 Our 6.00 Phase PROD4 Op Code DRILL Activity Code DDRL Time P -T -x P Operation Stan Depth(M) (WB) End Depth (WS) 18:00 00:00 Directionally drill 6-3/4" production L3 12,360.0 12,964.0 lateral in WestSak B sand from 12,360'to 12,962' MD, 3871' TVD. Pump at 270 gpm, 2490 psi, 21% F/0, ECD 11.56 ppg, MW 9.2ppg. Rotate at 130 rpm with 9k on-btm Tq, 8k off-btm Tq. 3k WOB. PUW 154k, unable to slack off, ROT 107k. Max gas 310 units. ADT 3.83 hrs, Bit 36.63 hrs, Jars 78.61 hrs. OA pressure at midnight = 290 psi Downhole losses over past 24 hours = 139 bbls. Note: Rig isolated dump line to rockwasher and inspected line - observed the 8ft of level section of 16" dump line was -80% packed off with cement and mud material. Cleaned out line, reinstalled, and discussed future mitigations to ensure we will be able to sufficiently clean this level section of line after future cement jobs. Concretions drilled at 12759'- 12771' and 12800'- 12802'. 10/3/2017 00:00 10/3/2017 06:00 6.00 PRO54 DRILL DDRL P Directionally drill 6-3/4'Production L3 12,964.0 13,519.0 lateral in WestSak B sand from 12964' to 13519' MD, 3866' TVD. Pump at 272 gpm, 2645 psi, 21 % F/O, ECD 11.71 ppg, MW 9.2ppg. Rotate at 160 rpm with 9k Tq on-btm, 8k Tq off-btm. 2-5k WOB. PUW 164k, unable to slack off, ROT 1071k. Max gas 144 units. ADT 3.67 hrs, Bit 40.3 hrs, Jars 82.28 hrs. SPRs @ 13042' MD 3877' TVD, MW=9.20 ppg, 00:25 hours MP#1: 20 spm=690 psi, 30 spm=920 psi. MP #2: 20 spm=680 psi, 30 spm=910 psi. Concretions drilled at 13063'- 13075', 13232'- 13238', and 13320'- 13325'. 10/3/2017 06:00 10/3/2017 6.00 PROD4 DRILL DDRL P Directionally tldll 6-3/4" production L3 13,519.0 14,079.0 12:00 lateral in WestSak B sand from 13519' to 14079' MD, 3852' TVD. Pump at 272 gpm, 2735 psi, 21% F/O, ECD 11.97 ppg, MW 9.2 ppg. Rotate at 160 rpm with 9k Tq on-btm, 8k Tq off-btm. 3k WOB. PUW 168k, unable to slackoff, ROT 106k. Max gas 279 units. ADT 3.87 hrs, Bit 44.17 hrs, Jar 86.15 hrs. Concretions drilled at 13548' - 13553', 13686' - 13692', 13731'- 13739', 13750'- 13762', and 13771'- 13774'. Page 57/79 Report Printed: 10130/2017 Operations Summary (with Timeiog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time 10/3/2017 End Time 10/3/2017 Our (hr) 6.50 Phase PROD4 Op Code DRILL IA—y Cade DDRL Time P-T-X Op hon scan Oepth (ftKB) End Depth (llKB) 12:00 18:30 P Directionally drill 6-3/4" production L3 14,079.0 14,686.0 lateral in WestSak B sand from 14079' to TO of 14686' MD, 3844' TVD. Pump at 272 gpm, 2770 psi, 21 % F/O, ECD 11.86 ppg, MW 9.2 ppg. Rotate at 180 rpm with 9.5k Tq on-btm, 8k Tq off- _ btm. 3k WOS. Max gas 110 units. ADT 5.1 hrs, Bit 49.27 hrs, Jars 91.25 hrs. Note: Remained in WestSak B Sand zone 100% throughout the L3 lateral. SPRs @ 10245' MD 3837' TVD, MW=9.20 ppg, 00:15 hours MP#1: 20 spm=580 psi, 30 spm=780 psi. MP #2: 20 spm=580 psi, 30 spm=800 psi. Concretions drilled at 14079'- 14093', 14098'- 14103', 14115'- 14123', 14126' - 14129',14170' - 14177', 14201'- 14207', 14217' - 14222', 14335'- 14349', 14449'- 14450', 14466' - 14474', 14540'- 14562', and 14663'- 14668' 10/3/2017 10/3/2017 1.50 PROD4 CASING CIRC P Obtain final parameters, downlink 14,686.0 14,615.0 18:30 20:00 powerdnve to neutral, and circulate 1 x bottoms up with 270 gpm, 2760 psi, 20% F/O, 180 rpm, 8k Tq, MW 9.2ppg in / 9.3ppg out. ECD 11.8 ppg. Total of 4500 strokes pumped. PUW 184k, SOW 47k, ROT 117k. Note: After circulating bottoms up, we were able to slack off at -47k HL SPRs @ 10245' MD 3837' TVD, MW=9.20 ppg, 00:15 hours MP#1: 20 spm=580 psi, 30 spm=780 psi. MP #2: 20 spm=580 psi, 30 spm=800 psi. 10/3/2017 20:00 10/3/2017 0.50 PROD4 CASING OWFF P Monitor well for flow-observe fluid 14,615.0 14,615.0 20:30 level fall -4 it over 30 minutes. 10/3/2017 10/4/2017 3.50 PROD4 CASING BKRM P Backream out of hole from 14615'10 14,615.0 13,332.0 20:30 00:00 13332' MD with 270 gpm, 2520 psi, 21 % F/O, 180 rpm, 7k Tq, ECD 11.41 ppg, PUW 1601k, SOW 63k, ROT 115k Note: SOW = 53k at 14350' MD. OA pressure at midnight= 270 psi Downhole losses over past 24 hours = 182 bbls. 10/4/2017 10/4/2017 6.00 PROD4 CASING BKRM P Backream out of hole from 13336'to 13,332.0 10,540.0 00:00 06:00 10540' MD at 272 gpm, 2091 psi, 19% F/, ECD 10.81 ppg, 180 rpm, 6k Tq. PUW 118k, SOW 77k, ROT 93k. 10/4/2017 10/4/2017 5.50 PROD4 CASING BKRM IP Backream out of hole from 10540' to 10,540.0 7,980.0 06:00 11:30 7980' MD with 272 gpm, 1875 psi, 19% F/O, 180 rpm, 5k Tq, ROT 92k. Page 58179 Report Printed: 10/30/2017 Rig: DOYON 142 Operations Summary (with Timelog Depths) 1H-102 Inh- nPI11 Ird6` r%Dl/]IrdAI Time Leg Stanlmre End Time Mr (hr) Phase Op Cotle AcWhy Cotle Time P-T.X Operation Start (son End Depth (flKa) 10/4/2017 10/4/2017 0.75 PROD4 CASING TRIP P Trip out of hole on elevators from 7,980.0 7,593.0 11:30 12:15 7980'to 7593', observing no issues or drag pulling BHA through window. PUW 118k, SOW 85k 10/4/2017 10/4/2017 - 1.25 PROD4 CASING CIRC P Circulate bottoms up while 7,593.0 7,593.0 12:15 13:30 reciprocating from 7593' to 7503' with 270 gpm, 1815 psi, 20% F/O, 120 rpm, 3.3k Tq, ECD 10.25 ppg, MW in/out 9.2ppg. Total of 3905 strokes pumped. PUW 112k, SOW 86k. 10/4/2017 10/4/2017 0.50 PROD4 CASING OWFF P Mondor well for flow. Hold PJSM for 7,593.0 7,593.0 13:30 14:00 slip/cut drilling line. 10/4/2017 10/4/2017 1.50 PROD4 CASING §LPC P Slip/cut drilling line. Calibrate blocks 7,593.0 7,593.0 14:00 15:30 and service rig. T0-14/2017 10/42017 2.50 PROD4 CASING TRIP P7— Trip out of hole on elevators racking 7,593.0 306.0 15:305:30 18:00 back 4" DP from 7593'to 306', monitoring displacement via trip tank. 10/4/2017 10/4/2017 1.00 PROD4 CASING SHAH P Pull out of hole from 306' to surface, 306.0 0.0 18:00 19:00 laying down L3 RSS drilling BHA. Monitor displacement via trip tank.Stabilizers were in gauge and bit looked good with no damaged/wom teeth and was in gauge. Graded 0 -0 - NO -A -X -O -NO -TD. 10/4/2017 10/4/2017 0.50 PROD4 CASING BHAH P Clean antl clear Floor of BHA 0.0 0.0 19:00 19:30 equipment. 10/42017 10/4/2017 1.00 15OMPZ4 FISH BHAH P PJSM. Make up L-3 whipstock 0.0 229.0 19:30 20:30 retrieval BHA, scribe MWD, and RIH to 229' MO - 348.48° toolface offset obtained. Monitor displacement via trip tank. 10/4/2017 10/4/2017 1.00 C0MPZ4 FISH TRIP P Trip in hole on 4" DP from 229 to 229.0 2,120.0 20:30 21:30 2120' MD, monitoring displacement via trip tank. 10/4/2017 10/4/2017 0.25 C0MPZ4 FISH DHEQ P Fill pipe and shallow hole test MWD 2,120.0 2,120.0 21:30 21:45 with 250 gpm, 940 psi, 19% F/O - good test. 10/412017 10/5/2017 2.25 C0MPZ4 FISH TRIP P Trip in hole on 4" DP and 4" HWDP 2,120.0 7,637.0 21:45 00:00 from 2120' to 7637' MD, stopping to fill pipe at 5050' MD, monitoring displacement via trip tank. OA pressure at midnight = 0 psi. Downhole losses for past 24 hours = 95 bbls. Page 59/79 ReportPrinted. 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log seen Tres End Time Dur (hr) Phase Op Cade A;-ty Code Time P -T -X Operation Start Depth (RKB) End Depth(ftKB) 10/5/2017 10/5/2017 0.75 COMPZ4 FISH FISH P Make up 4" DP single on top of stand 7,637.0 7,647.0 00:00 00:45 #79, fill pipe, and obtain parameters. PUW 143k, SOW 109k with pumps off, PUW 138k and SOW 107k with pumps on at 251 gpm. Pump at 251 gpm, 1358 psi, 17% F/O and orient to 155° right. RIH and jet retrieval slot (retrieval slot 5.23' down from top of whipstock). Pick up above top of whipstock and orient to 22' left. RIH and set down 8k on bottom of retreival slot with hook right on depth. Pick up and confirm latched. Kill pump and startlarring to pull free. Increase jarring weight in stages from -40k overpulll. Observe whipstock pull free when jarring with 220k HL (77k overpull). Pick up and confirm whipstock free, PUW 143k. Observe fluid level drop to down blind rams, -25 ft. 10/5/2017 10/5/2017 1.50 COMPZ4 FISH CIRC P Lay down 4" DP single, kelly up to 7,647.0 7,647.0 00:45 02:15 stand #79 and circulate 2 x bottoms up at 251 gpm, 1330 psi. No gas observed at bottoms up. Total of 18 bbls required to fill hole after pulling whipstock. 10/5/2017 10/5/2017 0.25 COMPZ4 FISH TRIP P Drop 2.10" hollow drift on -100' of wire 7,647.0 02:15 02:30 on stand #79. Pull up and rack back .7,647.0 stand per Baker. 10/5/2017 10/5/2017 0.50 150MPZ4 FISH OWFF P Monitor well for flow -observe fluid 7,647.0 7,647.0 02:30 03:00 1level drop -2 ft. Service top drive. 10/5/2017 10/5/2017 4.50 COMPZ4 FISH TRIP P Trip out of hole racking back 4" HWDP 7,647.0 76.0 03:00 07:30 and 4" DP from 7647'to 76' at top of L3 whipstock, monitoring displacement via trip tank, stage up pulling speed to 80 fUmin max. 10/5/2017 10/5/2017 3.00 COMPZ4 FISH BHAH P Lay down L3 whipstock BHA per 76.0 0.0 07:30 10:30 Baker. Observe mill pattern extend past bottom of slide to bottom of whipstock (-tft). Clean and clear rig floor of whipstock BHA. 10/5/2017 10/5/2017 1.00 COMPZ4 WHDBOP RURD P Flush and drain stack, pull 0.0 0.0 10:30 11:30 wearbushing, and install test plug. Rig up 4-1/2" test joint and test assembly. Purge air out of lines with freshwater. Page 60179 Report Printed: 1013012017 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sa Fstl Time our (hr) Phase Op Cade Activity Cotle Time P -T -X I Operation Start Depth (W) EM Depth (f KB) 10/5/2017/2017 10/5/2017 4.00 COMPZ4 WHDBOP BOPE P Test ROPE with 4" and 4-1/2" test joint 0.0 0.0 11:30 15:30 to 250/3500 psi 5/5 min, witness waived by AOGCC rep Chuck Scheve. Test Sequence as follows: Install 4-1/2" test joint 1) Annular, Choke valves #1, 12, 13, & 14, 4" Kill, and 4" XT39 Dart valve. 2) Choke valves #9 and 11, Mezzanine Kill valve, and 4" XT39 FOSV. 3) Choke valves #8 and 10, and HCR Kill 4) Choke valves #6 and 7, Manual 1011, Upper IBOP 5) Manual and Super chokes (tested to 2000 psi) 6) Choke valves #2 and 5, and Lower IBOP 7) Lower 3-1/2" x 6" rams Remove test joint 8) Blind rams, Choke valves #3 and 4 Install 4" test joint 9) Annular and HCR choke 10) Manual choke 11) Lower 3-1/2" x 6" rams Perform koomey drawdown test: System Pressure = 2,950 psi PSI after closure = 1,750 psi 200 psi Attained with 2 x electric pumps = 8 seconds Full Pressure attained with 2 x electric and 2 x air pumps = 50 seconds N2 = 6 each @ 2,075 psi Tested all gas and H2S sensors, PVT and flow alarms both audio and visual, and functioned primary and remote BOP controls - all good. Upper 7-5/8" casing rams not tested. 10/5/2017 1015/2017 1.00 COMPZ4 WHDBOP RURD P Rig down and blow down test 0.0 0.0 15:30 16:30 equipment. Re -install wearbushing. 10/5/2017 10/62017 7.50 COMPZ4 CASING PUTB P PJSM. Make up bent shoe and run in 0.0 6,168.0 16:30 00:00 hole with 4-12" 11.6# L-80 IBTm slotted liner / 4-1/2" 12.6# L-80 TXPm blank liner per tally to 6168' MD, monitoring displacement via trip tank. MUT of IBTm = 4500 fl -lbs. MUT of the blank 12.6# L-80 TXPm joints = 7000 ft -lbs. Install 1 x 6-1/8" Volant thick-walled centralizer free-floating on each joint. PUW 87k, SOW 70k. OA pressure at midnight = 0 psi Downhole losses over past 24 hours = 74 bbls Page 61179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Suri Time End Time Dur(M) Phase Op Code Activity Code Time P -T-% Openatim Start Depth (fiKa) End Depth (WB) 10/6/2017 10/6/2017 1.50 COMPZ4 CASING PUTB P Run in hole with 4-1/2" 11.6# L-80 6,168.0 6,996.0 00:00 01:30 IBTm slotted liner/4-1/2" 12.6# L-80 TXPm blank liner per tally from 6168' to 6996' MD, monitoring displacement via trip tank. MUT of IBTm = 4500 ft - lbs. MUT of the blank 12.6# L-80 TXPm joints = 7000 ft -lbs. Install 1 x 6- 1/8" Volant thick-walled centralizer free-floating on each joint. Pick up 1 x Baker 6" OD swell packer (2.67' element) with centralizer above and below. PUW 95k, SOW 72k. 10/6/2017 10/6/2017 1.00 COMPZ4 CASING OTHR P Pick up MWD collar and install 6,996.0 .7,030.0 01:30 02:30 Slimpulse tool. Pick up Baker B-3 Flanged Hook hanger and M/U per Baker. Scribe MWD to 180° off from hook, toolface offset = 303.55°. Run in hole to from 6996'tp 7030' MD. 10/6/2017 10/6/2017 0.25 COMPZ4 CASING RUNL P Run 1-3 lower completion in hole on 4" 7,030.0 7,600.0 02:30 02:45 DP stands from derrick from 7030' to 7600' MD, monitoring displacement via trip tank. 10/6/2017 10/6/2017 0.25 COMPZ4 CASING DHEQ P Circulate through running tools and 7,600.0 7,600.0 02:45 03:00 shallow hole test MWD tool with 90 gpm, 260 psi, 11 % F/O - good test. 10/6/2017 10/6/2017 4.00 COMPZ4 CASING RUNL P Run 1-3 lower completion in hole on 4" 7,600.0 14,622.0 03:00 07:00 DP / 4" HWDP stands from derrick from 7600'tc 14622' MD, monitoring displacement via trip tank and allowing pipe to self -fill. No issues running through window with bent shoe. 10/6/2017 10/6/2017 1.00 COMPZ4 CASING RUNL P Orient to 160° right with 92 gpm, 540 14,622.0 14,668.0 07:00 08:00 psi, PUW 166k, SOW 92k. Run in hole to 14668' MD, no drag observed. Pick up above window, orient to 25° left, run in and engage hook on window at 14667.74' MD (3.31' deep to plan), set down 20k weight. Observe orientation roll to 8° left. Pick up —25 ft, run in and re-engage hook on window at same depth, set down 201k. Confirm orientation at 8° left. 10/6/2017 10/6/2017 0.75 COMPZ4 CASING CIRC P Drop 29/32" phenolic ball and pump 14,668.0 7,644.0 08:00 08:45 down at 127 gpm, 825 psi, 12% F/O for 300 strokes, then 86 gpm, 500 psi, 9% F/O for 200 strokes, then 64 gpm, 375 psi, 8% F/O for 100 strokes, then 43 gpm, 276 psi, 4% F/O to seat ball - seat at 635 strokes. Pressure up to 3500 psi to release from hook hanger and hold for 1 minute. Continue pressuring up to shear out ball seat, observe shear at 4270 psi (pinned for 4000 psi). Pick up and confirm released from hook hanger with PUW 143k. Confirm circulation with 85 gpm, 300 psi, 8% F/O. Top of hook hanger at 7644.62' MD. Page 62/79 Report Printed: 10/30/2017 AddrML Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log $Intl Tvne Entl Time our (hr) phase Op Code Atlnaty Code Time P -T -X Operation SW Depth (WB) End Depth (111(8) 10/6/2017 10/6/2017 0.25 COMPZ4 WELLPR OWFF P Monitor well for flow and confirm 7,644.0 7,644.0 08:45 09:00 static. 10/6/2017 10/6/2017 2.50 COMPZ4 WELLPR TRIP P Trip OOH on elevators from —7644' to 7,644.0 0.0 09:00 11:30 surface, racking back 4" HWDP and 4" DP, monitoring displacement via trip tank. 10/6/2017 10/6/2017 0.50 COMPZ4 WELLPR BHAH P Lay down SLB Slimpulse MWD and 0.0 0.0 11:30 12:00 Baker running tools. 10/6/2017 10/6/2017 0.50 COMPZ4 WELLPR BHAH P Clean and clear rig floor of running 0.0 0.0 12:00 12:30 tools. 10/6/2017 10/6/2017 1.50 COMPZ4 RWRID RURD P Rig up GBR torque turn and casing 0.0 0.0 12:30 14:00 equipment for running LEM. 10/6/2017 10/6/2017 2.50 COMPZ4 RWRID PUTB -F— PJSM. Make up LEM I ZXP assembly 0.0 328.0 14:00 16:30 for L3 lateral with SLB Slim Pulse installed. GBR utilize torque tum while making up TXP connections to 7000 ft -lbs, no issues observed. Scribe MWD offset to 92'. Had issue stinging in seal assembly but eventually got it installed. Make up 2 x Baker magnets and XO and RIH to 328' MD. 10/6/2017 10/6/2017 0.50 COMPZ4 RWRID CIRCP Run in hole on 1 x stand 4" DP to 420' 420.0 420.0 16:30 17:00 MD and circulate through LEM assembly at 30 gpm, 180 psi, no issues observed. Blow down topdrive. 10/6/2017 10/6/2017 1.00 COMPZ4 RWWRID RCST P Run in hole with L3 LEM / ZXP 420.0 1,741.0 17:00 18:00 assembly on 4" DP from 420'to 1741' MD, monitoring displacement via trip tank. W WT inspect and adjust super sliders as needed. 10/6/2017 10/6/2017 1.00 COMPZ4 RWRID DHEQ P Shallow hole testMWD tool. Increase 1,741.0 1,741.0 18:00 19:00 flow from 90 gpm up to 120 gpm, cycling pumps twice, and observe tool tum on. Confirm setting for gravity toolface - all good. 10/6/2017 10/6/2017 4.25 COMPZ4 RWRID RCST P Run in hole with L3 LEM / ZXP 1,741.0 7,638.0 19:00 23:15 assembly on 4" DP and 4" HWDP from 1741' to 7638' MD, monitoring displacement via trip tank. W WT inspect and adjust super sliders as needed. Calculated displacement = 58 bbls, Actual displacement = 44.8 bbls. Note: Total of 10 x SS sleeves replaced and 22 x SS sleeves flipped to distribute wear. No stop collars needed to be replaced. 10/6/2017 10/6/2017 0.50 COMPZ4 RWRID CIRC P Kelly up and establish circulation at 7,638.0 7,638.0 23:15 23:45 107 gpm, 838 psi, 11% F/O. Increase rate to 120 gpm, 974 psi, 12% F/O with no sign of signal to MWD - cycle pumps and increase rate to 132 gpm, 1024 psi, 12% F/O and observe pressure drop to 800 psi and tool start transmitting signal. Page 63179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) Fle 1H-102 Conoc(�Philllipsl Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slut Tme End Time D. (hr) Phase Op Code Achwty Code Time P -T -X Operation Start Depth (ftKB) End Depth(ftKS) 10/6/2017 10/7/2017 0.25 COMPZ4 RWRID RCST P Orient LEM to 80° left with 132 gpm, 7,638.0 7,735.0 23:45 00:00 806 psi, 12% F/O and RIH to 7735' MD (stand #79 buried). No issues running muleshoe through hook hanger. Make up 4" DP single, Kelly up, establish circulation at 127 gpm, 770 psi, 12% F/0. OA pressure at midnight = 0 psi Downhole losses for past 24 hours = 53 bbls 10/7/2017 1017/2017 0.50 COMPZ4 RWRID PACK P RIH from 7735' and observe seals 7,735.0 7,753.1 00:00 00:30 tagging up on top of L2 seal bore extension at 7738' MD- work seals in SBE down @ 127 gpm, 760 psi, 12% F/0, setting down max of 15k weight. Once seals worked in and moving down, observe -6k seal drag through SBE. Latch LEM into hook hanger on depth @ 7644.62' MD, set down 15K, observed tool face roll from 80 Deg L to 28 Deg L. Pick up 10K over. Set down 20K then pulled 15K over to confirm LEM latched into hook hanger, good. Tool face still @ 28 deg L. 10!712017 10/7/2017 0.50 00MPZ4 RWRID PACK P Set ZXP liner top packer, drop 15/8" 7,753.1 7,753.1 00:30 01:00 frac ball and pump down 3 bpm= 770 psi, slow down to 1.5 bpm=355 psi. Ball on seat @ 55 bbls away, pressure up to set packer. Observed packer set @ 2300 psi, cont to pressure up to 4000 psi to release. 10/72017 10/7/2017 0.50 COMPZ4 RWRID PRTS P P/U 3' @ 143K P/U, close annular 7,753.1 7,751.0 01:00 01:30 preventer and pressure test ZXP liner top packer to 3500 psi f/ 10 min on chart, good. 10/7/2017 1017/2017 0.75 60MPZ4 RWRID CRIH P Spot corrosion inhibited brine f/ 7751' 7,751.0 7,639.0 01:30 02:15 MD to 7639' MD( talc TOW @ 7376' MD) Pumped 25 bbls of Cl brine followed by 73 bbls of drilling mud, pumped @ 255 gpm=870 psi. 10/7/2017 10/7/2017 0.50 COMPZ4 RWRID OWFF P OWFF f/ 30 min, static to 2" below, 7,639.0 7,639.0 02:15 02:45 flowline. 10/72017 10/7/2017 2.50 50MPZ4 RWRID TRIP P POOH on elevators -f/7639 MD to 7,639.0 0.0 02:45 05:15 surface. Calculated displacement= 52.8 bbls, Actual displacement= 57.5 bbls. (4.7 bbl loss) 10!712017 1.00 COMPZ4 RWRID BHAH P LID Baker running tools and SLB 0.0 0.0 r06:15 06:15 MWD. 1017/2017 1.50 PRODS WHPST BHAH P Mobilize L4 whipstock BHA to rig floor. 0.0 0.0 07:45 Page 64179 Report Printed: 1 0/3 012 01 7 Operations Summary (with Timelog Depths) 1H-102 Li- : DOYON 142 Job: DRILLING ORIGINAL err(hr) Phase Op Cotla Activity Cade Time P -T -X Operation Slart Depth (UB) ErM Depth (IMa) 3.00 PROD5 WHPST SHAH P FUSM. M/U Milling BHA as per Baker. 0.0 319.0 07:45 10:45 M/U window mill, lower and upper mills, 1 HWDP, XO, float sub and SLB slimpulse. Scribe MWD to window mill, 187 Deg tool face offset. Stand milling easy back in derrick. P/U Baker Whipstock and built anchor assy below as per BHA order. M/U milling easy to whipstock easy as per tally w/ 25K shear bolt. Verified 3 screws installed in Anchor for shear rating of 10,500K. Confirmed shipping bolt is removed from anchor. RIH to 319'. 10/7/2017 10/7/2017 0.75 PROD5 WHPST TRIP P Trip in hole on 4" DP stands from 319' 319.0 1,350.0 10:45 11:30 to 1350' MD, running speed of 60 ft/min, monitoring displacement via trip tank. 10/7/2017 10/7/2017 0.25 PROD5 WHPST DHEO P Shallow hole test MWD toolwith 205 1,350.0 1,350.0 11:30 11:45 gpm, 490 psi, 15% F/O - good test. Blow down top drive. 10/7/2017 10/712017 4.25 PROD5 WHPST TRIP P7 Tdp in hale on 4" DP / 4"HWDP 1,350.0 7,360.0 11:45 16:00 stands from 135V to 7360' MD, running speed of 60 ft/min, monitoring displacement via trip tank. Calculated , displacement = 49.6 bbls, Actual displacement = 45.5 bbls (4.1 bbl loss) 10/7/2017 10/7/2017 1.25 PROD5 WHPSTWPST P Kelly up on stand #76. Establish 7,360.0 7,360.0 16:00 17:15 circulation and stage pumps up to 282 gpm, 1480 psi, 18% F/O until signal obtained with ShmPulse. Orient whipstock to 23° left. PUW 136k, SOW 108k 10/7/2017 10/7/2017 0.50 PROD5 WHPST WPST P Wash down from 7360' to 7453'. Kelly 7,360.0 7,377.0 17:15 17:45 up on stand #77, wash down at 179 gpm, 880 psi, 15% F/O and tag L3 liner top with No -Go at 7461.18' MD (0.76' deep, -amount that pusher tool compresses LTP). Confirm orientation at 23° left, kill pump, set down 10k weight, observing good indication of anchor shear at 81k down. Pick up to 146k HL (10k overpull) and confirm anchor set. Shear bolt with 32k set down weight. Pick up and confirm free With PUW 140k. Top of window Q 7377.00' MD Btm of window @ 7390.60' MD Page 65/79 Report Printed: 10/30/2017 - Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End7m �r(.2 Phase Code ActivityCoda Time P -TX Operation Start Depth (11Ka) End Depth ftKa) 10/712017 10/8/2017 6.25 PRODS IP WHPST MILL P Establish parameters with 282 gpm, 7,377.0 7,394.0 17:45 00:00 1509 psi, 19% F/O, 80 rpm, 3.5k Tq. Mill window per Baker from 7377' to 7394' MD with 282 gpm, 1560 psi, 20% F/0, 100 rpm, 3-5k Tq, 1-3k WOB. PUW 131k, SOW 108k, ROT 111 k. Pump super sweeps every 5' per Baker, observing moderate increase of metal cuttings over shakers at bottoms up. OA pressure at midnight = 0 psi Downhole losses for past 24 hous = 9 bbls 10/8/2017 10/8/2017 4.50 PRODS WHPST MILL P Mill L4 window from 7394' to 7412' MD 7,394.0 7,412.0 00:00 04:30 with 282 gpm, 1620 psi, 20% NO, 100 rpm, 3-5k Tq, 2-8k WOB, PUW 131 it, SOW 108k ROT 111 k. Pump super sweep at TD. Top of window @ 7377.00' MD Btm of window Q 7390.60' MD —5' of gauge hole @ 7396' MD Ralhole to 7412' MD 10/8/2017. 10/8/2017 0.75 PRODS WHPST REAM P Circulate sweep around to surface and 7,412.0 7,348.0 04:30 05:15 work mills through window with 282 gpm, 1630 psi, 22% F/O, 100 rpm, 3k Tq. Observed moderate increase in metal cuttings at surface as sweep came around. Kill rotary and drop rate to 1 bpm, 430 psi, 3% F/O. Trip through window with no issues, observed 0-1k drag. PUW 135k, SOW 109k. Pull up above window to 7348' MD. 10/8/2017 10/8/2017 0.50 PRODS WHPST CIRC P Circulate at 255 gpm, 1371 psi, 19% 7,348.0 7,348.0 05:15 05:45 F/O and confirm MW 9.2 ppg in/out. 10/8/2017 10/8/2017 0.50 PRODS WHPST FIT P Rig up and perform FIT for L4 window 7,348.0 7,348.0 05:45 06:15 to 13.0 ppg EMW (3737.9' ND) using 9.2ppg FloPro. Close annular, pump down drill pipe and IA with mud pump #1. Pressure up to 739 psi and shut in, observe pressure drop to 590 psi after 10 minutes. Pumped 1.4 bbls, returned 1.0 bbls. Blowdown lines. 10/8/2017 10/8/2017 0.50 PRODS WHPST OWFF P Monitor well for flow - well static. 7,348.0 7,348.0 06:15 06:45 10/8/2017 10/8/2017 0.25 PRODS WHPST TRIP P Trip OOH from 7348'to 6810' MD, 7,348.0 6,810.0 06:45 07:00 1 monitoring displacement via trip tank. 10/8/2017 10/8/2017 0.25 PRODS WHPST CIRC P Pump dry job. 6,810.0 6,810.0 07:00 07:15 10/8/2017 1D/8/2017 2.25 PRODS WHPST TRIP P Trip OOH from 6810' to 232' MD, 6,810.0 232.0 07:15 09:30 racking back 4" HWDP and 4" DP, monitoring displacement via trip tank. Page 66179 Report Printed: 1 013 0/2 01 7 Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sait'rune End Time our M PhaseOp Code Activity Code Time P -T -X Operation Start Depth (MI®) EM Depth M(B) 10/8/2017 10/8/2017 1.50 PR0D5 WHPST BHAH P Lay down L4 milling BHA and clean off 232.0 0.0 09:30 11:00 magnets. Observe pockets on each magnet full with metal cuttings. Gauge mills. Upper 6-3/4" Mill - In Gauge Lower 6-5/8" Mill - 1/4" undergauge ' Window 6-3/4" Mill - 3/8" undergauge 10/8/2017 10/8/2017 0.50 PROD5 WHPST WWWH P Make up stackwasher and jetstack. 0.0 0.0 11:00 11:30 SIMOPS - Clean and clear dg Floor of BHA components. 10/8/2017 10/8/2017 0.50 PROD5 WHPST SVRG P Service rig. Grease blocks, crown, 0.0 0.0 11:30 12:00 topdrive, and washpipe. 10/812017 10/8/2017 3.00 PROD5 WHPST BHAH P PU M. Prep rig floor and pipeshed for 0.0 897.0 12:00 15:00 BHA and confirm tally. Make up Motor BHA per SLB to 897' MD, monitoring displacement via trip tank. Re -run 6- 3/4" Smith Milltcoth bit. Run new 1.5° mud motor. MWD scribed to 182° toolface offset. 10/8/2017 10/812017 0.25 PRODS WHPST TRIP P Trip in hole from 897'to 1840' MD, 897.0 1,840.0 15:00 15:15 monitoring displacement via trip tank. 10/8/2017 10/8/2017 0.75 PRODS WHPST DHEA P Shallow hole test MWD with 209 gpm, 1,840.0 1,840.0 15:15 16:00 782 psi, 18% F/O - good test. Blowdown tap drive. 10/8/2017 10/8/2017 3.00 PROD5 WHPST TRIP P Tdp in hole from 1840'to 7244' MID 1,840.0 7,244.0 16:00 19:00 monitoring displacement via trip tank, filling pipe every 20 x stands. PUW 116k, SOW 86k. 10/8/2017 10/8/2017 0.50 PROD5 WHPST CIRC P Fill pipe and orient motor to 10° left 7,244.0 7,300.0 19:00 19:30 with gpm, 7356 psi, 18% F/O. T0_1812017 10/8/2017 0.25 PROD5 WHPST TRIP P in h 00' Trip in hole from 73to 7412' MD, 7,300.0 7,412.0 19:309:30 19:45 SOW 85k. No drag observed while running bit across window. Started seeing 1-7k drag after 7396' (end of gauge hole) and continued tripping to 7412', tagging up with 1 O weight. Page 67179 ReportPrinted: 10/30/2017 Operations Summary (with Timelog Depths) I: 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sad Time End Time our (hr) Phase Op Code Activity Code Time P-T-XOperation Start Depth (ftKB) End DePN(ftKe) 10/8/2017 10/9/2017 4.25 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 7,412.0 7,524.0 19:45 0000 from 7412' to 7524' MD, 3815' TVD. - Pump at 231 gpm, 1442 psi on-btm, 1383 psi off-btm, 17% F/O. Rotate at 40 rpm with 3-4k Tq on-btm, 3k Tq off- btm. 3-18k WOB. PUW 116k, SOW 82k, ROT 92k. AST 2.29 hrs, ADT 2.8 hrs, Bit 12.59 hrs, Jars 94.05 hrs. Displace milling fluid out of well with new/used 9.2 ppg FloPro at 7477' MD. Concretions drilled from 7412' - 7419', 7428'- 7432', 7434'- 7440', and 7450' to 7453'. Utilize rig's twister system to help transfer weight down to bit when sliding through concretions. SPRs @ 7430' MD 3750' TVD, MW=9.25 ppg, 21:30 hours MP#1: 20 spm=550 psi, 30 spm=720 psi. MP #2:20 spm=550 psi, 30 spm=720 psi. OA pressure at midnight = 0 psi Downhole losses for past 24 hours = 2 bbls 10/9/2017 10/9/2017 2.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 7,524.0 7,650.0 00:00 02:00 from 7524' MD to TO of 7650' MD, 3815' TVD. Pump at 231 gpm, 1352 psi on-btm, 1270 psi off-btm, 17% F/O. Rotate at 40 rpm with 3-4k Tq on- btm, 3k Tq off-btm. 3-18k WOB. PUW 116k, SOW 82k, ROT 93k. AST .86 hrs, ADT 1.09 hrs, Total Bit 13.68 hrs, Jars 95.16 hrs.. SPRs Q 7524' MD 3815' TVD, MW=9.2 ppg, 00:18 hours MP#1: 20 spm=380 psi, 30 spm=540 psi. MP #2:20 spm=380 psi, 30 spm=540 psi. 10/912017 10/9/2017 0.50 PROD5 DRILL BKRM P Backream OOH f/ 7650' MD to 7525' 7,650.0 7,525.0 02:00 02:30 MD, Rotate@ 40 rpm's w/ 3 K Tq, pump @ 230 gpm= 1270 psi, ROT= 96K. 1019/2017 10/912017 0.25 PROD5 DRILL CIRC P Orient motor to 20 deg L @ 7525' MD, 7,525.0 7,525.0 02:30 02:45 before BHA enters the slide. 10/9/2017 10/9!2017 0.25 PR555 DRILL OWFF P OWFF, static. 7,525.0 7,525.0 02:45 03:00 10/9/2017 10/9/2017 0.50 PROD5 DRILL TRIP P POOH on elevators f/ 7525' MD to 7,525.0 7,146.0 03:00 03:30 7146' MD, Observed 12K overpull 7445' MD, slack off and work back though. Pulled up through w/ 3-5k drag. No overpull observed when pulling bit through window. Page 68/79 Report Printed: 10130120171 Rig: DOYON 142 Operations Summary (with Timelog Depths) 1H-102 n6• nMII I ILI^ ^MI^ILI AI Time Log Ln�la.�rnv vnloln.,� StartTime 10/9/2017 End Tune 10/9/2017 Our (hr) 4.50 Phase PROD5 Op Code Actmt Code Y Time P -T -x Operation Start Oepih (7,1 End Depth 03:30 08:00 DRILL TRIP P Pull OOH on elevators from 7146'to 7,146.0 7.0 897.0 897', monitoring displacement via trip tank. Rack back 4" DP stands with good hardbanding and lay down 19 x stands containing joints with worn hardbanding. Calculated displacement = 42 bbls, Actual displacement = 44.5 bbls. 10/9/2017 10/9/2017 1.50 PROD5 TR—ILL—ETH—AH P Confirm well static. PJSM. Pull OOH 897.0 0.0 08:00 09:30 laying down Motor BHA, cleaning off magnets. Observe pockets –1/2 full with metal cuttings. Bit was in good shape and in gauge. Graded 0 -0 -NO - A -X -0 -NO -BHA. Monitor displacement via trip tank. 10/9/2017 10/9/2017 0.50 PROD5 DRILL W W WH P Make up stackwasEet stack. 0.0 0.0 09:30 10:00 UD same. 10/9/2017 10/92017 1.00 PRODS DRILL BHAH P PJSM. Make up L4lling BHA 0.0 307.0 10:00 11:00per SLB to 307'Mringdisplacement via t 11:00 17 11:00 10/9/2017 0.75 PROD5 DRILL PULD P Run in hole on 4" DP singles from pipe 307.0 1,254.0 11:45 shed from 307'to 1254' MD, monitoring displacement via trip tank. 10/9/2017 11:45 10/9/2017 0.50 PROD5 DRILL DHEQ P Shallow hole test MWD with 210 gpm, 1,254.0 1,254.0 12:15 755 psi, 16% F/O - good test. Blow down top drive. 10/92017 12:15 10/9/2017 0.75 PROD5 DRILL PULD P Run in hole on 4"13P singles from pipe 1,254.0 2,106.0 13:00 shed from 1254' to 2106' MD, monitoring displacement via trip tank. Note: Total of 57 joints picked up to replace the stands layed down due to worn hardbanding. 1 77 13:00 10/9/2017 2.75 FRO—D55 DRILL TRIP V- Trip in hole on 4" DP from 2106'to 2,106.0 7,210.0 15:45 7210' MD, monitoring displacement via trip tank, filling pipe every 20 x stands. PUW 11 Ok, SOW 81k T0-1912017 15:455:45 10/9/2017 1.25 PROD5 DRILL SLPC P Slip and cut 58' of drill line. Calibrate 7,210.0 7,210.0 17:00 blocks. Monitor well via hole fill. 10/9/2017 17:00 10/9/2017 0.25 PROD5 DRILL TRIP P Trip in hole on 4" DP from 7210'—to 7,210.0 7,400.0 17:15 7400' MD, monitoring displacement via trip tank. No drag observed tripping bit across window. PUW 114k, SOW 83k. Calculated displacement = 53 bbls, Actual displacement = 53.6 bbls. 10/9/2017 10/92017 0.25 POD5 CIRC P Fill pipe and obtain slaw pump rates.;7,400 17:15 17:30 SPRs @ 7400' MD 3744' TVD, MW=9.2 ppg, 17:15 hours MP#1: 20 spm=400 psi, 30 spm=580 psi. MP #2:20 spm=390 psi, 30 spm=570 pSt. 10/9/2017 10/9/2017 17:30 1.75 PROD5 URILL P Perform MAD pass from 7400'to 19:15 7650' MD at 300 ft/hr with 200 gpm, 1000 psi, 14% F/O. Stop and shoot surveys per DD. Observe 1-6 k drag while washing down. Page 69179 Report Primed 1 013 012 01 7 Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Terse 10/9/2017 End Time 10/10/2017 Our (M) 4.75 Phase ROD5 Op Code DRILL Activity Cotle DDRL Time P -T -X Operation SWDepM (I B End Oepm (flKB) 19:15 00:00 P Directionally drill 6-3/4" L4 "D" lateral 7,650.0 7,976.0 from 7650'to 7976' MD, 3759' TVD. Pump at 272 gpm, 1748 psi, 21% F/O, ECD 10.31 ppg, MW 9.2 ppg. Rotate at 140 rpm with 3-5k Tq on-btm, 2k Tq off-btm. 3k WOB. PUW 109k, SOW 81 k, ROT 94k. Max gas 87 units. ADT 3.8 hrs, Bit 3.8 hrs, Jars 98.96 hrs. OA pressure at midnight = 0 psi Downhole losses for past 24 hours = 3 bbls. 10/10/2017 00:00 10/10/2017 6.00 PR005 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 7,976.0 8,338.0 06:00 from 7976'to 8338' MD, 3751' TVD. Pump at 272 gpm, 1820 psi, 21 % F/O, ECD 10.50 ppg, MW 9.2+ ppg, Rotate at 140 rpm with 3-6k Tq on-btm, 3k Tq off-btm. 3k WOB. PUW 11 Ok, SOW 76k, ROT 92k. Max gas 105 units. ADT 4.98 hrs, Bit 8.78 hrs, Jars 103.94 hrs. SPRs @ 7976' MD 3744' TVD, MW=9.2 ppg, 00:30 hours MP#1: 20 spm=370 psi, 30 spm=550 psi. MP #2: 20 spm=380 psi, 30 spm=510 psi. 10/10/2017 06:00 10116/2017 12:00 6.00 PRODS DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 8,338.0 8,650.0 from 8338'to 8650' MD, 3753' TVD. Pump at 275 gpm, 1885 psi, 21 % F/O, ECD 10.58 ppg, MW 9.2+ ppg, Rotate at 120-140 rpm with 3£k Tq on-btm, 4k Tq off-btm. 3-7k WOB. PUW 112k, SOW 73k, ROT 89k. Max gas 391 units. ADT 4.8 hrs, Bit 13.58 hrs, Jars 108.74 hrs. TM 0/ 0017 12:00 10/10/2017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 8,650.0 9,265.0 18:00 from 8650' MD, 3753' TVD - 6,265' MD 3,763' TVD. Pump at 275 gpm, 1905 psi, 20% F/O, ECD 10.58 ppg, MW 9.3 ppg. Rotate at 150 rpm with 5 -6k TO on-btm, 5k TO off-btm. 1-10k WOB. PUW 118k, SOW 71 k, ROT 93K. Max gas 425 units. ADT 5.9 hrs, Bit 18.13 hrs, Jars 113.29 hrs. SPRs @ 7,728' MD 3,753' TVD, MW=9.3 ppg, 13:30 hours MP#1: 20 spm=460 psi, 30-spm=650 psi. MP #2: 20 spm=460 psi, 30 spm=640 psi. Page 70179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Lag Stad Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (f Ka) End Depth (RKin 10/10/2017 10/11/2017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 9,265.0 9,653.0 18:00 00:00 from 6,265' MD 3,763' TVD - 9,653' MD 3,774' TVD. Pump at 275 gpm, 1,896 psi, 21 % F/O, ECD 10.61 ppg, MW 9.3 ppg. Rotate at 150 rpm with 6k TQ on-btm, 5k TQ off-btm. 1-51K WOB. UP WT= 117K, DWN WT= 72K, ROT 93K. Max gas 303 units. ADT 4.7 hrs, Bit 22.83 hrs, Jars 117.99 hrs. 10/11/2017 10/11/2017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 9,653.0 9,850.0 00:00 06:00 from 9,653' MD 3,774' TVD - 9,850' MD 3,777' TVD . Pump at 275 gpm, 1,896 psi, 21 % F/0, ECD 10.61 ppg, MW 9.3 ppg. Rotate at 150 rpm with 6k TO on-btm, 5k TO off-btm. 1-51K WOB. UP WT = 117K, DWN WT = 72K, ROT 93K. Max gas 303 units. ADT 4.7 hrs, Bit 22.83 hrs, Jars 117.99 hrs. SPRs @ 9,681" MD 3,775' TVD, MW=9.2+ppg, 01:30 hours MP#1: 20 spm=390 psi, 30 spm=580 psi. MP #2: 20 spm=400 psi, 30 spm=580 psi. 10/11/2017 10/11/2017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 9,850.0 10,065.0 06:00 12:00 from 9,850' MD 3,777' TVD - 10,065' MD 3,777' TVD . Pump at 277 gpm, 1,948 psi, 21 % 17/0, ECD 10.52 ppg, MW 9.2+ ppg. Rotate at 120 rpm with 6k TO on-btm, 5k TO off-btm. 1-5K WOB. UP WT = 119K, DWN WT = 70K, ROT 92K. Max gas 44 units. ADT 4.19 hrs, Bit 26.75 hrs, Jars 126.91 hrs. 10/11/2017 10/11/2017 6.00 PROD5 DRILL DDRL P Directionally drill -6-3/4" L4 "D" lateral 10,065.0 10,537.0 12:00 18:00 from 9,850' MD 10,065' MD 3,777' TVD - 10,537' MD 3,780' TVD . Pump at 272 gpm, 1,990 psi, 21% F/0, ECD 10.52 ppg, MW 9.2+ ppg, Rotate at 120 rpm with 7K TO on-btm, 61K TO off -btm. 2K WOB. UP WT = 122K, DWN WT = 68K, ROT 93K. Max gas 259 units. ADT 4.48 hrs, Bit 36.23 hrs, Jars 131.39 hrs. SPRs @ 10,156"' MD 3,771' TVD, MW=9.2+ppg, 13:15 hours MP#1: 20 spm=460 psi, 30 spm=660 psi. MP #2: 20 spm=440 psi, 30 spm=590 psi Page 71/79 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Time 10/11/2017 End Time 10/12/2017 our (hr) 6.00 Phase PROD5 Op Code DRILL Activity Code DDRL Time P -T -X Operation start Depth (Wia) Em! Depth (ftl(a) 18:00 00:00 P Directionally drill 6-3/4" 1-4 "D" late'ral 10,537.0 10,792.0 from 10,537' MD 3,780' TVD - 10,792' MD 3,790' TVD . Pump at 272 gpm, 2.013 psi, 21% F/O, ECD 10.52 ppg, MW 9.2+ ppg, Rotate at 120 rpm with 7K TQ on-btm, 5K TQ off-btm. 2-5K WOB. UP WT = 123K, DWN WT = 67K, ROT 94K. Max gas 185 units. ADT 5.21 hrs, Bit 41.44 hrs, Jars 136.6 hrs. 10/12/2617 00:00 10/1272017 6.00 PROW UPILL P Directionally drill6-3/4" L4 "D" lateral 10,792.0 10,980.0 06:00 fmm10,792' MD 3,790' TVD - 10,980' MD 3,791' TVD. Pump at 272 gpm, 2.050 psi, 21 % F/O, ECD 10.92 ppg, MW 9.2+ ppg, Rotate at 120 rpm with 7K TQ on-btm, 6K TQ off-btm. 1,993 PSI off BTM 2-5K WOB. UP WT = 128K, DWN WT = 55K, ROT 94K. Max gas 66 units. ADT 5.43 hrs, Bit 46.87 hrs, Jars 142.03 hrs. SPRs @ 10,820"' MD 3,792' TVD, MW=9.2+ppg, 00:30 hours MP#1: 20 spm=500 psi, 30 spm=700 psi. MP #2: 20 spm=510 psi, 30 spm=680 psi 10/12/2017 06:00 10/12/2017 12:00 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4'L4"D"lateral 10,980.0 11,535.0 from10,980' MO 3,791' TVD - 11,535' MD 3,802' ND. Pump at 272 gpm, 2.200 psi, 21 % F/O, ECD 11.7 ppg, MW 9.2+ ppg, Rotate at 120 rpm with 8K TQ on-btm, 6K TQ off-btm. 2,150 PSI off BTM 2-5K WOB. UP WT = 126K, DWN WT= 59K, ROT 96K. Max gas 53 units. ADT 4.55 hrs, Bit 51.42 hrs, Jars 146.58 hrs. 10/12/2017 12:00 10/12/2017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 11,535.0 12,249.0 18:00 from11,535' MD 3,802' TVD - 12,249' MD 3,789' TVD. Pump at 272 gpm, 2.398 psi, 21 % F/O, ECD 1146 ppg, MW 9.2+ ppg, Rotate at 110 rpm with 8K TQ on-btm, 7K TQ off-btm. 2,390 PSI off BTM 1-2K WOB. UP WT = 137K, DWN WT= 52K, ROT 92K. Max gas 261 units. ADT 4.61 hrs, Bit 56.03 hrs, Jars 151.19 hrs. SPRs @ 11,577"' MD 3,802' TVD, MW=9.4+ ppg, 12:30 hours MP#1: 20 spm=600 psi, 30 spm=810 psi. MP #2: 20 spm=600 psi, 30 spm=820 psi Page 72/79 Report Printed: 10130/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time 10/12/2017 End Tune 10/13/2017 Dur(hr) 6.00 Phase 1R005 Op Code DRILL Ac ffy Code DDRL Time P-T-X Opemeon sten Depth (ftKB) End Depth(ftKS) 18:00 00:00 P Directionally drill 6-3/4" L4 "D" lateral 12,249.0 12,503.0 from 12,249' MD 3,789' TVD - 12,503 MD 3,789' TVD. Pump at 272 gpm, 2.390 psi, 21% F/O, ECD 11.41 ppg, MW 9.2+ ppg, Rotate at 120 rpm with 9K TQ on-btm, 8K TQ off-btm. 2,380 PSI off BTM 2-5K WOB. UP WT = 139K, DWN WT = 52K, ROT 94K. Max gas 261 units. ADT 4.91 hrs, Bit 60.94 hrs, Jars 156.1 hrs. 10/13/2017 00:00 10/13/2017 6.00 TR-0D5-DR-ILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 12,503.0 12,921.0 06:00 froml2,503 MD 3,789' TVD - 12,921' - MD 3,808' TVD . Pump at 277 gpm, 2.397 psi, 23% F/O, ECD 11.53 ppg, MW 9.2+ ppg, Rotate at 120 rpm with 9K TO on-btm, 7K TQ off-btm. 2,380 PSI off BTM 2-5K WOB. UP WT = 154K, DWN WT = 56K, ROT 106K. Max gas 93 units. ADT 4.57 hrs, Bit 65.51 hrs, Jars 160.67 hrs. 10/13/2017 06:00 10/13/2017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 12,921.0 13,217.0 12:00 from12,921' MD 3,808' TVD - 13,217' MD 3,813' TVD . Pump at 279 gpm, 2.550 psi, 23% F/O, ECD 11.48 ppg, MW 9.2+ ppg, Rotate at 100 rpm with 9K TO on-btm, 7.5K TQ off-btm. 2,500 PSI off BTM 1-6K WOB. UP WT = 154K, DWN WT= 56K, ROT 106K. Max gas 178 units. ADT 4.89 hrs, Bit 70.40 hrs, Jars 165.56 hrs. SPRs @1 13,264" MD 3,814' TVD, MW=9.4 ppg, 06:45 hours MP#1: 20 spm=580 psi, 30 spm=800 psi. MP #2: 20 spm=580 psi, 30 spm=820 psi 10/13/2017 12:00 10/13/2017 18:00 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 13,217.0 13,476.0 from13,217' MD 3,813' TVD - 13,476' MD 3,796' TVD . Pump at 277 gpm, 2.597 psi, 23% F/0, ECD 11.62 ppg, MW 9.2+ ppg, Rotate at 120 RPM with 9K TQ on-btm, 8K TQ off-btm. 2,572 PSI off BTM 1-6K WOB. UP WT = 160K, DWN WT= K, ROT 109K. Max gas 403 units. ADT 5.33 hrs, Bit 75.73 hrs, Jars 170.89 hrs. - SPRs @ 13,529" MD 3,801' TVD, MW=9.4 ppg, 14:10 hours MP#1: 20 spm=640 psi, 30 spm=880 psi. MP #2: 20 spm=640 psi, 30 spm=840 psi Page 73179 Report Printed: 10/30/2017 Operations Summary (with Timeiog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tme End Time Dur(hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth M) End Depth (flKB) 10/13/2017 10/14/2017 6.00 PR0D5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 13,476.0 13,961.0 18:00 00:00 from 13,476' MD 3,796' TVD to 13,961' MD 3,798' TVD . Pump at 277 gpm, 2.687 psi, 23% F/O, ECD 11.62 ppg, MW 9.2+ ppg, Rotate at 120 RPM with 9K TQ on-btm, 8K TQ off - trim. 2,680 PSI off BTM 1-6K WOB. UP WT=165K, DWN WT= K, ROT 109K. Max gas 669 units. ADT 4.17 hrs, Bit 79.90 hrs, Jars 175.06 his. 10/14/2017 10/14/2017 6.75 PROD5 DRILL DDRL P Directionally drill 6-3/4" LTD lateral 13,961.0 14,670.0 00:00 06:45 from 13,961' MD 3,798' TVD to 14,670' TVD 3,779' TVD . Pump at 275 gpm, 2,760 psi, 23% F/O, ECD 11.78 ppg, MW 9.2+ ppg W/2% lube. Rotate at 140 RPM with 10K TO on- btm, 8K TQ off-btm. 2,750 PSI off BTM 1-61K WOB. UP WT = 178K, DWN WT= K, ROT 119K. Max gas 150 units. ADT 5.07 hrs, Bit 84.97 hrs, Jars 180.13 hrs. SPRs @ 13,974" MD 3,789' TVD, MW=9.4+ ppg, 00:09 hours MP#1: 20 spm=680 psi, 30 spm=920 psi. MP #2: 20 spm=670 psi, 30 spm=920 psi 10/14/2017 10/14/2017 1.25 PROD5 CASING CIRC P CBU during reciprocation from 14,670' 14,670.0 14,670.0 06:45 08:00 MD - 14,630' MD UP DWN // 275 GPM @ 2,150 PSI, 21 % FO 120 RPM, 8K TO with 11.45 ECD. STKS PUMPED = 4,618. MW 1/0=9.3 PPG. UP WT = 178K DNW = K, ROT 119K. 7.8K TQ. SPRs @ 14,670" MD 3,780' TVD, MW=9.3 ppg, 08:00 hours MP#1: 20 spm=660 psi, 30 spm=920 psi. MP #2: 20 spm=670 psi, 30 spm=920 psi 10/14/2017 10/14/2017 0.50 PROD5 CASING OWFF P OWFF dropped 18". 14,670.0 14,670.0 08:00 08:30 10/14/2017 10/14/2017 3.50 P PROD5-CA-SING CASING BKRM P BKRM OOH From 14,670' MD - 14,670.0 13,332.0 08:30 12:00 13,332' MD. 275 GPM @ 2,360 PSI. 21 % F/O @120 RPM, 7.3K TQ. 11.18 EC, UP WT=150K DWN WT=61 K. DWN WT @ 14,250' = 50K 13,793' MD = 64K. 10/14/201710/14/2017 6.00 PROD5 CASING BKRM P BKRM OOH From 13,332' MD - 13,332.0 10,551.0 12:00 18:00 10,551' MD. 270 GPM @ 1,975 PSI. 20% F/O @120 RPM, 6K TQ. 10.8 ECD, UP WT = 92K @ full pump rate 10/14/2017 10/15/2017 6.00 PROD5 CASING BKRM P BKRM OOH From 10,551' MD - 7,690' 10,551.0 7,690.0 18:00 00:00 MD. 270 GPM @ 1,754 PSI. 20% F/O @120 RPM, 5K TQ. 10.8 ECD, UP WT = 88K @ full pump rate. UP WT=112K DWN WT=80K. Page 74179 Report Printed: 10/30/2017 Rig: DOYON 142 Operations Summary (with Timelog Depths) 1H-102 Job: DRILLING Start Tme 10/15/2017 Entl Time 10/15/2017 our (hr) 1.75 Phase PROD5 Op Code CASING AcW4 Code Time P-T-XOperation Start Depth (ta(9) End Depth (flKa) 00:00 01:45 TRIP P POOH on elevators. F/7,690' MD UP 7,690.0 7,314.0 WT=118K. DWN WT=81K Encountered drag at 7,533' MD so slacked off with 1 OK DWN WT. Bring on pumps to circulate possible fill/junk. PU to 130K UP WT for check. 3X jar licks down to free up. RIH fto 7,592' MD and bring pumps up to 275 GPM 1,710 PSI DPP. PUH to 7,502' MD 2X to wash / smear area with 7K drag. PUH to 7,314' MD at 116K UP WT 84K DWN WT. 10115/2017 01:45 10/15/2017 1.25 1ROD5 CASING CIRC P Circ while rotating from 7,309'to 7,314.0 7,223.0 03:00 7,223' MD with 275 GPM 1,760 PSI 20% F/O, 120 RPM with 4K TO. ECD = 10.32 PPG EMW. UP WT = 108K, DWN WT = 85K. Total STKS = 4,611. 9.3 PPG MW IN/OUT. 10/15/2017 10/15/2017 0.25 PROD5 CASING OWFF P OWFF. 7,223.0 7,223.0 03:00 03:15 10/15/2017 10/15/2017 0.25 PROD5 CASING SVRG P Service crown / top drive. 7,223.0 7,223.0 03:15 03:30 10/15/2017 03:30 10/15/2017 0.50 PROD5 CASING TRIP P STND BK 2 stands DP to 7,125' MD. 7,223.0 7,125.0 04:00 Pump dry job /install stripping rubber. 10/15/2017 04:00 10/15/2017 6.50 PROD5 CASING PULD P PULD drill pipe sideways from 7,125' 7,125.0 306.0 10:30 to 306' MD. Monitor disp via TT. UP wt=49K DWN WT=54K. 10/15/2017 10:30 10/15/2017 1.50 PROD5 CASING BHAH P Lay down BHA #26 as per DD. 306.0 0.0 12:00 Monitor disp via TT. 10/152017 10/15/2017 0.75 15ROD5 CASING BHAH P Clear rig floor of SLB tools BHA #26 0.0 0.0 12:00 12:45 and clean same. 10/15/2017 10/152017 1.50 COMPZ5 FISH BHAH P MU hook BHA #27 as per Baker Rep. 0.0 225.0 12:45 14:15 UP WT=47K DWN WT 52K. Monitor disp via TT. 10/15/2017 14:15 10/152017 3.75 COMPZ5 FISH TRIP P RIH with HOOK asym from 225' to 225.0 7,391.0 18:00 7,351' MD. UP WT= 136K DWN WT = 111 K. Monitor disp via TT. Shallow holes test MWD at 1,650' with 252 GPM PSI 1,681. 28% F/O. (PASSED). 10/15/2017 18:00 10/15/2017 0.50 COMPZ5 FISH FISH P Orient hook to 160 DEG R. with 233 7,391.0 7,350.0 18:30 GPM 1,141 PSI DPP. 16% F/O. Wash down to 7,391' MD. Engage hook top of Whipstock at 23 DEG L highside as per BOT. Attemp to straight pull with 80K over.. NOPE. Jar IX 20K, 40K, 60K over before release. UP WT= 138K. 10/15/2017 18:30 10/15/2017 1.50 50MPZ5 FISH CIRC —p7— Circulate 2X BU. 7,350' MD with 246 7,350.0 7,350.0 20:00 GPM @ 1,219 PSI DPP. 17% F/O--- Lost 45 BBLS when seals pulled. 85 BBLS lost during circ. Pumped 4,590 STKS 10/15/2017 10/15/2017 0.50 COMPZ5 FISH OWFF P OWFF. static 7,350.0 7,350.0 20:00 20:30 10/15/2017 10/1612017 20;30 3.50 COMPZ5 FISH TRIP P POOH from 7,350' MD - 2,220' MD 7,350.0 2,220.0 00:00 UP WT = 75K. Monitor Disp via TT. 10/16/2017 10/16/21 00:00 1I 1.50 COMPZ5 FISH TRIP P Continue to POOH with Whipstock 2,220.0 319.0 01:30 fishing assym from 2,200' MD to 319' MD. Monitor disp via TT. Page 75/79 Report Printed: 1013012017 : DOYON 142 Operations Summary (with TimelQg Depths) IH -102 Job: DRILLING I Stan Time I End Time I rmrrnn I on... I I _ 1 _..I 1 Sl Depth I I 10/16/2017 10/16/2017 2.25 ...___ COMPZ5 _.____ FISH ..,...,.�,,,,,, BHAH ,,,,,, ,,,,,n f Uperauon LD Whipstock and all Baker fishing (NKB) 319.0 EM Depm(WB) 0.0 01:30 03:45 tools as per BOT rep. Monitor disp via TT. 10/16/2017 10/16/2017 1.00 COMPZ5 FISH BHAH P Send all Baker fishing tools down 0.0 0.0 03:45 04:45 beaver slide and or pipe shed. Wash rig floor. 10/16/2017 10/16/2017 0.25 COMPZ5 CASING SFTY P PJSM 0.0 0.0 04:45 05:00 10/16/2017 10/16/2017 0.50 COMPZ5 CASING RURD lower sompletion easy. Pick 0.0 0.0 05:00 05:30 lest handeling equipment. p same. 10/16/2017 05:30 10/16/2017 0.75 COMPZ5 CASING PUTB h 4 1/2" 11.6# L-80 IBTM/TXP 0.0 254.0 06:15 Esloffted / Blank lower liner asym as per 254' MD. Installing cent on all s per program. TQ IBTM to /LB10/16/2017 06:15 10/16/2017 0.50 COMPZ5 CASING EQRP ange out to spare GBR casing 254.0 254.0 06:45 power unit. Was on location. Quick changeover. 10/16/2017 06:45 10/16/2017 8.50 COMPZ5 CASING PUTB P Continue to RIH with 4 1/2" 11.6# 254.0 7,252.0 15:15 IBTM / TXP slotted / Blank liner as per detail. UP WT=95K DWN WT=75K Monitor disp via TT. Install 6.25" cent on all joints while RIH. IBTM TQ = 4.5 FT/LB. TXP TQ = 7K FT1LB. 10/16/2017 15:15 10/16/2017 0.75 COMPZ5 CASING OTHR P PU hook hanger assym, slim pulse 7,252.0 7,285.0 16:00 MWD and scribe as per BOT/ SLB. 10/16/2017 16:00 - 10/16/2017 2.00 COMPZ5 CASING RUNL P Continue to RIH with liner as per tally. 7,285.0 8,795.0 18:00 Monitor disp via TT. 10/16/2017 18:00 10116/2017 0.50 50MPZ5 CASING DHEA P Shallow hole test MWD. 100 GPM 8,795.0 8,795.0 18:30 353 PSI DPP. 10% F/O (PASSED). 10/16/2017 18:30 10/16/2017 4.00 COMPZ5 CASING RUNL P Continue to RIH with 4" DP / HWDP 8,795.0 14,591.0 22:30 from 8,795' MD to 14,591' MD. Monitoring disp via TT. UP WT = 169K DWN WT= 87K. 10/16/2017 22:30 10!16/2017 1.00 COMPZ5 CASING OTHR P Kelly up and orient to 157 DEG R high 14,591.0 14,655.0 23:30 side with 92 GPM @ 530 PSI 9% F/O. Wash DWN from 14,591' MD to 14,655' MD. Orient to 13 DEG left highside and hang hook hanger as per Baker REP. 10/16/2017 23:30 10/17/2017 0.50 COMPZ5 CASING CIRC P Drop 29/32 ball and pump down at 85 14,655.0 14,652.0 00:00 GPM 515 PSI DPP. 8% F/O. slow rate to 62 GPM, 375 PSI with 7 1/2 FO/ at 400 SKS. 10/17/2017 00:00 10/17/2017 0.50 00MPZ5 CASING CIRC P Continue to pump 29/32" ball on seat 14,652.0 7,351.0 00:30 at 1 BPM @ 605 strokes pressure up to 3,800 PSI and release. PU 114K UP WT. Pressur sup to 4,250 PSI DPP and shear out ball seat. Tag up to confirm depth w 5K DWN WT. DWN WT= 111K PUH above liner to - 7,351' MD. 10/17/2017 10/17/2017 0.2 5 COMPZS W ELLPR OWFF P OWFF 10 min. Dropped 1'. 7,351.0 7,351.0 00:30 00:45 10/17/2017 10/17/2017 00:45 0.75 COMPZS CIRC P PUH to 7,190' MD and pump dry job. 7,351.0 7,190.0 01:30 Install stri ppin rubbers + BD TD. 10/17/2017 10/17/2017 3.50 COMPZ5 JWELLPR WELLPR TRIP P from 7,190' MD to 90' MD 7,190.0 90.0 01:30 05:00 1POOH monitor DISP via TT. Page 76179 Report Printed: 1 0/3 012 01 7 Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log StartTine T 10/17/2017 Entl Tlme 10/17/2017 our (hr)Phase 0.75 COMPZ5 Op Code WELLPR Activity Cade BHAH Time P -T -X Operalion sen Depth (flKB) End DOM (WS) 05:00 05:45 P LD liner running tools and confirm pins 90.0 0.0 sheared as per BOT rep. 10/17/2017 10/17/2017 0.25 COMPZ5 WELLPR BHAH P Clean rig floor 0.0 0.0 05:45 06:00 10/17/2017 10/17/2017 1.00 COMPZ5 RWRID RURD P RU to run LEM 0.0 0.0 06:00 07:00 10/17/2017 10/17/2017 0.25 DOYMPZ5 RWRID SFTY P PJSM0.0 0.0 07:00 07:15 10/17/2017 10/1712017 2.25 COMPZ5 RWRID PUTS P MU L-4 LEM/ZXP and scribe as per 0.0 255.0 07:15 09:30 BKR and SLB Rep. Monitor DISP via TT. 10/17/2017 10/17/2017 1.00 COMPZfi RWRIDWWRID RCST P RIH with LEM /ZXP on 4- DP from 255.0 1,667.0 09:30 10:30 255' MD - 1,667' MD. Monitor disp via TT. 10/17/2017 10/17/2017 0.50 COMPZ5 RWRID DHEQ f Shallow hole test MWD at 103 GPM 1,667.0 1,667.0 10:30 11:00 350 PSI w/10% F/O. (PASSED) BD - TD 10/17/2017 10/17/2017 3.25 COMPZ5 RWRID RCST P Continue to RIHfrom 1,667' MD- 1,667.0 7,459.0 11:00 14:15 7,459' MD. UP WT= 137K DWN WT = 107K Monitor disp via TT. 10/172017 10/17/2017 1.75 COMPZ5 RWRID PACK P Kelly up and orient to 30 DEG left 7,459.0 7,495.0 14:15 16:00 High side @ 127 GPM 785 PSI, 13% F/O. Wash down and set LEM as per BOT REP. Drop 1.625" ball to set ZXP PKR and release running tool. Pump down at 150 GPM 954 PSI with 13% F/O Ball on seat at 520 STKS. Pressure up to 2,800 PSI. Witness set at 2,350 PSI DPP. Pressure up to 3,550 PSI DPP to ensure released. BD TD. Bottom of non locating seal assym = 7,495' MD. PT ZXP liner top PKR to 3,500 PSI for 30 min (PASSED). 30 STKS to pressure up with 2.8 BBLS bled back. 10/17/2017 10/17/2017 2.75 C0MPZ5 RWRID CIRC P PU to 7,463' MD and displace well as 7,495.0 7,463.0 16:00 18:45 per program to 9.4 PPG brine. Pump 38 BBL spacer @ 150 GPM 650 PSI with 13% F/O. Chase with 9.4 PPG brine with 150 GPM. ICP = 650 PSI DPP FCP = 376 DPP. 11 % F/O total stks 3,748. Continue to pump and spot 25 BBL hich vis pill at liner top packer with 150 GPM 443 PSI DPP 10% F/O total stks pumped = 939 BD TD with simops of L/D three STDS left in derrick via mousehole and single joint elevators. 10/17/2017 10/17/2017 0.50 COMPZ5 RWRID OWFF P OWFF (static) 7,463.0 7,463.0 18:45 19:15 10/172017 10/18/2017 4.75 50MPZ5 RWRID PULD P POOH laying down 4" DP from 7,463' 7,463.0 3,952.0 19:15 00:00 MD - 3,952' MD removing SS on dg floor. Monitor Disp via TT. UP WT = 88K. DWN WT=80K. 10/18/2017 TOM 8/ 0017 5.50 COMPZ5 RWRID PULD P Continue pulling outof hole F/3,952' 3,952,0 40.0 00:00 05:30 MD. Laying down 4" Drillpie & Super Sliders. Monitor 10/18/2017 10/18/2017 0.75 COMPZ5 RWRID BHAH P Lay down ZXP running tool. Clear and 40.0 0.0 05:30 06:15 clean rig floor. Page 77179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sted Tim End Time D r(hr) T Phase Op Code Activity Code Time P -T -X Operation Stan Depth (RKB) End Depth(fe(e) 10/18/2017 10/18/2017 2.50 COMPZ5 EVALWB ELOG P PJSM / Rig up SLB E -Line toolsat 0.0 0.0 06:15 08:45 surface. Test tools prior to running in hole. Monitor well via trip tank. 10/18/2017 10/18/2017 3.25 COMPZ5 EVALWB ELOG P Run in hole with USIT & CBL tools via 0.0 6,950.0 08:45 12:00 E -line to 6,950 MD. Monitor displacement via trip tank. OA Pressure = 0 Static fluid loss 54 bbls. 10/18/2017 10/18/2017 7.75 COMPZ5 EVALWB ELOG P POOH logging with Usit and CBL from 6,950.0 0.0 12:00 19:45 6,950' MD. Monitoring Displacement via TT. 10/18/2617 10/18/2017 1.25 COMPZ5 EVALWB ELOG P RD SLB wieline and Wellteh 0.0 0.0 19:45 21:00 equipment. 10/18/2017 10/18/2017 1.00 C0MPZ5 WHDBOP KURD P Empty stack and pull wear ring. Install 0.0 0.0 21:00 22:00 test plug. Rig up test equipment 10/18/2017 16/19/2017 2.00 COMPZ5 WHDBOP BOPE P BOPR test. ((AOGCC Brian Bixby 0.0 0.0 22:00 00:00 waived witness at 1830 hrs.)). 10/19/2017 10/19/2017 4.25 COMPZ5 WHDBOP BOPE P Continue to test BOPE to 250/3500 0.0 0.0 00:00 04:15 PSI aser p permit to drill with 4 1/2" 1- 80 testjoint. Kill HCR failed initial test / greased and passed. 10/19/2017 TOM 9/2017 1.25 COMPZ5 RPCOMP SLPC P Slip / cut drill line. 0.0 0.0 04:15 05:30 10/19/2017 10/19/2017 14.50 COMPZ5 RPCOMP PUTB P Rig up and RIH with 4 1/2" 12.6# TXP 0.0 7,292.0 05:30 20:00 L-80 production tubing with completion equipment as per approved program. Pressure test DH gauge to 5000 psi as per proceedure for 5 min. Install Cannon Clamps on all connections and monitoring pressure gauge on the fly. TQ all connections in TQ TURN mode1o7Kft/LB. UPWT=98K DWN WT= 76K. Witnessed drag as stinging into seal asym and tagged up at 7,292' with 1 O DWN. 10/19/2017 10/19/2017 1.25 COMPZ5 RPCOMP PRTS P Close Ann and test sealbore seals 7,292.0 7,292.0 20:00 21:15 down IA 1/500 PSI. (GOOD) 10/19/2017 10/19/2017 0.75 COMPZ5 RPCOMP THGR P Terminate tech wire for SLB pressure 7,260.0 7,260.0 21:15 22:00 gauge. 10/19/2017 10/19/2017 1.00 COMPZ5 RPCOMP CRIH P Spot 25 BBLS Cl as per program at 7,260.0 7,270.0 22:00 23:00 211 GPM 480 PSI, 10% F/O Chase CI with 105 BBLS of 9.4 PPG brine @ 211 GPM 573 PSI 15% F/O. Total STKS pumped = 1,273. SIMOPS RD GBR. 10/19/2017 10/20/2017 1.00 COMPZ5 RPCOMP THGR P RIH to 7,289' MD land tubing hanger 7,270.0 0.0 23:00 00:00 and RILDS. Sim ops RD / BD cement line. 10/20/2017 10/20/2017 0.50 COMPZ5 RPCOMP THGR P Test upper & lower Hanger seals 0.0 0.0 00:00 00:30 T/5,000 psi 10 min. each. Test witnessed by CPAI rig supewlser. Test IA to 1,000 psi for 5 min. All tests good - Charted. 10/20/2017 10/2012017 2.75 COMPZ5 RPCOMP PRTS P Drop ball &rod. R/U &test tubing & IA 0.0 0.0 00:30 03:15 to 3,500 psi 30 min each. Tests charted. Good tests. Bleed down tubing to zero to shear SOV. Page 78179 Report Printed: 10/3012017 f Operations Summary (with Timeiog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Log og k End Time Our(hr) Phase Op Code Adihy Code Time P -T-% Operation Stan Depth (ftKB) End Delphi MKB) 017 10/20/2017 0.50 COMPZ5 RPCOMP KURD P Rig down test equipment, Pull landing 0.0 0.0 03:45 joint &lay down. Drain stack &blow down choke, kill and hole fill lines. 1020/2017 10/20/2017 0.50 COMPZ5 WHDBOP MPSP P Set BPV. Test BPV from below to 0.0 0.0 03:45 04:15 2,500 psi for 10 min. Test charted, Good test. 10/20/2017 10/20/2017 3.25 COMPZ5 WHDBOP NUND P Nipple down BOP stack and rack back 0.0 0.0 04:15 07:30 on pedestal. Remove choke and kill lines. Lay down to -hi pressure riser. 10/20/2017 1020/2017 1.75 COMPZ5 WHDBOP NUND P Clean out hanger void. Nipple up 0.0 0.0 07:30 09:15 production tree. 10/20/2017 10/20/2017 -0 75 50MPZ5 WHDBOP PRTS P Test hanger void to 5,000 psi for 15 0.0 0.0 09:15 10:00 min. Good test. 10/20/2017 10/20/2017 0.75 COMPZ5 WHDBOP NUND P Terminate tec wire &test 0.0 0.0 10:00 10:45 10/20/2017 10/20/2017 1.25 COMPZ5 WHDBOP -15-RTS P Flood lines and tree with diesel. Test 0.0 0.0 10:45 12:00 250/5,000 for 10 min each. Tests good and tests charted. Rig down from test. 10/20/2017 10/20/2017 -0 50 COMPZ5 WHDBOP MPSP P Pull BPV and prep for FP 0.0 0.0 12:00 12:30 10/20/2017 10/20/2017 1.50 COMPZ5WHDBOP FRZP P Engage LRS to pump 135 BBLS of 0.0 0.0 12:30 14:00 diesel freeze protect. 3 BPM Q 500 PSI, FCP = 3 BPM AT 550 PSI. SI and dg down. 10/20/2017 10/20/2017 1.50 COMPZ5 WHDBOP FRZP P Install utube system and allow well to D.0 0.0 14:00 15:30 utube. 10/20/2017 10/20/2017 0.50 COMPZ5 WHDBOP MPSP P SET BPV 0.0 0.0 15:30 16:00 1020/2017 10/21/2017 8.00 COMPZ5 MOVE MOB P Move to 1H-111 0.0 0.0 16:00 0000 Page 79/79 Report Printed: 1 013 012 01 7 NADConversion Kuparuk River Unit Kuparuk 1H Pad IH -1021-4 1H -102L4 ConocoPhillips Definitive Survey Report 18 October, 2017 _ ConocoPhillips ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference' Stsa: Kuparuk 1H Pad MD Reference: well. 1H-102 North Reference: Wellbore: 1 H-1021-4 Survey Calculation Method: Design: 11-1-1021-4 Database: Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) usft Map Zone: Alaska Zone 04 0.00 Well 1 H-102 1 H-102 actual @ 92.62usft (Doyon 142) 1 H-102 actual Q 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 Mean Sea Level Using Well Reference Point Using geodetic scale factor Nell 1H-102 Autlft Notes: To Nell Position +N/ -S 0.00 usft Northing: 5,980,662.56 usft Latitude: 70" 21'28.630 7,293.52 +E/ -W 0.00 usft Easting: 549,577.46 usft Longitude: 149° 35'50+423 % rosition Uncertainty (usft) 0.00 usft Wellhead Elevation: usft Ground Level: 54.00 usl Wellbore 111-1021-4 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) r) (nT) BGGM2017 10/13/2017 17.45 80.94 57,488 Design 111-1021-4 Date Autlft Notes: To Map Map Version: 1.0 Phase: ACTUAL Tie On Depth: 7,293.52 Vertical section: Depth From (TVD) +N/ -S +E/ -W Direction 1,050.36 (usft) (usft) (usft) (% 1,777.33 38.82 0.00 0.00 0.00 Survey Program Date From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 67.62 1,009.26 1 H-102 Srvy 1 - SLB_GWD70 (1H-102) GYD-GC-SS Gymdata gyro single shots 8/24/2017 10:04 1,050.36 1,678.041H-102 Srvy 2- SLB _MWD+GMAG(1 H- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 8/24/2017 10:12 1,777.33 7,293.521H-102 Srvy 3-SLB_MWD+GMAG(1 H- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 8/27/201712:16 7,377.00 7,480.661H-1021-4 Srvy 1-SLB_MWD-INC_Filler MWD -INC -ONLY MWD -INC -ONLY FILLER 10/9/2017 10:13 7,575.34 14,608.581H-1021-4 Srvy 2-SLB_MWD+GMAG(I MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 10/9/201712:53 Survey 10/1&2017 2'11:30PM Page 2 COMPASS 5000.14 Build 85 Map Map Vertical MO Inc AN TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) 0 (usft) (usft) (usft) (usft) (ft) (ft) ('/100) (ft) Survey Tool Name 38.62 0.00 000 38.62 -54.00 0.00 0.00 5,980,662.56 549,577.46 0.00 0.00 UNDEFINED 6762 0.19 41.29 67.62 -2580 0.04 0.03 5,980.66260 549,577.49 0.65 0.04 GYD-GC-SS(1) 165.90 0.45 132.01 165.90 73.28 -0.10 0.43 5,98,66246 549,577.89 0.50 4010 GYD-GC-SS(1) 258.98 1.01 128.15 258.97 166.35 -0.85 1.34 5,960,661.72 549,578.81 0.60 -0.85 GYD-GC-SS(1) 354.48 3.34 138.19 354.40 261.78 3.44 3.85 5,980,659.14 549,581.34 2.46 -344 GYD-GC-SS(1) 447.17 4.61 135.26 446.86 354.24 .8.10 8.28 5,980,654.51 549,585.79 1.39 3.10 GYD-GC-SS(1) 53982 5.77 132.42 53913 446.51 -13.89 14.34 5,980,648.77 549,591.89 1.28 -1389 GYD-GCSS(1) 632.84 7.61 134.49 631.51 538.89 -21.36 22.19 5,980,641.35 549,593.79 1.99 -21,36 GYD-GC-SS(1) 725.82 8.77 137.82 72354 630.92 30.93 31.34 5,980,631.84 549,609.00 1.35 -30.93 GYD-GC-SS(1) 821.24 10.73 141.32 817.58 724.96 -03.25 4118 5,98,619.59 549,619.52 2.15 43.25 GYD-GC-SS(1) 10/1&2017 2'11:30PM Page 2 COMPASS 5000.14 Build 85 Company: NADConversion Pmj"L. Kuparuk River Unit Site: Kuparuk 1H Pan Well: IH -102 I1114,0hom: 11-1-10214 Daiign: 1H-10214 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1H-102 1 H-102 actual @ 92.62usft (Doyon 142) 1 H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 survey Map Map Vertical MD Inc AN TVD TVDSS +N/S +E7 -W Northing Easting DLS Section (us(t) (h (1) Wait) (usft) (usft) (uafry (ft) (ft) (17001) (ft) Survey Tool Name 914.20 12.89 139.81 908.57 815.95 57.91 53.90 5,980,605.01 549,631.74 2.35 -57.91 GVD-GC-SS (1) 1,009.26 14.89 136.85 1,000.84 90822 -74.90 69.13 5,980,588.13 549,647.8 2.22 -74.90 GVD-GC-SS(1) 1,050.36 15.72 135.96 1,040.49 947.87 52.75 76.61 5,980,580.32 549,654.61 2.10 52.75 MVJD+1FR-AK-CAZ-SC (2) 1,144.89 17.17 134.37 1,131.15 1,038.53 -101.72 95.49 5,980,561.49 549,673.61 1.61 -101.72 MWD+IFR-AK-CAZ-SC(2) 1,239.16 20.84 134.25 1,220.26 1,127.64 -123.16 117.46 5,980,540.20 549,695.72 389 -123.16 MWD+1FR-AK-CAZSC(2) 1,334.20 24.71 136.54 1,307.88 1,215.26 -149.38 143.24 5,980,514.14 549,721 67 4.18 -149.38 MWD+IFR-AK-CAZ-SC (2) 1,428.98 27.54 13]49 1,392.97 1,300.35 -179.92 171.68 5,980,483.80 549,750.31 3.02 -179.92 MWD+IFR-AK-CAZ-SC(2) 1,523.25 28.14 137.93 1,476.33 1,383.71 -212.49 201.30 5,980,45143 549,780.14 0.67 -21249 MWD+IFR-AK-CAZ-SC(2) 1,618.09 28.94 137.33 1,559.64 1,467.02 -245.96 231.84 5,980,418.16 549,810.90 0.90 -245.96 MV4D+IFR-AK-CAZSC (2) 1,678.04 29.99 135.80 1,611.84 1,519.22 -2 TW 252.11 5,980,39689 549,831.31 2.15 -267.37 MWD+IFR-AK-CAZ-SC(2) 1,771.0 33.38 13572 1,690.93 1,598.31 502.34 286.17 5,980,362.15 549,865.60 3.65 -30234 NOT anAMualSurvey 10 374" z 13412" 1,777.33 33.61 M3 72 1,69621 1,603.59 50485 288.61 5,980,35966 549,868.06 3.65 504.85 MWD+IFR-AK-CAZ-SC(3) 1,801,61 34.53 134.79 1,716.32 1,623.70 -314.50 298.19 5,980,350.07 549,877,69 4.35 514.50 MWD+IFR-AK-CAZ-SC(3) 1,896.66 37.81 133.50 1,793.04 1,700.42 .353,55 338.45 5,980,311.29 549,918.21 3.54 -353.55 MWD+IFR-AK-CAZSC (3) 1,991.93 40.85 131.83 1,86612 1,774,10 -394.45 382.87 5,980,270.70 549,962.89 3.39 594.45 MWD+IFR-AK-CAZ-SC(3) 2,086.48 43.97 13099 1,936.52 1,843.90 -036.61 430.70 5,980,228.85 550,011.00 3.34 -436.61 MWD+IFR-AK-CAZ-SC(3) 2,184.36 47.16 129.49 2,005.04 1,912.42 -481.73 484.06 5,98,184.09 550,064.65 3.44 481.73 MWD+IFR-AK-CAZSC(3) 2,276.23 50.08 128.77 2,06516 1,973.14 -525.22 537.53 5,983,140.96 650,118.40 3.23 52522 MWD+IFR-AK-CAZ-SC(3) 2,371.48 53.12 127.35 2,124.92 2,032.30 571.22 596.31 5,980,095.36 550,177.48 3.40 -571.22 MWD+IFR-AK-CAZSC(3) 2,464.98 55.35 124.47 2,179.57 2,086.95 515.68 657.76 5,980,051.30 550,239.21 3.45 515.68 MWD+IFR-AK-CAZ-SC(3) 2,559.60 56.73 122.73 2,232.43 2,139.81 559.10 723.12 5,980,00832 550,304.86 2.11 559.10 MWD+IFR-AK-CAZSC(3) 2,653.87 58.79 122.43 2,282.72 2,190.10 -702.03 79031 5,979,96584 550,372.32 2.20 -702.03 MWD+1FR-AK-CAZ-SC(3) 2,748.30 59.37 121.74 2,331.24 2,238.62 -745.06 858.95 5,979,923.27 550,441.23 0.88 -745.06 MWD+IFR-AK-CAZSC(3) 2,84307 61.0 121.48 2,378.07 2,285.45 -788.24 929.11 5,979,880.56 55Q51167 2.16 -788.24 MWD+IFR-AK-CAZ-SC (3) 2,937.25 65.11 121.93 2,420.45 2,327.83 532.4 1,000.65 5,979,836.84 550,583.50 3.96 -832.44 MWD+IFR-AK-CAZ-SC(3) 3,032.88 69.13 121.16 2,45]62 2,365.00 -878.52 1,075.72 5,979,79127 550.658,87 427 578.52 MWD+IFR-AK-CAZ-SC(3) 3,126.86 71.43 121.37 2,489.33 2,396.71 -924.43 1,151.34 5,979,745.86 550,734.78 2.46 -924.43 MWD+IFR-AK-CAZ-SC(3) 3,221.95 72.62 121.37 2,51867 2,426.05 -971.51 1,228.56 5,979,699.29 550,812.31 1.25 -971.51 MWD+IFR-AK-CAZSC(3) 3,316.6 73.03 121.69 2,546.58 2,453.96 -1,018.73 1,305.53 5,979,652.59 550,889.57 0.54 -1,018.73 MWD+IFR-AK-CAZ-SC(3) 3,410.86 73.34 122.71 2,573.89 2,481.27 -1,066.89 1,381.99 5,979,60495 550,966.35 1,09 -1,066.89 MWD+IFR-AK-CAZ-SC(3) 3,506.07 73.21 122.55 2,601.29 2,508.67 -1,116.05 1,458.78 5,979,556.30 551,043.45 021 -1,116.05 MWD+IFR-AK-CAZSC(3) 3,601.42 73.21 122.70 2,628.83 2,536.21 -1,165.27 1,535.66 5,979,507.59 551,120.65 0.15 -1,165.27 MWD+1FR-AK-CAZ-SC(3) 3,696.85 73.21 122.29 2,656.40 2,563.78 -1,214.35 1,612.72 5,979,459.03 551,198.03 0.41 -1,214.35 MWD+IFR-AK-CAZSC(3) 3,791.46 73.30 120.98 2,6e3.66 2,591.04 -1,261.87 1,689.85 5,979,41203 551,275.46 1.33 -1,261.87 MWD+IFR-AK-CAZ-SC (3) 3,886.74 73.14 118.95 2,711.17 2,618.55 -1,307.43 1,768.88 5,979,366.99 551,354.78 2.05 -1,307.43 M1MD+1FR-AK-CAZ-SC(3) 3,981.94 73.09 119.64 2,738.82 2,646.20 -1,352.00 1,648.32 5,979,322.95 551,434.51 0.70 -1,352.00 MWD+IFR-AK-CAZ-SC(3) 4,07841 73.30 119.87 2,766.13 2,673.51 -1,396.88 1,926.84 5,979,278.59 551,513.31 0.32 -1,396.88 MWD+IFR-AK-CAZ-SC(3) 4,171.02 73.17 118.99 2,793.42 2,700.80 -1,441.40 2,005.73 5,979,234.61 551,592.49 0.90 -1,441.40 MWD+IFR-AK-CAZ-SC(3) 4,268.02 73.06 119.53 2,821.02 2,728.40 -1,485.83 2,085.04 5,979,190.71 551,672.08 0.56 -1,485.83 MWD+IFR-AK-CAZ-SC(3) 4.360.46 73.01 119.04 2,848.57 2,755.95 -1,530.01 2,163.83 5,979,147.05 551,751.15 0.50 -1,530.01 MWD+IFR-AK-CAZ-SC(3) 7w1tvm17 2..11:30PM Page 3 COMPASS 500014 Build 65 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordmate Reference: Well 1H-102 Project: Kupsruk River Unit TJD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kupamk 1 H Pad MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Well: 1H-102 North Reference: True Wellbore: 1H-1021.4 Survey Calculation Method: Minimum Curvature Design: 1H-1021.4 Database: OAKEDMP2 Survey 10/1&2017 2:11:30PM Page 4 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc An TVD TVDSS -N/-S +E1 -W Northing Eesung DLS Section (usft) (ry V) (usft) (usft) (usft) finish) (ft) (ft) (°N0ill (ft) Survey Tool Name 4,455.58 72.90 11977 2,876.45 2,783.83 -1,574.66 2,243,05 5,979,102.93 551,830.66 0.74 -1,574.65 MWD+IFR-AK-CAZ-SC(3) 4,549.81 72.87 120.06 2,904.19 2,811.57 -1,619.57 2,321.11 5,979,058.54 551,909.01 0.30 -1,619.57 MWD+FR-AK-CAZ-SC (3) 4,644.52 7320 118.40 2,931.82 2,839.20 -1,663.81 2,400.16 5,979,014.84 551,988.35 1.71 -1,663.81 MWD+IFR-AK-CAZSC(3) 4,739.99 72.42 114.51 2,960.05 2,86]43 -1,704.44 2,481.79 5,978,974.75 552,070.24 3.98 -1,70444 MWD+IFR-AK-CAZSC(3) 4,786.24 72.31 110.47 2,974.06 2,881.44 -1,721.29 2,522.51 5,978,958.17 552,111.06 8.33 -1,721.29 MWD+IFR-AK-CAZ-SC (3) 4,83376 7248 108.23 2,988.44 2,895.82 -1,736.30 2,565.24 5,978,943.45 552,153.89 4.51 -1,736.30 MWD+IFR-AK-CAZ-SC(3) 4,928.09 72.21 103.78 3,017.06 2,924.44 -1,761.08 2,651.62 5,978,919.24 552,240.42 4.50 -1,76108 MWD+IFR-AKCAZSC(3) 5,022.87 71.11 100.68 3,046.89 2,954.27 -1,760.14 2,739.52 5,978,90076 552,328.44 3.31 -1,780.14 MWD+IFR-AKCAZ-SC(3) 5,070.23 7127 98.69 3,052.16 2,969.54 -1,787.68 2,783.71 5,978,693.52 552,37267 3.99 -1,787.68 MWD+IFR-AK-CAZ-SC(3) 5,116.77 71.68 96.97 3,076.95 2,984.33 -1,793.69 2,827.43 5,978,887.79 552,416.42 361 -1,79369 MWD+IFR-AK-CAZSC(3) 5,211.19 72.12 93.77 3,10629 3,013.67 -1,802.09 2,916.77 5,978,879.99 552,505.81 3.25 -1,802.09 MWD+IFR-AKCAZ-SC(3) 5,305.75 71.74 88.59 3,135.64 3,043.02 -1,803.94 3,006.61 5,978,878.73 552,595.65 5.22 -1,803.94 MWD+IFR-AK-CA7-SC(3) 5,400.08 71.70 83.77 3,165.24 3,072.62 -1,79298 3,095.95 5,978,885.29 552,684.94 4.85 -1,79298 MWD+IFR-AK-CAZSC(3) 5,495.26 72.32 81.29 3,19464 3,102.02 -1,786.21 3,185.70 5,978,897.65 552,77460 2.56 -1,786.21 MWD+IFR-AKCAZSC(3) 5,590.01 72.15 76.05 3,223.57 3,130.95 -1,768.49 3,274.13 5,978,915.95 552,862.91 5.27 -1,768.49 MWD+IFR-AK-CAZ-SC(3) 5,685.45 72.61 70.23 3,252.48 3,159.86 -1,74211 3,361.14 5,978,942.90 552,949.73 5.83 -1,742.11 MWD+IFR-AK-CAZSC(3) 5,779.73 73.02 64.52 3,280.36 3,187.74 -1,707.48 3,444.24 5,978,978.08 553,032.59 5.80 -1,707.48 MWD+IFR-AKCAZSC (3) 5,874.02 73.87 63.54 3,307.23 3,214.61 -1,667.90 3,525.49 5,979,018.19 553,113.57 1.34 -1,667.90 MWD+IFR-AKCAZ-SC(3) 5,968.69 74.38 63.99 3,333.12 3,240.50 -1,627.64 3,607.17 5,979,058.98 553,194.97 0.71 -1,627.64 MWD+IFR-AK-CAZ-SC(3) 6,063.17 74.61 63.93 3,358.38 3,265.76 -1,587.68 3,688.97 5,979,09949 553,276.50 0.25 -1,587.68 MWD+IFR-AK-CAZ-SC(3) 6,156.96 7468 58.30 3,38323 3,290.61 -1,544.01 3,768.12 5,979,143.67 553,355.35 5.79 -1,544,01 MWD+IFR-AKCAZSC(3) 6,252.33 7403 54.53 3,408.96 3,316.34 -1,493.22 3,844.61 5,979,194.96 553,431.50 3.87 -1,493.22 MWD+IFR-AK-CAZ-SC(3) 6,346.97 7268 51.05 3,436.08 3,343.46 -1,438.41 3,916.82 5,979,250.25 553,503.33 3.60 -1,438.41 MWD+IFR-AK-CAZ-SC(3) 6,441.76 72.16 48.05 3,464.71 3,372.09 -1,379.79 3,985.56 5,979,30931 553,57169 3.07 -1,379.79 MWD+IFR-AK-CAZ-SC(3) 6,537.27 73.10 45.02 3,493.23 3,400.61 -1,317.09 4,051.72 5,979,372.44 553,63242 3.18 -1,317.09 MWD+IFR-AK-CAZSC(3) 6,585.21 73.18 41.30 3,507.14 3,414.52 -1,283.63 4,083.10 5,979,406.1 553,668.57 7.43 -1,283.63 MWD+IFR-AK-CAZSC(3) 6,632.17 7264 38.72 3,520.94 3,428.32 -1,249.25 4,111.96 5,979,44067 553,697.19 5.38 -1,249.25 MWD+IFR-AK-CAZ-SC(3) 6,727.59 71.99 32.96 3,549.95 3,457.33 -1,175.60 4,165.17 5,979,51467 553,749.91 5.79 -1,175.60 MWD+IFR-AK-CAZ-SC(3) 6,822.80 72.62 27.41 3,578.91 3,486.29 -1,097.23 4,210.74 5,979,593.33 553,794.96 5.59 -1,097.23 MWD+IFR-AK-CAZ-SC(3) 6,915.59 72.83 23.59 3,606.48 3,513.86 -1,017.27 4,248.88 5,979,673.53 553,832.57 3.94 -1,017.27 MWD+IFR-AKCAZSC(3) 7,011.34 7249 19.50 3,635.02 3,542.40 -932.28 4,28244 5,979,758.73 553,865.56 4.09 -932.28 M6W+IFR-AK-CAZ-SC(3) 7,10401 73.90 18.25 3,661.82 3,569.20 -848.34 4,311.14 5,979,842.85 553,89370 1.99 -848.39 MWD+IFR-AK-CAZ-SC(3) 7,198.95 73.27 13.49 3,688.66 3,596.04 -760.78 4,336.05 5,979,930.57 553,918.03 4.85 -760.78 MWD+IFR-AK-CAZ-SC(3) 7,293.52 74.08 7.89 3,715.26 3,622.64 871.64 4,352.87 5,980,019.81 553,934.25 5.75 .671.64 MWD+IFR-AK-CAZ-SC(3) I 7,377.00 7447 4.54 3,737.89 3,645.27 591.76 4,361.56 5,980,099.73 553,942.42 3.89 591.76 NOT an Actual Survey 7418" x9.718" 7,390.60 75.83 4.00 3,741.38 3,648.76 -578.66 4,362.54 5,980,112.85 553,943.31 10.71 -578,66 MWD -INC -ONLY (4) 7,480.66 79.20 5.00 3,760.84 3,668.22 -491.01 4,369.44 5,980,200.53 553,949.63 3.90 -091.01 MM -INC _ONLY (4) 7,575.34 84.81 5.00 3,774.01 3,681.39 -397.65 4,377.61 5,980,293.93 553,957,18 5.93 -39]65 MWD+IFR-AKCAZSC(5) 7,631.80 9033 5.30 3,776.40 3,683.78 541.49 4,382.67 5,980,350.12 553,961.87 9.79 541.49 MWD+1FR-AKCAZ-SC(5) 10/1&2017 2:11:30PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 1 H-102 Project: Kuparuk River Unit TVD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 11-1-102 actual @ 92.62usft (Doyon 142) Well: 1H-102 North Reference: True Wellbore: 11-1-1021-4 Survey Calculation Method: Minimum Curvature Design: 1 H-1021.4 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/ -W Northing Eaatlng OLS Section (usft) (*) (°) (weft) (usft) (ui (usft) (ft) (ft) (°/1009 (it) Survey Tool Name 7,677.29 92.17 3.66 3,775.41 3,682.79 -296.15 4,386.23 5,980,39648 553,965.12 5.42 -296.15 MWD+IFR-AK-CAZSC(5) 7,77565 93.32 358.47 3,770.70 3,678.08 -197.95 4,388.05 5,980,49367 553,966.30 5.40 -197.95 MWD+IFR-AK-CAZ-SC(5) 7,865.25 92.89 352.09 3,765.84 3,673.22 -108.84 4,380.69 5,980,582.73 553,958.35 7.13 -108.84 MWD+IFR-AK-CAZ-SC(5) 7,91666 92.50 353.16 3,763.42 3,670.80 -57.91 4,374.10 5,980,633.61 553,951.42 2.21 -57.91 MWD+11FR-AK-CAZ-SC(5) 8,012.54 92.03 352.69 3,759.63 3,667.01 37.17 4,362.30 5,983,72859 553,939.00 0.69 37.17 MWD+IFR-AK-CAZ-SC(5) 8,108.07 91.29 351.10 3,756.86 3,664.24 131.70 4,348.84 5,980,823.03 553,924.91 1.84 131.70 MWD+IFR-AK-CAZ-SC(5) 8,202.05 91.66 354.34 3,754.44 3,661.82 224.88 4,336.94 5,930,916.11 553,912.39 3.47 224.88 MWD+IFR-AK-CAZSC(5) 8,291-04 91.10 355.52 3,752.16 3,659.54 31947 4,328.54 5,981,010.64 553,903.37 1.37 319.47 MWD+IFR-AK-CAZSC(5) 8,391.90 90.59 355.57 3,750.76 3,658.14 414.03 4,321.16 5,981,105.14 553,895.38 0.54 414.03 MWD+IFR-AK-CAZSC(5) 8,485.70 89.75 356.26 3,750.48 3,657.86 507.59 4,31449 5,981,198.64 553,888.08 1.16 507.59 MWD+IFR-AK-CAZ-SC(5) 8,580.35 89.18 0.83 3,751.35 3,658.74 602.18 4,31289 5,981,29321 553,885.05 4.87 602.18 MWD+IFR-AK-CAZ-SC(5) 8,675.09 88.14 1.55 3,753.58 3,660.96 696.87 4,314.06 5,981,387.90 553,886.39 1.34 696.87 MWD+IFR-AK-CAZ-SC(5) 8,769.22 68.25 456 3,755.54 3,663.92 790.81 4,319.07 5,981,48186 553,890]8 3.20 790.81 MWD+IFR-AK-CAZ-SC(5) 8,864.59 89.29 3.77 3,758.59 3,665.97 885.90 4,326.00 5,981,57999 553,897.08 1.37 885.90 MVM+IFR-AK-CAZ-SC(5) 8,959.46 89.85 2.69 3,759.30 3,666.68 98062 4,331,34 5,981,671.73 553,901.80 1.28 98062 MWD+IFR-AK-CA7-SC(5) 9,054.39 89.13 359.26 3,760.15 3,667.53 1,075.52 4,332.96 5,981,765.63 553,90218 3.69 1,075.52 MWD+IFR-AK-CAZ-SC(5) 9,149.46 89.19 357.10 3,761,54 3,668.92 1,170.52 4,329.94 5,981,861,60 553,899.14 2.27 1,170.52 MWD+IFR-AK-CA7.-SC(5) 9,244.06 8865 356.84 3,763.32 3,670.70 1,264.97 4,324.94 5,981,956.01 553,893.51 0.63 1,264.97 MW13+11FR-AK-CA7-SC(5) 9,33946 88.46 358.90 3,765.73 3,673.11 1,360.20 4,319.73 5,982,051.19 553,887,68 0.21 1,360.20 MWD+IFR-AI(-CAZ-SC(5) 9,433.08 88.32 WT73 3,768.36 3,675.74 1,453,68 4,315.35 5,982,144.63 553,882.67 0.90 1,453.68 MWD+IFR--CAZ-SC(5) 9,528.14 88.29 0.77 3,771.17 3,678.55 1,548.68 4,314.10 5,982,239.61 553,880.80 3.20 1,548.68 MWD+IFR-AK-CAZ-SC(5) 9,672.81 87.96 2.92 3,774.27 3,681.65 1,643.24 4,317.15 5,982,334.18 553,883.22 2.30 1,643.24 MWD+IFR-AK-CAZ-SC(6) 9,719.62 89.52 4.58 3,776.40 3,683.78 1,739.82 4,323.48 5,982,430.78 553,888.91 2.35 1,739.82 MWD+IFR-AK-CAZSC(5) 9,811]5 8971 1.38 3,77702 3,684.40 1,831.81 4,328.27 5,982,52280 553,893.09 3.48 1,831.81 MWD+IFR-AK-CAZSC(5) 9,906.99 91.12 356.51 3,776.33 3,663.71 1,927.00 4,32652 5,982,61796 553,890.71 5.32 1,927.00 MWD+IFR-AK-CAZ-SC(5) 9,951.63 91.55 35.71 3,77529 3,682.67 1,971.52 4,323.49 5,982,66746 553,887.39 2.03 1,971.52 MWD+IFR-AK-CAZSC(5) 10,002.07 90.85 352.94 3,774.23 3,681.61 2,021.70 4,31850 5,982,71260 553,882.07 5.66 2,02110 MWD+IFR-AK-CAZSC(5) 10,096.45 90.70 349.63 3,772.96 3,680.34 2,114.97 4,304.21 5,982,80516 553,867.16 3.51 2,114.97 MWD+IFR-AK-CAZSC(5) 10,191.82 89.75 347.85 3,772.58 3,679.96 2,208.50 4,285.58 5,982,899.16 553,847.92 2.12 2,208.50 MWD+1FR-AK-CAZSC(5) 10,286.69 89.36 344.77 3,773.32 3,680.70 2,300.66 4,263.14 5,982,991.16 553,824.86 3.27 2,30066 MWD+IFR-AK-CAZSC(5) 10,381.45 89.05 345.67 3,774.63 3,682.01 2,392.27 4,238.96 5,983,082.60 553,800.09 1.00 2,39227 MWD+IFR-AK-CAZSC(5) 10,476.55 87.69 346.86 3,777.34 3,684.72 2,484.61 4,216.39 5,983,174.78 553,776.91 1.90 2,484.61 MWD+IFR-AK-CAZ-SC(5) 10,570.94 87.71 346.65 3,781.13 3,688.51 2,576.42 4,19479 5,983,266.43 553,754.69 0,22 2,576.42 MWD+IFR-AK-CAZSC(5) 10,666.13 87.35 348.71 3,78523 3,692.61 2,669.32 4,174.49 5,983,359.19 553,733.79 2.19 2,669.32 MWD+IFR-AK-CAZSC(5) 10,761.88 88.50 350.88 3,78870 3,696.08 2,763.49 4,157.54 5,983,453.24 553,716.22 2.56 2,763.49 MWD+IFR-AK-CAZSC(5) 10,855.64 89.40 353.44 3,790.42 3,697.80 2,856.55 4,144.73 5,983,546.20 553,702.79 2.89 2,856.55 MWD+IFR-AK-CAZSC(5) 10,950.99 89.26 357.21 3,791.53 3,698.91 2,951.36 4,136.98 5,983,640.94 553,69441 3.96 2,951.36 MWD+IFR-AK-CAZSC(5) 11,046.51 88.51 359.84 3,793.39 3,700.77 3,046.82 4,134.52 5,983,736.38 553,691.32 2.86 3,046.82 MWD+IFR-AK-CAZSC(5) 11,140.94 88.69 2.04 3,795.70 3,703.08 3,141.20 4136.07 5,983,830.76 553,69225 2.34 3,141.20 MWD+IFR-AK-CAZ-SC(5) 11,235.07 86.88 5.25 3,799.34 3,706.72 3,235.05 4,142.04 5,983,924.64 553,69760 3.91 3,235.05 MWD+IFR-AK-CAZ-SC(5) 70/182017 2.11:30PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion local Co-ordinate Reference: Well 1 H-102 Project: Kupanik River Unit TVD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Well: 1H-102 North Reference: True Wellbore: 11-1-10214 Survey Calculation Method: Minimum Curvature Design: 1 H-10214 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (7 (1) (usft) (usft) (usm (uaft) (ft) (fl) ('HOOT (ft) Survey Tool Name 11,32970 89.54 7.65 3,80229 3,709.67 3,329.02 4,152.67 5,984,01867 553,707.60 3.79 3,329.02 MWD+IFR-AK-CAZ-SC(5) 11,423.82 89.83 7.70 3,802.81 3,710.19 3,422.30 4,165.24 5,984,112.02 553,719.55 0.31 3,422.30 MWD+IFR-AK-CAZ-SC(5) 11,51823 89.92 7.00 3,803.02 3,710.40 3,515.93 4,177.32 5,964,205.72 553,731.01 0.75 3,515.93 MWD+IFR-AK-CAZ-SC(5) 11,61240 90.76 6.68 3,802.46 3,709.84 3,609.43 4,188.53 5,984,299.28 553,741.60 0.95 3,609.43 MWD+IFR-AK-CAZSC(5) 11 704.20 91.41 6.33 3,800.72 3,708.10 3,700.62 4,198.93 5,984,39053 553,751.40 0.80 3,700.62 MWD+IFR-AK-CAZSC (5) 11,796.49 91.86 5.60 3,7W(M) 3,705.47 3,792.37 4,208.52 5,984,482.34 553,760.3B 0.93 3,792.37 MWD+IFR-AK-CAZ-SC(5) 11,888.13 9242 3.35 3,79466 3,702.04 3,883.66 4,215.66 5,984,57366 553,766.92 2.53 3,883.66 MWD+IFR-AK-CAZ-SC(5) 11,980.01 91.72 2.97 3,791.34 3,69812 3,975.34 4,220]2 5,984,665.36 553,771.37 0.87 3,975.34 MWD+IFR-AK-CAZ-SC(5) 12,071.11 91.00 4.38 3,789.18 3,6%.56 4,066.23 4,226.56 5,984,756.28 553,77861 1.74 4,066.23 MWD+IFR-AK-CAZ-SC(5) 12,162.50 89.79 4.96 3,788.55 3,695.93 4,157.31 4,234.00 5,964,847 40 553,78346 1.47 4.157.31 MWD+IFR-AK-CAZ-SC(5) 12,255.25 88.48 4.56 3,78995 3,697.33 4,249.73 4,241.70 5,984,939.85 553,790.53 1.48 4,249.73 MWD+IFR-AK-CAZ-SC(5) 12,347.06 87.76 2.10 3,792.96 3,700.34 4,341.33 4,247.03 5,985,03148 553,7%.25 2.79 4,341.33 MW0+1FR-AK-CAZ-SC(5) 12,439.47 88.05 357.72 3,7%.34 3,703.72 4,433.65 4,246.88 5,985,12379 553,794.49 4.75 4,43365 MWD+IFR-AK-CAZ-SC(5) 12,532.42 88.10 354.48 3,799.47 3,706.85 4,526.32 4,240.56 5,985,21641 553,78256 3.48 4,526.32 MWD+IFR-AK-CAZ-SC(5) 12,623.39 89.63 349.63 3,801.27 3,708.65 4,616.37 4,228.00 5,985,30636 553,774.40 5.59 4,616.37 MWD+IFR-AK-CAZ-SC(5) 12,715.20 89.37 346.85 3,802.07 3,709.45 4,706.24 4,209.29 5,985,396.10 553,755.10 3.04 4,706.24 MWD+IFR-AK-CAZ-SC(5) 12,807.77 86.09 34239 3,80514 3,713.12 4,7%40 4,188.67 5,985,486.11 553,733.89 3.59 4,796.40 MWD+IFR-AK-CAZSC(5) 12,899.26 89.26 347.33 3,809.45 3,716.83 4,885.59 4,16867 5,985,575.15 553,713.30 3.47 4,885.59 MWD+IFR-AK-CAZSC(5) 12,991.71 90.40 344.51 3,809.72 3,71210 4,975.25 4,146.18 5,985,664.66 553,690.22 3.29 4,975.25 MWD+IFR-AK-CAZSC(5) 13,083.97 88.42 338.76 3,810.67 3,718.05 5,062.76 4,117.13 5,985,751.97 553,660.59 6.59 5,062.76 MWD+IFR-AK-CAZSC(5) 13,13160 89.23 334.91 3,811.64 3,71962 5,105.98 4,09&63 5,985,795.06 553,641.81 8.36 5,105.98 MWD+IFR-AK-CAZSC(5) 13,176.50 90.90 329.92 3,811.59 3,718.97 5,146.30 4,077.57 5,985,835.23 553,620.49 11.56 5,146.30 MWD+IFR-AK-CAZ-SC(5) 13,268.58 92.77 328.84 3,808.64 3,716.02 5,225.49 4,030.70 5,985,914.11 553,573.10 2.34 5,22549 MWD+IFR-A -W-SC(5) 13,36042 9364 328.15 3,803.50 3,710.88 5,303.67 3,982.78 5,%5,991.% 553,52467 1.21 5,303.67 MWD+IFR-AK-CAZ-SC(5) 13,451.57 9260 328.13 3,798.54 3,705.92 5,380.97 3,934.74 5,986,068.93 553,476.12 1.14 5,380.97 MWD+IFR-AK-CAZ-SC(5) 13,545.62 91.95 324.98 3,794.81 3,702.19 5,459.38 3,882.% 5,985,14699 553,423.82 3.42 5,45938 MWD+IFR-AK-CAZ-SC(5) 13,637.33 91.38 321.08 3,792.14 3,699.52 5,532.60 3,827.83 5,986,21984 553,368.22 4.30 5,532.60 MWD+IFR-AK-CAZ-SC(5) 13,72995 89.78 31462 3,791.20 3,698.58 5,601.23 3,765.72 5,98(3,28804 553,305.88 7.18 5,60123 MWD+IFR-AK-CAZ-SC(5) 13,821.41 90.35 31227 3,791.10 3,698.48 5,664.12 3,699.32 5,986,35049 553,238.85 2.64 5,664.12 MWD+IFR-AK-CAZ-SC(5) 13,913.93 9094 311.34 3,79[1.06 3,697.44 5,725.79 3,630.36 5,986,411.69 553,16949 1.19 5,725.79 MWD+IFR-AK-CAZ-SC 15) 14,003.71 90.72 308.19 3,788.76 3,696.14 5,783.20 3,561.36 5,986,468.64 553,100.12 3.52 5,783.20 MWD+IFR-AK-CAZ-SC(5) 14,095.72 90.72 3%.46 3,787.60 3,694.98 5,838.98 3,488.20 5,986,523.93 553,026.60 1.88 5,838.98 MWD+IFR-AK-CAZSC(5) 14,187.95 90.90 304.48 3,786.30 3,693.68 5,892.49 3,413.10 5,986,576.94 552,951.16 2.16 5,892.49 MWD+IFR-AK-CAZSC(5) 14,280.41 90.62 302.04 3,785.07 3,692.45 5,943.19 3,335.80 5,9%,627.12 552,873.53 2.66 5,943.19 MWD+IFR-AK-CAZSC(5) 14,373.09 90.62 30163 3,784.07 3,69145 5,992.08 3,257.07 5,986,675.48 552,794.48 0.44 5,992.08 MWD+IFR-AK-CAZSC(5) 14,464.79 90.69 301.02 3,783.02 $69040 6,039.75 3,178.74 5,986,72263 552,715.85 0.67 6,039.75 MWD+IFR-AK-CAZSC(5) 14,55711 90.80 301.90 3,781.81 3,689.19 6,088.24 3,099.48 5,986,770.59 552636.28 0.95 6,088.24 MWD+IFR-AK-CAZSC(5) 14,978.58 90.72 30014 3,781.14 3,688.52 6,114.68 3,056.03 5,988796.74 552,592.66 2.29 6,11468 MWD+IFR-AK-CAZSC 5 14,652.00 9072 300.74 3,780.59 3,687.97 6,136.87 3,018.72 5,986,818.68 552,555.20 0.00 6,136.8] NOT an Actual Survey 4112" x "W' 10/182017 2:11:30PM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 11-1-102 Project: Kuparuk River Unit TVD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Well: 1H-102 North Reference: True Wellborn: 1H -102L4 Survey Calculation Method: Minimum Curvature Design: 1H-1021_4 Database: OAKEDMP2 Survey Final Definitive Survey Verified and Signed -off All targets and/or welt position objectives have been achieved. L] yes ❑ No 1 have checked to the best of my ability that the following data is correct: E) Surface Coordinates E) Declination & Convergence Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Eugng DLS Section (Trott) (ry (7 (usft) (usft) (usft) (usft) (/t) Itt) r/1007 (ft) Survey Tool Name 14,670.00 90.72 300.74 3,780.37 3,687.75 6.14607 3,00325 5,986,82778 552,539.67 0.00 6,146.07 PROJECTEDto TO Final Definitive Survey Verified and Signed -off All targets and/or welt position objectives have been achieved. L] yes ❑ No 1 have checked to the best of my ability that the following data is correct: E) Surface Coordinates E) Declination & Convergence 21 GRS Survey Corrections El Survey Tool Codes Brandon Tem le Digitally signed by Brandon Temple SLB DE: p Date: 2017.10.1814:19:20-08'00' Kelsey Hallford N avMbYr+L9'MVad ��dge'b{mP'Ygm Ytl4ocp'npdWi'a Client Representative: Date. 1 011 8112 01 7 10/182017 2:11:30PM Page 7 COMPASS 5000.14 Build 85 „ Cement Detail Report 11-1-102 String: Conductor Cement Job: DRILLING ORIGINAL, 8/22/201718:00 C€meM Details Description Cementing Star' Date ming End Date Wellbore Name Conductor Cement 1/11/2016 18:15 1/11/2016 22:15 1 H-102 Comment Cement Stages stage # 1 Description Conductor Cement Objective cement 20” 34" Top Depth (ftKB) Bottom Depth (ftKB) Fuil Retum? Vol Cement... Top Plug? Bum Plug? x 43.1 118.6 No No No Insulated Conductor in 42" hole Q Pump Ink (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 105.0 Drill Bit 118.6 131/21 Comment Cement Fluids 8 Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) 3500 mix 43.1 118.6 Yield (fPlsack) MIX H2O Ratio (gal/3a... Free Water (%) Density (Iblgal) Plastic Viscosity (Pa•$) Thickening Time (hr) CmprStr 7 (psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 11N4/2017 Cement Detail Report AM -, qW 111-102 String: Surface Casing Cement Job: DRILLING ORIGINAL, 8/22/2017 18:00 Cement Details Description Cementing Start Date Cementing Entl Date Wellbore Name Surface Casing Cement 8/25/2017 18:15 8/25/2017 22:07 1H-102 Comment Stage pumps up to 8 BPM 290 PSI DPP with 268 PSI FDPP. 23% F/O. While recip from 1,740-1770' MD. Pump maker sweep and observe back at 3,650 STKS. 12,000 Total stks pumped @ 8 BPM. UP WT = 117K DWN WT = 109K. Line up SLB pump 5 BBLS CW100, PT lines & chart 3,500 PSI test. Pump remainder CW for total BBLS of 40 @ 3.1 BPM 75 PSI DPP. 15% F/O. Batch up and pump'77.4 BBLS 10.5 PPG Mud Push. @ 3.5 BPM 115 PSI DPP. 19% F/O. Drop BTM plug. Batch and pump 296 BBLS of 11# cement ( yield 1.91 cuf /sx, mix water 6.828 gal/sx, thickening time 6hr 22 min) @ 5.6 BPM 180 PSI DPP, 21 % F/O. Balch and pump 61.9 BBLS 12# tail cement (yield 1.65 cuft/sx, mix water 5.733 gal/sx, thickening time 4 hr 1 min) and pump at 4 BPM 164 PSI DPP with 19% F/O. Drop top plug and pump with 10 BBLS H2O, UP WT = 111K-DWN WT= 95K. Chase cement with ng pumps utilizing 9.6# mud @ 5 BPM 330 PSI 31-55% F/O. from 1356 STKS reduce rate to 3 BPM 300 PSI FCP 56% Flo. Bump plug at 1,502 STKS at 2207. increase pressure to 1,082 PSI and hold for 5 min. Bleed off pressure and check floats. GOOD. Cement in place at 2207 hrs. Recip until last 30 bills pumped. Circulated contaminated cement to surface 67.7 bbls prior to bumping the plug, circulated 9 bbis of good 11. ppg cement to surface. CIP 2207 his 8/25/2017. Cement Stages Stage # 1 Description Objective Top Depth (RKB) Bottom Depth (ftHB) Full Retum? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement Cement 10 314" 42.0 1,777.0 Yes 9.0 Yes Yes Q Pump Ink (bbllm... Q Pump Final (bb9... Q Pump Avg (bbll... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (R) Rotated? Pipe RPM (rpm) 5 3 5 286.0 1,082.0 Yes 30.00 No Tagged Depth (ttKB) Tag Method Depth Plug Drilled Out To tkKB] Drill Out Diameter (in) Drill Bit 1,777.0 97/8 Comment Stage pumps up to 8 BPM 290 PSI DPP with 268 PSI FDPP. 23% F/O. While recip from 1,740-1770' MD. Pump maker sweep and observe back at 3,650 STKS. 12,000 Total stks pumped @ 8 BPM. UP WT = 117K DWN WT = 109K. Line up SLB pump 5 BBLS CW100, PT lines & chart 3,500 PSI test. Pump remainder CW for total BBLS of 40 @ 3.1 BPM 75 PSI DPP. 15% F/O. Batch up and pump 77.4 BBLS 10.5 PPG Mud Push. @ 3.5 BPM 115 PSI DPP. 19% F/O. Drop BTM plug. Batch and pump 298 BBLS of 11# cement ( yield 1.91 cuR/sx, mix water 6.828 gal/sx, thickening time 6hr 22 min) @ 5.6 BPM 180 PSI DPP, 21 % F/O. Batch and pump 61.9 BBLS 12# tail cement (yield 1.65 cuf 1sx, mix water 5.733 gal/sx, thickening time 4 hr 1 min) and pump at 4 BPM 164 PSI DPP with 19% F/O. Drop top plug and pump with 10 BBLS H2O, UP WT = 111 K-DWN WT = 95K. Chase cement with rig pumps utilizing 9.6# mud @ 5 BPM 330 PSI 31-55% F/O. from 1356 STKS reduce rate to 3 BPM 300 PSI FCP 56% F/O. Bump plug at 1,502 STKS at 2207. increase pressure to 1,082 PSI and hold for 5 min. Bleed off pressure and check floats. GOOD. Cement in place at 2207 hrs. Recip until last 30 bbls pumped. Circulated contaminated cement to surface 67.7 bbls prior to bumping the plug, circulated 9 bbls of good 11. ppg cement to surface. CIP 2207 his 8/25/2017. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (106) Est Btm (fd(a) Amount (sacks) Class Volume Pumped (bbl) MudPush II 77.4 Yield tit'/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (lb/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 10.60 I I Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (RKB) Est Bum (RKB) Amount (sacks) Class Volume Pumpetl (bbl) Lead Cement 42.0 1,250.2 876 1 298,0 Yield (ft'/sack) Mix H2O Ratio (gadsa... free Water (%) Density pblgal)Plastic Viscosity (Pa -s) Thickening Time (hr) Cmpr3(r 1 (psi) 1.91 6.83 11.00 6.37 Additives Additive Type Concentration Cone Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Cone Unit label D185 Dispersant 0.08 %BWOC Additive Type Concentration Cone Unit label D177 Retarder 0.02 gaVsx Fluid Fluid Type Fluid Description Estimated Top (kKB) Est Btm (kKB)Amount (sacks) Class Volume Pumpetl (bbl) Tail Cement 1,250.2 1,777.0 211 1 61.9 Yield fwlsack) Mix H2O Ratio (gallsa... Free Water (%) Density (Intgal) Plastic Viscosity (Pa -s) Thickening Time (hd CmprStr 1 (psi) 1.65 5.73 1 12.02 I 4.00 Additives Additive Type Concentration Cone Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Cone Unit label D185 Dispersant 0.1 %BWOC Additive Type Concentration Cone Unit label D177 Retarder 0.005 gal/sx Page 112 ReportPrinted: 11114/2017 a -I Cement Detail Report qW IH-102 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 8/22/2017 18:00 Cement Detalle Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 9/31201703,00 9/312017 06:10 1H-102 Comment Pump cement job as follows: SLB pump 5 bills freshwater and pressure test lines to 400 / 3500 psi - good test. Pump 50 bible 12.5ppg Mudpush at 3 bpm, ICP 450 psi, FCP 210 psi. Drop Davis Lynch anti-rotational bottom plug. Batch mix cement, cement wet at 03:46 his. SLB pump total of 239.3 bbis 15.8ppg Class G cement. Pumped 170 bbis at 6 bpm, ICP 459 psi, FCP 315 psi. Then observe "H" pump fail so swap to 'I pump which has slightly lower rate capacity. Did not have to stop pumping but rate briefly dropped to -3 bpm. Continue pumping additional cement at -4.5 bpm, ICP 230 psi, FCP 190 psi. Drop Davis Lynch anti- rotational top plug. SLB pump 10 bbis freshwater at 4 bpm, 120 psi. Reciprocate pipe -15 ft, PUW 220k, SOW 95k. Swap to rig mud pump #1 and displace cement with 9.3ppg LSND at 8 bpm for 3250 strokes, ICP 242 psi, FCP 1587 psi. Drop rate to 3 bpm and continue displacing cement, ICP 1120 psi. Bump plug at 3797 strokes, FCP 1423 psi. Pressure up to 2000 psi and hold for 5 minutes. Bleed off and check floats - floats holding. Cement in place @ 06:10 hrs. Note: Total downhole losses throughout cement job = 11 bbis Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing Cement Intermediate 4,250.0 6,591.0 No Yes Yes Cement casing Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (btill... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotatetl? Pipe RPM (rpm) 6 3 6 1,423.0 2,085.0 Yes 15.00 No lagged Depth (ftKB) Tag Methotl Depth plug Grilled Out To (ftlte) Drill Out Diameter (in) Comment 63/4 Pump cement job as follows: SLB pump 5 bills freshwater and pressure test lines to 400/3500 psi - good test. Pump 50 bible 12.5ppg Mudpush at 3 bpm, ICP 450 psi, FCP 210 psi. Drop Davis Lynch anti-rotational bottom plug. Batch mix cement, cement wet at 03:46 hrs. SLB pump total of 239.3 bbls 15.8pp9 Class G cement. Pumped 170 bbis at 6 bpm, ICP 459 psi, FCP 315 psi. Then observe "H" pump fail so swap to "G" pump which has slightly lower rate capacity. Did not have to stop pumping but rate briefly dropped to -3 bpm. Continue pumping additional cement at -4.5 bpm, ICP 230 psi, FCP 190 psi. Drop Davis Lynch anti- rotational top plug. SLB pump 10 bbls freshwater at 4 bpm, 120 psi. Reciprocate pipe -15 ft, PUW 220k, SOW 95k. Swap to rig mud pump #1 and displace cement with 9.3ppg LSND at 8 bpm for 3250 strokes, ICP 242 psi, FCP 1587 psi. Drop rate to 3 bpm and continue displacing cement, ICP 1120 psi. Bump plug at 3797 strokes, FCP 1423 psi. Pressure up to 2000 psi and hold for 5 minutes. Bleed off and check floats - floats holding. Cement in place @ 06:10 hrs. Note: Total downhole losses throughout cement job = 11 bbis Cedtent Fluids & Additives Fluid Fluid Type Fluid Description Estimatetl Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push 3,317.0 4,250.0 50.0 Yield (ft /sack) Mix H2a Ratio (gause... rise Water (%) Density (Ib/gal) Plastic Viscosity (Pa•s) Thickening Time (hr) CmprStr 1 (psi) 12.50 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB)Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Cement 4,250.0 8,591.0 1,159 G 239.3 Yield (ft /sack) Mix H2O Ratio (gausa... Free Water (%)Density (Iwilay Plastic viscosity (Pa s) I ntckening Time (hr) CmprStr 7 (psi) 1.16 5.12 15.80 4.30 Additives Additive Type Concentration Cone Unitlabel 0255 aFluid Loss 0.5 %BWOC a Type ion Co D047Concentratnc Unit label Antifoam Additive 0.05 gaysx .ugi Type Conc Conc Concentration Unit label 0065 Dispersant 0.3 %BWOC i^ea '^ ReportPrinted: 11114120171 RECEIVED OCT 2 6 2017 berger AOGCC Transmittal #: 260CT17-SP05 Drilling & Measurements Product Delivery Customer: ConocoPhillips Alaska Dispatched To: Well Name: 1H-10214 Service Order #: 17AKA0021 Date Dispatched: DATA LOGGED k\ / A /201'1 M K BENDEP AOGCC: Makana Bender 26 -Oct -17 Dispatched By: Stephanie Pacillo Product Description Hardcopy Digital CopV Logging Date Color Log Prints: 4 Contents on CD 15 -Oct -17 Scope Resistivity 2" MD x x 2" TVD x x 5" MD x x 5" TVD x x Digital Data N/A Contents on CD LAS/DLIS Data x Surveys 2 Contents on CD Directional Survey Nad27 x x Directional Survey Nad83 x x CD 1 Contents on CD Data: DLIS/ LAS x Graphics: PDF x Surveys: PDF/TXT x Please sign and email a copy to: Please sign and email a copy to: Tom Osterkamota")conocoohillips com AlaskaPTSPrintCenter(a)slb com Attn: Tom Osterkamp Attn: Stephanie Pacillo Received By: 21 7105 28 75 2 RECEIVED OCT 2 6 2017 FINAL AOGCC NADConversion Kuparuk River Unit Kuparuk 1H Pad 1H -102L4 1H -102L4 NAD 27 ConocoPhillips Definitive Survey Report 18 October, 2017 21 7105 28 75 2 ConocoPhillips ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1H-102 Project: Kuparuk River Unit TVD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 11-1-102 actual @ 92.62usft (Doyon 142) Well: 1H-102 North Reference: True Wellbore: 1H-10214 Survey Calculation Method: Minimum Curvature Design: 1H-10214 Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States 38.62 Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) (usft) Using Well Reference Point Map Zone: Alaska Zone 04 lush) Using geodetic scale factor Well 11-1-102 Well Position +N/-8 0.00 usft Northing: 5,980,662.56 usft Latitude: 70° 21'28.630 N +EI -W 0.00 usft Easting: 549,577.46 usft Longitude: 149'35'50.423 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 54.00 usft Nellbore 111-10214 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°I (nT) BGGM2017 10/13/2017 17.45 80.94 57,488 Design 1H-10214 Data Gyrodata gyro single shots From To Audit Notes: (usft) (usft) Survey (Wellbore) Tool Name 67.62 Version: 1.0 Phase: ACTUAL Tie On Depth: 7,293.52 Vertical Section: Depth From (TVD) -NI-S +El -W Direction MWD -INC _ONLY (usft) (usft) (usft) (1) TVD 38.62 0.00 0.00 0.00 rey Program Data Gyrodata gyro single shots From To MWD+IFR AK CAZ SCC (usft) (usft) Survey (Wellbore) Tool Name 67.62 1,009.261H-102 Srvy 1- SLB _GWD70(1 H-102) GYD-GC-SS 1,050.36 1,678.041H-102 Srvy 2 -SLB MWD+GMAG(1 H. MWD+IFR-AK-CAZ-SC 1,777.33 7,293.521H-102 Srvy 3-SLB_MWD+GMAC It H- MWD+IFR-AK-CAZ-SC 7,377.00 7,480.661H-10214 Srvy 1-SLB_MWD-INC_FiHer MWD -INC _ONLY 7,575.34 14,608.581H-10214 Srvy 2-SLB_MWD+GMAG (1 MWD+IFR-AK-CAZ-SC Description Survey Date Gyrodata gyro single shots 8/24/2017 10:04 MWD+IFR AK CAZ SCC 8124/2017 10:12 MWD+IFRAKCAZSCC 8/27/2017 12:16 MWD -INC -ONLY _ FILLER 10/9/2017 10:13 MWD+IFRAKCAZSCC 10/9/2017 12:53 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) lush) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 38.62 0.00 coo 38.62 -54.00 0.00 0.00 5,980,662.56 549,577.46 0.00 0.00 UNDEFINED 67.62 0.19 41.29 67.62 -25.00 0.04 0.03 5,980,66260 549,577.49 0.66 0.04 GYD-GC-SS(1) 165.90 0.45 132.01 165.90 73.28 -0.10 043 5,980,662.46 549,577.89 0.50 -0.10 GYD-GC-SS(1) 258.98 1.01 128.15 258.97 166.35 -0.85 1.34 5,980,661.72 549,578.81 0.60 -0.85 GYD-GC-SS(1) 354.48 3.34 138.19 354.40 261.78 -3.44 3.86 5,980,659.14 549,581.34 246 -3.44 GYD-GC-SS(1) 447.17 4.61 13526 448.86 354.24 -8.1D 8.28 5,980,654.51 549,58539 1.39 -8.10 GYD-GC-SS(1) 539.82 537 132.42 539.13 446.51 -13.89 14.34 5,980,848.77 549,591.89 1.28 -13.89 GYD-GC-SS(1) 632.84 761 134.49 631.51 538.89 -21.36 22.19 5,980,641.35 549,599.79 1.99 -21.36 GYD-GC-SS (1) 725.82 8,77 137.82 723.54 630.92 -30.93 31.34 5,980,631.84 549,609.00 1.35 -30.93 GYD-GC-SS(1) 821.24 10.73 141.32 817.58 724.96 -03.25 41.78 5,980,619.59 549,619.52 2.15 43.25 GYD-GC-SS(1) 107152017 2,11:30PM Page 2 COMPASS 5000.14 Build 85 1 � ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1H-102 Project: Kuparuk River Unit TVD Reference: IH -102 actual @ 92.62usft (Doyon 142) Site: Kupamk 1 H Pad MD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Well: 1H-102 North Reference: True Wellborn: 1H-1021-4 Survey Calculation Method: Minimum Curvature Design: 1 H-1021.4 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 914.20 12.89 139.61 908.57 815.95 -57.91 53.90 5,980,605.01 549,63174 2.35 -57.91 GVD-GC-SS(1) 1,009.26 1489 136.85 1,000.84 908.22 44.90 69.13 5,980,588.13 549,647.08 2.22 -74.90 GVD-GC-SS(1) 1,050.36 15.72 135.96 1,040.49 947.87 -82.75 76.61 5.980,580.32 549,654.61 2.10 -82.75 MWD+IFR-AK-CAZ-SC (2) 1,144.89 17.17 134.37 1,131.15 1,038.53 -10172 95.49 5,980,561.49 549,673.61 1.61 -101.72 MWD+IFR-AK-CAZ.SC(2) 1,239.16 20.84 134.25 1,220.26 1,127.64 -123.16 117.46 5,98,540.20 549,695.72 3.89 -123.16 MWD+IFR-AK-CAZ-SC(2) 1,334.20 2411 136.54 1,307.88 1,21526 -149.38 143.24 5,980,514.14 549,721.67 4.18 -149.38 MWD+IFR-AK-CAZ-SC(2) 1,428.98 27.54 137.49 1,392.97 1,300.35 -179.92 171.68 5.98,483.80 549,750.31 3.02 -179.92 MWD+IFR-AK-CAZ-SC(2) 1,523.25 28.14 137.93 1,476.33 1,383.71 -21249 201.30 5,980,451.43 549,780.14 0.67 -21249 MWD+1FR-AK-CAZ-8C(2) 1,618.09 28.94 137.33 1,559.64 1,467.02 -245.96 231.84 5.9W,418 16 549,810.90 0.90 -245.96 MWD+IFR-AK-CAZ-SC(2) 1,67804 29.99 135.80 1,611.84 1,519.22 -26737 252.11 5,980,396.89 549,831.31 2.15 -267.37 MWD0FR-AK-CAZ-SC(2) 1,771.00 33.38 135.72 1,690.93 1,598.31 -302.34 286.17 5,980,362.15 549,865.60 3.65 -302.34 NOT an Actual Survey 10 3/4" x 13-1/2" 1J77.33 33.61 135.72 1,696.21 1,603.59 -304.85 288.61 5,980,359.66 549,868.06 3.65 -3D4.85 MWD+IFR-AK-CAZ-SC (3) 1,80161 34.53 134.79 1,716.32 1,623.70 -314.50 298.19 5,980,350.07 549,877.69 4.35 -31450 MWD+IFR.AK-CAZ-SC(3) 1,896.66 37.81 133.50 1,793.04 1,700 42 -353.55 338.45 5,980,311.29 549,918.21 3.54 -353.55 MWD+IFR-AK-CAZ-SC (3) 1,99193 40.86 13183 1,866.72 1,774.10 -394.45 382.87 5,980,270.70 549,962.89 3.39 -394.45 MWD+IFR-AK-CAZ-SC(3) 2,086.48 43.97 130.99 1,936.52 1,843.90 -43661 430,70 5,980,228.85 550,011.00 3.34 43861 MWD+1FR-AK-CAZ-SC 13) 2,184.36 47.16 129.49 2,00504 1,912.42 -481.73 484.06 5,980,184.09 550,064.65 344 -481.73 MWD+IFR-AK-CAZ-SC(3) 2,276.23 50.08 12877 2,065.76 1,973.14 -525.22 537.53 5,980,140.96 550,118.40 3.23 -525.22 MWD+1FR-AK-CAZ-SC(3) 2,371.48 53.12 127.35 2,124.92 2,032.30 -571.22 5%.31 5,980,095.36 550,177.48 3.40 -571.22 MWD+IFR-AK-CAZ-SC(3) 2,464.98 55.35 12447 2,179.57 2,086.95 -615.68 65776 5,980,051.30 550,239.21 3.45 -615.68 MWD+IFR-AK-CAZ-SC(3) 2,559.60 56.73 122.73 2,23243 2,13981 -659.10 723.12 5,980,008.32 550,304.86 2.11 -659.10 MWD+1FR-AK-CAZ-SC(3) 2,653.87 58.79 122.43 2,282.72 2,190.10 -702.03 790.31 5,979,965.84 550,372.32 2.20 -702.03 MWD+IFR-AK-CAZ-SC(3) 2,748.30 59.37 121.74 2,331.24 2,238.62 -745.06 858.95 5,979,923.27 550,441.23 0.88 -745.06 MWD+IFR-AK-CAZ-SC (3) 2,843.07 6140 121.48 2,378.07 2,28545 -788.24 929.11 5,979,880.56 550,511.67 2.16 -788.24 MWD+IFR-AK-CAZ-SC(3) 2,937.25 65.11 121.93 2,420.45 2,32783 -832.44 1000.65 5,979,83684 550,583.50 3.96 -83244 MWD+IFR-AK-CAZ-SC(3) 3,032.88 69.13 121.16 2,457.62 2,365.00 -878.52 1,075.72 5,979,791.27 550,658.87 4.27 -878.52 MWD+IFR-AK-CAZ-SG(3) 3,126.86 71.43 121.37 2.489.33 2,396.71 -92443 1,151.34 5,979,745.86 550,734.78 2.46 -92443 MWD+IFR-AK-CAZ-SC(3) 3,221.95 72.62 121.37 2,51867 2,426.05 -971.51 1,228.56 5,979,69929 550,812.31 1.25 -971.51 MWD+1FR-AK-CAZ-SC(3) 3,316.46 7303 121.69 2,546.58 2,453.96 -1,018.73 1,305.53 5,979.652.59 550,889.57 0.54 -1,018.73 MWD+IFR-AK-CAZ.SC(3) 3,410.86 73.34 122.71 2,573.89 2,481.27 -1,066,89 1,381.99 5,979,604.95 550,966.35 1.09 -1,066.89 MWD+IFR-AK-CAZ-SC(3) 3,506.07 73.21 122.55 2,601.29 2,508.67 -1,116.05 1,458.78 5,979,556.30 551,04345 0.21 -1,116.05 MWD+IFR-AK-CAZ-SC(3) 3,601.42 73.21 122.70 2,628.83 2,536.21 -1,16527 1,535.66 5,979,507.59 551,120.65 0.15 -1,165.27 MWD+IFR-AK-CAZ-SC (3) 3,696.85 73.21 122.29 2,656.40 2,563.78 -1,21435 1,612]2 5,979,459.03 551,198.03 0.41 -1,214.35 MWD+IFR-AK-CAZ-SC(3) 3,79146 73.30 120.98 2,683.66 2,591.04 -1,261.87 1,689.85 5,979,412.03 551,275.46 1.33 -1,261.87 MWD+IFR-AK-CAZ.SC(3) 3,886.74 73.14 118.95 2,711.17 2.618.55 -1,307.43 1,768.88 5,979,36699 551,35438 2.05 -1,307.43 MWD+IFR-AK-CAZ-SC(3) 3,981.94 73.09 119.64 2,738.82 2,646.20 -1,352.00 1,848.32 5,979,322.95 551,434.51 0.70 -1,352.00 MWD+IFR-AK-CAZ-SC (3) 4,076.41 73.30 119.87 2,766.13 2,673.51 -1,396.88 1,926.84 5,979,27859 551,513.31 0.32 -1,396.88 MWD+IFR-AK-CAZ-SC(3) 4,171.02 73.17 118.99 2,793.42 2,700.80 -1,441.40 2,005.73 5,979,234.61 551,592.49 0.90 -1,44140 MWD+IFR-AK-CAZ-SC(3) 4,266.02 7306 119.53 2,821.02 2,728.40 -1A85.83 2,085.04 5,979,190.71 551,672.08 0,56 -1485.83 MWD+IFR-AK-CAZ-SC(3) 4,360.46 73.01 119.04 2,848.57 2,75595 -1, 53D.01 2,163.83 5,979,147.05 551,751.15 0.50 -1,530.01 MWD+IFR-AK-CAZ-SC(3) 107182017 2.11:30PM Page 3 COMPASS 500014 Blind 85 I I Conocophillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1H-102 Project: Kuparuk River Unit TVD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Site: Kupamk 1 H Pad MD Reference: 1H-102 actual Q 92.62usft (Doyon 142) Well: 1H-102 North Reference: True Wellbore: 1 H-10214 Survey Calculation Method: Minimum Curvature Design: 1H -102L4 Database: 0AKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +EI -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,455.58 72.90 119.77 2,876.45 2,783.83 -1,574.66 2,243.05 5,979,10293 551,830.66 0.74 -1,574.66 MWD+IFR-AK-CAZ-SC(3) 4,549.81 72.87 120.06 2,904.19 2,811.57 -1,619.57 2,321.11 5,979,058.54 551,909.01 0.30 -1,6%57 MWD+IFR-AK-CAZ-SC (3) 4,644.52 73.20 118.40 2,931.82 2,839.20 -1663.81 2,400.16 5,979,014.84 551.988.35 1.71 -1,663.61 MWD+IFR-AK-CAZ-SC(3) 4,739.99 72.42 114.51 2,98005 2,867.43 -1,70444 2,481.79 5,978,97475 552,070.24 3.98 -1,704.44 MWD+IFR-AK-CAZ-SC(3) 4,786.24 72.31 110.47 2,974.06 2,88144 1,721.29 2522.51 5,978,958.17 552,111.08 8.33 -1,721.29 MWD+IFR-AK-CAZ.SC(3) 4,833.76 7248 108.23 2,98844 2,895.82 -1,736.30 2,565.24 5,978,94345 552,153.89 4.51 -1,736.30 MWD+IFR-AK-CAZ-SC(3) 4,928.09 72.21 103.78 3,017.06 2,924.44 -1761.08 2,651.62 5,978,919.24 552,24042 4.50 -1,761.08 MWD+IFR-AK-CAZ-SC(3) 5,022.87 71.11 100.68 3,046.89 2,954.27 -1,780.14 2,739.52 5,978,900.76 552,328.44 331 -1,780.14 MWD+IFR-AK-CAZ-SC(3) 5,07023 71.27 98.69 3,062.16 2,969.54 -1,787.68 2,783.71 5,978,893.52 552,372.67 3.99 -1787.68 MWD+IFR-AK-CAZ-SC(3) 5,116.77 71.68 96.97 3,07695 2,984.33 -1,79369 2,82743 5,978,887.79 552,416.42 3.61 -1,793.69 MWD+IFR-AK-CAZ-$C(3) 5,211.19 72.12 93.77 3,106.29 3,013.67 -1,802.09 2,916.77 5,978.87899 552,505.81 3.25 -1,802.09 MWD+IFR-AK-CAZ-SC(3) 5,30575 7174 W59 3.135.64 3,04302 -1,803.94 3,006.61 5,978,878.73 552,59565 5.22 -1,803.94 MWD+IFR-AK-CAZ-SC(3) 5,400.08 71.70 83.77 3,165.24 3,072.62 1,797.98 3,095.95 5,978,885.29 552,684.94 4.85 -1797.98 MWD+IFR-AK-CAZ-SC (3) 5,495.26 72.32 81.29 3,194.64 3,102.02 -1,786.21 3,185.70 5,978,89765 552,774.60 2.56 -1,786.21 MWD+IFR-AK-CAZ-SC (3) 5,59001 72.15 76.05 3,223.57 3,130.95 -1,76849 3274.13 5,978,915.95 552,862.91 5.27 -1,768.49 MWD+1FR-AK-CAZ-SC(3) 5,685.45 7261 70.23 3,252.48 3,159.86 -1,742.11 3,361.14 5,978,942.90 552,949.73 5.83 -1,742.11 MWD+IFR-AK-CAZ-SC(3) 5,779.73 73.02 64.52 3,280.36 3,187.74 -1,70]48 3,444.24 5,978,978.08 553,032.59 5.80 -1,707.48 MWD+IFR-AK-CAZ-SC (3) 5,874.02 7387 63.54 3,307.23 3,214.61 -1,667.90 3,52549 5,979,018.19 553,113.57 1.34 -1,%%90 MWD+IFR-AK-CAZ-SC(3) 5,968.69 74.38 63:99 3,333.12 3,24050 -1,62764 3,607.17 5,979.058.98 553,194.97 0.71 -1,627.64 MWD+IFR-AK-CAZ-SC(3) 6,063.17 7461 63.93 3,358.38 3,265.76 -1.587.68 3,688.97 5,979,099.49 553,276.50 0.25 -1,587.68 MWD+IFR-AK-CAZ-SC(3) 6.156.98 74.68 58.30 3,383.23 3,290.61 -1,54401 3768.12 5,979,143.67 553,355.35 579 -1,544.01 MWD+IFR-AK-CAZ-SC(3) 6,252.33 74.03 54.53 3,408.96 3,316.34 -1,493.22 3,844.61 5.979,19496 553,431.50 3.87 -1,493.22 MWD+IFR-AK-CAZ-SC(3) 6,346.97 72.68 51.05 3,436.08 3,343.46 -1,438.41 3,916.82 5,979,250.25 553,503.33 3.80 -1,438.41 MWD+IFR-AK-CAZ-SC(3) 6,441.76 72.16 48.05 3464.71 3.372.09 -1,379.79 3.985.58 5,979,309.31 553.571.69 3.07 -1,379.79 MWD+IFR-AK-CAZ-SC(3) 6,537.27 73.10 4502 3,49323 3,400.61 -1.31709 4,051.72 5,979,372,44 553,637.42 3.18 -1,31709 MWD+IFR-AK-CAZ-SC(3) 6,58521 73.18 41.30 3,507.14 3,414.52 -1,283.63 4,083.10 5,979,406.11 553,668.57 7.43 -1,283.63 MWD+1FR-AK-CAZ-SC(3) 8632.17 7264 38.72 3,520.94 3,428.32 -1,249.25 4,111.% 5,979,440.67 553,697.19 5.38 -1,249.25 MWD+IFR-AK-CAZ-SC(3) 6,727.59 71.99 32.96 3,549.95 3,457.33 -1,17560 4,165.17 5,979,514.67 553,749.91 5.79 -1,175.60 MWD+IFR-AK-CAZ-SC(3) 6,822.80 72.62 27.41 3,578.91 3,486.29 -1,097.23 4,21074 5,979,593.33 553,794.96 5.59 -1,097.23 MWD+IFR-AK-CAZ-SC(3) 6,915.59 72.83 23.59 3,6WA8 3,513.86 -1,017.27 4,248.88 5,979673.53 553,832.57 3.94 -1,017.27 MWD+IFR-AK-CAZ-SC(3) 7,011.34 72.49 1950. 3,635.02 3,542.40 -932.28 4,282.44 5,979,758.73 553,865.% 4.09 -932.28 MWD+IFR-AK-CAZ-SC(3) 7,104.01 7390 18.26 3,661.82 3,569.20 -848.34 4,311.14 5,979,84285 553,893.70 1.99 -848.34 MWD+IFR-AK-CAZ.SC(3) 7,198.95 73.27 13.49 3,688.66 3,596.04 -760.78 4,336.05 5,979,930.57 553,918.03 4.86 -760.78 MWD+IFR-AK-CAZ-SC(3) 7,293.52 74.08 7.89 3,715.26 3,622.64 -671.64 4,352.87 5,980,019.81 553,93425 575 -671.64 MWD.lFR-AK-0AZ-SC (3) 7,377.00 74.47 4.54 3,737.89 3,645.27 -591.76 4,361.56 5,980,099.73 553,942.42 3.89 -591.76 N0TanActual3urvey 7-610" x 9.716" 7,390.60 75.83 4.00 3,741.38 3,64876 -578.66 4,362.54 5,980,112.85 553,943.31 10.71 -57886 MWD -INC ONLY(4) 7,480.66 79.20 5.00 3,760.84 3,668.22 -491.01 4,369.44 5,980,200.53 553,949.83 3.90 -491.01 MWD -NC _ONLY (4) 7,575.34 84.81 &00 3.774.01 3,681.39 -397.65 4,377.61 5,980,293.93 553,957.18 5.93 -397.65 MWD+IFR-AK-CAZ-SC(5) 7,631.80 90.33 5.30 3,77640 3,683.78 -341.49 4,382.67 5,980,350.12 553.961.87 9.79 -341.49 MWD+IFR-AK-CAZ-SC(5) 10/18/2017 2.11:30PM Page 4 COMPASS 5000.14 Build 85 I ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 11-1-102 Project: Kuparuk River Unit TVD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Well: 1H-102 North Reference: True Wellbore: 1H-10214 Survey Calculation Method: Minimum Curvature Design: 11-1-1021.4 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azl TVD NDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (') (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,677.29 92.17 366 3,775.41 3,682.79 -296.15 4,386.23 5,98,395.48 553,96512 542 -296.15 MWD+IFR-AK-CAZ-SC(5) 7.775,65 93.32 358.47 3,770.70 3,678.08 -197,95 4,388.05 5,980,493.67 553,966.30 5.40 -19795 MWD+IFR-AK-CAZ-SC(5) 7,865.25 92.89 352.09 3,76584 3,673.22 -108.84 4,380.69 5,980,582.73 553,958.35 7.13 -108.84 MWD+IFR-AK-CAZ-SC(5) 7,916.66 92.50 353.16 3,763.42 3,670.80 -57.91 4,374.10 5,980.633.61 553,951.42 2.21 -57.91 MWD+IFR-AK-CAZ-6C (5) 8,012.54 92.03 35269 3,759.63 3,667.01 37.17 4,362.30 5,980,728.59 553,939.00 069 37.17 MWD+IFR-AK-CAZ-SC(5) 8,108.07 91.29 351.10 3,756.86 3,664.24 131.70 4,348.84 5,980,823.03 553,924.91 1.84 131.70 MWD+IFR-AK-CAZ-SC (5) 8,202.05 91.66 354.34 3,7&144 3,661.82 224.86 4,336.94 5,980.916.11 553,91239 347 224.88 MWD+IFR-AK-CAZ-SC (5) 8,297.04 81.10 355.52 3,752.16 3,659.54 31947 4,328.54 5,981,010.64 553,903.37 1:37 31947 MWD+IFR-AK-CAZ-SC(5) 8,391.90 90.59 355.57 3,750.76 3,658.14 414.03 4,321.18 5,981,105.14 553,895.38 0.54 414.03 MWD+IFR-AK-CAZ-SC(5) 6,485.70 89.75 356.26 3,750.48 3657.86 507.59 4,314.49 5,981,198.64 553,888.08 1.16 507.59 MWD+IFR-AK-CAZ-SC(5) 8,5130 35 B9.18 0.83 3,751.36 3,65874 602.18 4,312.09 5,981,293.21 553,885.05 4.87 602.18 MWD+IFR-AK-CAZ-SC(5) 8,675.09 88.14 1.55 3,753.58 3,660.96 696.87 4,314.06 5,981,387.90 553,886.39 1.34 69687 MWD+IFR-AK-CAZ-SC(5) 8,769.22 8825 4.56 3,756.54 3,663.92 790.81 4,319.07 5,981,481.86 553,890.78 3.20 790.81 MWD+IFR-AK-CAZ-SC(5) 8,864.59 8829 317 3,758.59 3665.97 88590 4,326.00 5,981,57699 553,897.08 1.37 885.90 MWD+IFR-AK-CAZ-SC(5) 8,959.46 89.85 2.69 3,759.30 3.686.68 980.62 4,331.34 5,981,671.73 553,901.80 128 980.62 MWD+IFR-AK-CAZ-SC (5) 9,054.39 89.13 359.26 3,760.15 3,66].53 1,075.52 4,332.96 5,98176663 553,802.78 3.69 1,075.52 MWD+1FR-AK-CAZ-8C(5) 9,149.46 89.19 357.10 3,76154 3,688.92 1,170.52 4,329.94 5,981,861.60 553,899.14 2.27 1,170.52 MWD+IFR-AK-CAZ-SC(5) 9.244.06 88.65 355.84 3,763.32 3.670.70 1,264.97 4,32494 5,981,956.01 553,893.51 0.63 1,264.97 MWD+IFR-AK-CAZ-SC(5) 9,339.46 88.46 356.90 3,76533 3,673.11 1,360.20 4,319.73 5,982,051.19 553,88]68 0.21 1,W020 MWD+IFR-AK-CAZ-SC(5) 9433.08 88.32 357.73 3,768.36 3,675.74 1,453.68 4,315.35 5.982,144.63 553,882.67 0.90 1,453.68 MWD+IFR-AK-CAZ-SC(5) 9,528.14 88.29 077 3,771.17 3,678.55 1,548.68 4,314.10 5,982,239.61 553,880.80 3.20 1,548.68 MWD+IFR-AK-CAZ-SC (5) 9622.81 87.96 2.92 3.774.27 3,681.65 1,643.24 4,317.15 5,982,3U 18 553,883.22 2.30 1,643.24 MWD+IFR-AK-CAZ-SC(5) 9,71962 89.52 4.58 3,776.40 3,68378 1139.82 4,323.48 5.982,430.76 553.888.91 2.35 1,739.82 10WD+IFR-AK-CAZ-SC(5) 9,811.75 8971 1.38 3,777.02 3,684.40 1,831.81 4,328.27 5,982,522.80 553.893.09 348 1,831.81 MWD+IFR-AK-CAZ-SC(5) 9,90699 91.12 356.51 3,776.33 3,6133.71 1,92700 4,32652 5,982,617.96 553.890.71 5.32 1,927.00 MWD+1FR-AK-CAZ-SC(5) 9,951.63 91.55 355.71 3,775.29 3,682.67 1,971.52 4,323.49 5,982,662.46 553,88739 2.03 1,971.52 MWD+IFR-AK-CAZ-SC(5) 10,002.07 9085 352.94 3,774.23 3,613161 2,021.70 4,318.50 5,982,712.60 553,88207 5.66 2,02110 MWD+IFR-AK-CAZ-SC(5) 10,096.45 9010 34963 3,772.96 3.680.34 2.114.97 4,304.21 5,982,805.76 553,867.16 3.51 2,114.97 MWD+IFR-AK-CAZ-SC(5) 10,191.82 89.75 347.85 3,772.56 3,679.96 2,208.50 4,285.58 5,982,899.16 553,847.92 2.12 2,208.50 MWD+IFR-AK-CAZ-SC(5) 10,286.69 89.36 344.77 3,773.32 3,680.70 2,30066 4,263.14 5,982,991.16 553,824.86 3.27 2,300.66 MWD+IFR-AK-CAZ-SC(5) 10,38145 89.05 345.67 3,77463 3,682.01 2,39227 4,238.96 5,983,08260 553,800.09 1.00 2,392.27 MWD+IFR-AK-CAZ-SC(5) 10,476.55 87.69 346.86 3,777.34 3,684.72 2,484.61 4,21839 5,983.17478 553,776.91 1.90 2,484.61 MWD+1FR-AK-CAZ-8C(5) 10,57094 8771 346.65 3,781.13 3,688.51 2,576.42 4,194.79 5,983,26843 553,754.69 022 2,576.42 MWD+IFR-AK-CAZ-SC(5) 10,666.13 87.35 348.71 3,785.23 3,692.61 2,669.32 4,17449 5,983,359.19 553,733.79 2.19 2,669.32 MWD+IFR-AK-CAZ-SC(5) 10,761.68 88.50 350.88 3,788.70 3,696.08 2,763.49 4,157.54 5,963,45324 553,716.22 2.56 2.76349 MWD+1FR-AK-CAZ-SC(5) 10,855.84 89.40 353.44 3.790.42 3,697.80 2,856.55 4,144]3 5,983,546.20 553,702.79 2.89 2,856.55 MWD+IFR-AK-CAZ-SC (5) 10,950.99 89.26 357.21 3.791.53 3,698.91 2,951.36 4,136.98 5,983,640.94 553,69441 3.96 2,951.36 MWD+IFR-AK-CAZ-SC(5) 11,046.51 88.51 359.84 3,793.39 3,700.77 3,046.82 4,134.52 5,983,736.38 553,691.32 2.86 3,046.82 MWD+IFR-AK-CAZ-SC(5) 11,140.94 8869 2.04 3,795.70 3.703.08 3,141.20 4,136.07 5,983830.76 553,692.25 2.34 3,141.20 MWD+IFR-AK-CAZ-SC(5) 11,235.07 86.08 5.25 3,799.34 3,706.72 3,235.05 4,142.04 5,983,924.64 553,697.60 3.91 3,235.05 MWD+IFR-AK-CAZ-SC(5) 101182017 2.11:30PM Page 6 COMPASS 5000.14 Build 85 I ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1H-102 Project: Kuparuk River Unit TVD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Weil: 1H-102 North Reference: True Wellbore: 1H -102L4 Survey Calculation Method: Minimum Curvature Design: 1H -102L4 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,32970 89.54 7.65 3,802.29 3,709.67 3,32902 4,152.67 5,984,01867 553,707.60 379 3,329.02 MWD+IFR-AK-CAZ-SC(5) 11,423.82 89.83 7.70 3,80281 3,710.19 3,422.30 4,165.24 5,984112.02 553,719.55 0.31 3,422.30 MWD+IFR-AK-CAZ-SC(5) 11,518.23 89.92 7.00 3,803.02 3,710.40 3,515.93 4,177.32 5,984,205.72 553,731.01 0.75 3,515.93 MWD+IFR-AK-CAZ-SC (5) 11,612.40 90.]6 6.68 3,80246 3.70984 3,609.43 4,188.53 5,984,299.28 553,741,60 0.95 3,609.43 MWD+IFR-AK-CAZ-SC(5) 11,704.20 91.41 6.33 3,800.72 3.708.10 3.700.62 4,198.93 5,984,390.53 553,751.40 0.80 3,700.62 MWD+IFR-AK-CAZ-SC (5) 11,796.49 91.88 560 3,79809 3,70547 3,792.37 4,208.52 5,984,482.34 553,760.38 0.93 3,792.37 MWDNFR-AK-CAZ-SC(5) 11,888.13 92.42 3.35 3,794.66 3,702.04 3,883.66 4,215.66 6,984,573.66 553,766.92 2.53 3,883.66 MWD+IFR-AK-CAZ-SC(5) 11,980.01 91.72 297 3,791.34 3,69832 3,975.34 4,22072 5.984,665.36 553.771.37 0.87 3.975.34 MWD+IFR-AK-CAZ-SC(5) 12,071.11 91.00 4.38 3,789.18 3.696.56 4,066.23 4,226.56 5,984,756.28 553.776.61 174 4.066.23 MWD+IFR-AK-CAZ-SC(5) 12,162.50 89.79 4.96 3,788.55 3,695.93 4,15731 4,234.00 5,984,847 40 553,78344 147 4,157.31 MWD+IFR-AK-CAZ-SC(5) 12,25525 88.48 4.56 3,789.95 3,697.33 4.249.73 4,241.70 5,984,939.85 553,790.53 1.48 4,249.73 MWD+IFR-AK-CAZ-SC(5) 12;347.07 8776 2.10 3,792.96 3,700.34 4,341.33 4,24703 5.965,03148 553.795.25 2.79 4,341.33 MWD+IFR-AK-CAZ-SC(5) 12,43947 88.05 357.72 3,796.34 3,703.72 4,433.65 4,246.88 5,985,12379 553,794.49 4.75 4,433.65 MWD+IFR-AK-CAZ-SC(5) 12,532.42 88.10 35448 3.79947 3,706.85 4,526.32 4,240.56 5,985,216.41 553,787.56 3.48 4,526.32 MWD+IFR-AK-CAZ-SC(5) 12,623.39 89.63 349.63 3,80127 3,708.65 4,616.37 4,228.00 5,965,306 36 553,774.40 5.59 4,616.37 MWD+IFR-AK-CAZ-SC(5) 12,71520 89.37 346.85 3,802.07 3,709.45 4,706.24 4,20929 5,985396.10 553,755.10 3.04 4,706 24 MWD+IFR-AK-CAZ-SC(5) 12,807.77 86.09 347.39 3,805.74 3,713.12 4,796.40 4,18867 5.985,486.11 553,733.89 3.59 4,70.40 MWD+IFR-AK-CAZ-SC(5) 12,89926 89.26 347.33 3,80945 3,71683 4,885.59 4,188.67 5985,575.15 553,71330 347 4,885.59 MW1)+IFR-AK-CAZ-SC(5) 12,99171 9040 344.51 3,809.72 3,717.10 4,975.25 4,146.18 5,985,664.66 553,690.22 3.29 4,975.25 MWD+IFR-AK-CAZ-SC(5) 13,083.97 88.42 338.76 3,81067 3,718.05 5,06276 4,117.13 5,985,751.97 553,660.59 6.59 5,06276 MWD+IFR-AK-CAZ-SC(5) 13,131.00 89.23 334.91 3,811,64 3,719.02 5,105.98 4,098.63 5,985,795.06 553,641.81 8.36 5,105.98 MWD+IFR-AK-CAZ-SC(5) 13,176.50 90.90 329.92 3,811.59 3,718.97 5,146.30 4,077.57 5,985,835.23 553,620.49 11.56 5,146.30 MW0+1FR-AK-CAZ-SC(5) 13,268.58 9277 328.84 3,80864 3,71602 5,22549 4,030.70 5,985,914.11 553,573.10 2.34 5,22549 MWD+IFR-AK-CAZ.SC(5) 13,360.42 9364 328.15 3,803.50 3,710.88 5,303.67 3,982.78 5,985,991.96 553,524.67 1.21 5,30367 MWD+IFR-AK-CAZ-SC(5) 13,451.57 92.60 328.13 3,798.54 3.705.92 5,380.97 3,934.74 5,986,068.93 553,476.12 1.14 5,380.97 MWD+IFR-AK-CAZ-SC(5) 13,545.62 91.95 324.98 3,794.81 3,702.19 5,459.38 3,882.95 5,986,146.99 553,42382 3.42 5,459.38 MWD+IFR-AK-CAZ-SC(5) 13,637.33 91.38 321.08 3,792.14 3,699.52 5,53280 3,827.83 5,986,21984 553,368.22 430 5,53260 MWD+IFR-AK-CAZ-SC(5) 13,729.95 89.78 314.62 3,791.20 3,698.58 5,601.23 3,765.72 5,986,288.04 553,305.66 7.18 5,601.23 MWD+IFR-AK-CAZ-SC(5) 13,821.41 90.35 312.27 3,791.10 3,698.48 5,664.12 3,699.32 5,986,35049 553,238.85 2.64 5,664.12 MWD+1FR-AK-CAZ-SC (5) 13,913.93 90.94 311.34 3,790.06 369744 5,72579 3.63036 5,988,41169 553,16949 1.19 5,72579 MW13+1FR-AK-CAZ-SC(5) 14,003.71 90.72 308.19 3,788.76 3,60.14 5,78320 3,561.36 5,986,468.64 553,100.12 3.52 5,783.20 MWD+IFR-AK-CAZ-SC(5) 14,095.72 90.72 306.46 3,787.60 3,694.98 5,838.98 3,488.20 5,986,52393 553,026.60 1.88 5,838.98 MWD+IFR-AK-CAZ-SC(5) 14,187.95 90.90 304.48 3.786.30 3,693.68 5,892.49 3,413.10 5,986,576.94 552,951.16 2.16 5,892.49 MWD+IFR-AK-CAZ-SC(5) 14,260.41 90.62 302.04 3,785.07 3,692.45 5,943.19 3,335.80 5,986,627.12 552,873.53 266 5,943.19 MWD+IFR-AK-CAZ-SC(5) 14,373.09 90.62 301.63 3,784.07 3,691.45 5,992.08 3,257.07 5,986,675.48 552,794.48 044 5,992.08 MWD+IFR-AK-CAZ-SC(5) 14,464.79 90.69 301.02 3,783.02 3,69040 6,039.75 3,178.74 5,986,72263 552,715.85 067 6,039.75 MW1)+IFR-AK-CAZ-SC(5) 14,557.71 90.80 301.90 3,781.81 3,689.19 6,088.24 3,099.48 5,985,770.59 552,636.28 0.95 6,088.24 MWD+IFR-AK-CAZ-SC(5) 14,608.58 90.72 300.74 3,781.14 3,688.52 6,114.68 3,056.03 5,986,796.74 552,592.66 2.29 6,114.68 90.72 300.74 3,780.59 3,68797 6,136.87 3,01872 5,986,81868 552,555.20 0.00 �KC14,65200 6,136.87 41/2" z 6-3/4" 10/182017 2.11:30PM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1H-102 Project: Kuparuk River Unit TVD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Well: 1H-102 North Reference: True Wellbore: 1H-1021.4 Survey Calculation Method: Minimum Curvature Design: 111-10214 Database: OAKEDMP2 Survey Map Map Verdcal MD Inc Azi TVD TVDSS -NI-S +E/ -W Northing Easdng OLS Section (usft) (') (°) (usft) (usft) (usft) (usft) (ft) (ft) (o/100') (ft) Survey Tool Name 14.670.00 9072 300.74 3,780.37 3.68775 6,146.07 3,003.25 5.986,82778 552,539.67 000 6,146.07 PROJECTED to TD Final Definitive Survey Verified and Signed -off All targets andlor well position objectives have been achieved. 7 Yes n No I have checked to the best of my ability that the following data is correct: p Surface Coordinates Q Declination & Convergence O GRS Survey Corrections 7, Survey Tool Codes Digitally si gned by Brandon Temple SLI3De Brandon Temple Date 2017.10.1814:19:20-08'00' Kelsey Hallford va�rd:v wibdQ[msy.�auwixokwmswwai., Client Representative: Date: 10118PO17 1011812017 2:11:30PM Page 7 COMPASS 5000.14 Build 85 RECEIVED OCT 2 6 2011 FINAL AOGCC ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad 1H -102L4 1 H-1 02L4 ConocoPhillips Definitive Survey Report 18 October, 2017 21 71 05 28 75 2 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 H-102 Project: Kuparuk River Unit TVD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Well: 1H-102 North Reference: True Wellbore: 1H -102L4 Survey Calculation Method: Minimum Curvature Design: 1H-10214 Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States TVDSS Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 (usft) Using Well Reference Point Map Zone: Alaska Zone 4 (usft) Using geodetic scale factor (usft) (ft) (ft) (-1100') Well 11-4-102 0.00 000 Well Position -NI-S 0.00 usft Northing: 5,980,414.37 usft Latitude: 70'21'27.583 N 5,980,414.37 +E/ -W 0.00 usft Easting: 1,689,609.08 usft Longitude: 149° 36' 1.638 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 54.00 usft Olellbore 1H-10214 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 11 (1 InT) BGGM2017 10/13/2017 17.45 80.94 57,488 Design 1H-10214 Date 10/18/2017 MWD+IFR AK CAZ SCC From Audit Notes: 8/27/2017 12:16 (usft) (usft) Survey (Wellbore) Version: 1.0 Phase: ACTUAL Tie On Depth: 7,293.52 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 7,293.521H-102 Srvy 3- SLB _MWD+GMAG(1 H- (usft) (usft) lusft) (9 MWD -INC -ONLY 38.62 0.00 0.00 0.00 Survey Program Date 10/18/2017 MWD+IFR AK CAZ SCC From To 8/27/2017 12:16 (usft) (usft) Survey (Wellbore) Tool Name 67.62 1,009.26 1H-102 Srvy 1 - SL13_GWD70 (1H-102) GYD-GC-SS 1,050.36 1,678.041H-102 Srvy 2-SLB_MWD+GMAG(11H- MWD+IFR-AK-CAZ-SC 1,777.33 7,293.521H-102 Srvy 3- SLB _MWD+GMAG(1 H- MWD+IFR-AK-CAZ-SC 7,377.00 7,480.661H-1021-4 Srvy 1-SLB_MWD-INC Filler MWD -INC -ONLY 7,575.34 14,608.581H-1021-4 Srvy 2-SLe MWD+GMAG(1 MWD+IFR-AK-CAZ-SC Description Survey Date Gyrodata gyro single shots 8/24/2017 10:04 MWD+IFR AK CAZ SCC 8/24/2017 10:12 MWD+IFRAKCAZSCC 8/27/2017 12:16 MWD -INC -ONLY -FILLER 10/9/2017 10:13 MWD -IFR AK CAZ SCC 10/9/2017 12:53 Survey Map Map Vertical MD Inc An TVD TVDSS +NI -S +El -W Northing Easting DLS Section (usft) (1) V) (usft) (usft) (usft) (usft) (ft) (ft) (-1100') (ft) Survey Tool Name 38.62 0.00 000 38.62 -54.00 0.00 0.00 5,980,414.37 1,689,609.08 0.00 0.00 UNDEFINED 6762 0.19 41.29 67.62 -25.00 0.04 0.03 5.98D,414 40 1,689,609.12 066 0.04 GYD-GC-SS(1) 165.90 0.45 132.01 165.90 73.28 -0.10 0.43 5,980,414.27 1,689,609.51 0.50 -0.10 GYD-GC-88(1) 258.98 1.01 128.15 258.97 166.35 -0.85 1.34 5,98D,413.52 1689.610.43 0.60 -0.85 GYD-GC-SS(1) 354.48 3.34 138.19 354.40 261.78 -3.44 3.86 5,980,410.95 1.689,612.97 246 -3.44 GYD-GC-S$(1) 447.17 4.61 13526 446.86 354.24 -8.10 8.28 5,980,406.32 1,689,61742 1.39 -8.10 GYD-GC-SS(1) 53982 5.77 13242 539.13 446.51 -13.89 1434 5,980,400.57 1.689,623.51 1.28 -13.89 GYD-GC-SS(1) 632.84 761 134.49 631.51 538.89 -21.36 22.19 5,980,393.15 1,689,63141 1.99 -21.36 GYD-GC-SS(1) 725.82 8.77 137.82 723.54 630.92 -30.93 31.34 5,980,383.65 1,689,640.62 1.35 -30.93 GYD-GC-SS(1) 821.24 10.73 141.32 817.58 724.96 -43.25 41.78 5.980,371.39 1,689,651.14 2.15 -43.25 GYD-GC-SS(1) 10/18/2017 10.57:29AM Page 2 COMPASS 5000.14 Build 65 ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 H-102 Project: Kuparuk River Unit TVD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: iH-102 actual @ 92.62usft (Doyon 142) Well: 1H-102 North Reference: True Wellbore: 1H-10214 Survey Calculation Method: Minimum Curvature Design: 1H-10214 Database: OAKEDMP2 Survey Map Map Vertical MD Inc AN TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (ueft) 0 (1 (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 91420 12.89 139.61 908.57 815.95 -57.91 53.90 5,960,356.82 1,689,663.38 2.35 -57.91 GYD-GC-SS(1) 1,009.26 14.89 136.85 1,000.84 908.22 -74.90 69.13 5.980,339.93 1,689,678.70 2.22 -7490 GYD-GC-SS(1) 1,05036 1572 135.96 1,040.49 947.87 -82.75 76.61 5,980,332.13 1,689,686.23 2.10 -82.75 MWD+IFR-AK-CAZ-SC (2) 1,144.89 17.17 134.37 1,131.15 1,038.53 -101.72 95.49 5,980,313.29 1,689,705.23 161 -10172 MWD+IFR-AK-CAZ-SC (2) 1,239.16 20.84 134.25 1,220.26 1,127.64 -123.16 117.46 5,980,292.00 1,689,727.33 3.89 -123.16 MWD+IFR-AK-CAZ-SC(2) 4,334.20 24.71 136.54 1,307.88 1215.26 -149.38 143.24 5,980,26594 1689,753.29 4.18 -149.38 MWD+IFR-AK-CAZ-SC(2) 1428.98 27.54 137.49 1,392.97 1,300.35 -17992 171.68 5,980,235.60 1,689,781.92 3.02 -17992 MWD+1FR-AK-CAZ-SC(2) 1,523.25 28.14 137.93 1476.33 1,38371 -212.49 201.30 5,980,203.23 1,689,811.75 067 -21249 MWD+IFR-AK-CAZ-SC(2) 1,61809 28.94 137.33 1,559.64 1,467.02 -245.96 231.84 5,980,169.96 1,689,842.51 0.90 -24596 MWD+IFR-AK-CAZ-SC(2) 1,678.04 29.99 135.80 1,611.84 1,519.22 -267.37 252.11 5,980,14869 1689,862.92 2.15 -267.37 MWD+IFR-AK-CAZ-SC(2) 177100 33.38 135.72 1,690.93 1,598.31 -302.34 286.17 5,980,113.94 1,689,897.21 365 -30234 NOT an Actual Survey 10 314" x 13-1/2" 1,777.33 33.61 135.72 1.696.21 1,603.59 -304.85 288.61 5,980,11145 1,689,899.66 3.65 -304.85 MWD+1FR-AK-CAZ-SC(3) 1,801.61 34.53 13479 1,716.32 1,623.70 -314.50 298.19 5,980,101.86 1,689,909.30 4.35 -314.50 MWD+IFR-AK-CAZ-SC(3) 1,696.65 37.81 133.50 1,793.04 1,700.42 -353.55 338.45 5.980,063.08 1,689,949.82 3.54 -353.55 MWD+IFR-AK-CAZ-SC(3) 1,991.93 40.86 131.83 1,866.72 1,774.10 -39445 38287 5,980,022.48 1,689,994.50 3.39 -39445 MWD+1FR-AK-CAZ-SC(3) 2,08648 43.97 130.99 1.936.52 1,84390 -436.61 430.70 5,979,98063 1,690,042.60 3.34 436.61 MWD+IFR-AK-CAZ-SC(3) 2,184.36 47.16 12949 2,005.04 1,912.42 -481.73 484.06 5,979,935.87 1,690,096.25 344 -081.73 MWD+IFR-AK-CAZ-SC(3) 2.276.23 50.08 128.77 2.06576 1,973.14 -525.22 537.53 5.979,892.74 1,60,150.00 3.23 -525.22 MWD+IFR-AK-CAZ-SC(3) 2,371.48 53.12 127.35 2,124.92 2,032.30 -571.22 596.31 5.979,847.13 1,690,209.07 340 -571.22 MWD+1FR-AK-CAZ-SC(3) 2,464.98 55.35 12447 2,179.57 2,086.95 -615.68 65776 5,979,803.07 1,690,270.80 3.45 61568 MWD+1FR-AK-CAZ-SC(3) 2,559.60 56.73 122.73 2,232.43 2,139.81 659.10 723.12 5,979,760.09 1,690,33645 2.11 -559.10 MWD+IFR-AK-CAZ-SC(3) 2,653.87 58.79 12243 2,282.72 2,190.10 -702. D3 790.31 5,979,717.61 1,690,403.91 2.20 40203 MW +1FR-AK-CAZ-SC(3) 2,748.30 5937 121.74 2,331.24 2,236.62 -74506 858.95 5,979,675.03 1,690,47282 0.88 -745.06 MWD+IFR-AK-CAZ-SC(3) 2,843.07 61.40 12148 2,378.07 2,285.45 -788.24 929.11 5,979,632.32 1,690,543.26 2.16 -788.24 MWD+IFR-AK-CAZ-SC(3) 2,937.25 65.11 121.93 2,420.45 2,327.83 -832.44 1,000.65 5,979,588.60 1,690.615,08 396 -832.44 MWD+IFR-AK-CAZ-SC(3) 3,032.88 69.13 121.16 2,457.62 2,365.00 -878.52 1,075.72 5,979,543.02 1,690,69045 4.27 -87852 MWD+IFR-AK-CAZ-SC(3) 3,126.86 71.43 121.37 2,489.33 2,396.71 -924.43 1,151.34 5,979,49761 1,690,766.35 2.46 -924.43 MWD+IFR-AK-CAZ-SC(3) 3,221.95 72.62 121.37 2,518.67 2,426.05 -97151 1,228.56 5,979,451.04 1,690.843.88 1.25 -971.51 MWD+IFR-AK-CAZ-SC(3) 3,316.46 73.03 121.69 2,546.58 2,453% -1,018.73 1,305.53 5,979,404.33 1,690,921.15 0.54 -1,018.73 MWDHFR-AK-CAZ-SC(3) 3,410.86 73.34 122.71 2,573.89 2,481.27 -1,066.69 1,38199 5,979,356.68 1,690,997.92 1.09 -1,066.89 MWD+IFR-AK-CAZ-SC(3) 3,506.07 73.21 122.55 2,601.29 2,508.67 -1,116.05 1458.78 5,979,30803 1,691,075.02 0.21 -1,116.05 MWD+IFR-AK-CAZ-SC(3) 3,601.42 7321 122.70 2,628.83 2,536.21 -1,165.27 1,535.66 5,979,259.32 1,691,15222 0.15 -1,165.27 MWD+IFR-AK-CAZ-SC(3) 3,696.85 7321 122.29 2,656.40 2,563.76 -1,214.35 1,612.72 5,979,210.75 1,691,229.59 0.41 -1,214.35 MWD+IFR-AK-CAZ-SC(3) 3,791.46 7330 120.98 2,683.66 2,59104 -1,261.87 1,689.85 5,979,16375 1691,30703 1.33 -1,261.87 MWD+IFR-AK-CAZ-SC(3) 3,886.74 73.14 118.95 2,711.17 2,618.55 -1,307.43 1,76888 5,979,118.71 1,691,386.34 2.05 -1,307.43 MWD+IFR-AK-CAZ-SC(3) 3,981.94 7309 119.64 2,738.82 2,64620 -1.352.00 1,848.32 5,979,07466 1,691,46807 070 -1.352.00 MWD+IFR-AK-CAZ-SC(3) 4,076.41 73.30 119.87 2,766.13 2,673.51 -1,396.88 1,926.64 5,979,030.30 1,691,54487 0.32 -1,396.88 MWD+IFR-AK-CAZ-SC(3) 4,171.02 73.17 118.99 2,793.42 2700.80 -1,441.40 2,005.73 5,978,966.31 1,691,62405 0.90 -1,441.40 MWD+IFR-AK-CAZ-SC(3) 4,266.02 73.06 119.53 2.821.02 2,728.40 -7485.83 2,085.04 5,978,94241 1,691,70363 0.56 -1,485.83 MWD+IFR-AK-CAZ-SC(3) 4,360.46 73.01 11904 2,648.57 2,755.95 -1,530.01 2.16383 5,978,898]5 1,691,782.70 0.50 -1,530.01 MWDHFR-AK-CAZ-SC (3) 10/182 0 1 7 f 0:57:29AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupt Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1H Pad MD Reference: Well: 1H-102 North Reference: Wellbore: 1H-1021-4 Survey Calculation Method: Design: 11-1-10214 Database: Well 1 H-102 1 H-102 actual @ 92.62usft (Doyon 142) 1 H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) V) (1) (usft) (usft) (usft) fusty) (ft) (ft) ('/100-) (ft) Survey Tool Name 4.455.58 72.90 119.77 2,876.45 2,783.83 -1,574.66 2,243.05 5.978,854.62 1,691,862.21 0.74 -1,574.66 MWD+IFR-AK-CAZ-SC (3) 4,549.81 72.87 120.06 2,904.19 2,811.57 -1,619.57 2,321.11 5,978,810.23 1,691,940.55 0.30 -1,619.57 MW0+IFR-AK-CAZ-SC(3) 4,644.52 73.20 118.40 2,931.82 2,839.20 -1,663.81 2,400.16 5,978.766.52 1,692,01989 1.71 -1,663.81 MWD+IFR-AK-CAZ-SC(3) 4,739.99 72.42 114.51 2,960.05 2,867.43 -1,70444 2,481.79 5,978,726.43 1,692,101.78 3.98 -1,70444 MWD+1FR-AK-CAZ-SC(3) 4,786.24 72.31 110.47 2,974.06 2,881.44 -1,]21.29 2,522.51 5.978,709.84 1,692,14260 8.33 -1,721.29 MWD+IFR-AK-CAZ-SG(3) 4,833.76 72.48 108.23 2,988.44 2895.82 -1,736.30 2,565.24 5,978,695.12 1,692,185.42 4.51 -1736.30 MWD+IFR-AK-CAZ-SC(3) 4,928.09 7221 10378 3,017.06 2,924.44 -1.761.08 2,651.62 5,978,670.91 1,692 271 .95 4.50 -1,761.08 MWD+IFR-AK-CAZ-SC(3) 5,022.87 71.11 100.68 3,046.89 2,954.27 -1780.14 2,739.52 5,978,652.43 1,692,359.97 331 -1,780.14 MWD+IFR-AK-CAZ-SC(3) 5,070.23 71.27 Wes 3,062.16 2,969.54 -1787.68 2,783.71 5,978,645.18 1,692,40421 3.99 -1,787.68 MWD+IFR-AK-CAZ-SC(3) 5,116.77 71.68 96.97 3,07695 2,984.33 -1,793.69 2,827.43 5,978,639.46 1,692,447.96 3.61 -1793.69 MWD+1FR-AK-CAZ-SC(3) 5,211.19 72.12 93.77 3,106.29 3,01367 -1,802.09 2,916.77 5,978,63165 1,692,53734 3.25 -1,802.09 MWD+IFR-AK-CAZ-SC(3) 5,305.75 7174 88.59 3,135.64 3,043. 02 -1,803.94 3,00.61 5,978,630.38 1,692,627.18 522 -1,803.94 MWD+IFR-AK-CAZ-SC(3) 5,400.08 71.70 83.77 3,165.24 3,072.62 -1,797.98 3,095.95 5,978,636.93 1,692,71847 4.85 -1,797.98 MWD+IFR-AK-CAZ-SC(3) 5,495.26 7232 81.29 3,194.64 3,102.02 -1,786.21 3,185.70 5,978,64929 1,692,806.13 2.% -1786.21 MWD+IFR-AK-CAZ-SC(3) 5,59001 72.15 76.05 3,223.57 3,130.95 -1,768.49 3,274.13 5,978,667.59 1,692,894.44 5.27 -1.768.49 MWD+IFR-AK-CAZ-SC(3) 5,685.45 7261 70.23 3,252.48 3.159.86 -1,742.11 3,361.14 5,978,694.53 1,692,981.27 5.83 -1,742.11 MWD+IFR-AK-CAZ-SC (3) 5,779.73 7302 64.52 3,280.36 3,18774 -1,70748 3,444.24 5,978,729.71 1,693,064.13 5.80 -1707.48 MWD+IFR-AK-CAZ-SC 13) 5,874.02 73.87 63.54 3,307.23 3,214.61 -1,667.90 3,525.49 5,978,769.82 1,693,145.11 1.34 -1,667.90 MWD+IFR-AK-CAZ-SC(3) 5,968.69 74.38 63.99 3,333.12 3,240.50 -1,627.64 3,607.17 5,978,810.60 1,693,226.51 031 -1,627.64 MM+IFR-AK-CAZ-SG(3) 6,063.17 74.61 63.93 3,358.38 3,265.76 -1,587.68 3,688.97 5,978,851.10 1,693,308.04 0.25 -1,587.68 MWD+IFR-AK-CAZ-SC(3) 6,156.98 7468 58.30 3,383.23 3,290.61 -1,544.01 3,768.12 5,978,89529 1,693,385.90 539 -1,544.01 MWD+IFR-AKCAZ-SC (3) 6,252.33 74.03 54.53 3,40.96 3,316.34 -1,49322 3,844.61 5,978,946.57 1,693,46305 3.87 -1493.22 MWD+iFR-AK-CAZ-SC(3) 6,346.97 72.68 51.05 3,436.08 3,343.46 -1,438.41 3,916.82 5,979,001.85 1,693,534.89 3.80 -1,438.41 MWD+IFR4K-CAZ-SC(3) 6,441.76 72:16 48.05 3,464.71 3,37209 -1,379.79 3,985.58 5,979,060.91 1,693,603.25 3.07 -1,379.79 MWD+IFR-AK-CAZ-SC(3) 6,537.27 73.10 45.02 3,49323 3,400.61 4,317.09 4,051.72 5,979,12404 1,693,668.97 3.18 -1,317.09 MWD+1FR-AK-CAZ-SC(3) 6,58521 73.18 41.30 3,507.14 3,414.52 -1,283.63 4,063.10 5,979,15730 1,693,700.13 7.43 -1,28363 MWD+IFR-AK-CAZ-SC (3) 6,632.17 7264 38.72 3,520.94 3,428.32 -1,249.25 4,111.96 5,979,192.26 1,693,728.76 5.38 -1249.25 MWD+IFR-AK-CAZSC(3) 6,727.59 71.99 32% 3,549.95 3,457.33 -1,175.60 4,165.17 5,979,266.26 1,693,78148 5.79 -1,175.60 MM+IFR-AK-CAZ-SC(3) 6,822.80 72.62 27.41 3,578.91 3,486.29 -1,097.23 4,210.74 5,979,344.92 1 693,826.53 5.59 -1,097.23 MWD+IFR-AK-CAZ-SC (3) 6,915.59 72.83 23.59 3,6048 3,513.86 -1,017.27 4,248.88 5,979,42512 1,693,864.14 3.94 -1,017.27 MWD+IFR-AK-CAZ-SC(3) 7,011.34 72.49 19.50 3,635.02 3,54240 -932.28 4,28244 5,979,510.32 1,893,897.14 4.09 -93228 MWD+IFR-AK-CAZ-SC(3) 7,104.01 73.90 18.26 3,661.82 3,569.20 -M&M 4,311.14 5,979,594.44 1,693,925.28 1.99 -848.34 MWD+IFR-AK-CAZ-SC(3) 7,198.95 73.27 1349 3,688.66 3,596.04 -760.78 4,33605 5,979,682.15 1,693,949.61 4.86 -76038 MWD+1FR-AK-CAZ-SC(3) 7,293.52 74M 7.89 3,715.26 3622.64 -671.64 4,352.87 5,979,771.40 1,693,965.84 535 -671.64 MWD+1FR-AK-CAZ-SC 3 7,377.00 74.47 4.54 3,737.89 3,645.27 -591.76 4,361.56 5,979,851.31 1,693,97401 3.89 -59136 Nin BR Actual .SIt1Y8y 7.5/8" z 0-718" 7,39060 75.83 4.00 3,741.38 3,648.76 -57B.W 4,362.54 5,979,864.43 1,693,974.91 1031 -578.66 MWD -INC -ONLY (4) 7,480.65 79.20 5.00 3.760.84 3,668.22 -491.01 4,36944 5,979,952.11 1,693,981.23 3.90 -491.01 MWD -INC _ONLY (4) 7,575.34 8481 5.00 3,774.01 3,681.39 -397.65 4,377.61 5,980,045.52 1,693,988.79 5.93 -397.65 MWD+IFR-AK-CAZ-SC(5) 7,631.80 90.33 5.30 3,776.40 3,683.78 -34149 4,38267 5,980,101.70 1,693,99348 9.79 -301.49 MWD+IFR-AK-CAZ-SC(5) 10/18/2017 10,57 29AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1 H Pad MD Reference: Well: 1 H-102 North Reference: Wellbore: 1 H-1021-4 Survey Calculation Method: Design: 1H-1021-4 Database: Well 1 H-102 1H-102 actual @ 92.62usft (Doyon 142) 1 H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (I Wait) (usft) (usft) Wait) (ft) (ft) (-/100-) (ft) Survey Tool Name 7,677.29 92.17 3.66 3,77541 3.682.79 -296.15 4,386.23 5,980,147.06 1,693,996]3 542 -296.15 MWD+IFR-AK-CAZ-SC(5) 7,775.65 93.32 358.47 3,770.70 3,678.08 -197.95 4,388.05 5,980,245.25 1,693,99792 5.40 -197.95 MWD+IFR-AK-CAZ-SC(5) 7,865.25 92.89 352.09 3,765.84 3,673.22 -108.84 4,380.69 5,980,334.31 1,693,989.97 7.13 -108.84 MWD+IFR-AK-CAZ-SG(5) 7,916.66 92.50 353.16 3,763.42 3,670.80 -57.91 4,374.10 5,980,385.19 1,693,983.05 2.21 -57.91 MWD+IFR-AK-CAZ-SC (5) 8,012.54 92.03 35269 3,75963 3,667.01 37.17 4,362.30 5,980,480.18 1,693,970.62 069 37.17 MWD+IFR-AK-CAZ-SC(5) 8,108.07 91.29 351.10 3,756.66 3,664.24 131.70 4,348.84 5,980,574.61 1,693,956.54 1.84 13170 MWD+IFR-AK-CAZ-SC (5) 8,202.05 91.66 354.34 3,754.44 3,661.82 224.88 4,336.94 5,980,667 70 1,693,944.03 3.47 224.88 MWD+IFR-AK-CAZ-SC (5) 8.297.04 91.10 355.52 3,752.16 3,659.54 319.47 4,328.54 5,980,762.22 1.693,935.02 1.37 31947 MWD+1FR-AK-CAZ-SC(5) 8,391.90 90.59 355.57 3,750.76 3,658.14 414.03 4,321.18 5,980,856.72 1,693,927.03 0.54 414.03 MWD+IFR-AK-CAZ-SC (5) 805.70 89.75 356.26 3,750.48 3,657.86 507.59 4,314.49 5.980,950.23 1,693,919.73 1.16 507.59 MWD+IFR-AK-CAZ-SC(5) 8,580.35 89.18 0.83 3,751.36 3,658.74 602.18 4,312.09 5,981,04479 1,693,916.71 4.87 602.18 MWD+IFR-AK-CAZ-SC(5) 8,675.09 88.14 1.55 3,753.58 3,660.96 696.87 4,314.06 5,981,139.49 1,693,918.05 134 696.87 MWD+IFR-AK-CAZ-SC(5) 8,769.22 88.25 4.56 3,758.54 3,663.92 790.81 4,319.07 5,981,23345 1.693,92245 320 790.81 MWD+IFR-AK-CAZ-SC(5) 8,864.59 89.29 3.77 3,758.59 3,665.97 885.90 4,326.00 5.981.328.57 1,693.928.75 1.37 885.90 MWD+IFR-AK-CAZ-SC (5) 8,959.46 89.85 2.69 3,759.30 3,666.68 980.62 4,331.34 5,981,423.31 1,693,933.47 1.28 980.62 MWD+IFR-AK-CAZ-SC(5) 9,054.39 89.13 359.26 3,760.15 3.667.53 1,075.52 4,332.96 5,981,518.21 1.693,934.46 3.69 1,075.52 MWD+IFR-AK-CAZ-SC(5) 9,14946 89.19 357.10 3,761.54 3,668.92 1,170.52 4,329.94 5,981,613.19 1,693,930.82 2.27 1,170.52 MWD+IFR-AK-CAZ-SG(5) 9,244.06 88.65 356.84 3.763.32 3,67970 1,264.97 4,324.94 5,981,707.59 1,693,925.20 0.63 1,264.97 MWD+IFR-AK-CAZ.SC(5) 9,339.46 WAS 356.90 3,765.73 3,673.11 1,360.20 4,319.73 5,981,802.77 1,693,919.37 0.21 1,360.20 MWD+IFR-AK-CAZ-SC(5) 9,433.08 88.32 357.73 3,768.36 3,675.74 1,45368 4,31535 5,981,896.21 1,693,914.37 0.90 1,453.68 MWD+IFR-AK-CAZ-SC(5) 9,528.14 88.29 0.77 3,771.17 3,678.55 1,54868 4,314.10 5,981,991.19 1,693,912.51 3.20 1,548.68 MWD+IFR-AK-CAZ-SC(5) 9,622.81 87.96 2.92 3,774.27 3,681.65 1,643.24 4,317.15 5,982,08577 1,693,914.93 2.30 1,643.24 MWD+IFR-AK-CAZ-SC(5) 9,719.62 89.52 4.58 3.776.40 3,683.78 1,739.82 4,323.48 5,982,182.37 1,693,92063 2.35 1,739.82 MWD+IFR-AK-CAZ-SC(5) 9,811.75 89.71 138 3,777.02 3,684.40 1,831.81 4,328.27 5,982,274.38 1,693,92481 3.48 1,831.81 MWD+IFR-AK-CAZ-SC (5) 9.906.99 91.12 356.51 3,776.33 3,683.71 1,92790 4,326.52 5,982,369.55 1693,922.43 5.32 1,927.00 MWD+IFR-AK-CAZ-SC(5) 9,95163 91.55 355.71 3,775.29 3,682.67 1971.52 4,323.49 5,982,41405 1,693,919.11 2.03 1,971.52 MWD+IFR-AK-CAZ-SC(5) 10,002.07 90.85 352.94 3,774.23 3,681.61 2,021.70 4,318.50 5,982,464.19 1,693,913.80 5.66 2,021.70 MWD+IFR-AK-CAZ-SC (5) 10.096.45 90.70 349.63 3,772.96 3,680.34 2,114.97 4,304.21 5,982,557.35 1,693,898.89 3.51 2,114.97 MWD+IFR-AK-CAZ-8C(5) 10,191.82 89.75 347.85 3.772.58 3,679.96 2,208.50 4,285.56 5,982,650.74 1,693,879.66 2.12 2,208.50 MWD+IFR-AK-CAZ-SC(5) 10.286.69 89.36 344.77 3,773.32 3,680.70 2,300.65 4,263.14 5,982,74275 1,693,856.60 3.27 2,300.66 MWD+IFR-AK-CAZ-SC (5) 10,381.45 89.05 345.67 3,77463 3,682.01 2,392.27 4,238.96 5,982,834.19 1,693,83183 1.00 2,392.27 MWD+IFR-AK-CAZ-SC(5) 10,476.55 87.69 346.86 3,777.34 3,68472 2,484.61 4,216.39 5,982,926.37 1,693.80866 1.90 2,484.61 MWD+IFR-AK-CAZ-SC(5) 10,570.94 87.71 346.65 3,781.13 3,688.51 2,576.42 4,194.79 5,983,018.02 1,693,78645 0.22 2.57642 MWD+IFR-AK-CAZ-SC(5) 10,666.13 87.35 348.71 3,785.23 3,692.61 2,669.32 4,17449 5,983,110]9 1,693,785.55 2.19 2,669.32 MWD+IFR-AK-CAZ-SC(5) 10,761.88 88.50 350.88 3,788.70 3,696.08 2,76349 4,157.54 5,983,204.83 1,693,747.99 2.56 2,763.49 MWD+IFR-AK-CAZ-SC(5) 10,855.84 89.40 35344 3,790.42 3,697.80 2,856.55 4,144.73 5,983,297.79 1,693,734.56 2.89 2,856.55 MWD+IFR-AK-CAZ-SC(5) 10,950.99 89.28 357.21 3,791.53 3,698.91 2,951.36 4,136.98 5,983,392.54 1,693,726.19 3.96 2,951.36 MWD+IFR-AK-CAZ-SC(5) 11,046,51 88.51 359.84 3,793.39 3,700.77 3,046.82 4,134.52 5,983,487.97 1,693,723.10 2.86 3946.82 MWD+IFR-AK-CAZ-SC(5) 11,140.94 88.69 2.04 3,795.70 3,703.08 3,141.20 4,136.07 5,983,582.36 1,693,724.03 2.34 3,141.20 MWD+IFR-AK-CAZ-5C(5) 11,235.07 86.68 5.25 3,799.34 3,706.72 3,235.05 4,142.04 5,983,67824 1,693,729.39 3.91 3,235.05 MWD+IFR-AK-CAZ-SC(5) 10/18/2017 10:57:29AM Page 5 COMPASS 5000.14 Build 85 Company: ConowPhillips (Alaska) Inc. -Kupi Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: 1H-102 Wellbore: 11H-10214 Design: 1H-10214 Survey ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1 H-102 11H-102 actual @ 92.62usft (Doyon 142) 1H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 1011812017 10..57,29AM Page 6 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,329.70 89.54 7.65 3.802.29 3,709.67 3,329.02 4,152.67 5,983,770.27 1,693,73940 3,79 3.329.02 MWD+IFR-AK-CAZ-SC(5) 11423.82 89.83 7.70 3,802.81 3,710.19 3,422.30 4,165.24 5,983,86361 1,693,751.35 0.31 3,422.30 MWD+IFR-AK-CAZ-SC(5) 11,518.23 89.92 7.00 3,803.02 3,71040 3,515.93 4,177.32 5,983,957.31 1,693,76282 0.75 3,515.93 MWD+IFR-AK-CAZ-SC(5) 11,61240 90.76 668 3,80246 3,70984 3,609.43 4,188.53 5,984050.87 1,693,773.42 0.95 3,609.43 MWD+IFR-AK-CAZ-SC(5) 11,704.20 91.41 6.33 3,8D0.72 3,708.10 3,700.62 4,198.93 5,984,142.12 1,693,783.21 0.80 3,70062 MWD+IFR-AK-CAZ-SC(5) 11]96.49 91.86 560 3,798.09 3,705.47 3,792.37 4,208.52 5,984,233.93 1,693,792.20 0.93 3,792.37 MWD+IFR-AK-CAZ-SC(5) 11,888.13 9242 3.35 3,794.66 3,702.04 3,883.66 4,215.66 5,984325.25 1693,79874 2.53 3,883.66 MWD+IFR-AK-CAZ-SC(5) 11980.01 91.72 2.97 3,791.34 3,69832 3,975.34 4,220.72 5,984,41695 1,693,803.20 0.87 3,975.34 MWD+IFR-AK-CAZ-SC(5) 12,071.11 91.00 4.38 3,789.18 3,696.56 4,066.23 4,226.56 5,984,507.87 1,693,808.44 1.74 4,06623 MWD+IFR-AK-CAZ-SC(5) 12,162.50 89.79 496 3,788.55 3,695.93 4,157.31 4,234.00 5,984,598.99 1,693,815.28 1.47 4.157.31 MVM+IFR-AK-CAZ-SC(5) 12,255.25 88.48 4.56 3.789.95 3,697.33 4,249.73 4,241.70 5,984,691.45 1,693,822.37 1.48 4,249.73 MWD+IFR-AK-CAZ-SC (5) 12347.06 87.76 2.10 3,792.96 3,700.34 4,34133 4,247.03 5,984,783.07 1.693,827 10 279 4,341.33 MWD+IFR-AK-CAZ-SC(5) 12,439.47 88.05 357.72 3,796.34 3,703.72 4,433.65 4,246.88 5.984875.38 1,693,828.35 475 4,433.65 MWD+IFR-AK-CAZ-SC(5) 12,532.42 88.10 354.48 3,799.47 3,706.85 4,526.32 4,240.56 5,984,968.0D 1,693,81942 3.48 4.526.32 MWD+IFR-AK-CAZ-SC(5) 12,623.39 89.63 349.63 3,801.27 3,708.65 4,616.37 4,228.00 5,965,057.95 1,693,806.26 5.59 4,616.37 MWD+IFR-AK-CAZ-SC (5) 12,715.20 89.37 34685 3,802.07 3,709.45 4,706.24 4,20829 5,985,14769 1,693,786.96 3.04 4,7%.24 MWD+IFR-AK-CAZ-SC(5) 12,807.77 8609 347.39 3,805.74 3,713.12 4,796.40 4,188.67 5,985,237.70 1,693,765.76 3.59 4,7136.40 MWD+IFR-AK-CAZ-SC(5) 12,899.26 89.26 34733 3,809.45 3,716.83 4,885.59 4,168.67 5,985,326.75 1,693,745.17 3.47 4,885.59 MWD+IFR-AK-CAZ-SC(5) 12,991,71 90.40 344.51 3,809.72 3,717.10 4,975.25 4,146.18 5,985,416.25 1,693,722.10 3.29 4,975.25 MWD+IFR-AK-CAZ-SC (5) 13,083.97 8642 338.76 3,810.67 3,718.05 5,062.76 4,117.13 5,985,503.57 1,693,692.48 6.59 5,06276 MWD+IFR-AK-CAZ-5C(5) 13,131.00 89.23 334.91 3,811.64 3,719.02 5,105.98 4,098.63 5,985,546.66 1,693,673.70 8.36 5,105.98 MWD+IFR-AK-CAZ-SC(5) 13,176.50 90.90 329.92 3,611.59 3,718.97 5,146.30 4,077.57 5,985,58683 1.693,652 38 11.56 5,146.30 MWD+IFR-AK-CAZ-SC(5) 13,268.58 92.77 328.84 3,808.64 3,716.02 5.225.49 4,030.70 5,985,66571 1,693,604.99 2.34 5,225.49 MWD+IFR-AK-CAZ-SC(5) 13,36042 9364 328.15 3,803.50 3,710.88 5,30367 3,982.78 5.985,743.56 1,693,556.56 1.21 5.30367 MWD+IFR-AK-CAZ-SC(5) 13,451.57 92.60 328.13 3,798.54 3,705.92 5,380.97 3.934.]4 5,985,820.54 1,693,508.02 1.14 5,380.97 MWD+IFR-AK-CAZ-SC (5) 13,54562 91.95 324.98 3,794.81 3,702.19 5,459.38 3,882.95 5,985,89860 1,693,455.73 3.42 5,459.38 MWD+IFR-AK-CAZ-SC(5) 13,637.33 91.38 321.08 3,792.14 3,699.52 5,532.60 3,827.83 5,98597145 1,693,400.13 4.30 5,532.60 MWD+IFR-AK-CAZ-SC(5) 13,729.95 8978 314.62 3,79120 3,698.58 5,601.23 3,765.72 5,985,03966 1,693,337.57 7:18 5,601.23 MWD+IFR-AK-CAZ-SC(5) 13,821.41 90.35 312.27 3,791.10 3,698.48 5,664.12 3,699.32 5,986,102.11 1,693,270.77 2.64 5,664.12 MWD+IFR-AK-CAZ-SC (5) 13,913.93 90.94 311.34 3,790.06 3,697.44 5.725.79 3,630.36 5,986,163.31 1,693,20141 1.19 5,725.79 MWD+IFR-AK-CAZ-SC (5) 14,003.71 90.72 308.19 3,788.76 3,696.14 5,783.20 3,561.36 5,986,2202] 1,693,13204 3.52 5,783.20 MWD+1FR-AK-CAZ-SC(5) 14,095.72 90.72 306.46 3,787.60 3,694.98 5,838.98 3,488.20 5,986,275.56 1,693,058.53 1.88 5,838.98 MWD+IFR-AK-CAZ-SC(5) 14.18795 90.90 304.48 3,786.30 3,69368 5,892.49 3,413.10 5,986 328 57 1,692,983.08 2.16 5,89249 MWD+IFR-AK-CAZ.SC(5) 14,280.41 90.62 302.04 3,785.07 3,692.45 5,943.19 3,335.80 5,986,37876 1,692,905.46 2.66 5,943.19 MWD+IFR-AK-CAZ.SC(5) 14,37309 90.62 30163 3,784.07 3,691:45 5,992.08 3,257.07 5,986,427.12 1,692,826.41 0.44 5,992.08 MWD+IFR-AK-CAZ-SC(5) 14,464.79 90.69 301.02 3,783.02 3,690.40 6,039.75 3,178.74 5,986,47427 1,692,747]8 067 6,039.75 MWD+IFR-AK-CAZ.SC(5) 14,557.71 90.80 301,90 3,781.81 3,689.19 6,088.24 3,099.48 5,986,522.24 1,692,668.22 0.95 6,088.24 MWD+IFR-AK-CAZ-SC(5) 14,60858 90.72 300.74 3,781.14 3,688.52 6,11468 3,056.03 5,986,548.39 1692,624.60 2.29 6,11468 MWD+IFR-AK-CAZ-SC(5) 14,652.00 9072 300.74 3,780.59 3;687.97 6.136.87 3,01872 5,986,57033 1,692,587.14 0.00 6,136.87 NOT anAcWalSurvey 41/2" z 6,7/47 1011812017 10..57,29AM Page 6 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 11-1-102 Wellbore: 1 H-10214 Design: 1H-1021-4 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1H-102 1H-102 actual @ 92.62usft (Doyon 142) 1H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. ❑ Yes ❑ No 1 have checked to the best of my ability that the following data is correct: ] Surface Coordinates (] Declination & Convergence Map Map GRS Survey Corrections Vertical MD Inc Azi TVD TVDSS -NI-S +E7 -W Northing Easting DLS Section (usft) (I V) (usft) (usit) lust) (usft) lft) (ft) (o/loo') (ft) Survey Tool Name 14,670.00 90.72 300.74 3780.37 3,687.75 6,146.07 3,003.25 5,986,579.43 1,692,571.61 0.00 6,146.07 PROJECTEDto TD Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. ❑ Yes ❑ No 1 have checked to the best of my ability that the following data is correct: ] Surface Coordinates (] Declination & Convergence GRS Survey Corrections n Survey Tool Codes Brandon Temple Digitally signed by Brandon Temple SLB DE. Date: 2017.10.1814:19:20-08'00' Kelsey Hallford w�xaw wu.a=aise.mwair�axr mrewaix Client Representative: Date 1 011 82 01 7 1011812017 10.57'29AM Page 7 COMPASS 500014 Build 85 THE STATE Alaska Oil and Gas °fALASKA Conservation Commission GOVERNOR BILL WALKER G. Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.ciasko.gov Re: Kuparuk River Field, West Sak Oil Pool, KRU 1 H -102L4 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-105 Surface Location: 40.52' FNL, 764.65' FEL, SEC. 33, T12N, R10E, UM Bottomhole Location: 4259.5' FNL, 2861.8' FEL, SEC. 22, TI 2N, RI OE, UM Dear Mr. Alvord: Enclosed is the approved application for permit to re -drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 217-097, API No. 50-029- 23580-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, qjthyFoee�rste"r Commissioner DATED this 7jp a y of July, 2017. STATE OF ALASKA A KA OIL AND GAS CONSERVATION COM( ION PERMIT TO DRILL lZf 20 AAC 25.005 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG Service - Disp ❑ 1c. Specify if well is proposed for: Drill [ I Lateral Stratigraphic Test ❑ Development - Oil ❑� Service- Winj ❑ Single Zone ❑� Coalbed Gas ❑ Gas Hydrates ❑ Redrill [J Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Single Well�!� 11. Well Name and Number: ConocoPhillips Bond No. 59-52-180 ?4 KRU 1H-1021-4 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 14425 ' TVD: 3801 Kuparuk River Field West Sak Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: IN Surface: 40.52' FNL, 764.65' FEL, Sec 33, T 12N, R010E, UM - ADL025639x PGY w 2563 L Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 557.39' FNL, 1676.84' FEL, Sec 34, T 12N, R010E, UM LO/NS 80-261 8/1/2017 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4259.5' FNL, 2861.8' FEL, Sec 22, T 12N, R010E, UM 2560 SHL - 4515'; BHL - 584' 4b. Location of Well (State Base Plane Coordinates - NAD 27): % KB Elevation above MSL (11): 93 15. Distance to Nearest Well Open Surface: x-549577.46 y- 5980662.56 Zone- 4 GL / BF Elevation above MSL (ft): 54 to Same Pool: 898' 16. Deviated wells: Kickoff depth: 7204 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 93.53 degrees Downhole: 1635 psi Surface: 1260 psi 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 42" 20" 94# H40 Welded 80 Surface Surface 80 80 Existing, cement to surface 13.5" 10.75" 45.5# 1794 Surtace Surface 1794 1700 914 sx 11.0 Lead, 145 sx 12.0 Tail 9.875" 7.625" 29.7# 7204 ii Surface Surface 7204 3763 644 sx 15.8 Class G gIH563 6.75" 4.5" 11.6# 7371 7054 3700 14425 3801 N/A: Un -cemented slotted liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface 111M lil!linl Intermediate Production Liner 1017 Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes El No ❑Q 20. Attachments: Property Plat BOP Sketch Diverter Sketch e Drilling Program Time v. Depth Plot Shallow Hazard Analysis Seabed Report e Drilling Fluid Program e 20 AAC 25.050 require 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be Kelsey Hallford deviated from without prior written approval. Contact Name: Authorized Name: G. Alvord Contact Email: kelsey.hallfor Conoco lllips.com Authorized Title: Alaska Drilling Manager Contact Phone: 1-907-265-T577 Authorized Signature: _4.(n-,, Date: 20 -Jun -17 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: - QS' 50- o - 35 - 3 - oo Date: '�(- 2,(s. requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed metha_nte, gas hydrates, or gas contained in shales : Other: Samples req'd: Yes ❑ No[a Mud log req'd: Yes q Nov [3oP first to 3 5-1) (9 p zsoa Izf ❑ vv easures: Yes No,--,( Directionals re d: Yes No Cil ❑ �vynv RY 471-C ✓Cvr Tf r q' /- Spacing ex ption mq'd: Yes ❑ No LSI Inclination -only svy req'd: Yes El NoU Post initial injection MIT req'd: Yes ❑ No APPROVED BY Approved by COMMISSIONER THE COMMISSION Date:7' Zip [fid �L�J���.,�{ I •r ,��\I1 Submit Form and Form 0 0 e i / 7 ''(,/'[ {�r��l r 4 L�onths from the date of approval per 20 AAC 25.005(8) gttachme b in Duplicate Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone (907) 265-1577 Email: kelsev.hallfordCabconocoohillips com July 10, 2017 Alaska Oil and Gas Conservation Commission 333 West 7`I' Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVE® ,JUL 12 2011 Re: Application for Permit to Drill, West Sak Producer, IH -102L3 Dear Commissioner: Application for Permit to Drill, Well 1 H-1021-3 Saved: 10 -Jul -17 ConocoPhillips ConocoPhillips Alaska, Inc. hereby applies for a permit to drill a grass roots onshore producer, a penta-lateral horizontal well in the West Sak A2, A3, A4, B and D sands. The expected spud date for this well is August 1, 2017. 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 fourth 6-3/4" production lateral, 1H -102L3, will be milled out of the IH -102 intermediate casing and be geo-steered in the West Sak B sand, lined with 4-1/2" slotted liner. The next and final lateral will again be drilled with 6-3/4" hole and lined with 4-1/2" slotted liner in the West Sak D sand. A separate PTD application will be submitted for each lateral: 11-1-102, 1H -102L1, 1H -102L2, 1H -102L3, and IH -102L4 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 layout 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 Hallford at 265-1577 (kelsev.hallford(a,conoconhillias.com) or Chip Alvord at 265-6120. Y ere y,ey HallfoVdDrilling Enger Application for Permit to Drill Document Kuparuk Well 1H-1021-4 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 1H -102L4 Location Summary Renuirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill anon be accompanied bo each of llieJoilomring items. except fm' an i/ern ah eado on,Qle with the commission and identified it, the apphcaton: (2) a plat identi6ing the propery and the propero s owners and shaving (A)de coordinates of the proposed location of the well at the surface, at the lop of each ohjecliee formation. and at total depth, referenced to governmental section lines. (B) the coordinates of the p, oposed location of the well at the surface, referenced to the state plane coordinate system far this slate as maintained by the National Geodetic Suroev in the National Oceanic and Aanospheric Adminism'ation: (C) the proposed depth of the well at the top of each objective fornmtion and at total depth: Location at Surface 40.52' FNL, 764.65' FEL, Sec 33, T 12N, R010E, UM NGS Coordinates Northings: 5980662.56' Eastings: 549577.46' RKB Elevation 93'AMSL Pad Elevation 54' AMSL Location at Surface asin 349.45 FNL, 466.77 FEL, Sec 33, T12N, R010E, UM NGS Coordinates Northings: 5980355.65' Eastings. 549878.04' Measured De th, RKB: 1794' Total Vertical De th, RKB: 1700' Tota[ Vertical De th, SS: 1607' Location at Intermediate Casing 4743.15' FNL, 1667.16' FEL, Sec 27, T12N, R010E, UM NGS Coordinates Northings: 5981270.1' Eastings: 553949.3' Measured Depth, RKB: 8325' Total Vertical De th, RKB: li 4004' Total Vertical Depth, SS: 1 391 P Location at Total De th 4259.5' FNL, 2861.8' FEL, Sec 22, T12N R010E, UM NGS Coordinates Northings: 5987024.4' Eastings: 552703.9' Measured De th, RKB: 1 14425' Total Vertical De th, RKB: 3801' Total Vertical Depth, SS: 3708' and (D) other ima,,n aiwr required by 20 AAC 25.050(13): Requirements of 20 AAC 25.050(b) if a wet] is to he imenlionallo deviated, the application for a Penni! to Drill (Form 10-401) must (1) include a plat, drawn to a suitable settle, shot ring the path oj'the proposed wellbore, including all adjacent wellha es within 200 feel of tiny portion of the proposed well: Please see Attachment: Directional Plan And (2)jor all it ells it ilhrn 200,feet m' iheproposedu ellbme (A) list the mimes of the operators of those wells, to the extent dal those names are &noun or discoverable in public records, and shoo that each named operator has been Jin'nished a colo of the application by certijied mail; or (B) state that the applicant is the onto tJfected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) .4n application for a Permit to Drill must he acconipanied by each t f rhe follortug llenn, except for an item alreadyon file it ah the commission and idemilied in the application: (3) a dtagran, and etescriptiot of the blorout prevention equipment (BOPS) is required by 20 AAC 25.035. 20 AAC 25.036, or 20 A: f 25.037. as applicable: Please reference BOP schematics on file for Doyon 142. 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 fm' a Permit to Or -ill most be acconrpamed by each of the fi4 tiring items, ercepl,for an net,, alread) on file it id the commission and identified in the application: (4) adox, o rttion on drilling hazards. including (A) the niasiuuan domrnhole pressure that mao be encomuered. criteria used to determine it. and maximtnn potential surface pressure based on a methane gradiern; The maximum potential surface pressure (MPSP) while drilling IH -102L4 is calculated using an estimated maximum reservoir pressure of 1635 psi (based on 1 H -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 D sand window at 3753' TVD: D Sand Estimated. BHP D Sand estimated depth Gas Gradient Hydrostatic of full gas column MPSP = BHP — gas column (B) data on potential gas --ones: = 1,635 psi = 3,753' TVD = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) = 375 psi (3,753' TVD * 0.10 psi/ft) = 1,260 psi (1,635 psi — 375 psi) The wellbore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes ofhole problems such as abnormal/) geo-pressured strata, lost circulation _onesand cones'that hire a propensio-for differential sticking; See attached 1H -102L4 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An applicationfoi a Permit to Drill in ntst he accompanied by each of the following items, exeept for an igen, adread)-on file it the commission and (dent fed in the application: l5) a description of the p ocednre fitr conducting formation integrity tests, ns required under 20 AAC 25.030(Q: A procedure is on file with the commission for performing FIT/LOT's. 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, following items, except for an item already on file with the carnndssam and ideniVied in the application: (6) a complete proposed casing and cementing program as required by 20 AAC _'5.030, and a descrtplion afmi) sinned liner, pi e-perjoraled Inter. or' screen to be installed Casing and Cement Program 18. Casing ogram Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 42" 20" 94# H40 Welded 80 Surface Surface 80 80 Ex is ting, cementto surface 13.5" 10.75" 45.5# L-80 H563 1794 Surface Surface 1794 1700 914 sx 11.0 Lead, 145 sx 12.0 Tail 9.875" 7.625" 29.7# L-80 H563 7204 Surface Surface 7204 3753 644 sx 15.8 Class G 6.75" 4.5" 11.6# L-80 BTM 7371 7054 3700 14425 3801 WA: Un -cemented slotted liner r Diverter System Information Requirements of 20 AAC 25.005(c)(9) ;1n application for a Permit to Dr 111 muss be accompanied by each ofdre follmcing items, eecep(for an item already onJile with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25035, unless this requirement is waived by the commission 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 (ma Permit to Drill must be accompanied by each ol7he follmring items. weep(for an item ab'eady on file it the commission and identified in the application: (8) a drilling fluid program, fnduding a diagram and description of the drilling fluid system, as required by 20 AAC25.033, Mud Program Summary 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. Surface Intermediate Production 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole 10-3/4" Casio 7-5/8" Casing 4-1/2" Liner Mud System Spud WBM LSND WBM Flo -Pro WBM Density 8.8-9.5 9.0-9.5 9.0-9.5 PV ALAP ALAP ALAP YP 30-80 20-30 15-20 Funnel Viscosity 250-300 Permafrost Base 100-150 to TD N/A N/A Initial Gel 30-50 9-11 7-11 10 minute Gel 1 30-50 1 < 20 1 8-16 API Filtrate NC < 6 < 6 HTHP Fluid Loss at 160 F N/A <10 <10 H 10.8-11.2 9.5-10.0 9.5-10.0 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 Requirements of 20 AAC 25.005 (c)(13) An applicalmn for a Permit to Drill mist he accompanied by each of the follmring items, except for an item already on file irith the commission and idem fied in the application: The proposed drilling program follows. Please refer to attachment for proposed well schematic. Note: Previous operations are covered under the 1H-102, 1H -102L1, 1H -102L2 and IH -1021-3 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 D Sand 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. PU gas lift completion as required and RIH to depth, land tubing. 9. Nipple down BOPE, nipple up tree and test. 10. Freeze protect well with diesel by pumping into 4-1/2" x 7-5/8" annulus, taking returns from tubing and allowing to equalize. 11. Ensure well is secure and move rig off. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) .An application fina Permit to Drill nacre be accompanied by each of the following items, except for on item alread) on file with the commission ami identified in the application: (14) a general description of hose the ope, toot plans to dispose of drilling mud and cuttings and a statement of whether the operatar intends to requesi audro, izaoon under 20 AAC- 25.080 for an anmdm' disposal operation in the welL: Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well at the 113 Facility. All cuttings generated will be hauled to the 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 2 Well Schematic Attachment 3 Diverter Layout Diaeram Attachment 4 Directional Plan Attachment 5 Drilling Hazards Summary Attachment 6 Cement Summaries Fixed BOP configuration for West Sak Operations Class 2 BOP mm VOR—Y..a- ;a n ZXP Packer Wellhead / Tubing Head / Tree, (� Insulated Conductor 13-3/8" x 4-%", 5,000 ksi 3 Casing, 20", 949, N K55 x 34", 0.312" Tubing String: 0 WT @ 4-I2", 12.6 #,1-80 TXP +/-80'MD Of c S C Level 3 Junction Systems Gas Lift Mandrel, 4-1/2" x 1" w/ dummy valve 10-3/4",45.5#, L-80, Hyd563 —>• Gas Lift Mandrel, 4-12"x l" w/ SOV 4-'/." SSD with 3.812" DB Nipple profile 1794' MD / 1700' TVD Perrnanent Down Hole Gauge Tubing Seal Assembly ;a n ZXP Packer 0 m Landing nipple profile mx N a. �o c 4 Stacked Baker Hook Hanger C Level 3 Junction Systems z ZXP Packer 1H-102 Producer Schematic DRAFT L4 "D" Sand Window r@ 7204' MD / 3753' TVD 75.570 inc � 4-12", 11.6# IBTM L80, Slotted Liner _ L3 "B" Sand Window @ 7472' MD / 3820' TVD 75.570 inc 4-1/2" Slotted Liner. 11.64 IBTM L80 Lateral Entry Module Seal x 4. Tubing Seal Assembly Landing nipple profile .g ZXP packer Z m o 7-5/8", 29.7#, L-80, Hyd563, Csg 8325' MD /4004' TVD .. ------------------ Swell Peckers .................................. L2 "A4" Sand Window n 7677' MD / 3871' TVD 75.570 inc 4-12" Slotted Liner11 69 1RTM ..•................•......•_.•..••..•..•.---•--. LI "A3" Sand Window rci 7834' MD / 3910' TVD, 75.57 0 inc '•.�-4-1/2"Slotted Liner, 11.6# IBTM L80 4-12" Slotted Liner, 11.6# IBTM L80 6-3/4" D sand lateral 14425' MD / 3801' TVD 6-3/4" B sand lateral 4444' MD / 3959'. TVD 6-3/4" A4 sand lateral 12522' MD / 3905' TVD __���•: 6-3/4" A3 sand lateral 12526: MD / 3964=TVD 6-3/4" A2 sand lateral 12526' MD / 4015' TVD ---------------------- t AM uoz-Lo-W :MVO IDIN 13N]V ONIMVNO inO),V3 HISO :31111 :AB NMVNG .oel .el5ero, sdipiydo:)ouo] 0 1 H-102L4wp23 11.G_C 3500 0 -6 M m o A� 0 1500 3000 to N rn N U 3C 7000 14000 Depth Reference: Plan: 54+39 @ 93.00uslt(Doyon 142) Rig: Doyon 142 ]5/8" x 9 -)IB" 4-12"x8.316" 1 i O p 1 Op � VYn 0 0 2000 4000 6000 6000 10000 SURVEY PROGRAM 1th From Depth To Survey/Plan Tool 39.00 700.00 1H-102wp23(Plan: 1H-102) GYD-GC-SS 700,00 1794.10 lH-102vvp23(Plan: 1H-102) MWD+IFR-AK-CAZ-SC 1794.10 7204.22 11-1-102M23 (Plan: 11-102) MWD+IFR-AK-CAZ-SC 7204.22 7554.22 iH-1021-4wp23(Plan: IH -1021-4) MWD -INC 7554.22 905422 iHA0214n23(Plan'. 11-10214) _ONLY MWD 7554.22 14425.15 1H -10214w 23 (Plan: 1H-10214) MWD+IFR-AK-CAZSC Prepared by: 10500 12000 14000 Pad Elevation: 54.00 CASING DETAILS 7.2107 I plan Summary a TVD MD Name 3753.15 7204.23 7-5/8" x 9-70' 3800.66 14425.15 4-12" x 6-3M" SECTION DETAILS Sec MD Inc Axi TVD -NAS -B-W Dleg Waco VSecl Target 1 ]204.22 75.57 0.00 3753.15 -512.01 4369.05 0.00 0.00 -512.01 2 721).02 77.61 0.00 3756.12 -499.56 4369.05 15.90 0.00 499,56 3 7237.02 77,61 0.00 3760.41 -400.03 4359,05 0.00 0.00 480.03 4 7553.78 90.00 2.65 3794.55 -165.85 437600 4.00 12.17 -165.85 5 767239 93.53 359.19 3]90.]4 -42.36 437839 400 -44.37 42.36 67921.70 93.53 359.19 3775.69 201.46 4374.93 0.00 0.00 201.46 7 ad 14.73 90.00 0.36 3))2.02 294.44 43]4.5] 4.00 181.80 294.44 1H -102D o1.T102C61] RP 8 8025.38 89.79 0.36 3))2.04 305.09 4374.64 2.00 -179.97 305.09 9 8]94.34 8979 0136 3775.70 1074.03 4379.49 0.00 0.00 1074.03 10 8005.02 90.00 0.30 37]5.]2 1084]0 437856 2.00 3.92 1D0470 1H -102D 02.T2 ON217 RP 11 8871.34 90.17 1.69 3]]562 1151.01 438076 200 82.66 1151,01 12 9289.93 90.17 1.69 3774.45 1548.43 4392.49 0.00 0.00 1540.43 13 9501.82 90.00 355.44 3773.98 186106 4384.60 2.00 -91.54 1861.08 11+1021)03.737717 RP i4 978.20 89.51 357.30 3774.40 1957.24 4378.55 200 104.00 1957.24 f5 10104,46 89.51 35).30 3)]0.06 2383.01 4350.40 0.00 0.00 2383.01 16 10422.86 a7, 36 348.00 3)8683 2698.10 4317.85 3.00 403.22 2690,10 1H -102004.T5030217 RP 17 10652.64 87.34 340.0 3797.50 292283 4270.08 0.00 000 2922.83 410992.06 90.00 0.00 3805.41 3259.65 4234.70 3.62 77.68 3259.65 111]4.28 811.00 3.7 380541 3441.75 4140.53 2.01 09.96 344175 20 11184.54 W.00 3.7 3805.41 3451.99 4241.19 0.00 0.00 3451.99 1H -102D 7.78 02021] RP 21 11354.39 93.58 357.88 3800.09 3621.64 4243.49 6.01 -58.21 3621.64 22 11361.07 93.58 357.88 3799.60 3628.30 4243.25 000 040 3628.30 1 H-1 02D WJ9 02021) RP 23 t 4:8.Ha 81.16 1.22 3794.01 3]85.98 4262.17 3.00 128.15 P65.90 24 11780.35 91.16 1.22 3]88.2) 4055.31 4240.32 0.00 0.00 4055.31 25 11915.99 90.00 350.93 3]8)00 410293 4240.49 2.00 -116.40 4182.93 1H-102009.71002021) RP 26 11929.10 89.94 35905 3787.01 419612 4248.26 1.00 115.91 4196.12 27 12239,89 89.94 359.05 377.32 4506.89 4243.11 0.00 0.00 4506.89 28 12332.69 87.88 358.00 3789.09 4599.53 4240.72 2.50 -153.05 4599.53 1H -102D 10311 OW211RP 29 13290.49 8102 318.73 3016.12 5472.13 3894,64 4.10 -88.96 5472.13 30 13352.11 89.02 310.73 3017.10 5510.45 3853.89 0.00 0.00 5518.45 31 13407.86 91.12 317.85 3817.11 5560.7 3816,80 4.10 -22.75 5560,7 IH -1020 13.T1670717RP 32 13935.50 91,12 317.85 3a08]8 5951.23 3462.72 0.00 000 5951.23 1H-102D14.T15027PRP 33 14160.10 90.59 324.56 3803.40 6126.10 3322.15 300 94.48 6128.10 34 14425.15 90.59 324.56 3800.66 6342.04 316640 0.00 0,00 6342.04 11-1-102D 15716020717 RP I ack lmledoe that I have been Checked by: Huy But Ann Accepted by Enk S1erk 0- - ]204 ]tH - 7390 )390 - 770 m0 - 7760 7760 - 794o 7940 - 8130 8130 - 8310 8310 - moo 8500 - 87W 3)50 9000 90N - 9250 90 92.4 - 9500 900-970 9)50 - 1000 10000 - 1025 10250 - 1050 low - 1099 10990 - it 11480 - HW 11970 - 1246 12480 - 1296 12960 1345 3450 394 13940 - 1442 Magnellc MMGI: DGGM2U1] I Magnetic MWN Dale: 22.62'-17 Magagnc Ce P irocl0n: TO convert a Magnetic DlreNon 108 aTrue True Dredlon, 400 17.62° East 1620.4 PFROST Annolatlon KOP:15.9-1109 DLS, 0° TE for 12.8' 1788.8 Hold for 2b T-3 008.4 Minor Risked I K-15 HOW for 310.01 3135.4 UG G 3382.6 UG 0 3486.8 UG -A 36101 Na Approved by: am ® COMPVia,v M PmduN n �` 4 Flit Editt View Analyss Plot Report Tr-lhF9CylindorWae Tooh Window Help aPi#"'a R M $ k Tig* G/ L LID 95 On [41 0'o0 L1tih: MI U$Suver Eaelr- oapxn:Plan:549A Q93.Ill Olinin 142:_rT4Dt ti, !Ilea. -R-5-ot- flxN:r� ®Plan Fill -p-, lar, 1H-102 3131PIen: 1H 1021J,9H10Lawp3 +'r1 10.9 L41°../al QP... �m_.- Plan LIf9 PI 4u5eIIpaC11 so In ram[ IIB.W Is 00 2 Mt41.37 11 t9 3f4 v 111/ u t`ei, 1 X ' h 11fI' 10+� ForHtlp, press fl rozl oy g7 0 3( 13 12 ]COW MO a Inc AY TtD Mss 15 E\v .,I, T.iam (u ft (usN) (9 (� (mR) R) (r¢It) Iusft3 (=It00usH 0.00 (y p➢ 000 •Tre TN9at 1 7Z0 22 )5 5] o W . 315 5 Mfi 11 51201 4369,95 2 ]2 ) 0$ I] 30 JI b] 0 A : 3156 IZ 3663 R -099 56 %9,05 15.90 Ill 0) 3 I: 102 bl0 J]6 .3JfiO4 366141 -09003 419.OS O.W o005b 4 ]553 )8 316 ]6 `b U) $ 5 3794 55 3]0155 165 85 43]6.. 4. 400 12 t] IM 44-7 OP 5 ]6)) 39 1-- 1-1 359 19 3]90 )i 11 ]a -42. 53.,79 6 I'Di 25431 9353 35919 3]]569 360]69 _ IDI$ 4314.93 0,00 000 - 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J3 9305'. .00 0 M 1]]282 bA82 294. 537957 5.00 16160 iH- IFFM O I.T10y361JRP 3 all,. 1065 897 036-311Z$ bA 89 30509 437964 2,00 "I9J OP 9 879434 79095 8979 (F3,5 3M J0 365279 107403 437999 0.00 0 n 10 880502 ID. 9p 10 338 3775 72 182 72 -U84ID 437956 2.00 2.M 392 92 nfi W 'NJON302.T20L]20PP I'll 697139 66 32 90 I l M )) 6$ 3692 6$ 5101 490 76 12 926893 7]79: 991] 1W 3P 95 368145 ISa3=3 439249 O.N 006 ll 959162 31269 Al 311.41 37398 .11 :861064384.66 _2,00 2,In 9154 --I,=.W IH 10ID03,T3020217PP 1 14 968 4 9fi 33: 9 51 35I . 3179. 181.. 1111. +3]9.55 0 11 42626 fe51 39A 3M.06 369506 238301 431858 0,00 000 16 10122,11 aiS18 -[139 3Y0' 3lnnn 369383 269610 431765 3.011 0.00 .322 000 IV 1X FPM 04.T50A231. a 1710652 4 2 `00 8111 ydp9 379750 379430 X2$83 42A.OH 18 1199$ 6 1... 99 0 3 3403 AI 3]1241, 315965 4234)0 -3 S$ 8e6 ,1n[ 19 11179)8 18222 9000 361 30W41 37IZ41' 3W1IS 42. 53 2 Il 8996 OY 20 111845963.26 ..On 367 380541 3]]291 395]99 42". 0.00 000' 1H W.0).THON2IJRP e 21 ?135 39 6995. 9359 35]1 360099 379>W 352]69 4$..49 401 y821 OT 22 113[ 07` fi.fi8 935° 35).88 37969 3]:16.66 36]X30 4143.25 0,00 000 91-]pID Od 190A21JRP 23 ]159899 {31,83 9114 I-- 37401 3Jo1.o1 376508 ^242.11 5D 12615'OP = 29 limIs x9.45 9114 111 3M.27 3595.27 05531 4248.32 0,00 000. _ 25 1191,99 12164 90.00 35$,93 3.700 M... 418293 42... 2.00 116.40 ' IH102009.T W O.IU7 RP 7611911,19 13.4 09,99'. 359,05 3M7 01 369901 419"0.12 42..25 1.00 11591 :CG Z] 12ll9.99 IIII, • '69.94 359.05 318132 314.32 1.6.89 4243,11 0.00 O,OD A 12332.69 92669 31.33 35$.09 3.9,09 M96 09 4599.53 42.72 2.59 153.05. IX l0YI l0.T 1192021]RP 29 13299.49 9s].A 89.02 318.73 3$16.12 3)23.12 541913 7994,54 80.96. 30 1335211 61 63 318.73 W 7 3ITII 372916 551045 153,69 O.W 0.09 31 13.185 55.75 9112 91.12 317.95 381211 389.11. 1S60.o] }916.80 4610 _ -22.15 Wl0ID ATM0N]IJRP 32 ]3935.Q 527.12 91.12 3V.85 3806. ]fi 3]13.76 5951.23 3462. T[ 0.00 9.00:m 1H-102L119.T35020III D, ]3 141F.0. 10 224.5$ 9959. 3$4.$ 3893..,3]10...6126.10 33$2.15' 390 94,9DT 14 1442515 M5I, 9059. 324.1 380D.66 370].66. 6342794 3168.9 0,00 000. IM -1070 Ie Tt60411]RP Plan LIf9 PI 4u5eIIpaC11 so In ram[ IIB.W Is 00 2 Mt41.37 11 t9 3f4 v 111/ u t`ei, 1 X ' h 11fI' 10+� ForHtlp, press fl rverP � Pxeroere, oIo J Leland o L]^ Y 2 oVial, Plar, let 10216wp23(PIan: 1HID2(formcAy 3)i^Ian: 1H 10217 61H-1021-dwp23 (-%.)'ep -a 0:11t -61H 105,1H 105'M dF1H 05, 1H- I 191H 09,1H -09,1H 09 V1 ___ 191H -11.1H -U,, I1H 11 2! - r/1H12H1; 1H-1211 iq I. e1H-13, 1H 13, 1H3311 F @1H-15, 11--15, 31-1-15 -t-1H A, 1H -113H-11 V1 @1H 101(UCNU),1H 401 $Plan IH -101 (formlyl.. 9 PIan'lil l(formerlyl.., > Y @PIan:1H 101 (term 1y1.. GPlamiH ePlan.1H 102(form iF Plan 1H102(formerlY 3._ Q Plan 11-1-1020(formerly 3... \i Plan 1H 1023.. 'K @Plan iH 101 (formery 3... ' I" '-. --�-- I 9•PIan1H1u30ormaryl.. - I L 4Plan.IH 103 (formery 1. #PIerv.3H 103(farmedyl-.-- �Plan'I 103(nnnnalyl.. ua r _ i Plan 11-1.ID3 a0rmeq l... _ w.+sessraon mr' HPI 1H 112 iformedyl ' #PI '.1H 1120ormedyl 1H -t! Fill ' t I i, $PI aH 113llcrmetlyi. - 1H -1f -I I MD TD1)H TYOP N Si,,, T-1 I k) f k Onk) (uay Were 19>'S 162, "o IIA`q PeRi ill, 15 l ',A IF ]69 3FalTI JZ'SC 319 200950 Y915.9,j Al15 16x.'08. 11 5 V Ya41 T � ii'1l An m r:r r' 9.5 .61 ",A I, . 3.91 8.9 3979 9'J ` � S 792 IITravellin '$ Common'rl'ell Name Unit Syslem'. API US Survey Feet [usft] MAP. usk rozl oy g7 0 3( 13 12 ]COW 1.9110 11 9 >A. 1'9n to R(v12 zoal2 •5S<22 rverP � Pxeroere, oIo J Leland o L]^ Y 2 oVial, Plar, let 10216wp23(PIan: 1HID2(formcAy 3)i^Ian: 1H 10217 61H-1021-dwp23 (-%.)'ep -a 0:11t -61H 105,1H 105'M dF1H 05, 1H- I 191H 09,1H -09,1H 09 V1 ___ 191H -11.1H -U,, I1H 11 2! - r/1H12H1; 1H-1211 iq I. e1H-13, 1H 13, 1H3311 F @1H-15, 11--15, 31-1-15 -t-1H A, 1H -113H-11 V1 @1H 101(UCNU),1H 401 $Plan IH -101 (formlyl.. 9 PIan'lil l(formerlyl.., > Y @PIan:1H 101 (term 1y1.. GPlamiH ePlan.1H 102(form iF Plan 1H102(formerlY 3._ Q Plan 11-1-1020(formerly 3... \i Plan 1H 1023.. 'K @Plan iH 101 (formery 3... ' I" '-. --�-- I 9•PIan1H1u30ormaryl.. - I L 4Plan.IH 103 (formery 1. #PIerv.3H 103(farmedyl-.-- �Plan'I 103(nnnnalyl.. ua r _ i Plan 11-1.ID3 a0rmeq l... _ w.+sessraon mr' HPI 1H 112 iformedyl ' #PI '.1H 1120ormedyl 1H -t! Fill ' t I i, $PI aH 113llcrmetlyi. - 1H -1f -I I MD TD1)H TYOP N Si,,, T-1 I k) f k Onk) (uay Were 19>'S 162, "o IIA`q PeRi ill, 15 l ',A IF ]69 3FalTI JZ'SC 319 200950 Y915.9,j Al15 16x.'08. 11 5 V Ya41 T � ii'1l An m r:r r' 9.5 .61 ",A I, . 3.91 8.9 3979 9'J ` � S 792 IITravellin '$ Common'rl'ell Name Unit Syslem'. API US Survey Feet [usft] MAP. usk 16:24, June 29 2017 Easting (2500 usft/in) - ou 1R-25 1R-24 1R-16 1H-125wp20 1 R-01 BL1-01 1 H-124wp20 R g11H-123wp20 R-816 L' -01P61 1H-122wp20 1R-01 - 6 1H-121wp20 1 H-120wp21 1 C-164wp06 1"C - f1C 9wp�"j\1C-156wp06 5577 55 \ �1�C�i5 u�ipal 1R-27 p03) 1H-102L4wp 3 1R-29 L1 R -29L1-01 1 R-0 1H-20 -102L3 p23 JWPB1 _ 11 9i e 1 1 e A 9 p '1 H-19AL1 w '1 00 1G-07 1,1A 1H 16A 1H-11 wp2 H-0 1 - JNC-ONLY toolcode) 1 H-17 10 I t,GG nj]Bj� tci-�1)FtL1 Y 1H-16AL1 1H- p21 1H-115wp21 0 Z 1H-19AL2 1H- L1 116wp21 1G-10BPB1 1 tr_ to tu_m -1 - Kuparuk 1H Pag -11 9wp21 1H-12 1H-113wp21 1 -111wp21 1H- 0 H-21 04 1H-108wp2 1A Up21 1 A33 -12L1 -11A 1H-15 -104w 1s C 9 1H- 1H 1H -107w -106wp21 1 1 C-1 1C-1 1 4L1 1H-01 1B-102 1C- 1G-12 H-08 1H-02 1H- 1C-1 C--1111 L 02 iC 17 Easting (2500 usftlin) 1 C-164wp06 1"C - f1C 9wp�"j\1C-156wp06 5577 55 \ �1�C�i5 u�ipal 1 H-102L4wp23 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. K �It! 4-1/2" x 6-3/4"-6000 17 P 20717 P orth Fa 7 P 4500 outh 10.T11 020217 P 020217 P + p 3000 p o P Z 020217 P ' 020217 P "02232 L 3 O In 1500 020217 P 020217 P oo0 000 0 20" x 42"------ 0 1H -102D 01.T1 020617 10o po - P 7-5/8" x 9-7/8L- 10-3/4" x 13-1/2" o 0o r7p00 �' o 0 h -1500 0 -3000 -1500 0 1500 3000 4500 6000 7500 West( -)/East(+) 1 H-102L4wp23 Section View 3680 n 7-5/8" x 9-7/8" N w o , ----------------- rn---�o---- ----- Q _L 3760 c, C-) °) d CO C\r-> o o O CD. M 0 3840 0 0 00 N _ 0 CA) > v 3920 M ', W F 3 N J N O i 4000 CO a 3 J = Cli � O O � N ' r 4080 W 0 850 1700 2550 3400 4250 5100 5950 6800 Vertical Section at 0.000 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-102 (formerly 31) Plan: 11-1-1021-4 Plan: 1 H-102L4wp23 .3 stearin. Standard Proposal Report 29 June, 2017 Minor Risked Database: EDM Production Company: ConocoPhillips (Alaska) Inc. -Kupt Project: Kupamk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-102 (formerly 31) Wellbore: Plan: 11-1-1021-4 Design: 1 H-102L4wp23 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: SLB Standard Proposal Report Well Plan: 1H-102 (formerly 31) Plan: 54+39 @ 93.00usft (Doyon 142) Plan: 54+39 @ 93.00usft (Doyon 142) True Minimum Curvature Project Kupamk River Unit, North Slope Alaska, United States System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Kuparuk 1 H Pad Site Position: From: Map Position Uncertainty: 0.00 usft Slot Radius: 0" Well Plan: 1 H-1 02 (formerly 31) Well Position +N/ -S 0.00 usft +E/ -W 0.00 usft Position Uncertainty 0.00 usft Ground Level: 54.00 usft Wellbore Plan: 1H-10214 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (% M (nT) BGGM2017 6/22/2017 17.62 80.95 57,498 Design Audit Notes: Version: Vertical Section: 11-1-1021-4wp23 Phase: Depth From (TVD) (usft) 39.00 PLAN +N/ -S (usft) 0.00 Tie On Depth: +E/ -W (usft) 0.00 7,204.22 Direction (°I 0.00 6/29/2017 4:05:52PM Page 2 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production local Cc -ordinate Reference: Well Plan: 1 H-102 (formerly 31) Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kupauk River Unit MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Plan: 1H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-1021-4 Depth Inclination Design: 1H-102L4wp23 System +NIS Plan Sections Measured Vertical TVD Dogleg Build Tum Depth Inclination Azimuth Depth System +NIS +El -W Rate Rate Rate Tool Face (usft) (°) (1 (usft) usft (usft) (usft) (°1100usft) (°i100us(t 7,204.22 75.57 0.00 3,753.15 3,660.15 -512.01 4,369.05 0.00 0.00 0.00 0.00 7,217.02 77.61 0.00 3,756.12 3,663.12 499.56 4,369.05 15.90 15.90 0.00 0.00 7,237.02 77.61 0.00 3,760.41 3,667.41 -480.03 4,369.05 0.00 0.00 0.00 0.00 7,553.78 90.00 2.65 3,794.55 3,701.55 -165.85 4,376.40 4.00 3.91 0.84 12.17 7,677.39 93.53 359.19 3,790.74 3,697.74 -42.36 4,378.39 4.00 2.86 -2.80 -44.37 7,921.70 93.53 359.19 3,775.69 3,682.69 201.46 4,374.93 0.00 0.00 0.00 0.00 8,014.73 90.00 0.36 3,772.82 3,679.82 294.44 4,374.57 4.00 -3.80 1.26 161.60 8,025.38 89.79 0.36 3,772.84 3,679.84 305.09 4,374.64 2.00 -2.00 0.00 -179.97 8,794.34 89.79 0.36 3,775.70 3,682.70 1,074.03 4,379.49 0.00 0.00 0.00 0.00 8,805.02 90.00 0.38 3,775.72 3,662.72 1,084.70 4,379.56 2.00 2.00 0.14 3.92 8,871.34 90.17 1.69 3,775.62 3,682.62 1,151.01 4,380.76 2.00 0.26 1.98 82.66 9,268.93 90.17 1.69 3,774.45 3,681.45 1,548.43 4,392.49 0.00 0.00 0.00 0.00 9,581.82 90.00 355.44 3,773.98 3,680.98 1,861.06 4,384.66 2.00 -0.05 -2.00 -91.54 9,678.20 89.51 357.30 3,774.40 3,681.40 1,957.24 4,378.55 2.00 -0.51 1.93 104.80 10,104.46 89.51 357.30 3,778.06 3,685.06 2,383.01 4,358.48 0.00 0.00 0.00 0.00 10,422.64 87.34 348.00 3,786.83 3,693.83 2,698.10 4,317.85 3.00 -0.68 -2.92 -103.22 10,652.64 87.34 348.00 3,797.50 3,704.50 2,922.83 4,270.08 0.00 0.00 0.00 0.00 10,992.06 90.00 0.00 3,805.41 3,712.41 3,259.65 4,234.70 3.62 0.78 3.54 77.68 11,174.28 90.00 3.67 3,805.41 3,712.41 3,441.75 4,240.53 2.01 0.00 2.01 69.96 11,184.54 90.00 3.67 3,805.41 3,712.41 3,451.99 4,241.19 0.00 0.00 0.00 0.00 11,354.39 93.58 357.88 3,800.09 3,707.09 3,621.64 4,243.49 4.01 2.11 -3.41 -58.21 11,361.07 93.58 357.88 3,799.68 3,706.68 3,628.30 4,243.25 0.00 0.00 0.00 0.00 11,498.90 91.14 1.22 3,794.01 3,701.01 3,765.98 4,242.17 3.00 -1.77 2.42 126.15 11,788.35 91.14 1.22 3,788.27 3,695.27 4,055.31 4,248.32 0.00 0.00 0.00 0.00 11,915.99 90.00 358.93 3,787.00 3,694.00 4,182.93 4,248.49 2.00 -0.89 -1.79 -116.40 11,929.18 89.94 359.05 3,787.01 3,694.01 4,196.12 4,248.26 1.00 -0.44 0.90 115.91 12,239.99 89.94 359.05 3,787.32 3,694.32 4,506.89 4,243.11 0.00 0.00 0.00 0.00 12,332.69 87.88 358.00 3,789.09 3,696.09 4,599.53 4,240.72 2.50 -2.23 -1.13 -153.05 13,290.48 69.02 318.73 3,816.12 3,723.12 5,472.13 3,894.54 4.10 0.12 4.10 -88.96 13,352.11 89.02 318.73 3,817.18 3,724.18 5,518.45 3,853.89 0.00 0.00 0.00 0.00 13,407.86 91.12 317.85 3,817.11 3,724.11 5,560.07 3,816.80 4.10 3.78 -1.59 -22.75 13,935.58 91.12 317.85 3,806.76 3,713.76 5,951.23 3,462.72 0.00 0.00 0.00 0.00 14,160.10 90.59 324.56 3,803.40 3,710.40 6,126.10 3,322.15 3.00 -0.24 2.99 94.48 14,425.15 90.59 324.56 3,800.66 3,707.66 6,342.04 3,166.48 0.00 0.00 0.00 0.00 6/292017 4:05:52PM Page 3 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 1 H-102 (formerly 31) Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Plan: 1 H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-10214 Depth TVDss Design: 1HA02L4wp23 DLS Vert Section Planned Survey the lig@,tiefpre' Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W DLS Vert Section (usft) (_) (I (usft) usft (usft) (usft) 3,660.15 7,204.22 75.57 0.00 3,753.15 3,660.15 -512.01 4,369.05 0.00 -512.01 KOP: 15.9'/100' OLS, 0' TF, for 12.8' 7,204.23 75.57 0.00 3,753.15 3,660.15 -512.01 4,369.05 0.01 -512.01 7-6/8" x 9-7/8" 7,212.80 76.93 0.00 3,755.19 3,662.19 -503.68 4,369.05 15.92 -503.68 Start 4°1100' DLS, 0.02' TF, for 308.25' 7,217.02 77.61 0.00 3,756.12 3,663.12 499.56 4,369.05 15.90 -499.56 Hold for 20' 7,237.02 77.61 0.00 3,760.41 3,667.41 480.03 4,369.05 0.00 480.03 7,300.00 80.07 0.54 3,772.60 3,679.60 -418.25 4,369.34 4.00 -418.25 7,400.00 83.98 1.38 3,786.48 3,693.48 -319.25 4,371.00 4.00 -319.25 7,500.00 87.89 2.21 3,793.56 3,700.56 -219.57 4,374.13 4.00 -219.57 7,521.05 88.72 2.38 3,794.18 3,701.18 -198.54 4,374.97 4.00 -198.54 Adjust TF to 54.291, for 149.62' 7,553.78 90.00 2.65 3,794.55 3,701.55 -165.85 4,376.40 4.00 -165.85 7,600.00 91.32 1.36 3,794.01 3,701.01 -119.66 4,378.02 4.00 -119.66 7,670.68 93.34 359.38 3,791.14 3,698.14 49.05 4,378.47 4.00 49.05 Hold for 222.97' 7,677.39 93.53 359.19 3,790.74 3,697.74 42.36 4,378.39 4.00 -42.36 7,700.00 93.53 359.19 3,789.34 3,696.34 -19.79 4,376.07 0.00 -19.79 7,800.00 93.53 359.19 3,783.16 3,690.18 80.01 4,376.65 0.00 80.01 7,893.65 93.53 359.19 3,777.41 3,684.41 173.47 4,375.33 0.00 173.47 Start 4'1100' DLS, 143.51° TF, for 108.42' 7,900.00 93.53 359.19 3,777.02 3,684.02 179.81 4,375.24 0.00 179.81 7,921.70 93.53 359.19 3,775.69 3,682.69 201.46 4,374.93 0.00 201.46 8,000.00 90.56 0.18 3,772.89 3,679.89 279.71 4,374.50 4.00 279.71 8,002.07 90.48 0.20 3,772.87 3,679.87 281.78 4,374.51 4.00 281.78 Start 2'/100' DLS, -179.97' TF, for 10.65' 8,012.73 90.08 0.34 3,772.82 3,679.82 292.43 4,374.56 400 292.43 Hold for 768.96' 8,014.73 90.00 0.36 3,772.82 3,679.82 294.44 4,374.57 4.00 294.44 8,025.38 89.79 0.36 3,772.84 3,679.84 305.09 4,374.64 2.00 305.09 8,100.00 89.79 0.36 3,773.12 3,680.12 379.70 4,375.11 0.00 379.70 8,200.00 69.79 0.36 3,773.49 3,680.49 479.70 4,375.74 0.00 479.70 8,300.00 89.79 0.36 3,773.86 3,680.66 579.70 4,376.37 0.00 579.70 8,400.00 89.79 0.36 3,774.23 3,681.23 679.70 4,377.00 0.00 679.70 8,500.00 69.79 0.36 3,774.60 3,681.60 779.69 4,377.63 0.00 779.69 8,600.00 89.79 0.36 3,774.98 3,681.98 879.69 4,378.26 0.00 879.69 8,700.00 89.79 0.36 3,775.35 3,682.35 979.69 4,378.89 0.00 979.69 8,781.68 89.79 0.36 3,775.65 3,682.65 1,061.37 4,379.41 0.00 1,061.37 Start 2'1100' DLS, 3.92' TF, for 10.66' 8,792.36 89.79 0.36 3,775.69 3,662.69 1,072.04 4,379.48 0.00 1,072.04 Adjust TF to 82.66', for 66.32' 8,794.34 89.79 0.36 3,775.70 3,682.70 1,074.03 4,379.49 0.00 1,074.03 8,800.00 89.90 0.37 3,775.71 3,682.71 1,079.69 4,379.53 2.00 1,079.69 6/292017 4:05:52PM Page 4 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 1H-102 (formerly 31) Company: Con000Phillips (Alaska) Inc. -Kupi TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Site: Kupawk 1H Pad North Reference: True Well: Plan: 1 H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-1021-4 +Nf-S +E/ -W Design: 1H-102L4wp23 (usft) Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +Nf-S +E/ -W DLS Vert Section (usft) (usft) usft (usft) (usft) 3,682.72 8,805.02 90.00 0.38 3,775.72 3,682.72 1,084.70 4,379.56 2.00 1,084.70 8,858.68 90.14 1.44 3,775.65 3,682.65 1,138.35 4,380.41 2.00 1,138.35 Hold for 397.59' 8,871.34 90.17 1.69 3,775.62 3,682.62 1,151.01 4,380.76 2.00 1,151.01 6,900.00 90.17 1.69 3,775.54 3,682.54 1,179.66 4,381.60 0.00 1,179.66 9,000.00 90.17 1.69 3,775.24 3,682.24 1,279.62 4,384.55 0.00 1,279.62 9,100.00 90.17 1.69 3,774.94 3,681.94 1,379.57 4,387.51 0.00 1,379.57 9,200.00 90.17 1.69 3,774.65 3,681.65 1,479.53 4,390.46 0.00 1,479.53 9,256.27 90.17 1.69 3,774.48 3,681.48 1,535.77 4,392.12 0.00 1,535.77 Start 2'1100' DLS, -91.64' TF, for 312.89' 9,268.93 90.17 1.69 3,774.45 3,681.45 1,546.43 4,392.49 0.00 1,548.43 9,300.00 90.15 1.07 3,774.36 3,681.36 1,579.49 4,393.24 2.00 1,579.49 9,400.00 90.10 359.07 3,774.14 3,681.14 1,679.48 4,393.37 2.00 1,679.48 9,500.00 90.04 357.07 3,774.01 3,681.01 1,779.42 4,390.00 2.00 1,779.42 9,569.16 90.01 355.69 3,773.98 3,680.98 1,848.44 4,385.64 2.00 1,848.44 Adjust TF to 104.8°, for 96.38' 9,581.82 90.00 355.44 3,773.98 3,680.98 1,861.06 4,384.66 2.00 1,861.06 9,600.00 89.91 355.79 3,774.00 3,681.00 1,879.19 4,383.27 2.00 1,879.19 9,665.54 89.57 357.06 3,774.29 3,681.29 1,944.60 4,379.18 2.00 1,944.60 Hold for 426.26' 9,678.20 89.51 357.30 3,774.40 3,681.40 1,957.24 4,378.55 2.00 1,957.24 9,700.00 89.51 357.30 3,774.58 3,681.58 1,979.02 4,377.53 0.00 1,979.02 9,800.00 89.51 357.30 3,775.44 3,682.44 2,078.91 4,372.62 0.00 2,078.91 9,900.00 89.51 357.30 3,776.30 3,683.30 2,178.79 4,368.11 0.00 2,178.79 10,000.00 89.51 357.30 3,777.16 3,684.16 2,278.68 4,363.40 0.00 2,278.68 10,091.80 89.51 357.30 3,777.95 3,684.95 2,370.37 4,359.07 0.00 2,370.37 Start 3'/100' DLS, .103.22' TF, for 318.18' 10,100.00 89.51 357.30 3,778.02 3,685.02 2,376.56 4,358.69 0.00 2,378.56 10,10446 89.51 357.30 3,778.06 3,685.06 2,383.01 4,358.48 0.00 2,383.01 10,200.00 88.85 354.51 3,779.43 3,686.43 2,478.29 4,351.65 3.00 2,478.29 10,300.00 88.17 351.59 3,782.02 3,689.02 2,577.51 4,339.56 3.00 2,577.51 10,400.00 87.49 348.66 3,785.81 3,692.81 2,675.95 4,322.42 3.00 2,675.95 10,409.98 87.43 348.37 3,786.25 3,693.25 2,685.72 4,320.44 3.00 2,685.72 Hold for 230' 10,422.64 87.34 348.00 3,786.83 3,693.83 2,698.10 4,317.85 3.00 2,698.10 10,500.00 87.34 348.00 3,790.42 3,697.42 2,773.69 4,301.78 0.00 2,773.69 10,600.00 87.34 348.00 3,795.06 3,702.06 2,871.40 4,281.01 0.00 2,871.40 10,639.98 87.34 348.00 3,796.92 3,703.92 2,910.46 4,272.71 0.00 2,910.46 Start 3.62.1100' OLS, 77.68° TF, for 339.42' 10,652.64 87.34 348.00 3,797.50 3,704.50 2,922.83 4,270.08 0.00 2,922.83 10,688.95 87.62 349.29 3,799.10 3,706.10 2,958.40 4,262.93 3.62 2,958.40 WS_C 10,700.00 87.71 349.68 3,799.55 3,706.55 2,969.25 4,260.92 3.62 2,969.25 10,800.00 88.49 353.21 3,602.87 3,709.87 3,068.07 4,246.06 3.62 3,068.07 10,900.00 69.27 356.75 3,604.83 3,711.83 3,167.65 4,237.31 3.62 3,167.65 629/2017 4:05.52PM Page 5 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 1H-102 (formerly 31) Company: ConowPhillips (Alaska) Inc. -Kup1 TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Plan: 1H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 11-1-1021-4 DLS Vert Section Design: 1H-102L4wp23 (usft) usft Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W DLS Vert Section (usft) V) V) (usft) usft (usft) (usft) 3,712.40 10,979.40 89.90 359.55 3,805.40 3,712.40 3,246.99 4,234.75 3.62 3,246.99 Start 2.01.1100' DLS, 89.96° TF, for 182.22' 10,992.06 90.00 0.00 3,805.41 3,712.41 3,259.65 4,234.70 3.62 3,259.65 11,000.00 90.00 0.16 3,805.41 3,712.41 3,267.59 4,234.71 2.01 3,267.59 11,100.00 90.00 2.17 3,805.41 3,712.41 3,367.57 4,236.74 2.01 3,367.57 11,161.62 90.00 3.42 3,805.41 3,712.41 3,429.11 4,239.75 2.01 3,429.11 Hold for 10.26' 11,171.88 90.00 3.62 3,805.41 3,712.41 3,439.36 4,240.38 2.01 3,439.36 Start 4.01 VI 00- DLS, 58.21° TF, for 169.85' 11,174.28 90.00 3.67 3,805.41 3,712.41 3,441.75 4,240.53 2.01 3,441.75 11,184.54 90.00 3.67 3,805.41 3,712.41 3,451.99 4,241.19 0.00 3,451.99 11,200.00 90.33 3.14 3,805.36 3,712.36 3,467.42 4,242.11 4.01 3,467.42 11,300.00 92.44 359.74 3,802.95 3,709.95 3,567.34 4,244.62 4.01 3,567.34 11,341.73 93.31 358.31 3,800.85 3,707.85 3,609.02 4,243.91 4.01 3,609.02 Hold for 6.67' 11,348.41 93.45 358.08 3,800.46 3,707.46 3,615.67 4,243.70 4.01 3,615.67 Start 3°/100' DLS, 126.15° TF, for 137.84' 11,354.39 93.58 357.88 3,800.09 3,707.09 3,621.64 4,243.49 4.01 3,621.64 11,361.07 93.58 357.88 3,799.68 3,706.68 3,628.30 4,243.25 0.00 3,628.30 11,400.00 92.89 358.82 3,797.48 3,704.48 3,667.15 4,242.13 3.00 3,667.15 11,486.25 91.36 0.91 3,794.28 3,701.28 3,753.34 4,241.93 3.00 3,753.34 Hold for 289.44' 11,498.90 91.14 1.22 3,794.01 3,701.01 3,765.96 4,242.17 3.00 3,765.98 11,500.00 91.14 1.22 3,793.98 3,700.98 3,767.08 4,242.19 0.00 3,767.08 11,600.00 91.14 1.22 3,792.00 3,699.00 3,867.04 4,244.32 0.00 3,867.04 11,700.00 91.14 1.22 3,790.02 3,697.02 3,967.00 4,246.44 0.00 3,967.00 11,775.69 91.14 1.22 3,788.52 3,695.52 4,042.65 4,248.05 0.00 4,042.65 Start 2*1100' DLS, -116.4° TF, for 127.64' 11,788.35 91.14 1.22 3,788.27 3,695.27 4,055.31 4,248.32 0.00 4,055.31 11,800.00 91.03 1.01 3,788.05 3,695.05 4,066.96 4,248.55 2.00 4,066.96 11,900.00 90.14 359.22 3,787.02 3,694.02 4,166.94 4,248.75 2.00 4,166.94 11,903.33 90.11 359.16 3,787.02 3,694.02 4,170.27 4,248.70 2.00 4,170.27 Start 1 °/100' DLS, 115.91° TF, for 13.2' 11,915.99 90.00 358.93 3,787.00 3,694.00 4,182.93 4,248.49 2.00 4,182.93 11,916.52 90.00 358.94 3,787.00 3,694.00 4,183.47 4,248.48 1.00 4,183.47 Hold for 310.81' 11,929.18 89.94 359.05 3,787.01 3,694.01 4,196.12 4,248.26 1.00 4,196.12 12,000.00 89.94 359.05 3,787.08 3,694.08 4,266.93 4,247.08 0.00 4,266.93 12,100.00 89.94 359.05 3,787.18 3,694.18 4,366.92 4,245.43 0.00 4,366.92 12,200.00 89.94 359.05 3,787.28 3,694.28 4,466.90 4,243.77 0.00 4,466.90 12,227.33 89.94 359.05 3,787.31 3,694.31 4,494.23 4,243.32 0.00 4,494.23 Start 2.6°/100' DLS, -163.05° TF, for 92.69' 12,239.99 89.94 359.05 3,787.32 3,694.32 4,506.89 4,243.11 0.00 4,506.89 12,300.00 88.61 358.37 3,788.08 3,695.08 4,566.88 4,241.76 2.50 4,566.88 61292017 4: 05:52PM Page 6 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 1H-102 (formerly 31) Company: ConocoPhillips (Alaska) Inc. -Kupt TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 (off 93.00usft (Doyon 142) Site: Kuparuk 1 H Pad North Reference: True Well: Plan: 1H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 111-1021-4 usR (usft) Design: 1H-102L4wp23 12,320.03 Planned Survey Measuretl Vertical Depth Inclination Azimuth Depth TVDss +NIS +E/ -W DLS Vert Section (Usk) I.) (_) lush) usR (usft) lush) 3,596.65 12,320.03 88.16 358.14 3,788.65 3,695.65 4,586.89 4,241.15 2.50 4,586.89 Start 4.1°/100' DLS, -88.96' TF, for 957.79' 12,332.69 87.88 358.00 3,789.09 3,696.09 4,599.53 4,240.72 2.50 4,599.53 12,400.00 87.93 355.24 3,791.55 3,698.55 4,666.68 4,236.76 4.10 4,666.68 12,500.00 88.02 351.14 3,795.09 3,702.09 4,765.89 4,224.91 4.10 4,765.89 12,600.00 88.11 347.04 3,798.47 3,705.47 4,864.00 4,205.99 4.10 4,864.00 12,700.00 88.22 342.94 3,801.67 3,708.67 4,960.52 4,180.10 4.10 4,960.52 12,800.00 88.34 338.84 3,804.67 3,711.67 5,054.94 4,147.38 4.10 5,054.94 12,900.00 88.46 334.74 3,807.47 3,714.47 5,146.79 4,107.98 4.10 5,146.79 13,000.00 88.59 330.64 3,810.04 3,717.04 5,235.59 4,062.12 4.10 5,235.59 13,100.00 88.73 326.54 3,812.37 3,719.37 5,320.89 4,010.03 4.10 5,320.89 13,200.00 88.88 322.44 3,814.46 3,721.46 5,402.26 3,951.97 4.10 5,402.26 13,277.82 89.00 319.25 3,815.90 3,722.90 5,462.58 3,902.84 4.10 5,462.58 Hold for 61.63' 13,290.48 89.02 318.73 3,816.12 3,723.12 5,472.13 3,894.54 4.10 5,472.13 13,300.00 89.02 318.73 3,816.28 3,723.28 5,479.29 3,888.26 0.00 5,479.29 13,339.45 89.02 318.73 3,816.96 3,723.96 5,508.94 3,862.24 0.00 5,508.94 Start 4.1.1100' DLS, -22.76' TF, for 55.76' 13,352.11 89.02 318.73 3,817.18 3,724.18 5,518.45 3,853.89 0.00 5,516.45 13,395.20 90.65 318.05 3,817.31 3,724.31 5,550.67 3,825.28 4.10 5,550.67 Hold for 627.72' 13,400.00 90.83 317.97 3,817.24 3,724.24 5,554.24 3,822.07 4.10 5,554.24 13,407.86 91.12 317.85 3,817.11 3,724.11 5,560.07 3,816.80 4.10 5,560.07 13,500.00 91.12 317.85 3,815.30 3,722.30 5,628.36 3,754.98 0.00 5,628.36 13,600.00 91.12 317.85 3,813.34 3,720.34 5,702.49 3,687.88 0.00 5,702.49 13,700.00 91.12 317.85 3,811.38 3,718.38 5,776.61 3,620.79 0.00 5,776.61 13,800.00 91.12 317.85 3,809.42 3,716.42 5,850.73 3,553.69 0.00 5,850.73 13,900.00 91.12 317.85 3,807.46 3,714.46 5,924.85 3,486.59 0.00 5,924.65 13,922.92 91.12 317.85 3,807.01 3,714.01 5,941.85 3,471.21 0.00 5,941.85 Start 3°/100' DLS, 94.48° TF, for 224.62' 13,935.58 91.12 317.85 3,806.76 3,713.76 5,951.23 3,462.72 0.00 5,951.23 14,000.00 90.97 319.78 3,805.58 3,712.58 5,999.70 3,420.30 3.00 5,999.70 14,100.00 90.74 322.77 3,804.09 3,711.09 6,077.69 3,357.75 3.00 6,077.69 14,147.44 90.62 324.18 3,803.53 3,710.53 6,115.81 3,329.52 3.00 6,115.81 Hold for 266.06' 14,160.10 90.59 324.56 3,803.40 3,710.40 6,126.10 3,322.15 3.00 6,126.10 14,200.00 90.59 324.56 3,802.98 3,709.98 6,158.61 3,299.02 0.00 6,158.61 14,300.00 90.59 324.56 3,801.95 3,708.95 6,240.08 3,241.04 0.00 6,240.08 14,400.00 90.59 324.56 3,800.92 3,707.92 6,321.55 3,183.06 0.00 6,321.55 14,412.49 90.59 324.56 3,800.79 3,707.79 6,331.72 3,175.82 0.00 6,331.72 TD: 14412.49' MD, 3800.66' TVD 14,425.15 90.59 324.56 3,800.66 3,707.66 6,342.04 3,168.48 0.00 6,342.04 6292017 4:05.52PM Page 7 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 1 H-102 (formerly 31) Company: ConocePhillips (Alaska) Inc. -Kupl TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Site: Kuparuk 11H Pad North Reference: True Well: Plan: 1H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H -102L4 - plan hits target center Design: 1H-102L4wp23 1 H-1 02D 06.T6150ctl5 BW 0.00 0.00 3,798.51 3,711.20 4,396.81 Targets Target Name - hiVmiss target Dip Angle Dip Dir. TVD +W s +Ekw -Shape (°) (°) (usft) (usft) (usft) 1 H -102D 10.T11 020217 RP 0.00 0.00 3,789.09 4,599.53 4,240.72 - plan hits target center - Circle (radius 100.00) 1H -102D 02.T2150c115 BW 0.00 0.00 3,777.64 1,207.01 4,380.36 - plan misses target center by 2.99usft at 8927.30usft MD (3775.46 TVD, 1206.94 N, 4382.41 E) - Circle (radius 100.00) 1H -102D 03.73020217 RP 0.00 0.00 3,773.98 1,861.06 4,384.66 - plan hits target center - Circle (radius 100.00) 1 H-1 02D 06.T6150ctl5 BW 0.00 0.00 3,798.51 3,711.20 4,396.81 - plan misses target center by 15520usft at 11443.63usft MD (3795.57 TVD, 3710.74 N, 4241.64 E) - Circle (radius 100.00) 1 HA 02D 033316Febl 5 BW 0.00 0.00 3,809.00 3,003.15 4,392.16 - plan misses target center by 135.49usft at 10714.31 usft MD (3800.11 TVD, 2983.32 N, 4258.42 E) - Circle (radius 100.00) 1H -102D 01.Tl 15Oct15 BW 0.00 0.00 3,771.07 578.96 4,376.24 - plan misses target center by 2.79usft at 8299.25usft MD (3773.86 TVD, 578.95 N, 4376.37 E) - Circle (radius 100.00) 1H -102D 04.T415Oc115 BW 0.00 0.00 3,808.70 3,003.15 4,392.16 - plan misses target center by 135.47usft at 10714.30usft MD (3800.11 TVD, 2983.31 N, 4258.42 E) -Circle (radius 100.00) 1H -102D 05.T515OC115 BW 0.00 0.00 3,808.21 3,425.18 4,394.93 - plan misses target center by 155.16usft at 11167.22usft MO (3805.41 TVD, 3434.70 N, 4240.09 E) - Circle (radius 100.00) 111-1021)0737150C115 BW 0.00 0.00 3,787.29 4,403.25 4,401.35 - plan misses target center by 156.51 usft at 12133.75usft MD (3787.22 TVD, 4400.66 N, 4244.87 E) - Circle (radius 100.00) 1H -102D 15.T16020717 RP 0.00 0.00 3,800.66 6,342.04 3,168.48 - plan hits target center - Circle (radius 100.00) 1 H-1 02D 02.T216Febl5 BW 0.00 0.00 3,784.00 2,695.12 4,390.14 - plan misses target center by 70.20usft at 10405.22usft MD (3786.04 TVD, 2681.07 N. 4321.39 E) - Circle (radius 100.00) 1 H -102D 07.T8 02D217 RP 0.00 0.00 3,805.41 3,451.99 4,241.19 - plan hits target center -Circle (radius 100.00) 1H -102D 06.T616Feb15 BW 0.00 0.00 3,787.00 4,403.25 4,401.35 - plan misses target center by 156.51 usft at 12133.75usft MD (3787.22 TVD, 4400.66 N, 4244.87 E) -Circle (radius 100.00) 1H -102D 0939150ctl5 BW 0.00 0.00 3,816.62 5,009.30 4,405.34 - plan misses target center by 230.35usft at 12689.25usft MD (3801.33 TVD, 4950.23 N, 4183.22 E) - Circle (radius 100.00) 1H -102D 01.71 16Feb15 BW 0.00 0.00 3,778.00 1,207.01 4,380.36 - plan misses target center by 3.27usft at 8927.29usft MD (3775.46 TVD, 1206.94 N, 4382.41 E) -Circle (radius 100.00) 1H -102D 05.76020217 RP 0.00 0.00 3,800.89 2,994.45 4,253.99 - plan misses target center by 2.54usft at 10725.99usft MD (3800.54 TVD, 2994.84 N, 4256.47 E) - Circle (radius 100.00) 1H -102D 02.72020217 RP 0.00 0.00 3,775.72 1,084.70 4,379.56 612912017 4:05:52PM Page 8 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 11-1-102 (formerly 31) Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Plan: 1 H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-1021-4 - Circle (radius 100.00) - Polygon Design: 1H-102L4wp23 - plan misses target center by 155.21 usft at 11443.61 usft MD (3795.57 TVD, 3710.72 N, 4241.64 E) Point 1 - Circle (radius 100.00) 4,403.89 - plan misses target center by 180.52usft at 12500.00usft MD (3795.09 TVD, 4765.89 N, 4224.91 E) 1H-102004.75020217 RP 0.00 0.00 3,786.83 2,698.10 4,317.85 - plan hits target center - Circle (radius 100.00) - Circle (radius 100.00) 4,403.89 - plan misses target center by 180.52usft at 12500.00usft MD (3795.09 TVD, 4765.89 N, 4224.91 E) 11-1-102 South Fault 0.00 0.00 3,800.66 4,873.15 4,338.73 - plan misses target center by 131.62usft at 12583.93usft MD (3797.93 TVD, 4848.33 N, 4209.50 E) - Circle (radius 100.00) - Polygon 1H -102D 05.T516Febl5 BW 0.00 0.00 3,799.00 3,711.20 4,396.81 - plan misses target center by 155.21 usft at 11443.61 usft MD (3795.57 TVD, 3710.72 N, 4241.64 E) Point 1 3,800.66 0.00 0.00 Point 3,800.66 24.49 -306.18 1 H-102 Polygon 020717 BP 0.00 0.00 3,800.66 94.43 4,373.26 - plan misses target center by 18.61 usft at 7813.36usft MD (3782.36 TVD, 93.34 N, 4376.47 E) - Polygon Point 1 3,800.66 -0.60 99.98 Point 3,800.66 989.61 106.31 Point 3,800.66 1,770.44 111.38 Point 3,800.66 2,615.16 43.90 Points 3,800.66 2,915.18 -20.42 Point 3,800.66 3,120.82 -34.48 Point? 3,800.66 3,356.46 -32.05 Point 3,800.66 3,532.87 -29.96 Point 3,800.66 4,088.80 -24.76 Point 10 3,800.66 4,511.06 -82.89 Point 11 3,800.66 4,987.74 -182.95 Point 12 3,800.66 5,264.56 -328.53 Point 13 3,800.66 5,498.50 -518.76 Point 14 3,800.66 5,888.72 -872.04 Point 15 3,800.66 6,277.69 -1,164.82 Point 16 3,800.66 6,187.46 -1,284.67 Point 17 3,800.66 5,792.97 -987.52 Point 18 3,800.66 5,399.92 -631.84 Point 19 3,800.66 5,181.87 -453.69 Point 20 3,800.66 4,941.40 -325.62 Point 21 3,800.66 4,493.25 -231.83 Point 22 3,800.66 4,088.27 -224.78 Point 23 3,800.66 3,534.85 -229.97 Point 24 3,800.66 3,358.61 -232.05 Point 25 3,800.66 3,115.24 -234.42 Point 26 3,800.66 2,884.83 -218.12 Point 27 3,800.66 2,592.24 -154.81 Point 28 3,800.66 1,762.79 -88.49 Point 29 3,800.66 990.90 -93.70 Point 30 3,800.66 0.69 -100.04 1H -102D 08.T9 020217 RP 0.00 0.00 3,799.68 3,628.30 4,243.25 - plan hits target center -Circle (radius 100.00) 1H -102D 08.T8150ct15 BW 0.00 0.00 3,797.39 4,789.28 4,403.89 - plan misses target center by 180.52usft at 12500.00usft MD (3795.09 TVD, 4765.89 N, 4224.91 E) - Circle (radius 100.00) 1H -102D 14.715 020717 RP 0.00 0.00 3,806.76 5,951.23 3,462.72 - plan hits target center - Circle (radius 100.00) 1H -102D 073716Fe1b15 BW 0.00 0.00 3,797.00 4,789.28 4,403.89 - plan misses target center by 180.52usft at 12500.00usft MD (3795.09 TVD, 4765.89 N, 4224.91 E) - Circle (radius 100.00) 1H -102D 03.T315Octl5 BW 0.00 0.00 3,784.29 2,695.12 4,390.14 - plan misses target center by 70.19usft at 10405.24usft MD (3786.04 TVD, 2681.08 N, 4321.39 E) - Circle (radius 100.00) 1H -102D 05.T516Febl5 BW 0.00 0.00 3,799.00 3,711.20 4,396.81 - plan misses target center by 155.21 usft at 11443.61 usft MD (3795.57 TVD, 3710.72 N, 4241.64 E) 629/2017 4:05.52PM Page 9 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 1 H-102 (formerly 31) Company: ConocoPhillips (Alaska) Inc. -Kupi TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Site: Kupawk 1 H Pad North Reference: True Well: Plan: 1H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: iH-1021_4 - Circle (radius 100.00) UG_C Design: 1H-102L4wp23 -plan misses target center by 328.83usft at 12900.00usft MD (3807.47 TVD, 5146.79 N, 4107.98 E) 1,697.35 1H -102D 04,T416Febl5 BW 0.00 0.00 3,808.00 3,425.18 4,394.93 - plan misses target center by 155.16usft at 11167.22usft MD (3805.41 TVD, 3434.70 N, 4240.09 E) Measured - Circle (radius 100.00) Dip 1H -102D 06.77020217 RP 0.00 0.00 3,808.01 3,212.48 4,238.82 - plan misses target center by 4.40usft at 10944.79usft MD (3805.26 TVD, 3212.39 N, 4235.39 E) (usft) - Circle (radius 100.00) Name Lithology 1H -102D 13.774 020717 RP 0.00 0.00 3,817.11 5,560.07 3,816.80 - plan hits target center 7,200.81 - Circle (radius 100.00) WS D iH-102D 01.T1 020617 RP 0.00 0.00 3,772.82 294.44 4,374.57 - plan hits target center 5,166.08 - Circle (radius 100.00) UG_C 1H -102D 10.T1015Octl5 BW 0.00 0.00 3,824.02 5,282.32 4,407.13 -plan misses target center by 328.83usft at 12900.00usft MD (3807.47 TVD, 5146.79 N, 4107.98 E) 1,697.35 - Circle (radius 100.00) PFROST 1H -102D 09.710 020217 RP 0.00 0.00 3,787.00 4,182.93 4,248.49 - plan hits target center 6,706.09 - Circle (radius 100.00) Na 111-102 North Fault 0.00 0.00 3,800.66 5,573.40 4,267.44 - plan misses target center by 355.56usft at 13155.77usft MD (3813.57 TVD, 5366.79 N, 3978.36 E) - Polygon Point 1 3,800.66 0.00 0.00 Point 3,800.66 176.14 -288.40 Point 3,800.66 953.13 -921.17 Point 3,800.66 176.14 -288.40 7,204.23 3,753.15 7-5/8" x 9-7/8" 7-5/8 9-7/8 14,425.15 3,800.66 4-1/2'x6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology 5,975.61 3,382.60 UG -B 7,200.81 3,752.30 WS D 2,195.08 2,008.40 K-15 5,166.08 3,135.40 UG_C 1,903.05 1,788.60 T-3 1,697.35 1,620.40 PFROST 10,688.95 3,799.10 WS C 6,706.09 3,610.70 Na 6,319.91 3,486.80 UG -A 6292017 4:06:52PM Page 10 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 1H-102 (formerly 31) Company: ConocoPhillips (Alaska) Inc. -Kup1 TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Site: Kupamk 1 H Pad North Reference: True Well: Plan: 1H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-1021.4 Hold for 20' Design: 1 H-102L4wp23 -512.01 4,369.05 Plan Annotations Measured Vertical Local Coordinates Depth Depth -NI-S +E/ -W (usft) (usft) (usft) (usft) Comment 7,176.30 KOP: 13.56°R00' DLS, 0° TF, for 16.5- 7,192.80 Hold for 20' 7,204.22 3,753.15 -512.01 4,369.05 KOP: 15.9°/100' DLS, 0° TF, for 12.8' 7,212.80 3,755.19 -503.68 4,369.05 Start 4°/100' DLS, 0.02° TF, for 308.25' 7,217.02 3,756.12 -499.56 4,369.05 Hold for 20' 7,521.05 3,794.18 -198.54 4,374.97 Adjust TF to -54.29°, for 149.62' 7,670.68 3,791.14 -49.05 4,378.47 Hold for 222.97' 7,893.65 3,777.41 173.47 4,375.33 Start 4°/100' DLS, 143.51" TF, for 108.42' 8,002.07 3,772.87 281.78 4,374.51 Start 2°/100' DLS, -179.97° TF, for 10.65' 8,012.73 3,772.82 292.43 4,374.56 Hold for 768.96' 8,781.68 3,775.65 1,061.37 4,379.41 Start 2.1100' DLS, 3.92° TF, for 10.68' 8,792.36 3,775.69 1,072.04 4,379.48 Adjust TF to 82.66°, for 66.32' 8,858.68 3,775.65 1,138.35 4,380.41 Hold for 397.59' 9,256.27 3,774.48 1,535.77 4,392.12 Start 2°/100' DLS, -91.54° TF, for 312.89' 9,569.16 3,773.98 1,848.44 4,385.64 Adjust TF to 104.8', for 96.38' 9,665.54 3,774.29 1,944.60 4,379.18 Hold for 426.26' 10,091.80 3,777.95 2,370.37 4,359.07 Start 3°/100' DLS, -103.22° TF, for 318.18' 10,409.98 3,786.25 2,685.72 4,320.44 Hold for 230' 10,639.98 3,796.92 2,910.46 4,272.71 Start 3.62-/100' DLS, 77.68° TF, for 339.42- 10,979.40 3,805.40 3,246.99 4,234.75 Start 2.01"/100' DLS, 89.98° TF, for 182.22' 11,161.62 3,805.41 3,429.11 4,239.75 Hold for 10.26' 11,171.88 3,805.41 3,439.36 4,240.38 Start 4.01°/100'DLS, -58.21°TF, for 169.85' 11,341.73 3,800.85 3,509.02 4,243.91 Hold for 6.67' 11,348.41 3,800.46 3,615.67 4,243.70 Start 3°/100' DLS, 126.15° TF, for 137.84- 11,486.25 3,794.28 3,753.34 4,241.93 Hold for 289.44' 11,775.69 3,788.52 4,042.65 4,248.05 Start 2°/100' DLS, -116.4° TF, for 127.64' 11,903.33 3,787.02 4,170.27 4,248.70 Start 1-/100' DLS, 115.91° TF, for 13.2' 11,916.52 3,787.00 4,183.47 4,248.48 Hold for 310.81' 12,227.33 3,787.31 4,494.23 4,243.32 Start 2.5'/100' DLS, -153.05° TF, for 92.69' 12,320.03 3,788.65 4,586.89 4,241.15 Start 4.1'11 OO'DLS, -88.96° TF, for 957.79' 13,277.82 3,815.90 5,462.58 3,902.84 Hold for 61.63' 13,339.45 3,816.96 5,508.94 3,862.24 Start 4.1-1100'DLS, -22.75°TFT for 55.75' 13,395.20 3,817.31 5,550.67 3,825.28 Hold for 527.72' 13,922.92 3,807.01 5,941.85 3,471.21 Start 3°/100' DLS, 94.48° TF, for 224.52' 14,147.44 3,803.53 6,115.81 3,329.52 Hold for 265.05' 14,412.49 3,800.79 6,331.72 3,175.82 TD: 14412.49' MD, 3800.66' TVD 6292017 4:05:52PM Page 11 COMPASS 5000.1 Build 74 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-102 (formerly 31) Plan: 11-1-1021-4 50103xxxxx00 1 H-1021-4wp23 Clearance Summary Anticollision Report 29 June, 2017 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad - Plan: 1H-102(formerly 31) -Plan: 111-10214-1H-102L4wp23 Well Coordinates: Datum Height: Plan: 54+39 @ 93.00usft (Doyon 142) Scan Range: 7,204.22 to 14,425.15 usft. Measured Depth. Scan Radius is 1,638.61 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED'. All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Plan: 1H-102 (formerly 31)-1H-1O2L4wp23 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad -Plan: 1H-102(formerly 31) -Plan: 1H-102L4.1H-102L4wp23 Scan Range: 7,204.22 to 14,425.15 ustL Measured Depth. Scan Radius is 1,638.61 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft (usft) (usft) (usft) usft Kuparuk 1H Pad 1H-05-1H-05-iH-05 10,546.60 1,498.22 10,546.60 1,298.93 6,900.00 7.518 Clearance Factor Pass - Major Risk 1H -05 -1H -105-1H-105 10,436.06 297.44 10,436.06 190.76 7,325.00 2.788 Centre Distance Pass - Major Risk 1H -05 -1H -105-1H-105 10,473.04 309.96 10,473.04 178.33 7,425.00 2.355 Clearance Factor Pass - Major Risk Plan: 1 H-101 (formerly 103, 29) -Plan: 1H-iDi-1H-10 14,211.09 1,176.25 14,211.09 995.52 11,975.00 6.506 Clearance Factor Pass - Major Risk Plan: 1 H-101 (formerly 103,29) -Plan: 111-101 L7 -1H 14,145.92 1,202.83 14,145.92 1,014.29 11,900.00 6.380 Clearance Factor Pass - Major Risk Plan: 1H-101(formerly 103, 29) -Plan: iH-101 L2 -1H 14,124.95 1,220.59 14,124.95 1,034.14 11,850.00 6.547 Clearance Factor Pass - Major Risk Plan :1H-101(formerly 103, 29) -Plan: 1H-101 L3 -1H 14,100.00 1,238.37 14,100.00 1,059.46 11,800.00 6.922 Clearance Factor Pass - Major Risk Plan :1H-101(formerly 103, 29) -Plan: 1H-101 L4 -1H 14,071.71 1,298.90 14,071.71 1,112.70 11,700.0D 6.976 Clearance Factor Pass - Major Risk Plan: 1 H-102 (formerly 31) - Plan: I H-102 - 1 H-102wp2 10,728.15 963.71 10,728.15 825.91 7,225.00 6.994 - Pass - Major Risk Plan: 1 H-102 (formerly 31) - Plan: 1 H-10211 - 1 H-1 02L 9,227.44 626.37 9,227.44 530.05 6,500.00 6.503 - Pass -Major Risk Plan: 1 H-102 (formerly 31) - Plan: 1 H-1021-2 - i H -102L 9,235.97 627.14 9,235.97 529.41 6,525.00 6.417 - Plan: 1 H-102 (formerly 31) - Plan: 1 H-102 L3 - 1 H-1 02L Plan: 1 H-11 6 (formerly 114, 32B, 115) -Plan: 1H-116- 9,300.00 383.94 9,300.00 284.94 6,550.00 - Centre Distance Plan: 7 H-102 (formerly 31) - Plan: 1 H-1021.3 - 1 H-1 02L Plan: I H-1 16 (formerly 114, 328, 115) -Plan: 1H-116- 9,306.90 384.99 9,306.90 283.58 6,575.00 - Clearance Factor Plan: 1H-103(formerly 104, 33) -Plan: 1H -103L1 -1H 12,077.64 1,214.32 12,077.64 1,026.02 13,750.00 6.449 Clearance Factor Pass - Major Risk Plan: 1 H-1 03 (formerly 104, 33) -Plan: 1H-103L3-iH 12,044.02 1,210.71 12,044.02 1,027.12 13,675.00 6.595 Clearance Factor Pass - Major Risk Plan :1H-103(formerly 104, 33) -Plan: 1H-1 D31_4 -1H 12,006.72 1,211.71 12,006.72 1,029.56 13,575.D0 6.652 Clearance Factor Pass - Major Risk Plan* 1 H-109 (formerly 110, 30C) -Plan: 1H -109-1H-1 8,057.21 1,000.82 8,057.21 878.94 6,200.00 8.211 Centre Distance Pass - Major Risk Plan: 1H-109(formerly 110, 30C) -Plan: 1H -109-1H-1 8,194.73 1,002.46 8,194.73 877.61 6,350.00 8.029 Clearance Factor Pass - Major Risk Plan: 1H-111 (formerly 109, 32D) - Plan: 1H-111 - 1H-1 8,019.82 332.53 8,019.82 236.93 6,350.00 3.478 Centre Distance Pass- Major Risk Plan: 1H-111 (formerly 109, 32D) - Plan: iH-111 - iH-1 8,023.00 334.78 8,023.00 234.26 6,400.00 3.331 Clearance Factor Pass- Major Risk Plan: 1H-113(formerly 112, 348) -Plan: 1H -113-1H-1 8,190.15 673.22 8,190.15 578.98 6,325.00 7.144 Centre Distance Pass - Major Risk Plan: 1 H-1 13 (formerly 112, 34B) -Plan: 1H-113-iH-1 8,192.40 673.99 8,192.40 578.53 6,350.00 7.061 Clearance Factor Pass - Major Risk Plan: 1 H-114 (formerly 3013, 116) -Plan: 1H-114-iH-1 10,700.00 963.36 10,700.00 826.06 7,175.00 7.016 Centre Distance Pass - Major Risk Plan: 1H-114(formerly 308, iib) -PIan: 1H-114-iH-1 10,728.15 963.71 10,728.15 825.91 7,225.00 6.994 Clearance Factor Pass - Major Risk Plan: 1 H-115 (formerly 115, 34A, 114) -Plan: 1H-115- 9,227.44 626.37 9,227.44 530.05 6,500.00 6.503 Centre Distance Pass -Major Risk PIan:1H-115(formerly 115, 34A, 114) -Plan: 1H-115- 9,235.97 627.14 9,235.97 529.41 6,525.00 6.417 Clearance Factor Pass - Major Risk Plan: 1 H-11 6 (formerly 114, 32B, 115) -Plan: 1H-116- 9,300.00 383.94 9,300.00 284.94 6,550.00 3.878 Centre Distance Pass - Major Risk Plan: I H-1 16 (formerly 114, 328, 115) -Plan: 1H-116- 9,306.90 384.99 9,306.90 283.58 6,575.00 3.796 Clearance Factor Pass - Major Risk 29 June, 2017 - 16:06 Page 2 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Plan: 1H-102 (formerly 31)-1H-1O2L4wp23 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad - Plan; 1H-102(formerly 31) -Plan: 1H-1021-4-1H-102L4wp23 Scan Range: 7,204.22 to 14,426.15 usft Measured Depth. Scan Radius is 1,638.61 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited 29 June, 2017 - 16:06 Page 3 of 6 COMPASS Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft Plan: 11-1-118 (formerly 30A,119) -Plan: 11-1-118- 11-1-1 13,460.12 792.91 13,460.12 650.31 8,275.00 5.560 Clearance Factor Pass - Major Risk Plan : 1H -120(A1035, formerly 117) -Plan: 1H -120-1H 9,900.60 699.75 9,900.60 602.59 6,625.00 7.202 Centre Distance Pass - Major Risk Plan :1H-120(Al 035, formerly 117) -Plan: 1H -120-1H 9,909.14 700.41 9,909.14 602.00 6,650.00 7.118 Clearance Factor Pass - Major Risk Plan* 1H-121(Al 034, formerly 119) -Plan: 1H -121-1H 10,464.62 603.24 10,464.62 5D4.47 6,775.00 6.107 Centre Distance Pass - Major Risk Plan* 1H-121(Al 034, formerly 119) -Plan: 1H-121-iH 10,479.69 604.89 10,479.69 503.39 6,825.00 5.959 Clearance Factor Pass - Major Risk Plan: IH-122(Al 033, formerly A1040) -Plan: 1H-122 11,337.60 468.03 11,33260 356.90 7,175:00 4.212 Centre Distance Pass - Major Risk Plan: IH-122(At 033, formerly Al 040) -Plan: 1H-122 11,378.50 472.26 11,378.50 352.71 7,250.00 3.950 Clearance Factor Pass - Major Risk Plan: 1H-123(Al 032, formerly At 033) -Plan: 1H-123 12,208.30 283.30 12,208.30 165.79 7,675.00 2.411 Centre Distance Pass - Major Risk Plan: 1H-123(Al 032, formerly At 033) -Plan: 1H-123 12,255.78 289.69 12,255.78 157.74 7,750.00 2.195 Clearance Factor Pass - Major Risk Plan: 1H -124(A1031, formerly A1036) -Plan: 1H-124 13,149.61 155.18 13,149.61 40.90 8,100.00 1.358 Centre Distance Pass - Major Risk Plan* 1H-124(Al 031, formerty At 036) -Plan: 1H-124 13,156.08 157.57 13,156.08 37.77 8,125.00 1.315 Clearance Factor Pass -Major Risk Plan: 1 H-125 (Al 030, formerly At 039) - Plan: 1 H-125 - Plan: 11-1-125 (AiD30, formerly A1039) - Plan: IH -125 - - Survey too/ oroorarrr From To Survey/Plan Survey Tool (usft) (usft) 39.00 700.00 GYD-GC-SS 700.01) 1,794.10 MWD+IFR-AK-CAZ-SC 1,794.10 7,204.22 MWD+IFR-AK-CAZ-SC 7,204.22 7,554.22 1H-102L4wp23 MWD -INC ONLY 7,554.22 9,054.22 1H-102L4Wp23 MWD 7,554.22 14,425.15 111-1021-4wp23 MWD+IFR-AK-CAZ-SC 29 June, 2017 - 16:06 Page 3 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Plan: 11-1-102 (formerly 31) - 1H-102L4wp23 Ellipse error terms are correlated across survey tool tieon points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles- Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 29 June, 2017 - 16.06 Page 4 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-102 (formerly 31) Plan: 1 H -102L4 50103xxxxx00 1 H-102L4wp23 Clearance Summary Anticollision Report 29 June, 2017 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad - Plan: 1H-102(formerly 31) -Plan: 1H-1021.4-1H-102L4wp23 Well Coordinates: Datum Height: Plan: 54+39 @ 93.00usft (Doyon 142) Scan Range: 7,204.22 to 14,425.15 usft. Measured Depth. Scan Radius is 1,635.61 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIEDAll wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 Minor Risked ConocoPhillips (Alaska) Inc. -Kupt Kuparuk River Unit Anticollision Report for Plan: 1H-102 (formerly 31)-1H-1O2L4wp23 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad -Plan: 1H-102 (formerly 31). Plan: 1H-102L4.1H-102L4wp23 Scan Range: 7,204.22 to 14,426.16 usft Measured Depth. Scan Radius is 1,638.61 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Kuparuk 1H Pad 1H -05 -1H -05-1H-05 10,546.60 1,498.22 10,546.60 1,298.93 6,900.00 7.518 Clearance Factor Pass - Major Risk 1H -05 -1H -105-1H-105 10,436.06 297.44 10,436.06 190.76 7,325.00 2.788 Centre Distance Pass - Major Risk 1H -05 -1H -105-1H-105 10,473.04 309.96 10,473.04 178.33 7,425.00 2.355 Clearance Factor Pass - Major Risk Plan: 111-101 (formerly 103, 29) -Plan: 1H -101-1H-10 14,211.09 1,176.25 14,211.09 995.52 11,975.00 6.508 Clearance Factor Pass - Major Risk Plan: 1H-101(formerly 103, 29) -Plan: 1H-101 Li -1H 14,145.92 1,202.83 14,145.92 1,014.29 11,900.00 6.380 Clearance Factor Pass - Major Risk Plan: IH -101 (formerly 103, 29) -Plan: 1H -10112-1H 14,124.95 1,220.59 14,124.95 1,034.14 11,850.00 6.547 Clearance Factor Pass - Major Risk Plan: 1 H-101 (formerly 103, 29) -Plan: 1H -1011.3-1H 14,100.00 1,238.37 14,100.00 1,059.46 11,800.00 6.922 Clearance Factor Pass - Major Risk Plan: 1 H-101 (formerly 103, 29) -Plan: 1H -10114-1H 14,071.71 1,298.90 14,071.71 1,112.70 11,700.00 6.976 Clearance Factor Pass - Major Risk Plan: 1 H-102 (formerly 31) - Plan: 1 H-102 - 1 H-102wp2 - Plan: 1 H-102 (formerly 31) - Plan: 1 H -10211 -1H -102L - Plan: 1 H-102 (formerly 31) - Plan: 1 H-10212 -1 H-1 D2L - Plan: 1 H-102 (formerly 31) - Plan: 1 H-10213 - 1 H-1 02L - Plan: 1H-103 (formerly 104, 33) - Plan: 1H-1031.1 - 1 H 12,077.64 1,214.32 12,077.64 1,026.02 13,750.00 6.449 Clearance Factor Pass- Major Risk Plan : 1H-103 (formerly 104, 33) - Plan: 1 H-1031_3 - 1 H 12,044.D2 1,210.71 12,044.02 1,027.12 13,675.00 6.595 Clearance Factor Pass- Major Risk Plan : 1H-103(formerly 104, 33) -Plan: 1H -10314-1H 12,006.72 1,211.71 12,006.72 1,029.56 13,575.00 6.652 Clearance Factor Pass - Major Risk Plan: 1 H-109 (formerly 110, 30C) - Plan: 1H-109 - 1H-1 8,057.21 1,000.82 8,057.21 878.94 6,200.00 8.211 Centre Distance Pass - Major Risk Plan: 1 H-1 09 (formerly 110, 30C) -Plan: 1H -109-1H-1 8,194.73 1,002.46 8,194.73 877.61 6,350.00 8.029 Clearance Factor Pass - Major Risk Plan : 1H-111 (formedy 109, 32D) -Plan: iH-111 - 111-1 8,019.82 332.53 8,019.82 236.93 6,350.00 3.478 Centre Distance Pass - Major Risk Plan: 1 H-111 (formerly 109, 32D) -Plan: 1H -111-1H-1 8,023.00 334.78 8,023.00 234.26 6,400.00 3.331 Clearance Factor Pass - Major Risk Plan: 1 H-1 13 (formerly 112, 34B) -Plan: 1H -113-1H-1 8,190.15 673.22 8,190.15 578.98 6,325.00 7.144 Centre Distance Pass - Major Risk Plan- 1 H-11 3 (formerly 112, 34B) -Plan: 1H -113-1H-1 8,192.40 673.99 8,192.40 578.53 6,350.00 7.061 Clearance Factor Pass - Major Risk Plan: 1 H-114 (formerly 30B,116) -Plan: 1H -114-1H-1 10,700.00 963.36 10,700.00 826.06 7,175.00 7.016 Centre Distance Pass - Major Risk Plan :1H-114(formerly 30B, 116) -Plan: 1H -114-1H-1 10,728.15 963.71 10,728.15 825.91 7,225.00 6.994 Clearance Factor Pass - Major Risk Plan: 1H-115(formerly 115, 34A, 114) -Plan: 1H-115- 9,227.44 626.37 9,227.44 530.05 6,500.00 6.503 Centre Distance Pass - Major Risk Plan: 1H-115 (formerly 115, 34A, 114) - Plan: 1 H-115 - 9,235.97 627.14 9,235.97 529.41 6,525.00 6.417 Clearance Factor Pass- Major Risk Plan: 1H-116(formerly 114, 32B, 115) -Plan: 1H-116- 9,300.00 383.94 9,300.00 284.94 6,550.00 3.878 Centre Distance Pass - Major Risk Plan : 1H-116 (formerly 114, 32B, 115) - Plan: 1 H-116 - 9,306.90 384.99 9,306.90 283.58 6,575.00 3.796 Clearance Factor Pass- Major Risk Plan : 1H-118(formerly 30A, 119) -Plan: 1H -118-1H-1 13,460.12 792.91 13,460.12 650.31 8,275.00 5.560 Clearance Factor Pass - Major Risk 29 June, 2017 - 16:17 Page 2 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Plan: 11-1-102 (formerly 31) -1 H-102L4wp23 12,208.30 283.30 12,208.30 165.79 7,675.00 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Centre Distance Pass - Major Risk Plan: 1H-123(At 032, formerly At 033) -Plan: 11-1-123 12,255.78 289.69 12,255.78 Reference Design: Kuparuk iH Pad -Plan:1H-102(formerly 31) -Plan: iH-102L4-1H-1D2L4wp23 7,750.00 2.195 Clearance Factor Pass - Major Risk Plan :1H-124(At 031, formerly At 036) -Plan: 1H-124 13,149.61 Scan Range: 7,204.22 to 14,425.16 usft. Measured Depth. 13,149.61 40.90 8,100.00 1.358 Centre Distance Pass - Major Risk Scan Radius is 1,638.61 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited 13,156.08 157.57 13,156.08 37.77 8,125.00 Measured Minimum @Measured Ellipse @Measuretl Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft — Plan: 1H-120(At 035, formerly 117) -Plan: 1H -120-1H 9,900.60 699.75 9,900.60 602.59 6,625.00 7.202 Centre Distance Pass - Major Risk Plan: 1H-120(At 035, formerly 117) -Plan: 1H -120-1H 9,909.14 700.41 9,909.14 602.00 6,650.00 7.118 Clearance Factor Pass - Major Risk Plan: 1H-121(At 034, formerly 119) -Plan: 1H-121-iH iD,464.62 603.24 10,464.62 504.47 6,775.00 6.107 Centre Distance Pass - Major Risk Plan: 1H-121(At 034, formerly 119) -Plan: 1H -121-1H 10,479.69 604.89 10,479.69 503.39 6,825.00 5.959 Clearance Factor Pass - Major Risk Plan: 1H-122(At 033, formerly At 040) -Plan: 1H-122 11,337.60 468.03 11,337.60 356.90 7,175.00 4.212 Centre Distance Pass - Major Risk Plan :1H -122(A1033, formerlyA1040)-PIan: 1H-122 11,378.50 472.26 11,378.50 352.71 7,250.00 3.950 Clearance Factor Pass - Major Risk Plan: 1H -123(A1032, formerlyA1033)-PIan: 11-1-123 12,208.30 283.30 12,208.30 165.79 7,675.00 2.411 Centre Distance Pass - Major Risk Plan: 1H-123(At 032, formerly At 033) -Plan: 11-1-123 12,255.78 289.69 12,255.78 157.74 7,750.00 2.195 Clearance Factor Pass - Major Risk Plan :1H-124(At 031, formerly At 036) -Plan: 1H-124 13,149.61 155.18 13,149.61 40.90 8,100.00 1.358 Centre Distance Pass - Major Risk Plan: I H-1 24 (At 031, formerly At 036) -Plan: 1H-124 13,156.08 157.57 13,156.08 37.77 8,125.00 1.315 Clearance Factor Pass - Major Risk Plan: 1 H-125 (At 030, formerly At 039) - Plan: 1 H-125 — Plan: 1 H-125 (At 030, formerly At 039) - Plan: 1 H-125 — Survey fool program From To Survey/Plan SurveyTool (usft) (usft) 39.00 700.00 GYD-GC-SS 700.00 1,794.10 MWD+IFR-AK-CAZ-SC 1,794.10 7,204.22 MWD+IFR-AK-CAZ-SC 7,204.22 7,554.22 1H-102L4wp23 MWD-INC—ONLY 7,554.22 9,054.22 1H-102L4wp23 MWD 7,554.22 14,425.15 IH-102L4wp23 MWD+IFR-AK-CAZSC 29 June. 2017 - 16:17 Page 3 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Plan: 1H-102 (formerly 31) - 1H-1O2L4wp23 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor= Distance Between Profiles / (Distance Between Profiles- Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 29 June, 2017 - 16:17 Page 4 of 6 COMPASS Ladder View 1 H-102L4wp23 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. i i s i i x a I I d 150 U m c Ugnetl< EMa EW-Wnt OYsbn<e 0 7500 9000 10500 12000 13500 Displayed interval could be less than entire welhMeasured Depth7204.22 To 14425.15 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 700.00 1 H-102wp23 (Plan: IH -102) GYD-GC-SS 3753.15 7204.23 7-5/8" x 9-7/8" 700.00 1794.10 1 H-102wp23 (Plan: 1 H-102) MWD+IFR-AK-CAZ-SC 3800.66 14425.15 4-1/2"x6-3/4" 1794.10 7204.22 1H-102wp23 (Plan: 1H-102) MWD+IFR-AK-CAZ-SC 7204.22 7554.22 1H-102L4wp23 (Plan: 11-1-1021-4) MWD -INC 7554.22 9054.22 1H-102L4wp23 (Plan: 1H-1021-4) _ONLY MWD 7554.22 14425.15 1H-102L4wp23 (Plan: 11-1-1021-4) MWD+IFR-AK-CAZ-SC i Eq_ryLl)M g+e[c Ois�itt C L ( O 30 U 0 m c m r' U o .'. 7500 8000 8500 9000 9500 10000 10500 Partial Measured Depth Ladder View 1 H-102L4wp23 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. Minor Risked o e 3 3 300 I I n i d wi 150 U i .� N I UEquivela M g fic Oiaan<e ' IIIal l t IL 111 I 0 7500 9000 10500 12000 13500 Displayed interval could be less than entire well:Measured Depth7204.22 To 14425.15 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 700.00 1 H-102wp23 (Plan: 1 H-102) GYD-GC-SS 3753.15 7204.23 7-5/8" x 9-7/8" 700.00 1794.10 11-1-102wp23(Plan:1H-102) MWD+IFR-AK-CAZ-SC 3800.66 14425.15 4-1/2"x6-3/4" 1794.10 7204.22 11-1-102wp23 (Plan: 1H-102) MWD+IFR-AK-CAZ-SC 7204.22 7554.22 1H-102L4wp23 (Plan: 11-1-10214) MWD -INC 7554.22 9054.22 _ONLY 1H-102L4wp23 (Plan: 1H -102L4) MWD 7554.22 14425.15 1H-102L4wp23 (Plan: 1H-10214) MWD+IFR-AK-CAZ-SC 60 Equivtlan[Magne is Oisfan<e c O I l0 n d U m I 5 30- 0 0 0 d U 0 7500 8000 8500 9000 9500 10000 10500 Partial Measured Depth 1 H-1 02L4wp23 MD Inc Azi TVD Dleg TFace Target 7204 - 7390 7204.22 75.57 0.00 3753.15 0.00 0.00 39.00 To 14425.15 7217.02 77.61 0.00 3756.12 15.90 0.00 7390 - 7570 7237.02 77.61 0.00 3760.41 0.00 0.00 7553.78 90.00 2.65 3794.55 4.00 12.17 7570 - 7760 16'15, Jung 29 2017 7677.39 93.53 359.19 3790.74 4.00 -44.37 7760 7940 7921.70 93.53 359.19 3775.69 0.00 0.00 CASING DETAILS 8014.73 90.00 0.36 3772.82 4.00 161.60 1H-1020 O1.T1 020617 RP 7940 - 8130 8025.38 89.79 0.36 3772.84 2.00 -179.97 TVD MD Name 8794.34 89.79 0.36 3775.70 0.00 0.00 8130 - 8310 3753.15 7204.23 7-518- x 9-718- 8805.02 90.00 0.38 3775.72 2.00 3.92 1H.102D 02.1`2 020217 RP 3800.66 14425.15 4-112" x 6-314" 8871.34 96.17 1.69 3775.62 2.00 62.66 8310 - 8500 9268.93 90.17 1.69 3774.45 0.00 0.00 9581.82 90.00 355.44 3773.98 2.00 -91.54 IH -1020 03.T3 020217 RP 8500 8750 9678.20 89.51 357.30 3774.40 2.00 104.80 10104.46 89.51 357.30 3778.06 0.00 0.00 8750 9000 Tml 10422.64 87.34 348.00 3786.83 3.00 -103.22 1H -102D 04.T5 020217 RP 10652.64 87.34 348.00 3797.50 0.00 6.00 9000 - 9250 n. 1x:KKll KK 11- U -1 U-1 iwi �`-� � 10992.06 90.00 0.00 3805.41 3.62 77.68 9250 - 9500 .rz ...n..e imu.Axz �n..: +x.iaui nx.zzx-xx- 11174.28 11184.54 90.00 90.00 3.67 3.67 3805.41 3805.41 2.01 0.00 89.96 0.00 1H-1020 07.T8 620217 RP 9500 - 9750 11354.39 93.58 357.88 3800.09 4.01 -58.21 11361.07 93.58 357.88 3799.68 0.00 0.00 1H -102D 08.T9 020217 RP 9750 - 10000 11498.90 91.14 1.22 3794.01 3.00 126.15 10000 - 10250 11915.99 90.00 358.93 3787.00 2.00 -116.40 1H.102D 09.T10 020217 RP 11929.18 89.94 359.05 3787.01 1.00 115.91 __ 10250 10500 12239.99 89.94 359.05 3787.32 0.00 0.00 12332.69 87.88 358.00 3789.09 2.50 -153.05 1H -102D 10.Tll 020217 RP 10500 10990 13352.11 89.02 318 7 3 7.1 4.10 0 00 -88.96 000 0.00 10990 11480 13407.86 91 � .75 -��, 1H-1020 1H-102 13.714 14.1` 020717 RP 11480 11970 -30 / 330 14935.11 , ..� ,- -aQ T 1 H-124wp20 11970 - 12460 12460 12960 12960 13450 13450 13940 13940 - 14425 -901 wp20 1 H-1 02L4wp23ND Inc Az1 TVD Dleg TFace Target 7204 - 7390 7204.22 75.57 0.00 3753.15 0.00 0.00 To 1 4425.1 5 7217.02 77.61 0.60 3756.12 15.90 0.00 7390 - 7570 .39.00 7237.02 7553.78 77.61 90.00 0.00 2.65 3760.41 3794.55 6.00 4.00 0.00 12.17 7570 - 7760 16:16, June 29 2017 7677.39 93.53 359.19 3790.74 4.00 -44.37 7921.70 8014.73 8025.38 8794.34 93.53 90.00 89.79 89.79 359.19 0.36 0.36 0.36 3775.69 3772.82 3772.84 3775.70 0.00 4.00 2.00 0.00 0.00 161.60 -179.97 0.60 1H -102D 01.71 020617 RP 7760 - 7940 - 8130 - 7940 8130 8310 CASING DETAILS TVD ND Name 3753.15 7204.23 7-5/8' x 9-7/8' 8805.02 90.00 0.38 3775.72 2.00 3.92 1H -102D 02.T2 020217 RP 3800.66 14425.15 4-1/2" x 6-3/4' 8871.34 90.17 1.69 3775.62 2.00 82.66 8310 - 8500 9268.93 90.17 1.69 3774.45 0.00 0.00 9581.82 90.00 355.44 3773.98 2.00 -91.54 1H -102D 03.T3 020217 RP 8500 - 8750 9678.20 10104.46 10422.64 89.51 89.51 87.34 357.30 357.30 348.00 3774.40 3778.06 3786.83 2.00 0.00 3.00 104.80 0.00 -103.22 1H-1020 04.T5 020217 RP 8750 9000 voomun A1,17 a1m T. w...viu P... MT'j 10652.64 87.34 348.00 3797.50 0.00 0.06 9000 - 9250 "T"�" 10992.06 90.00 0.00 3805.41 3.62 77.68 9250 9500 u 'v"""" "ui mMOavn =:2 u.o..�. �x.va.x.n ,n-: .x -u - - 71174.28 90.00 3.67 3805.41 2.01 89.96 11184.54 90.00 3.67 3805.41 0.00 0.00 IH -102D 07.T8 020217 RP 9500 - 9750 11354.39 93.58 357.88 3800.09 4.01 -58.21 11361.07 93.58 357.88 3799.68 0.00 0.00 1H -102D 08.T9 020217 RP 9750 - 10000 11498.96 91.14 1.22 3794.01 3.00 126.15 10000 - 10250 11915.99 90.06 358.93 3787.00 2.00 -116.40 1H -102D 09.T10 020217 RP 11929.18 89.94 359.05 3787.01 1.00 115.91 10250 10500 12239.99 89.94 359.05 3787.32 0.00 0.00 7Minor Risked 12332.69 87.88 358.00 3789.09 2.50 -153.65 1H -102D 70.1`17 020217 RP 10500 - 10990 13290.48 89.02 318.73 63OM(12 4.10 -88.96 13352.17 89.02 318 317.1 0 00 0.00 10990 11480 13407.86 971. �7 rti ..2 .75 IN -102D 13.714 020717 RP 11480 - 11970 73935.58 o- 3 - �.0 IH -102D 74.7 -30/330 14 _D 11970 - 12460 y - 3�.1`1H-124Wp20 -.- 12460-12960 12960 13450 13450 13940 13940 - 14425 _ 13. 1H-125wp20 -60 / 30011 / 60 -90/270 -120/240 / 120 �1�-i -150/210 __]1H -102L 150 1 H-102wp23 16:20, June 29 2017 c_ Kuparuk 1H Pad Easting (2500 usft/in) Easting (2500 ustt/in) Iwp20 1H-120wp21 AC Flipbook ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-102 (formerly 31) 50103xxxxx00 Plan: IH -102L4 Plan: 1 H-102L4wp23 Error Ellipse Survey Report 29 June, 2017 Company: ConowPhillips (Alaska) Inc. -Kupi Project: Kupawk River Unit Site: Kupamk 1H Pad Well: Plan: 1 H-1 02 (formerly 31) Wellbore: Plan: 111-1021-4 Design: 111-10214wp23 SLB Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1 H-102 (formerly 31) Plan: 54+39 @ 93.00usft (Doyon 142) Plan: 54+39 @ 93.00usft (Doyon 142) True Minimum Curvature 1.00 sigma EDM Production Survey Tool Program Date 6/29/2017 From To Wait) (usit) Survey (Wellbore) Tool Name Description 39.00 700.00 1 H-102wp23 (Plan: 1H-102) GYD-GC-SS Gyrodata gyro single shots 700.00 1,794.101H-102wp23(Plan : 111-102) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 1,794.10 7,204.22 1 H-1 02wp23 (Plan: 1 H-102) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 7,204.22 7,554.22 1 H-1 02L4wp23 (Plan: 1 H-10214) MWD -INC -ONLY MWD -INC -ONLY -FILLER 7,554.22 9,054.22 1H-102L4wp23(Plan: 111-1021-4) MWD MWD -Standard 7,554.22 14,425.15 1H-102L4wp23(Plan: 11H-1021-4) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC Position uncertainty and bias at survey station Measu a Indinsfion ASlmplh Vertical Highside Idlaral V.M.1 M,naurb Semima)or Semlan�wr Beeth Depth Ener alas E., Bias Error Blas of Bias Error Error As.Wh Tool (usa) (°) 0 (usm (Oehl (vsB (usn) (un) luso) lusn) 1"017 lean) (-ft) P) 7,204.22 75.57 000 3,753.15 1047 1.44 944 2M 841 150 2.86 2448 761 103.89 MM+IFR-AK-OPZ-SC(1, 3) 7,20423 7557 0.00 3,753.15 1047 1.44 944 2.44 041 150 2 a 24.48 7.61 103.89 MM -INC _ONLY (1, 4) 7.21280 76.93 0.00 3,755.19 10.03 -148 944 244 839 1.50 286 24.58 7.70 103.54 MM -INC _ONLY (1, 4) ],21].02 77.61 000 3,756.12 10.03 -1.46 944 2M 8.39 150 2.86 24.58 7.70 10354 MWD -INC ONLY n. 4) 7,237.02 77.61 0.00 3,760.41 10.03 -1.46 945 2.44 839 1.50 286 24.58 730 103.54 MWD-INC_ONLY (1. 4) 7.52105 80.72 2.38 3,794.18 8.48 -1.52 18.16 2.43 848 1.52 2.89 24.96 17.09 112.39 MWD -INC _ONLY (1. 4) ],553]8 9000 265 3,794.55 848 -1.52 18.16 2.43 848 152 2.89 24.95 17.09 112.39 MW INC_ONLY(1, 4) ],6]0.68 93.34 359.38 3,791.14 849 -1.54 2027 2.20 650 1.52 275 24.90 1907 114.59 MM (1. 5) 7,6]1.39 93.53 359.19 3,]90.]4 8.49 .1.54 2027. 2.26 BSO 152 2.75 24.90 1907 114.59 MMM. 5) 7,893.65 93.53 359.19 3.T77.41 855 -1.54 2053. 1.87 858 1.52 244 24,39 1999 108.75 MM (1, 5) 7.92170 93.53 359.19 3,]]5.69 8.58 -154 20.59 183 859 1.52 241 24.35 20.10 109.10 MWD(1, 5) 8,002.07 9048 020 3,772.87 885 -1.51 2074 1.66 8.65 1.51 2.29 24.19 20.50 10455 MM (1, 5) 8,012.73 9008 0.34 3,772.82 885 -1.51 20.74 166 885 1.51 2.29 24.19 2050 104.55 MM (1, 5) 0.01473 90.00 0.36 3,772.82 8.65 4.51 2074 1.66 885 1.51 229 24.19 20W 104.55 mm (1, 5) 8,02538 89.79 038 3,772.84 866 4.51 20.76 1.84 8.65 1.51 2.28 24.17 20.54 10406 Mwo(1, 5) 6.78168 89.79 0.36 3,77565 9.60 451 25.85 0.33 9.00 1.52 177 26.93 22.78 3203 Nim (1. 5) 8,792,36 8979 0.38 3,77569 900 -151 25.85 0.33 9.00 1.52 1]] 28.93 22.78 3203 Mwo(1, 5) 8.794.34 89]9 036 3.775.]0 900 -1.51 25.85 033 9.00 1.52 177 26.93 22.78 32.03 MMM. 5) 8.605.02 90.00 038 3,77512 9.61 -152 25.95 031 9.61 1.52 1.77 2703 22.7B 3162 MWD (1. 5) 8,858.68 WA4 144 3,775.65 972 -1.52 26.61 0.18 9.73 1.52 1.77 27.61 22.73 29.82 Ni" n. 5) 8.871.34 90.17 1.69 3.]7562 9.72 -1.52 26.81 0.18 973 1.52 177 27.61 22.73 29.82 Nim (1. 5) 925827 90.17 169 3,77448 9.01 -152 21.67 242 9.02 1.51 3.00 2420 2154 10432 MWD+1FR-AK-CAZ-SC(2.5) 9,268.93 90.17 1.69 3,774.45 901 -1.52 2167 242 9.02 151 3.00 2420 21.54 104.32 MWD -IFR -AK -CA -SC (2. 5) 9,569.16 90.01 355.69 3,77396 9.22 -1.51 22.13 2.54 922 1.51 3.13 2408 22.02 98.38 MWD+1FR-AK-CAZ-SC(2. 5) 9,581.82 90.00 355.44 3,]]398 9.22 -1.51 22.13 2,5,1 9.22 151 3.13 24.08 2202 9838 MWD+1FR-AK-CAZ-SC(2. 5) 9,665.54 0957 357.06 3,]74.29 9.31 -1.50 22.16 2.50 9.29 151 3.15 24.05 22.12 95.01 MWD+IFR-AK-CA-SC(2, 5) 9.678.20 89.51 357.30 3.774.40 9.31 -1.50 22.16 2.50 9.29 1.51 315 24.05 22.12 95.81 MWO+IFR-AK-CA-SC(2.5) 10,091.80 09.51 357,30 3,777.95 964 .1.50 23.22 250 9.63 152 3.24 24W 23.18 74.13 MWDAFR-AK-CAZ-SC(2, 5) 10.104.46 89.51 357.30 3.77806 9.84 -1.50 23.22 2.50 9.63 152 324 24M 23.18 74.13 MWD+1FR-AK-CA-SC(2, 5) 10,4o99a 87.43 348.37 3,788.25 1001 -147 2356 2.71 981 152 331 24.37 2331 4902 MWDHFR-AK-CPZ-SO(2, 5) 10.422.64 67.34 340.00 3]85.83 1001 -147 23.56 271 9.91 1.52 331 24.37 23.31 49.02 MWDHFR-AK-CA-SC(2, 5) 10,639.98 87.34 348.00 3,796.92 10.23 447 24.13 271 10.13 1.53 3.36 24.86 23.38 33.07 MWD+1FR-AK-CAZ-SC(2. 5) 10,65264 87.34 348.00 3,797.50 1023 -147 24.13 271 10.13 1.53 3.36 24.86 23.38 33m MWD+1FR-AK-CAZ-SC(2, 5) 10,688.95 8762 349.29 3.799.10 1026 -147 24.27 2.67 10.17 1.53 337 24.96 23.37 31.32 MWD+IFR-AK-CAZ-SC(2, 5) 10,97940 8990 35955 3,80540 10.47 -153 25.10 2.37 10.47 1.53 345 25.58 23.25 27.53 MWD+IFR-AK-CAZ-SC(2. 5) 10.992.06 9000 000 3,80541 10.47 -1.53 25.10 2.37 10.47 1.53 3.45 25.58 23.25 27.53 MWD+IFR-AK-CPZ-SC(2,5) 11,161.82 WOO 342 3,80541 low -1.53 25.55 2.23 lose 1.53 3.50 25.97 23.18 27.09 MWD+IFR-AK-CAZ-SC(2. 5) 11,171.88 90.00 362 3,80541 We -1.53 2555 223 10.65 1.53 3.50 25.97 23.18 27.09 MWD+1FR-AK-CMS0(2, 5) 11,11428 WOO 3.67 3,80541 10.86 -1.53 2555 2.23 1000 1.53 3.50 25.97 23.18 27.09 MWB+1FR-AK CA -SC (2,5) 11,184.54 BOOS 367 3,80541 106] -153 25.58 223 10.67 1.53 3.51 2600 23.18 27.00 MWD+IFR-PRCA-SC(2.5) 11.341.74 93,31 358.31 3.800.85 10.85 -1.65 25.82 245 Was 153 355 26.50 23.15 25.33~+1FR-AK-CA-SC(2, 5) 5/29/2017 4.'07.'47PM Page 2 COMPASS 5000.1 Build 74 Company: ConowPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: Plan: 1H-102(formerly 31) Wellbore: Plan: 11-1-10214 Design: 111-1021-4wp23 Position uncertainty and bias at survey station SLB Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1H-102 (formerly 31) Plan: 54+39 @ 93.00usft (Doyon 142) Plan: 54+39 rQ 93.00usft (Doyon 142) True Minimum Curvature 1.00 sigma EDM Production Measured Incinabo Azimuth Vertical Hi9ftdEe 1-ete21 V.W.l Ma9nifude Semimajor Semiminor impa, papal Error Bias Eoor Biaz Error Bias a<Blaz Error Error AZImufi 1 91 luaftt 1°1 (°) (-aa) Insffl (ural lusft) (ush) lural (-ft) ("BR) (usft) lova) r) 11,34841 93.45 350.08 3,80046 10.85 -1.66 25.82 245 10,86 153 355 26.50 23.15 25.33 MWD+IFR-AWCA -SC (2, 5) 11,35099 9358 357.80 3,800.09 10.85 -1.66 25.82 245 1006 1.53 355 25.50 23.15 25.33 MM+IM-AK-CA -SC (2. 5) 11.361.07 93.58 35708 3,79960 10.85 -166 25.84 2.45 10.87 1.53 3.55 28.52 2315 25.25 MIND+IFR-AK-CA -SC (2, 5) 11.486.25 9136 091 3,794.28 11.00 -157 WAS 2.32 11.02 153 3.59 26]6 23AS 2540 MM+IFR-AK-CA -SC (2, 5) 11,490.90 91.14 1.22 3.794.01 11.00 -1.57 26.18 2.32 11.02 1,53 3.59 2838 23.08 2560 MWD+1FR-AK-CA-SC(2, 5) 11.775.69 91.14 122 3.788.52 11.34 -157 2725 2.32 11.36 1.52 368 27.03 2307 MAI MWD+1FR-AK-CPZSC(2, 5) 11,78835 91.14 1.22 3,788.27 11.34 -157 27.25 2so 11.35 152 3.68 27.83 2307 22.41 MM.IFRAK-CA -W(2, 5) 11,90333 90.11 359.16 3,787.02 1152 -1.52 27.31 2.42 1152 1.52 3,72 28.08 Mel 22.57 MWD+IFR-AK-CA-$C(2,5) 11,91599 90.00 35893 3]8]00 1152 .1.52 27.31 2.42 1152 152 3.72 2806 2301 2257 MWD+IFR-AK-CASG (2, 5) 11,91853 9ew 350.94 3,787,00 11.52 -152 2731 2.42 11.52 1.52 372 28.06 23.01 2257 MWD+1FR-AH-CP-SC (2,5) 11,929.18 8994 359.05 3,78701 11.53 -1.52 2794 241 11.53 1.52 3.72 28.09 23.00 22.58 MWD+IFR-AK-DA2-SC(2.5) 12.227.34 8994 359.05 3,787.31 1192 -1.52 28.46 2.61 1191 1.52 3.82 2921 2298 20.40 MWD+1FR-AK-CA -SC (2. 5) 12.239.99 8sw 35905 3.787.32 11.92 -1.52 28.46 2.41 11.91 152 382 2921 22.98 2040 MWD+1FR-AK-CA -SC (2, 5) 12,320.03 88.16 358.14 3,788.65 12.11 -1.63 20.55 248 1203 1.52 388 2940 22.94 2042 MWp+1FR-AK-0KSC(2. 5) 12.332.69 87.88 358.00 3,789.09 12.11 -143 2855 2A6 12.03 1.52 IN 29.40 22.94 2042 MWD+IFR-PH-CA-SC(2, 5) 13,277.82 89.00 319.25 3.815.90 1329 -1.52 2800 sea 13.30 1.54 4.10 31.77 2203 1369 MWD+IFR- -CP -SC (2, 5) 13,29048 8902 318.73 3,818.12 13.29 -1.52 2800 3.69 13.30 1.54 4.10 31.77 M,w 1369 MM+IFR-AK-CA-SC (2.5) 13,33945 89.02 31873 3,816.% 1338 -1,52 26.17 369 13.39 1M 4.11 3192 22.62 12.93 MWD+IFR-AK-CA-SC(2. 5) 13,362.11 89.02 31873 3,817.18 13.38 -1.52 25.17 3.69 1339 154 4.11 31.92 22.62 1293 MWD+IFR-AK-CA-SC(2, 5) 13,395.20 90.65 316.05 3,817.31 1349 4.56 26.19 371 1346 1.54 4.12 32.05 22.61 12.25 MM -FR -AK -CA -SO (2, 6) 13407,86 91.12 317.85 3,89.11 13.49 -156 26.19 3.71 13.46 1.54 4.12 32.06 2281 1225 MWD+1FR-AH-CA-SC(2,5) 13,92292 91.12 317.05 3,80701 14.24 -1.56 27.85 3,71 14.21 1.54 Cie 33.M 22.51 6.49 MWDHFR-AK-CA-SC (2,5) 13,935.58 91.12 317.85 3,806]1{ 14.24 -1.56 27.85 371 1421 1.54 4.18 3350 22.51 649 MWD+IFRAK-CA-50(2.5) 14.14744 9062 324.18 3.003.53 14.54 -1,55 29.69 3.54 14.53 1.53 4.21 3404 MAI 509 MWD+IFR-AK-CA-SC (2,5) 14,160.10 9059 324.56 3,803.40 14.54 -1.55 29.69 3.54 14.53 1.53 621 34.04 22.41 5.09 MWD+1FR-AK-CA-SC(2.5) 14.412.49 Bose 324.515 3.800.79 14.93 -155 3070 3.54 14.92 1.53 426 34.96 2237 3.04 MM+IFR-AR-CA-SC(2, 5) 14,425.15 90.59 324.56 3,80066 14.93 -155 3070 3.54 14.92 153 4.26 34.96 22.37 304 ~+1FR-AWCI -SC (2, 5) 6292017 4:07:47PM Page 3 COMPASS 5000.1 Build 74 Pool Report 1 H-102L4w 23 Surface Location M CPAI Coordinate Converter From: --- - To:--_ -- --_-- - Datum: NAD83 .' Region: jalaska . Datum: NAD27 . Region: 'falaska I- Latitude/Longitude Decimal Degrees r Latitude/Longitude Decimal Degrees r UTM Zone: F_ r- South r UTM Zone: True f South C• State Plane Zone: F__-] Units: us-ft . r State Plane Zone: F-----] Units: us-ft 7-3 f Legal Description (NAD27 only) C Legal Description (NAD27 only) -StartingCoordinates: X: 11689609.08 EndingCoordinates: - -- X: 549577.455558541 Y: 5980414.37 Y: 5980662.56352101 Transform it._ -- _Help 1H-102L4wp23 Surface Location N. CPAs Coordinate Converter From: _ j To: --- Datum: NAD83 Region lalaska Datum: NAD27 Region: alaska -i I • Latitude/Longitude IDecinnal Degrees C Latitude/Longitude IDecimal Degrees f•UTM Zone: F_ r- South C' UTM Zone: True r South t- State Plane Zone:. q Units: us-ft C State Plane Zone: q Units: us-ft r Legal Deeciiption (NAD27 onlyl t-- Legal Description (NAD27 only) I Starting Coordinates: -Legal Description-- j X: 11689609.08 Township: 012 N --,I Range: 010 Y�5900414.37 Meridian:.0 Section: 33 — -- - - FNL . 40.519229 FEL . 764.65061 Transform Ouit Help 1H-102L4wp23 Surface Casing M CPAs Coordinate Converter From: -_.---_ ----- Datum: NAD83 Rogion: alaska r Latitude/Longitude IDecimal Degrees * UTM Zone: F— F South C. State Plane Zone: F___-3 Units: us -ft C' Legal Description (NAD27 only) -To:__.---- Datum: NAD27 - Rcgion: Fala3kd C Latitude/Longitude jDecirnalDegrees !' UTM Zone: True i South r State Plane Zone: F--'--3 Units: us -ft C Legal Description (NAD27 only) I -Starting Coordinates: Ending Coordinates: X' 11689909.67 x: 549878.038975245 Y: 15980107.45 Y: r5980355.64507016 ..................................................... .................Transform,__..._ Quit Help 1H-102L4wp23 Surface Casing M CPAI Coordinate Converter From: Datum: NAD83 . Region alaska i Latitude/Longitude Decimal Degrees * UTM Zone:1 r South * State Plane Zone: F__� Units: urft r Legal Description(N.AD27 onlyl Starting Coordinates: - x 111389909.67 Y: 15980107.45 Iola To: Datum: fNAD27 __] Regionlalaska r Latitude/Longitude jl5eZlDegrees r UTM Zone: True r- South r State Plane Zone: J4 J Units: ju,ft t- Legal Description (NAD27 only) Legal Township: 012 I'" J Range: 010 Meridian:I j Section: 33 FNL 1349.44926 FEL 1466.76527 ............................:............................... Transform Quit I Help 11H-102L4wp23 Kick-off Point M CPAI Coordinate Converter, n r-• . =a F From: Datum: NAD83 . Rogion: alaska .'. r Latitude/Longitude IDecimalDQgfees f UTM Zonef— (- South G State Plane Zone: q Units:f7,—ft--,7 r Legal Description (NAD27 only) Starting Coordinates: - X: J1693980.98 y 15979931.10 -To:- --- Datum: NAD27 Rogion: alaska . r Latitude/Longitude Decimal Degrees - UTM Zone: True F South C State Plane Zone: F --J] Units: us -ft . (' Legal Description (NAD27 only) Ending Coordinates: X: 553949.285837716 Y: 5980179.22228383 ............................................._.......... Quit Help Transform 11H-102L4wp23 Kick-off Point M CPAI Coordinate Converter From: -. - -- - - - Datum: NAD83 Region:alaska (" Latitude/Longitude IDecimalDegrees--� ( UTM Zone: f— r South (- State Plane Zone: F--:-:1 Units: Fus ft . r Legal Description (NAD27 onlyl �StartingCoordinates: --------- -- X: 11693980.98 Y: 5979931.10 To — Datum: NAD27 . Region alaska • Latitude/Longitude Decimal Degrees C UTM Zone: True J- South (` State Plane Zone: F Units: us ft (- Legal Description (NAD27 only) Township: 012 F] Range: 010 Meridian: JU J Section: 3q FNL . 554.10063 .FEL 1676.8335 Transform I Quit Help 1 H-102L4wp23 Top of Production F. CPAI Coordinate Converter From: Datum: NAD83 . Rcgion jalaska . Datum: NA� Rcgion: Alaska .' • Latitude/Longitude Decimal Degrees —� r Latitude/Longitude IDecimal Degrees • UTM Zone: r— F South r UTM Zone: True i South State Plane Zone: 1" -1 Units: usft State Plane Zone: i' -D Units: us-ft . C Legal Description (NAD27 only) r Legal Description (NAD27 only) Starting Coordinates: -- ----- -- X 1693981.00 Ending Coordinates: X: 553949.305813978 Y: 1597992700 Y: 5980175.92236175 ........... Transform .. 1H-102L4wp23 Top of Production M CPAI Coordinate Converter Y d±'k'Sl7ZL:.. From: - - - - Ta - Datum: INAD83 .j Region: alaska .; Datum: INAD27 Region: ',,.,la_.ks�, i r Latitude/Longitude Decimal Degrees i Latitude/Longitude reoimal Degrees �.. C UTM Zone: South C UTM Zone.True i South C State Plane Zone: q Units: us-ft r State Plane Zone. Units: us-ft r Legal Description QdAG27 only) r Legal Description (NAD27 only) ,-Starting Coordinates: — Legal Description - X:1693981.00 � Township: p12 FN—,-1 Range: 010 Y: 5979927.60 Meridian: IU Section:34 FNL 557.39336 IFEL 1676.8389 ........................................................... . ,Transform Quit Help 1 H-102L4wp23 TD CPAI Coordinate Converter From: To: Datum: NAD83 + Rcgion: alaska Datum: NAD27 + Region: Alaska + r Latitude/Longitude Decimal Degrees +� r Latitude/Longitude Decimal Degrees .� UTM Zone: r— r South ii C UTM Zane:True r South G State Plane Zone: q Units: us-ft + %` State Plane Zone: q + Units: us -ft + C Legal Description (NAD27 only) C Legal Description (NAD27 only) • Starting Coordinates: � Ending Coordinates: IF X: 1692735.54 X: 552703.912252242 y 15986776.45 Y: 5987024.43441855 .Transform Quit Help 1H-1 2L4wp23 TD M CPA] Coordinate Converter '-� O �' S' -• • From: - - -- To: - Datum: INAD83 . Region: alaskaDatum: INAD27 Region:alaska Decimal De reelDecimal i"' Latitude/Longitude 1 g� C� Latitude/Longitude g Degrees m r UTM Zone: South � C UTM Zone: �— True South (" State Plane Zone: r4 Units: us-ft . C" State Plane Zone: q + Units: us-ft r Legal Description (id.AD27 onlyl G Legal Description (NAD27 only) (-Starting Coordinates: _ Legal Description-- X: 1692735.54 Township:� � Range; .012 1'"J' 9 010 Y: 15906776.45 Meridian:U - Section: 22 FNL ..4259.5203 12861.7877 ............................................................ ,Transform Quit Help 16:33, June 29 2017 1 H-102L4wp23 Quarter Mile View 0 N t` N O w 8000 Q C � 14�' iH'20 X000 n ^ 1R -29L1- 3 fn aQgqP`i �O O N g ,t CNH Ag Qm 1H-1 q }4000 1H -19A A2 1A �Q 1 -17 O Q z t oP -52000 3 / N -2000 -2000 1� 0 2000 WELLBORE TARGET DETAILS (VAP CO-OROINATI Name TVD shape 1H.102D 0111020617 Ris 3772.82 Circle (Radius '. 10000) 1H-mO D 02, T2 D20217 RP 3775 72 Circle (Radius: 100.00) 1H-I02003T3 D20217 RP 377396 Ci,cle(Radius: Imi IH-m2004.T5020217 RP 3786.3 Gild. (Radius 10000) 1H-f02007.T60z0217 RP 3605.41 Circle (Radius 10000) 1H-tOID 08.79020211 RP 379968 C,i(Radius 100,00, 1H -102D 00TID 020217 RP 378700 Drell, (Radius 100.00) 1H -102010.T11021217 RP 378909 Clrtle(Radius 100,00, 1 H 102D 13.T14 020717 Rp 3817.11 Circle (Radius_ 100.00) 111-102014.715020717 RP 380676 Circle (Radius 10000) 1H102D 15,716 020717 RP 380066 Circle (Radius 100.00) M 1H-102 NOFault 3800.66 polygon 1H- 102 Polygon 020717 BE 380066 Polygon W 02 ""' Fault 360066 Polygon 1H-12001.T10206V RP CImIe 377282 Circle (Radius 1320.00) tP-10 DOS.T6020217 Rp 3800.09 Circle (Radius 10000) t H -t02 O6.T7020217 Rp 380601 Cirde(Radlus: 100.00) 1H -i W0 5T160207P J.Ole 480066 Circle (Radius 132400) f 0 /`l`s 2 N O 2 2 I 4000 6000 8000 10000 12000 14000 ,(-)/East(+) (2000 usft/in) 0:32, June 292017 1 H-102L4wp23 WELLBORE TARGET DETAIL. (MPP—OF01NATE5) Name ND B6age 1H-1021) 01 T1 02069 RP 3]]2.82 Circle (Rectus: 1 W.00) Quarter Mile View 1H-102Dp2.T202D29RP 1.1 D2D0 T30209RP 1H -1021]01.T502021,7 RP 3i]5.]2 3]]3.93 3]88.83 Clrcle (Far 100.00) Circle (Rectus 100.00) Clrcle (Rados: 100.00) 11-1021) 07.7802021] RP 11-1021)06 T9 02029 RP 1H -102D 09.71 D 02029 RP 3805.41 3799.68 3]0)00 Circle(Radusi 100.00) Circle (Rafts: 100.00) Cants Radus: 100.00) _-.-_ 1H-102010.711 D20217 RP 1H -102013.T14 020717 RP 1H -102D 14.7150£0717 RP 1H -102015.T16 D20717 RP W-102 Ruch Fault 1H-102 Pdygon020717 BP 378909 3817.11 3006)6 3800.66 3800.66 380066 Cirds Rados: 100.00) Cimle (Radure 100.00) Cnee(Radus: 100.00) Oar. (Fundus: 100.00) Polygon Polygon _.... -- -3600.66... —%Jygon 1H-102D011T1Fel D61]RPCirde 3772.82 Circle (Fiscal 1320.00) 1 H- 02D 05 T6 M0217 RP 3800.89 Circle (Radius: 100.00) 1H -102D 06.T7 020217 RP 380001 Circle (Radius: 100.00) '. 1 H -102D 15T16 020717 RP Circle 380066 Circle (Radius: 1320.00) I 8000 X6000 D 0 0 0 N :111 J= tf 0 Z 2000 0 N 1117 -2000 0 2000 4000 6000 8000 10000 12000 14000 16:34, June 292017 1 H-102L4wp23 WELLBORE TARGET Name 1H- ;T 102D01.71020617 RP DETAILS rvo 3772.72 (MAP CO-ORDINATES, Snap) Circle Radius, loo o0) Quarter Mile View 1002D 02 T2 RP HE 102D 03:T1020217 RP 1H-1021301629217 RP 3]75]2 3)73.98 3788.03 Circle (R ad: 100.00) Cirtle(Radiu5100.00) Cimle(Radius: 100.00) 1H-1021)0].TB 020217 RP 3005.41 Circle (Radius: 100.00) 11-1020 OB T9 020217 RP 379968 Circle (Radius: 100.00) 1 H-0 0200971002027 RP 3787.0 Circle (Radius: 100.00) 1H-1020 ID.T110201 RP 3788.01, Circle (Radius 100.00) 1H-1021) Y3.T14020717 RP 3017.11 CIrUe (Rados: 100.00) 1 M. 02014.71502071) RP MM.76 Cbcle(Radius: 100.00) 111.102D 15.T16 U0717 RP 3800.86 Circle (Radius: 100.00) F IH-102 NOr10 Faull 3000.66 POg9on - 11--102 PO4 020717 BP 3800 66 Polygon — - 1H-002-S..h FeuM--- x0066 - PotygOn - 1&1021301.T1%0617RPCircle 377282 Cicie(Radius '. 132000) ',. '.. 1H-t02D 05.7642021) RP 380089 Circle (Radius, 100i 1 H-102D 011i 20N)RP 380001 Circle Radius, 100.00) ',. tK102016T18020717 RP Circle 380066 0.1.Ratlius: 1320,0) 8000 ---- ---- --X000 X000- ly_ CD O O IN +4000 L z 2000 - - VJ I N 0 - M 2 N -2000- -2000 0 2000 4000 6000 8000 10000 12000 14000 1 H-102L4wp23 Section View 3650 0 0 ^o 3700 3750 .- - o _--_...-.. $ - --- WS=C- WS=C- 7-5/8" x 9-7/8' _ rn o rn� o o A WS_� ° O OO � rrn 3800 ---------- ° WS A4 CD WS A4 Objective o o 3850 --- -- WS—A3 3900 ------------ -- 1y 21 2 -900 0 T 00 1800 2700 3600 4500 5400 6300 Vertical Section at 0.000 - -- ------- ------------ Lw Tollerable Collision Risk Worksheet ConocoPhillips Alaska ATolerable Collision Risk Worksheet based on Rev. 1 - 29 Jul 99 Use this sheet to describe a well interference scenario where ORA may be applicable. Check first that the scenario really is different from thane described on existing worksheels. Pfepared by: Kelsey Hallford y l Authorized by: Dan Bearden i-... ConocoPhillips Alaska, Inc Drilling Anti -Collision Management Generic name of scenario: Collision with other laterals In multi -lateral well (A3 with A2, A4 with A3 and A2, a with A4, A3, and A2. D with B. A4, A3 and A2) Description: (Be spec. Include all factors which affect either the cost of coNislon or the cost of redudn the risk Well 1H-102 A3, A4, Band D laterals fail anti collision with one another in the hor¢onlal legs of the well base on WP21. The four upper laterals will be geosleer id using periscope so disk or leaving the zone is minimal. There Is no immediate danger to life or impact on the environment If war! 1H- 102 intersects itself. If 1 H-102 Intersects Itself there would be damage to the liner and swell packers. No risk of a well control Issue exists because well 1H-102 lateral that Is being dulled is above the previous placed lalems (upper laterals have the same or slightly higher PP) and is )leing tlrilletl from the main here with kill weight mud In the hole. v The laterals fail with (he mother bore at the kick og point, but we are intentionally side tracking. We will be kicking off will motors to keep us in the target sands. Do the consequences of collision include a Orrs Are the Q+u risk to personnel or the consequences environment? of collision u. . List all the consequences of I v' collision and the necessary au remedial action: No HSE risks exist with 1H 102 intersecting Itself while drilling. An economic concern exists and It would be 0e cost of damage to the completion equipment that has already been placed in the lower laterals prior to chilling the upper laterals and the impacl it may have on future production from (he well. If necessary the lateral (he( had been drilled into can be isolated and production shut off (loss of lateral) which is wemt case scenario. The biggest chance of getting `lost' is when crossing faults, there are three fault crossings in IH -102. but since the lower laterals will have already ddNed across the fault the exact throw of (fie fault will be known so the fault crossing can be planned for. If we do get out of zone we can determine what zone we are in based on real time logs and cuttings and then steer back Into the comecl zone. How could the probability of collision or the severity of the consequences be reduced? How might this impact the drilling operation? Cost substantially reducing V = $0 Given the uncertainty In the aboveestimates, by how many times must the savings made from not reducing the risk outweigh he risk itself? (Guideline = 20) M = 20 F=1/M= 0.05 there practical way Q.g to substantially reduce either either thee probability of collision or the severity of the consequences? C— $10,000,000 I I V = $42,650,000 I Accepting a finite risk of collision will reduce the NPV of the planned well. What reduction, as a fraction of the total NPV, are you prepared to tolerate? (Guideline = 0.05) F= 0.01 VF/C= 0.04265 - If V F I then close approach tolerances need not be set C If VF C < / then Tolerable Collision Risk = I in C r V F Tolerable Collision Risk = 1 in 23 Minor Risk 1/50 applied to all laterals As -built 1 12/05/Oq MRT I CC I IRev. Per K05014ACS 12 02/01/1A JAH I LGM I Rev. Per K170005AGS 1. BASIS OF LOCATION AND ELEV. IS DS1H N 25 3D 29 28 27 25 2. COORDINATES SHOWN ARE ALASKA STATE iG PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 36 31 3. ELEVATIONS ARE B.P.M.S.L. 1H momm •14 PROTRACTED SECTIONS 28 AND 33, HCS 32 33 34 35 36 UMIAT MERIDIAN, ALASKA. •19 T1 1 E •225. 0 DATES OF SURVEY: 12-26-16 THRU OE 016 06 1-31-17 FIELD BOOKS L16-35, L16-40, 016 Ti 1N L17-02 & L17-03. •15 *1 6 5 4 3 2 •2 *7 IA 03 •18 FCPFI t0 �ti 0 ASPJTH2 7 8 •4 Fqc 1 inch = 200 ft. SEE SHEET 2 & 3 FOR COORDINATE TABLE LOUNSBURY ]*Ill oi'4 k ASSOCIATES, INC. 2 AREA: IH MODULE: XXXX UNIT: 51 ConocoPhillips DS1H e n s s a 3 CADD FILE LE N0. LK6108d31 2/05/05 DRANING N0. CEA—D1HX-6108D31 IE REV: iP 2 za 2420 21 2 23 MAP VICINITY E SCALE: 2 MILES 1" = 28 27 0102 33 34 0106 0101 NOTES: 1. BASIS OF LOCATION AND ELEV. IS DS1H MONUMENTATION PER LOUNSBURY & ASSOC. DS1 H 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, •20 •12 UMIAT MERIDIAN, ALASKA. •19 •11 •225. 0 DATES OF SURVEY: 12-26-16 THRU •17 016 06 1-31-17 FIELD BOOKS L16-35, L16-40, 016 021 L17-02 & L17-03. •15 *1 013 6. ALL DISTANCES SHOWN ARE GROUND. •9 •2 *7 03 •18 GRAPHIC SCALE 08 0 100 200 400 •4 1 inch = 200 ft. SEE SHEET 2 & 3 FOR COORDINATE TABLE LOUNSBURY oi'4 k ASSOCIATES, INC. RU TONS BNCMEERS PWNNERS AREA: IH MODULE: XXXX UNIT: 51 ConocoPhillips DS1H WELL CONDUCTOR Alaska, Inc. LOCATIONS CADD FILE LE N0. LK6108d31 2/05/05 DRANING N0. CEA—D1HX-6108D31 PART: REV: 1 of 3 2 1 02/01/11 JAH I LGM I ]Create Per K170005ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 28, T. 12 N__ R. 1n F__ 11MIAT uFalnleu Well No. NAD 27 ASP Coordinates NAD 27 Geo ra hic Coordinates Section Offset. Elev. Y X Lat. 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 5,9 81,111.42' 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' 795' 48.0' 54.1' 0 * CONDUCTOR ASBUILT THIS SURVEY ......y`�� SURVEYOR'S CERTIFICATE 49th ! V '; ♦�vI HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND ..................................A LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF p ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY .................................. DONE BY ME OR UNDER MY DIRECT SUPERVISION AND -MIAH F. CORNELL;°�. THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION LS -12663 • ,: AV ARE CORRECT AS OF JANUARY 31, 2017. q 411 +0 �FessloNn� LOUNSBURY ,,,,_"`••• � TORASHOCLITE9, PW NnS AREA: iH MODULE: XXXX UNIT: D1 ConocoMilli S DS1H WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. DRAWING N0. PART: REV: LK610801 12/27/16 CEA-DIHX-6108D31 1 3 of 3 1 Haagen Dazs Necessary Plan Request (NPR) Appendix ■ Tier 1: Standard Section ■ Intervals without issues noted for Tier 2 or 3 ■ Tier 2: Challenging Orientation ■ Drilling within 30' of horizontal inclination AND drilling within 30' of magnetic East/West azimuth in extreme northern or southern locations ■ Tier 3: Critical Steering ■ Driller's Target of 50' Radius or Less ■ Lease line constraint ■ Small Geologic Target ■ Failure of Major Risk Rule (Close Approach) ■ Defined during directional planning, based on the positional uncertainty ■ Theoretical intersection of the path of the well being planned with an offset well ■ If HSE risks are eliminated, the Tolerable Collision Risk assessment can be implemented ■ Tier 4: Single section containing both Tier 2 and Tier 3 challenges ■ Tier 1: ■ Directional interval across which no special mitigations are needed ■ Tier 2: ■ Increase non-magnetic insulation of MWD tool in the BHA ■ Take rotational check shots and/or increase survey frequency at the start of a BHA run ■ Alter well directional plan, if feasible • L-onsider gyro surveys where feasible ■ Tier 3: ■ Increase survey frequency across critical interval ■ Increase correction frequency across critical interval ■ Take rotational check shots and/or increase survey frequency if the critical interval is at the start of a BHA run ■ Define escalation based on deviation from plan ■ Minor Risked close approach intervals with a high financial or scope risk should strongly consider the use of relevant mitigations ■ Tier 4: 0 Consider all Tier 2 & 3 mitigations 1 ( 1H -1u2 Drilling Hazards Summary 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Mitigation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin 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 of trip 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 accurac . 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Strate Running Sands and Gravels -Mitigation 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" Own Hole / 4-1/2" Liner Intervals Hazard Risk Level Miti ation Strategj 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 weight if possible if pipe does get stuck, Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during completion run. 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. 1H-102 only has AC challenges between its laterals, we will be utilizing periscope to maintain eolo ical certain 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 we 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 drag. Whipstock Retrieval Moderate A dedicated clean out run prior to attempting to pull whipstock can be used to reduce the risk of fishing operations. 05 Attachment - 1H-102 Dolling Hazards Summary.doc 620/2017 9:22:47 AM 1H-102 Cement Calculations Ie9¢e 1 tt (TDq 1 tt (Bottom) OD) ID 42 39 80 20 18.5 13.5 39 1794 10.75 9.95 45.5 9.875 5900 8325 7.625 6.875 29.7 Surface Cement: Surface to 1,794' MD Slurrv: Lead 1.91 ft3 sx of 11.0 / ppg DeepCRETE Capacities 15.8ppg Class G yielding 1.16ft"3/sk Tail 2.28 113/ sx of 12.0 DeepCRETE OH 0.177045 Permafrost (PF) depth 1620 ft 13-1/2" x 10-3/4" 0.064783 XS% Lead 250% 20" x 10-3/4" 0.220213 XS% Tail 50% 30-3/4" 0.096175 Tail Cement 1.4 0.27 bbls Shoe Track 80 x Length 500 ft bbls Total 500 x 0.06478288 x 1.5 48.6 Shoe Track 80 ft ft3 80 x 0.09617496 x 1 7.7 Open Hole 10 x 0.17704488 x 1.5 2.7 Total 59 bbl 331 ft3 145 sx Lead Top Tail Cement to Conductor 1294 ft 1294 x 0.06478288 x 3.5 293.4 bbl Conductor Length 80 ft 80 x 0.22021323 17.6 bbl Total: 311 bbl 1746 ft3 914 sx Intermediate Cement: Cement from 8,325' MD to 5,900' MD Slurrv: Capacities: 15.8ppg Class G yielding 1.16ft"3/sk 9-7/8" x 7-5/8" 0.03825 XS%for open hole and annulus: 40% 9-7/8" OH 0.094731 1 7-5/8" ST 0.045916 Annulus Cement 2425 x 0.03825044 x 1.4 129.86 bbls Rathole Cement 2 x 0.09473055 x 1.4 0.27 bbls Shoe Track 80 x 0.0459157 x 1 3.67 bbls Total 134 bbls 751 ft3 648 sx TRANSMITTAL LETTER CHECKLIST WELL NAME: KALA, u ' �� L / PTD: 02 t /OS Development _ Service _ Exploratory _ Stratigraphic Test Non -Conventional FIELD: l ,V&r POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit No. API No. 50 -pa- 5 () (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 ermit). 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 ur. dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sam 30' sample intervals from below the permafrost or from where les are fns. caw t and 10'mLn le intervals throw tar et zones. se note the following special condition of this permit: uction or production testing of coal bed methane is not allowed forNon-Conventioe of well) until after (Comnany Name) has designed andWelllemented a water well testing program to provide baseline data onr quality and quantity. (Company Namemust contact the AOGCCtain advance ap roval of such water well testing rogram. rrequired ulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of logs to be run. In addition to the well logging program proposed by pany Name) in the attached application, the following well logs are required for this well: Well LoggingRequirementserStatute 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 da s after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL -490150 Well Name: KUPARUK RIV UNIT 1H -102L4 _ Program DEV _ Well bore seg PTD#:2171050 Company CONOCOPHILLIPS ALASKA, INC. Initial Class/Type DEV LPEND. GeoArea 890 Unit 11160_ _ _ On/Off Shore On Annular Disposal ❑ Administration 17 Noncoirven. gas conforms to AS31.05.0300.1.A),0.2.A-D) NA 1 Permit fee attached _ _ NA 2 Lease number appropriate.. _ _ Yes ADL0025639, Surf Loc & Top Prod; ADL0025636, TD. 3 Unique well name and number _ Yes _ KRU 11-1-1021-4_ 4 Well located in a. defined pool _ _ _ _ Yes KUPARUK RIVER, WEST SAK OIL - 490150,. governed by Conservation. Order No. 406C, 5 Well located proper distance from. drilling unit. boundary Yes CO 4060 contains no spacing restrictions with respect. to drilling unit boundaries.... 6 Well located proper distance from other wells. Yes CO 4060 has no interwell spacing restrictions... . 7 Sufficient acreage available in. drilling unit Yes 8 If deviated, is. wellbore plat included _ _ Yes _ 9 Operator only affected party. Yes Wellbore will be more than 500' from an external property line where ownership or landownership changes. 10 Operator has appropriate bond in force _ Yes _ Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative approval Yes PKB 7/18/2017 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order# (put 10# in comments) (For NA 15 All wells within 1/4 mile. area. of review identified (For service well only) NA 16 Pre -produced injector. duration of pre -production less than 3 months (For service well only) NA 18 Conductor string. provided NA Conductor set. in KRU 1 H-102 Engineering 19 Surface casing. protects all known USDWs NA Surface casing set in KRU 11-1-102 20 CMT vol adequate to circulate on conductor & surf csg _ _ NA. Surface casing will be set and fully cemented in KRU 1 H-102 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will cover all known. productive horizons _ No.. _ Productive_ interval will be completed with. slotted liner 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all waste to approved disposal wells 25 If a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; major risk failure w/ future well 1 H-125 27 If diverter required, does it meet regulations. NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is. 1635 psig(8.2 ppg EMW); will drill w/ 8.8-9.5 ppg EMW VTL 7/25/2017 29 BOPEs,. do they meet regulation Yes _ 30 BOPE press rating appropriate; lest to (put psig in comments) Yes MPSP is 1260 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 H2S 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 H2S measures required. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is 8.4 ppg EMW; lateral production hole will be drilled using 9.0 to 9.5 ppg mud. Appr Date 37 Seismic analysis of shallow gas zones NA PKB 7/18/2017 38 Seabed condition survey (if off -shore) _ NA. _ 39 Contact name/phone for weekly. progress reports [exploratory only] NA Onshore development lateral to be drilled. Geologic Engineering Public Commissioner: Date: C�om�jssioner Date Commissioner Date br' ' f i ):2 ( 7-06`117
