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Home My WebLink About217-103DATA SUBMITTAL COMPLIANCE REPORT 1/2212018 Permit to Drill 2171030 Well Name/No. KUPARUK RIV UNIT 1H-1021_3 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23580-62-00 MD 14686 ND 3844 Completion Date 10/20/2017 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION / Mud Log Nod/ Samples No Directional Survey Yes / DATA INFORMATION List of Logs Obtained: GR/Res (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH I Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 28751 Digital Data 1698 14740 10/26/2017 Electronic Data Set, Filename: CPAI 1 H-1021-3 - Scope Resistivity_RM_LWD002.Ias ED C 28751 Digital Data 7880 14686 10/26/2017 Electronic Data Set, Filename: CPAI 11-1-1021-3 Scope Resistivity_RM_LW D020.Ias ED C 28751 Digital Data 32 1776 10/26/2017 Electronic Data Set, Filename: CPAI 11-1-10213. VISION Resistivity_RM_LWD001.las ED C 28751 Digital Data 32 14686 10/26/2017 Electronic Data Set, Filename: CPAI 11-1-1021-3 Scope Resistivity RM.las ED C 28751 Digital Data 32 14686 10/26/2017 Electronic Data Set, Filename: CPAI 11-1-1021-3 . Scope Resistivity Customer Channel LAS.las ED C 28751 Digital Data 10/26/2017 Electronic File: CPAI 11-1-1021-3 Scope Resistivity, RM LWD002 DLIS.dlis ED C 28751 Digital Data 10/26/2017 Electronic File: CPAI 1H-1021-3 Scope Resistivity RM LWD002 DLIS.html ED C 28751 Digital Data 10/26/2017 Electronic File: CPAI 11-1-1021-3 Scope Resistivity RM LWD020 DLIS.dlis - ED C 28751 Digital Data 10/26/2017 Electronic File: CPAI 1 H-1021-3 Scope Resistivity RM LWD020 DLIS.html ED C 28751 Digital Data 10/26/2017 Electronic File: CPAI 11-1-1021-3 Scope Resistivity. RM LWD001 DLIS.dlis ED C 28751 Digital Data 10/26/2017 Electronic File: CPAI 1H-1021-3 Scope Resistivity RM LW D001 DLIS.html ED C 28751 Digital Data 10/26/2017 Electronic File: CPAI 11-1-1021-3 Scope Resistivity' RM DLIS.dlis ED. C 28751 Digital Data 10/26/2017 Electronic File: CPAI 11-1-1021-3 Scope Resistivity RM DLIS.html AOGCC Page 1 of 3 1 Monday, January 22, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/22/2018 Permit to Drill 2171030 Well Name/No. KUPARUK RIV UNIT 11-1-11021-3 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23580-62-00 MD 14686 TVD 3844 Completion Date 10/20/2017 Completion Status 1-0I1 Current Status 1-0I1- UIC No ED C 28751 Digital Data 10/26/2017 Electronic File: CPAI 1H - P 102L3_Scope_Resistivity_2in_MD.pdf' ED C 28751 Digital Data 10/26/2017 Electronic File: CPAI_1H- 102L3_Scope_Resistivity_2i n_TVD.pdf ED C 28751 Digital Data 0/26/2017 Electronic File: CPAI_1 H- 1021-3_ Scope_Resistivity_5in_MD.pdf ' ED ED C 28751 Digital Data (10/26/2017 Electronic File: CPAI_1H- (J 102L3_Scope_Resistivily_5in_TVD.pdf - ED C 28751 Digital Data 10/26/2017 Electronic File: 1H-1021-3 NAD27 EOW , Compass Survey.pdf ED C 28751 Digital Data 10/26/2017 Electronic File: 1H-1021-3 NAD83 EOW Compass Survey.pdf ED C 28751 Digital Data 10/26/2017 Electronic File: 11-1-1021-3 [Canvas] NAD27.txt ED C 28751 Digital Data 10/26/2017 Electronic File: 1 H-1021-3 [Canvas] NAD83.txt ' ED C 28751 Digital Data 10/26/2017 Electronic File: 11-1-1021-3 [Macro] NAD27.txt ED C 28751 Digital Data 10/26/2017 Electronic File: 1H-1021-3 [Macro] NAD83.txt' ED C 28751 Digital Data 10/26/2017 Electronic File: 1H-1021-3 [Petrel] NAD27.txt ` ED C 28751 Digital Data 10/26/2017 Electronic File: 11-1-1021-3 [Petrel] NAD83.txt ED C 28751 Digital Data 10/26/2017 Electronic File: 1 H-1021.3 [Surveys] NAD27.txt . ED C 28751 Digital Data 10/26/2017 Electronic File: 11-1-1021-3 [Surveys] NAD83.txt . ED C 28751 Digital Data 10/26/2017 Electronic File: CPAI 1H-1021-3 Survey List.csv Log C 28751 Log Header Scans 0 0 2171030 KUPARUK RIV UNIT 1H-1021-3 LOG HEADERS Well Cores/Samples Information: - - Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED VI W ( Page 2 of 3 Monday, January 22, 2018 DATA SUBMITTAL COMPLIANCE REPORT 112 212 01 8 Permit to Drill 2171030 Well Name/No. KUPARUK RIV UNIT 11-1-1021-3 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029.23580-62-00 MD 14686 TVD X3844 Completion Date 10/20/2017 Completion Status 1-0I1 Current Status 1 -OIL UIC No Completion Reportf Y t Directional / Inclination Data Mud Logs, Image Files, Digital Data Y / 1�A Core Chips Y NA Production Test Informalioli! / NA Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files C`/'�/ Core Photographs Y N Geologic Markers/Tops '() Daily Operations Summary V Cuttings Samples Y / & Laboratory Analyses Y / A COMPLIANCE HISTORY Completion Date: 10/20/2017 Release Date: 7/26/2017 Description Date Comments: Compliance Revie 10,16 Comments Date: I 1:r` � 18 A0G( t Page 3 of Monday, January 22, 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ■ 2r%05.1 IF a..v NOV 2 0 2017 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil❑+ ` Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 1b. 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: 217-103 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 9/30/2017 15. API Number: 50-029-23580-62-00 4a. Location of Well (Governmental Section): Surface: 40.52' FNL, 764.65' FEL, Sec 33, T12N, R10E, UM Top of Productive Interval: 373' FNL, 1667' FEL, Sec 34, T12N, R10E, UM Total Depth: 4455' FNL, 2979' FEL, Sec 22, T12N, R1 OE, UM 8. Date TD Reached: 10/3/2017 16. Well Name and Number: KRU 1H -102L3 9. Ref Elevations: KB:92.6 GL:54 • BF: 17. Field / Pool(s): Kuparuk River FieldlWest Sak Oil Pool 10. Plug Back Depth MD/TVD: 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- 553957 y- 5980360 Zone- 4 Total Depth: x- 552588 y- 5986828 Zone- 4 11. Total Depth MDrrVD: 14686/3844 - 19. DNR Approval Number: LO/NS 80-261 12. SSSV Depth MDITVD: N/A 20. Thickness of Permafrost MD/TVD: 1699/1630 5. Directional or Inclination Survey: Yes E - (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 7647/3811 ' 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 78.67 B 40 119 40 119 42 Existing Cement to Surface 103/4 45.5 L-80 40 1771 40 1691 13.5 876 sx 11.0 ppg Lead Cement 75/8 29.7 L-80 37 8593 37 3991 9.875 1155 sx 15.8 ppg, Class G 41/2 11.6 L-80 7645 14668 3809 3844 6.75 Uncemented Slotted Liner 24. Open to production or injection? Yes ❑� No ❑ If Yes, list each interval open (MD1TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Slotted Liner @: 7782 -14624 MD and 3828 - 3843 TVD _Oi A LETi0N D TE / )b�oII VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 41/2 7289 n/a 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes E] No Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 111412017 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 11/15/2017 Hours Tested: 13 hrs, 7 min Production for Test Period Oil -Bbl: 3058 bible Gas -MCF: 1154 MSCF Water -Bbl: 1 bbl Choke Size: 62% Gas -Oil Ratio: 416 SCF/STB Flow Tubinq Press. 334 PSI Casino Press: 1391 PSI Calculated 24 -Hour Rate Oil -Bbl: 54 Gas -MCF: 2273 MSCT/d Water -Bbl: 1 2.83 STB/d Oil Gravity- API (corr): 1 20.7 AN Form 10-407 R vi ed 5/2017 VTL �,�/2�1 CONTINUED ON PAGE 2 RBD"{$ L. NOVj 2017 Submit ORIGINAL opl[" Y)m 171 ; l�8 L /�i1r 28. CORE DATA Conventional Core(s): Yes ❑ No 2 Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑Q 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 7647 3811 information, including reports, per 20 AAC 25.071. Formation @ TPI -West Sak B TO 14686 3845 Formation at total depth: West Sak B ' 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, paleontological report, product n or well test results, per 20 AAC 25,070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G. L. Alvord Contact Name: Kelsey Hallford Authorized Title: Alaska Drilling Manager Contact Email: kelse .hallford o co .com Authorized 'p,y Contact Phone: 265-1577 Signature: �.{9L G 4t ate: Z ` INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only n 7 o 8® Wellhead/Tubing Head /Tn , IneelatedCandaror r13-3>a•x4K°.5.d90Lsi IH-102 Producer Schematic Coons, p'.' 4Tubing Saio8: 4-12", 12.6 9, 480 TXP Final—AS Run 05x39", 0.312" Lomor Seal cmbly®]259.98'h41 N-BV MD BotmmofMule Shoe Q]289OB'MD Ges Lift Mendml, 4-112"x V w/ dummy valve 2668,56'MD/788'TVD Gss Liftbl Nl,4- In" xI"w/ dummy valve 5515. P hfD/3199'TVD 10-M",45.50, Gu Lift Mmdml,4-h7x1"w/SOV ]05].4VBID /364T TVD 480, Hyd%3 4Y," MD wish 3.812" DB Nipple profile 7126M bU) V7'MD/1691'ND P.. Down Hole Gangs)193.23' MD Tubing Seal Anoo ably f,IZXPPackm@75323'MD "17 Sand Windom ®nn' MM 3,75" DP Nipple Profile®'208.25'MD _ IA an BID D 6-3/4'D sand late N + L Sweil Peckers , •' IB- LBO, S1otled Li, V/," BIa� k 1269 L80 TXP `•, �4--?M 1467P FID/3)80 TVD Lim TD ®14652 9 MD � s s -11.M pipe ,,,,,,,,, , ,,,,,,,,,,,,,,,,,,, ,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1 ..................................................................................................... .............. yp 6-WB sand lateral Q 4 SmrkM Baker Hook Hanger L3"W'Sad Willow®)647 MD I BOW:]660.TMD •••, 14686'MD/38WTVD ae Level 3 Junnion Svstems Liner TO®14668'MD� r, ••. 4-I2' Slotted Lim, I1 18TH Lflb, 0.'h' BImJ�RiPc 12 L-BOTXP a a n Panicer L2"A4"SmW Wivdow®)645'MD/BOW : ]859'MD ___ .: aeMlatud 7460ATpdu: L3®THS.42'MD •••,• ]5.5]°iK 435'IvA4 13435'MD/39)A'ND L2 /g1718.30 hID •. 4.12"Stoned Liimr, 11.6q 18TH La0;0.K"Blind: pipe l2.6p L-80 TXP Lim TD�13204:htD� LI "A3" Sand Window ®)9)9' hCiMOW )993'MD 63WA3 send lamml Lateral Entry MMuk ,'a ••,' 0.12'Slonel Liner, 110 IBTM Le0;4K"Black 12.60 L-80 TXP Li 1m61D MD /1309]BCD Tubing Sul AaswMy .... ............ ................................................................... . y 3.562" DPNipple Profile®8244.36'MD 6-3/4"A2amA lateral d . ..'Slonmn Slotted and Bland, LOZXP pecker®8249.5' hIIJ .. ..601BTM L80 12960' MD/ 4022'TVD Lim TD@12]90'SH) .................... .s___ ]-5/8', 29]0,L8Q HOa8 =_____---------------------------------------- ______-------_----------------_______- Yd 8591'h1D/3Wl'991'ND •�.... ............ ..............................................................: operations Summary (with Timelog uepths) 1 H-102 Rig:.DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Our(hr) Phase Op Code Activity Code Time P -T -x Operation Start Depth (ItKB) End Depth(ftKB) 8/22/2017 8/23/2017 6.00 MIRU MOVE MOB P Move dg f/ 1H-118 to iH-102 ('417). 18:00 00:00 At 2300 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. & GE starting head. build spud mud, C/O saver sub. Install bushings / and elevators to rig 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 SHAH P MU surface BHA. RIH with same to 105.0 21:00 23:00 tag at 105' 8/23/2017 8/242017 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 8/2412017 6.00 SURFAC DRILL DDRL P Drill 13 12" 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 TQ, off BTM pressure = 730 PSI. Maz gas units = 35. AST .66 , ART = 2. ADT = 2.66// Total bit hours = 13.3. Total jar him = 92.98 Page 1179 Report Printed: 10130/2017 . ' Operations Summary (with Timelog uepths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth De StartTime End Time Our hr ( ) Phase Op Cotle Activity Code Time P -T -X Opere6on (rt Eno Depth (flKB) 8124/2017 8/24/2017 6.00 SURFAC DRILL DDRL P Drill 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, 5KTQwith27KWOB. UPWT=93K. OWN WT = 94K. 1 K TQ, 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 8124/2017 6.00 SURFAC DRILL DDRL P Drill 13 1/2" surface hole froml,008' 1,008.0 1,558.0 12:00 18:00 MD - 1,558' MD 1,506' TVD. 500 GPM, 1,121 PSI DPP. 44% F/O 60 RPM, 5K TO with 28K WOB. UP WT =100K. OWN WT=99K. 1K TO, off BTM pressure = 943 PSI. Max gas units = 8658. AST 2.21 , ART = 2.11. ADT = 4.321/ 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. OWN 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 hm = 103.97 8/24/2017 8124/2017 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. OWN WT=I OOK. ROT = 103K 2K TQ total stks pumped 2,872. 8124/2017 8124/2017 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 8/25/2017 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 @ 1,128 PSI DPP. RPM =- 60. 2K TQ. UP WT=95K. OWN 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/0. 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. UP WT = 68K. OWN WT=71K. 8/25/2017 8125/2017 2.00 SURFAC CASING SHAH P RS stand 1 and break / LD 305.0 0.0 03:00 05:00 Schlumberger directional tools as per DD. 8/25/2017 825/2017 0.75 SURFAC CASING SHAH P Clean and dear rig floor of all handling 0.0 0.0 05:00 05:45 equip etc. 8/25/2017 8125/2017 2.00 SURFAC CASING RURD P RU all 10 314" 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: 10130/2017 AMN Operations Summary (with Timelog Liepths) 111-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stag Depth Start Time End Time Dur (hr) Phase Op cmie Activity Code Time P-T-X Opembon (ftKB) End Depth(flKB) 8/25/2017 8/25/2017 1.00 SURFAC CASING PUTB 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. 4BPM =17%F/O. 2 BPM = 11% F/O. 8125/2017 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. Jt # 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 BID 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 DWN WT= 109K. Line up SLB pump 5 BBLS CWIo PT lines & chart 3,500 PSI test. Pump remainder CW for total BELS of 40 @ 3.1 BPM 75 PSI DPP. 15% F/O. Batch up and pump 77.4 BELS 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 lop ;lug 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/0. 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 hrs 8/25/2017. 8/25/2017 8/26/2017 1.75 SURFAC CEMENT RURD P RD cement equipment BID 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" test joint to wash stack. Page 3179 ReportPrinted: 1013012017 . Operations Summary (with Timelog Laepths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Oeplh Stad Time I End Time Our (hr) Phase Op Coda Activity Code Time P -T -x Operation (MB) End Oeplh (flKB) 8/26/2017 8/26/2017 1.50 SURFAC CEMENT W W WH P Clean rig floor of casing equipment. 0.0 0.0 OO:DO 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 NO 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. 826/2017 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. IA1OA valves. Install test plug and MU dart /TIW valves, RU test pump. 8/26/2017 826/2017 1.25 SURFAC WHDBOP NUND P DNL valve IA & OA, Plug sec cndary 0.0 0.0 12:00 13:15 IA, insstall safely slings on choke & kill, air up boots. 81262017 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 4 112" - 5 "- 7 518" . 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 totco/amphion system for black height. 8/272017 8/27/2017 1.00 SURFAC CEMENT SVRG P Service topddve. 0.0 01:00 02:00 8/27/2017 8/27/2017 2.50 SURFAC CEMENT BHAH P MU BHA #2. as per OD. RIH to 829' 0.0 829.0 02:00 04:30 1 1 MD. Monitor displacement via pit1. 8/27/2017 8/272017 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. 8127/2017 8272017 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 silks pumped = 1,400. MW-in=9.5, MW -out =9.6.. UP WT =104K OWN 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 lest equip. 26 stks t / pressure up. 2.7 BBLS bleed back. Page 4179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Steri Depth Sted Thne. End Tm, D. (hr) Phase Op Code Activity Code Time P -T -X Operaaen (Wli) End Deplh(fIKB) 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 & shoe with 500 GPM 890 PSI DPP. 33% F/O. 3K WOB, 60 RPM. 2-5K TO. TOC @ 1,670' MD. TOP plugs @. 1,683.4 TOP F/C @ 1,683'. Top FIC@ 1,685.5' BTM F/C, 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 TQ. 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 INIOUT. 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 BELS bleed back. STBY for orders. 8/27/2017 8/27/2017 1.00 SURFAC CEMENT WAIT T Wait on orders from town for plan 1,797.0 1,797.0 12:00 13:00 toward. 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. Mixup number 2 FINE 10 PBL, #2 MED 209 PBL, Nut plug fine 5 PBL, Nut Plug Med 5# PBL. mix 50 BBLS to pump 35. perform rig 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 bbls 9# LSND. 8/27/2017 8127/2017 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 8128/2017 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: 10/3012017 Operations Summary (with Timeiog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start L)o Stan Time End Tune Dw(hr) Phase op Code Activity Code Time P -T -X operation In B) End D.Pih(fIKB) 8/28/2017 8/28/2017 0.50 SURFAC CEMENT SQEZ T Perfom SQZ push #11 to 306 PSI. 1,397.0 1,397.0 00:00 00:30 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, OWN 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 infout. total STKS pumped = 2,260. UP WT = 11 OK. DWN WT = 106K. 8128/2017 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 03:30 06:00 EXCEED. Dlill 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 TQ, 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/0, 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. 3.51K TQ. 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 Dtill97/8" 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% NO, 100 RPM 6- 9K TO, 1 O 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: 10/3012017 Operations Summary (with Timeiog Depths) AM - 1H -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sad Time End Time Dur (hr) Phase Op Cade Activity Cede Tme P -T -X Operation Sart Depth MKB) End Depth (rtKB) 8/28/2017 8/29/2017 6.00 INTRMI DRILL DDRL - P Dlill 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 = 125K DWN WT=96K. ROT =11 OK. 61K TO. Max gas 96 units. ADT 8.92, Bit him 15.19, Jar him 65.74 SPR's 3,571' MD 2,620' TVD MW = 9.0 PPG 2200 hrs MPI) 30 SPM 160 PSI 40 SPM 180 PSI MP2) 30 SPM 150 PSI 40 SPM 180 PSI 8/29/2017 8/29/2017 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/O, 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 him, 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 8/29/2017 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- btm, 1405 psi off-btm, 35% F/O, ECD 10.22 ppg. Rotate at 150 rpm with 10k Tq on-btm, 7.5k Tq off-btm. 11 k 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 7/79 ReportPrinted: 1 0/3 012 01 7 AL Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Stall Time End Dare our (hr) Phase Op Cade Activity Code Time P -T -x Opeation (fll®). End Depth(ftKB) 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. 8/2912017 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-blm. 11 k 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 ReportPrinted: 10/3012017 Operations Summary (with Timelog Depths) Y' 11-1-102 11W Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Sled Time End Time Dor(hr) Phase Op Code Activity Code Time P -T -X Operation (PIKE) End Dep1h(fiK8) 8/30/2017 8/30/2017 6.00 INTRM1 DRILL DDRL P Directionally drill 9-7/8" intermediate 6,339.0 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 126k. 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 INTRM1 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% F/O, 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 hrs, 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 INTRM1 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% F/O, ECD 10.19 ppg. Rotate at 120 rpm with 13k Tq on-btm, 9.5k Tq off-btm. 10k WOB. PUW 164k, SOW 99k, ROT 126k. Max gas of 161 units. ADT 5.26 hrs, Bit 52.08 hrs, Jars 102.63 hrs. 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 bbls. Page 9179 Report Printed: 1 013 012 01 7 Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tme End Time D (hr) Phase Op Code Mlivi Code N Time P -T -X O mtmn Pe Start (Depth (NCB) End Depth (N(9) 8/31/2017 8/31/2017 6.00 INTRMI 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- btm, 1855 psi off-btm, 35% F/O, ECD 10.39 ppg. Rotate at 110 rpm with 14k Tq on-btm, 11 k Tq off-btm. 10k WOB. PUW 164k, SOW 97k, ROT 128k. Max gas of 480 units. ADT 3.97 his. Bit 56.05 his. 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, 11k Tq off-blm. 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 INTRMI DRILL DDRL P Directionally drill 9-718" intermediate 8,142.0 8,598.0 12:00 18:45 hole from 8142'to TD of 8598' MD, 3991' TVD. Pump at 697 gpm, 2015 psi on-btm, 2010 psi off-btm, 36% NO, ECD 10.65 ppg. Rotate at 130 rpm with 12-16k Tq on-btm, 12.4k Tq off-btm. 1 O 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 @ 8211' MD 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 10/79 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Time Our(hr) Phase Op cods Activity code Time P -T -X Operstion (flka) Erni Depth ((iKB) 8/31/2017 8/31/2017 1.00 INTRMI CASING BKRM P Obtain final T&D paramters, SPR's, 8,598.0 8,500.0 18:45 19:45 and survey at TD, Downlink Xoeed to neutral. PUW 173k, SOW 92k, ROT 131 k w/ 12.4k Tq. Backream out stand to 8500' MD with 697 gpm, 2030 psi, . 35% F/0, 120 rpm, 11-16k Tq, ECD 10.62 ppg SPRs Q 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 INTRM1 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 INTRMI 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 bola. 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 10.48 ppg. Rotate at 120 rpm with 7k Tq. PUW 135k, SOW 92k. Monitor displacement via pits #1- 5. Increase pulling speed up to 1000 Whir. 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 INTRMI 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/0, Initial ECD 10.48 ppg, Final ECD 10.30 ppg. Rotate at 120 rpm with 5k Tq. Pull at -700 ft/hr from 4849' to 3120' then drop pulling speed to 200 Whir 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 11179 ReportPrinted: 1 013 012 01 7 Operations Summary (with Timelog Depths) IH-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sled Thea End Time D. (hr) Phase Op Catle Activity Code Time PJ4 tio Operan Start Depth (flK a End Depth (ilKa) 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 ft/hr 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 lay out 5" DP stands using mousehole while backreaming out. 9/1/2017 9/112017 0.25 INTRM1 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 INTRMI 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, 2k 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 9/112017 1.001NTRM1 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. 9/1/2017 9/1/2017 0.25 INTRMI CASING OWFF P Monitor well for flow at top of BHA- 829.0 829.0 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 UpperXceed 9-3/4" NM Integral Blade Stabilizer: In-gauge LowerXceed 9-3/4" NM Integeral Blade Stabilizer: 1/16" undergauge Calculated displacement for trip = 90.9 bbls Actual displacement for trip= 126.0 bbls 9/1/2017 9/1/2017 0.50 INTRMI CASING BHAH P Clean and clear floor of BHA 0.0 0.0 22:45 23:15 1 equipment. Page 12179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) IH-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 (N(B) End Depth (aKB) 9/1/2017 9/1/2017 0.50 INTRMI CASING WWWH P Make up 2x5" DP singles, XO, and 0.0 0.0 23:15 23:45 stack washer. Jet stack and wellhead with 819 gpm. 9/1/2017 9/212017 0.25 INTRMI CASING RURD P Lay out stack washer and make up 0.0 0.0 23:45 00:00 wearbushing retrieval tool. 9/2/2017 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 PUTS P Make up jt# 1 with the Weatherford 0.0 1,771.0 02:00 06:30 float shoe ((2) 7-5/8" x 9-3/8" OD centralizers & total of 4 stop rings. Centralizer I 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 it # 41. PU wt 86k, SO wt 88k. Fill pipe on the fly and top off every 10 jts. 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 Q 1771'. 9/2/2017 9/2/2017 3.75 INTRMI CASING PUTB P Continue 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 rasing f/ 1771' to 3780' installing 7-5/8" x 9-3/8" Volanl centralizers floating on its up to it 105. 90 joints in the hole at this depth. Average MU torque 14k It 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 INTRMI CASING PUTS 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 f/ 3780' to 4024' installing 7-5/8" x 9-3/8" Volanl centralizers floating on jts up to it 105. 96 joints in the hole at this depth. Average MU torque 14k It lbs. PU wt 120k, SO wt 96k. Fill pipe on the fly and top off every 10 its. Install centralizers per tally.. Calculated mud losses -17-19 bbls. Page 13179 ReportPrinted: 10/30/2017 Summary (with Timelog Depths) 1 H-102 W. ,isOperations Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log smnDepth Stan Time End nm our (hf) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depih (WE) 9/2/2017 9/2/2017 2.75 INTRM1 CASING PUTB P Conlimue to run in w/ 7-5/8" 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 jt 105. 130 joints in the hole at this depth. Average MU torque 14k It 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 9/2/2017 2.75 INTRMI CASING PUTB P Contiinue to run in w/ 7-5/8" 29.7 ppf L 5,480.0 6,873.0 16:00 18:45 -80 Hyd 563 dopeless casing 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. 9/2/2017 9/2/2017 0.25 INTRMI CASING RURD T Change out cup on volant tool. 6,873.0 6,873.0 18:45 19:00 9/212017 9/2/2017 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 Vis 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 PUTS 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 bbis . 9/2/2017 9/3/2017 0.25 INTRMI CASING HOSO P Make up Vetco 7-5/8" rasing hanger 8,550.0 8,550.0 23:45 00:00 using single -stack tongs. Pick up and make up landing joint to hanger. 9/3/2017 9/312017 0.50 INTRMI 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 Us 63. 9/3/2017 913/2017 1.50 INTRMI CEMENT CIRC P Rig up cement hose and continue 8,591.0 8,591.0 01:30 03:00 Circulating / conditioning mud at 254 gpm, 480 psi. Hold PJSM for cement job and rig up cementers. Page 14179 Report Printed: 10/3012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Ste n Trne End Time Our (h4 Phan Op Code Activity Cade Time P -T -X Operetion (flK End Depth (fU(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 lest 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 hm. 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 R, - 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 hm. Calculated TOC @ 4250' MD. Note: Total downhole losses throughout cement job = 11 bbls 9/3/2017 9/3/2017 0.75 INTRM1 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 lest. 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 Jay 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 Welitec 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 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 IEVALWB JELOG I I from 3000' to 7500', average of 57 ft/min with tractor. Page 15179 Report Printed: 10/30/2017 ANINL- Operations Summary (with Timelog Depths) 1H-102 mo Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time our thr) Phase Op Code Activity Coe Time P-T-K Operelbn Start Depth otKB) End Depth (WB) 9/3/2017 9/3/2017 8.00 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 INTRM1 EVALWB ELOG P Rig down E-line equipment. 0.0 0.0 22:30 23:15 9/3/2017 9/4/2017 0.75 INTRMI 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 RURD 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 RURD P Rig up to test BOPE. Assemble floor 0.0 0.0 01:00 02:30 valves and install ported sub on top drive. Make up 4-1/2" test joint and test plug. Troubleshoot inability to suck out stack through IA. Page 16179 Report Printed: 10130/2017 Summary (with Timelog Depths) IH -102 lipOperations Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Cade Time P -T -X Operation start Depth (ftKB) End Depth(ftKe) 914/2017 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 515 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 Me=nine 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 lest 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 Q 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 17/79 Report Printed: 10/3012017 "r Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log rs StaTune End Time Our Phase Op Code Activity Code Time P -T -X Operafion Sin Depth (NCB) End Depth (MB) 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 SHAH P Continue making up 6-3/4" drilling 118.0 302.0 14:00 14:45 BHA from 11 8'to 302' MD per DD, monitoring displacement via trip tank. 9/4/2017 9/4/2017 2.50 INTRM1 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 lest 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 INTRM1 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 filing pipe every 20 x stands. Page 18179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) Arch IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End ime DW (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ttl(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 tank 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 INTRMI 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/O, 40 rpm, 8-10k Tq, 1Ak WOB. 9/5/2017 9/5/2017 2.75 INTRM1 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, 8-1 Ok 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 8,618.6- 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/O, 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 bbls, Return 1.7 bbls. 9/5/2017 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 8618' 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: 10/30/2017 &1bi Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sled Time End Time Dur (hr) Phase Op Cede Activity Cade Time P-T-% Operation Sun Depth (ftKB) End Depth (f*(B) 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 FloPro WBM. Obtain new SPR's. SPRs @ 8631' MD 3992' TVD, 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 6-314" production 8,636.0 9,011.0 07:45 12:00 "AT 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 PROD1 DRILL DDRL P Directionally drill 6-3/4" production 9,011.0 9,554.0 12:00 18:00 "AT 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 81k 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 f 1hr 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 Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Tune Dur(hr) Phase Op Cade Activity Code Time P -T -X O p eration (rt Ke) End Depth (MKa) 9/5/2017 9/6/2017 6.00 PROD1 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' TVD. Pump at 275 gpm, 2000 psi on-btm, 1990 psi off-bim, 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 hrs, 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 -Torg. OA pressure at midnight = 460 psi Downhole losses over past 24 hours = 31 bbis. 9/6/2017 9/6/2017 6.00 PROD1 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/O, 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 17.72hrs, Jar 17.72 hrs. 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 PROD1 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-blm, 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: 10130/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stant Time End Time Dor (m) Phase Op Code ActivityCode Time P -T -X Operation Start Depth (f Ka) End Depth(HKB) 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% F/O, 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 @ 11340' MD 4033' TVD, MW=9.20 ppg, 12:45 hours MP#1: 20 spm=780 psi, 30 spm=980 psi. MP #2: 20 spm=780 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, 91k Tq-on- btm, 9k Tq off-blm. 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% 1/0, 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 1I10k. 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 0/2 01 7 Operations Summary (with Timelog Depths) i a; 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start DepdN Start Tune End Time our (hr) Phau Op Code Activity Code Time P -T -X Operation (fiKB) End Depth (fiKB) 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 9f7/2017 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/0, 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 PROD1 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 topddve 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 PROD1 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 bbis lost to formation. Page 23179 Report Printed: 10130120171 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Time Start me End Time Cur(hr) Phase Op Code Activity Code Time P-T.X Operation Start Depth (rt De End Depth (eK8) 9/8/2017 9/8/2017 1.50 PROD1 CASING SHAH P LID 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 -n -Seal 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 x joint (#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 1330 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 liner 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/0. Page 24179 ReportPrinted: 10130/20171 e Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Slav Time End Time Dw(hr) Phase Op Code Activity Code Time P-T-X Operation (W3) End Depth(ftK0) 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 COMPZI 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 - good test. Use mud pump #1. Pumped 4.0 bbls, Returned 4.0 bbls. Liner top packer set at 8249.5' MD 9/8/2017 9/8/2017 0.75 COMPZI 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 packoff. 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 bbls of 9.2ppg Flo-Pro at 4 bpm, 590 psi, 15% F/O. 9/8/2017 9/8/2017 0.25 COMPZI 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 COMPZI 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 COMPZI 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 COMPZI WELLPR BHAH P Service break Baker liner running 0.0 0.0 03:00 03:45 tools and L/D tools via beaver slide. 9/9/2017 9/9/2017 1.00 COMPZI 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 rig 0.0 0.0 04:45 05:45 1 I I floor. string mills, magnets, whip stock and misc BHA tools. Page 25179 ReportPrinted: 10 13012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time. Ertl Tim Dw(m) Phase Op Code Adivity Cods Time P -T -X Operation (WB) Ertl Depth(XKB) 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 = 5k. 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 In tank. 9/9/2017 9/9/2017 025 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 x 4" DP single (31.63 ft) 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. 919/2017 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 9/9/2017 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 141 k, SOW 106k. Work up and down to weaken bolt, setting down -651k 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 ReportPrinted: 10/30/2017 . Operations Summary (with Timel®g Depths) Ad7771:� 1% 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Du(hr) Phase Op Code Activity Code Time P -T -X Operation (fiKB) End Depth(ftKB) 9/9/2017 9/9/2017 0.50 PROD2 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 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 9/10/2017 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 SHAH T Make up whipstock retrieval BHA, 0.0 90.0 02:00 03:00 hook, HWDP, MWD and oil jars. Scribe MWD to jet, 171 ° toolface offset. 9/10/2017 9/10/2017 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 , P/U= 136K, S/O= 107K, Pump @ 237 gpm= 1130 psi. 9/10/2017 9/1012017 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 IOK @ 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 1 O 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 9110/2017 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, 11 K drag. 9/1012017 9/10/2017 0.50 PROD2 WHPST SFTY T Perform post jarring 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 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stad Time End 7me Dur(hr) Phase Op Code Actwi Code ty Tme P -T- X Operation S Oepdt (flKB) EM Depth (flKB) 9/10/2017 9/10/2017 1.75 PROD2 WHPST SHAH 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 9/10/2017 1.50 PROD2 WHPST BHAH T Clean and clear dg 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 WHPST TRIP 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 ft/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: 10130/2017 . Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur ft) Phase Op Code Activity Code Time P-T-X Opeiafion Start Depth (MB) Eritl Depth (flKB) 9/11/2017 9111/2017 3.25 PROD2 WHPST TRIP T Trip in hole on 4" DP 14" 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 If 1k overpull) and confirm anchor set. 9/1112017 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 (31 k HL) - no sign of shear. 9/1112017 9/11/2017 0.25 PROD2 WHPST WPST T Slack off to block weight, kill pumps, 8,249.5 8,249.5 04:45 05:00 and start using dg'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 Bim of window @ 7992.80' MO 9/11/2017 9/11/2017 0.25 PROD2 WHPST WPST P Obtain parameters with 238 gpm, 7,979.1 7,979.1 05:15 05:30 1225 psi, 19% F/O, PUW 134k. Engage rotary at 80 rpm, 4k Tq, ROT 114k. 9/11/2017 9/11/2017 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% F/O, 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 6-314" hole to 7997' MD, rathole to 8014.3' MD Page 29179 Report Printed: 10130/2017 Operations Summary (with Timelog Uepths) -_ 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Coco Time P -T -X operation Start Depth (110) End Depth(/tKa) 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% f/0, 80 rpm, 5-9k Tq and ream through window twice and wash down through window once. With pump on, PUW 133k, SOW 100k, ROT 122k. Once sweep turned comer, pull pipe from TO 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 9/1112017 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. 9111/2017 9/11/2017 0.75 PROD2 WHPST FIT P Blow down lop drive, 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' TVD. Close bag, pump down drillpipe - 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" OP / 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 9/1112017 9/12/2017 1.00 PROD2 WHPST SHAH P Lay down milling assembly per Baker. 133.0 0.0 23:00 . 00:00 Observe pockets full of metal shavings on all 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 1/8" undergauge. - 6-3/4" upper mill was in -gauge Calculated displacement = 55.4 bbls Actual displacement = 55.0 bbls OA pressure at midnight = 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 w14 Baker string magnets to 639' MD as per SLB. Page 30/79 ReportPrinted: 10130120171 . Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Tme EM Time Dur (hr) Phase Op Code Activity Co is Time P -T -X Opetatlon SIeM1 Depth (flK a End Depth (tlKB) 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, 5K Tq off. WOB= 2-14K. P/U= 133K, S/O= 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 IH -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 PROD2 DRILL OWFF P OWFF- Static 8,299.0 8,299.0 12:00 12:30 9/12/2017 9/12/2017 0.75 PROD2 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. 9/12/2017 9/12/2017 1.00 PROD2 DRILL SHAH P LD BHA. Monitor disp via TT. 101.0 0.0 17:30 18:30 1 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 31179 Report Printed: 10130/2017 Operations Summary (with Timelog Depths) IH-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time end Time our (hr) Phase 0 Catle P Acti" Cotle 'rM Time P-T-X Oere4on p Start Depth (flKB) EM Depth (flKB) 9/12/2017 9/13/2017 4.00 PROD2 WHDBOP BOPE P Test BOPE 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 SOP 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" 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 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 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: 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 P Cont to lest 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 1-12S and combustible gas alarms. Witness of BOP test waived by Jeff Jones of the AOGCC. 9/13/2017 9/13/2017 1.00 PROD2 WHDBOP 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. RID floor valves from testing equipment. Install wear bushing. 9/13/2017 1.00 PROD2 DRILL SHAH P M/U BHA as per SLB, X516 PDC bit, 0.0 302.0 19/13/2017 01:30 02:30 PowerDrive, PeriScope, ImPulse, I NMFC, Jars and 4" HWDP to 302' MD. Page 32179 Report Printed: 1013012017 j111111111 -,]j Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tme End Time our (hr) Phase Op Code 1 Activity Code Time P -T -X Operation P Start Depth (flKB) End Depth (MB) 9113/2017 9/13/2017 4.25 PROD2 DRILL TRIP P RIH w/ drilling BHA f/ 302' MD to TOW 302.0 8,093.0 02:30 06:45 @ 7979' MD. Shallow hole test tools @ 1500, tools in neutral. Slowly trip down thought window @ 7979' MD to 7993' MD. Cont RIH V 8093' MD. PIU= 117K. S/0= 82K. 9/13/2017 9/13/2017 0.75 PROD2 DRILL DLOG P MAD pass down f/ 8093' MD to 8300' 8,093.0 8,300.0 06:45 07:30 MD. Pump @ 236 gpm= 1460 psi, Rotate @ 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, DWN 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 @ 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 TO. 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 TQ. 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 TQ. 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, OWN 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: 1013012017 Operations Summary (with `Iimelog depths) IH-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Plwse DP Code Activity Code Time P-T-X Operation Start Depth (1K8) End Depth(aKa) 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% FJO. 120 - 135 RPM with 8K TQ. 2-6K WOB along with ECD's of 12.05 EMW. Off BTM 2,550 PSI DPP, UP WT= 125K, DWN WT = 76K. ROT= 117K. 7K TQ. MW = 9.2 PPG. Max gas = 65 units. ADT-4.16 Bit hrs - 20.3 Jar his - 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' MO 3,974' TVD. 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. 8K TQ. 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 TO. 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 TQ. 2-5K WOB along with ECD's of 11.95 EMW. Off BTM 2,700 PSI DPP, UP WT= 175K, DWN WT=63K. ROT =106K. 8K TO. MW = 9.2 PPG. Max gas = 150 units. ADT-2.7 Bit hrs - 31.08 Jar hrs - 69.63 Page 34179 Report Printed: 1013012017 r Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time Dur (hr) Phase Op Gods Activity Code Time P -T-% Operation start Depth Ift(6) End Depth (ftKe) 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, 8K 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 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 @ 2310-1,950 PSI DPP. RPM 130-80 with UP WT 145K. DWN WT=69K. ROT =101 K. 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. 9/15/2017 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. 4.5 TQ. UP WT=120K. DWN WT= 80K. 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. DWN WT = 80K. 9116/2017 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 9/1612017 9/16/2017 1.25 PROD2 CASING BHAH 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 9/16/2017 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 9/162017 1.75 COMPZ2 FISH BHAH P MU BHA # 10 and scrib as per BOT 0.0 230.0 04:15 06:00 rep to 230' MD 9/16/2017 9/1612017 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 9/1612017 9/16/2017 0.25 COMPZ2 FISH DHEQ P Shallow lest 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 35179 ReportPrinted: 1 013 012 01 7 Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stad Depth Start Tone End true our (hr) Phase Op code Activity Code Time P -T -X Opemtmn (flKB) End DepM(flKB) 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 Q 5.5 BPM 1,650 PSI DPP. 20% F/O. Up WT=120K, DWN 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 1 OK 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. 9/1612017 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 SHAH. 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 SHAH P Clean rig floor and LD running tools. 0.0 0.0 21:00 22:00 9/16/2017 91162017 1.50 COMPZ2 CASING RURD P Rig up to run liner., Bring GBR 0.0 0.0 22:00 23:30 j 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, DWN WT = 47K. 9/17/2017 9/17/2017 7.25 COMPZ2 CASING PUTB 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. Monitor 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 1Monitor Disp via TT. 9/17/2017 9/172017 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, DWN 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: 1 0/3 012 01 7 - Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slat Depth Stat Time End Time Dw(hr) Phan Op Cade Activity Cude Time P -T -X operation (MB) End Depth(ftKB) 9/17/2017 9/17/2017 0.75 COMPZ2 CASING CIRC P Drop 29/32" ball and pump down @ 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 75'-45' MD 75.0 45.0 19:30 20:00 9/17/2017 9/17/2017 1.00 COMPZ2 WELLPR SHAH P Lay down and flush SLB MWD tools. 45.0 0.0 20:00 21:00 9117/2017 9/17/2017 1.00 COMPZ2 WELLPR SHAH P Clean rig floor and remove BHA from 0.0 0.0 21:00 22:00 floor. Service TD. 9/17/2017 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 9/182017 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 tum TXP treads. 9/18/2017 9118/2017 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. 91182017 9/19/2017 5.00 COMPZ2 RWRID RCST P RIH with LEM / ZXP ASSYM from 399' 399.0 5,645.0 19:00 00:00 -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 lest 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. Blowdown 7,907.0 7,849.0 04:45 05:30 top drive. Fluid level dropped 2" Page 37179 Report Printed: 1 013 012 01 7 . ` Operations Summary (with Timelog Depths) n- IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth, Stall Time End Tune Dix (hr) Phase Op Code Activity Code Time P -T -X Operation (RKB) End Deph(ftKB) 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 40:00 10:45 9/19/2017 9/19/2017 0.50 COMPZ2 RWRID SHAH P Clean rig floor and perp for next run. 0.0 0.0 10:45 11:15 9/19/2017 9/19/2017 2.75 PRODS WHPST SHAH P PU Baker Whipstock BHA as per 0.0 305.0 11:15 14:00 Baker rep. Monitor Disp via TT. Dwn WT = 53K 9/19/2017 9/19/2017 5.25 PRODS 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 PRODS 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% Flo. 7,915' MD UP WT = 11 37K. DWN WT= 105K. 9/19/2017 9/19/2017 0.75 PRODS 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 1 OK over to check set. Shear off and slide with 40K DWN WT. 9/19/2017 9/20/2017 2.75 PRODS 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 w/ pump and rotary (GOOD) 2X w/o pump and rotary (GOOD) UP WT = 148K, OWN 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 lest equip. 9/20/2017 9/20/2017 0.25 PRODS 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 PRODS WHPST SHAH P LD Milling BHA as per Baker Rep from 231.0 0.0 16:00 17:15 I I I 231'to Surface. Upper mill was full guage. Page 38179 ReportPrinted: 1 013 012 01 7 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth StartTune End Time our (no Pheua Op cede Activity Code Time P -T -X Operation (flKB) End Depth(WB) 9/20/2017 9/20/2017 1.75 PROD3 WHPST WWWH 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 top 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 887'11D //UP WT=53K, DWN WT = 58K. Monitor disp via TT. 9/20/2017 9/2012017 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%F10. (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 DDRL 6 3/4" 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 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 DDRL 63/4" hole fro,m 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 ReportPrinted: 1 013 012 01 7 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Dept SIM Time End Time Dw(hr) Phase op cod. Activity Coda Time P-T-X Operation (RKB) End Depth (MB) 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% FlO. 40 RPM, with 6K DWN WT --UP WT=72K. ROT WT=94K, 2,580 STKS pumped. 9/2112017 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 Left 7,905.0 7,813.0 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 7,813.0 895.0 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 LD BHA as per SLB rep from 895' MD 895.0 0.0 19:00 20:30 to surface monitoring disp via TT. 9/21/2017 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. 9/21/2017 9/21/2017 0.50 PROD3 WHDBOP RURD P Pull wear bushing and install lest plug 0.0 0.0 21:00 21:30 9/21/2017 9122/2017 2.50 PROD3 WHDBOP BOPE P MU BOPE test joint 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 #14 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 BOPE P Continue to test BOPE. All lest 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 ISOP, 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 bttl 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 R/D test equipment BD top drive. 0.0 0.0 03:00 04:00 Drain stack and pull test plug. Install wear bushing. grease upper IBOP. 9/22/2017 9/22/2017 0.25 PROD3 DRILL SFTY P PJSM for upcoming BHA work 0.0 0.0 04:00 04:15 9/2212017 9/22/2017 1.50 PROD3 DRILL BHAH P PU1MU BHA # 14 as per DD / MWD. 0.0 306.0 04:15 05:45 Monitor disp via TT 9/22/2017 9/2212017 0.75 PROD3 DRILL TRIP P RIH from 306' MD to 2,105' MD. 306.0 2,105.0 05:45 06:30 Monitor disp via TT UP WT = 75K, DWN WT=75K. Page 40179 ReportPrinted: 1013012017 Operations Summary (with Timeiog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Dephi Stat Toe End Time Our (hr) Phase Op Code AcWily Code Time P4A operation (MB) End Depth (ftKa) 9/22/2017 9/2212017 0.25 PRODS 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 PROD3 DRILL TRIP P Continue to RIH from 2,105'-7,945' 2,105.0 7,945.6- 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, DWN WT =72K. ROT= 92K 6K TQ. 9/22/2017 9/22/2017 0.50 PRODS 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, 5.5K TQ. 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 TQ, 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 TO. 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 6 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' ND, 272 GPM at 2,005 PSI DPP. 22% F/O 150 RPM, 8K TQ, with 4-5K WOB. ECD's 10.98 PPG EMW, Off BTM 2,000 PSI DPP, UP WT= 137K DWN WT= 63K. ROT = 98K. 7.8K TQ. Max gas = 223 units. ADT - 4.31, Bit HRS = 8.51 Jars = 13.4 9123/2017 9123/2017 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' ND, 272 GPM at 2,185 PSI DPP. 21% F/O 150 RPM, 8K TQ, with 3K WOB. ECD's 11.52 PPG EMW, Off BTM 2,180 PSI DPP, UP WT = 125K DWN 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 PROD3 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 DWN WT=61K. ROT=99K. 7.7KTQ. Max gas = 450 units. ADT - 4, Bit HRS = 16.66 Jars = 21.55 Begin 290 BBLS dump and dilute @ 10,987'MD Page 41179 Report Printed: 1013012017 Operations Summary (with 3imeiog Depths) 114-102 • e Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Start Tme End T. Dur (h) Phase Op Cade Activity Cotle Time P -TA Operation (ftKB) End Depth (MB) 9/23/2017 9/23/2017 6.00 PROD3 DRILL DDRL P Drill 63/4" 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 STM 2,420 PSI DPP, UP WT = 148K DWN WT=67K. ROT =101K. 8.31K 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 P 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, 91K TO, with 51K WOB. ECD's 11.30 PPG EMW, Off BTM 2,420 PSI DPP, UP WT= 154K DWN WT=63K. ROT =101 K. 8.51K 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 2.51K WOB. ECD's 11.43 PPG EMW, Off BTM 2,495 PSI DPP, UP WT= 160K DWN WT=74K. ROT =11 OK. 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 6 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/0 120 RPM, 8.51K 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 42/79 Report Printed: 1013012017 . Operations Summary (with Timelog uepths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log slit Depth Slad Time End Time Dur (hr) Phase Op Code Acdvity Cede Time PJA Operation dtKB) End Mph (flKB) 9/24/2017 9/24/2017 3.00 PROD3 DRILL DDRL P Drill 6 3/4" hole froml3,177' MD 3,934' 13,177.0 13,435.0 12:00 15:00 TVD - 13,435' MD 3,924' TVD, 270 GPM at 2,820 PSI, DPP. 21% Flo 140 RPM, 8.5K TQ, with SK WOB. ECD's 11.81 PPG EMW, Off BTM 2,810 PSI DPP, UP WT= 177K DWN 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 9/24/2017 1.25 PROD3 CASING CIRC P Obtain survey and SPR's. CBU and 13,435.0 13,430.0 15:00 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 9/25/2017 7.25 PROD3 CASING BKRM P BROOH form 13,430' MD - 10,900' 13,430.0 10,900.0 16:45 00:00 MD at 270 GPM 2,265 PSI DPP. 20% F/O, 150 RPM, 6.5K TQ. 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 TQ. 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 9/25/2017 9/25/2017 0.50 PROD3 CASING OWFF P OWFF> 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 0.25 PROD3 CASING SVRG P Service top drive, Blocks and crown. 7,788.0 7,788.0 10:45 11:00 9/25/2017 9/25/2017 0.25 PRODS CASING CIRC P Pump wieghted slug. 7,788.0 7,788.0 11:00 11:15 Page 43179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slut Time EM Time Dur (hr) Phase Op Code Activity Code Time P -T -X opembw Start Depth (ftKB) End Depth (flKB) 9/25/2017 9/25/2017 4.25 PROD3 CASING TRIP P Blow down top drive and POOH from 7,788.0 306.0 11:15 15:30 - 7,788'- 306' MD. Monitor Disp via TT. UP WT=121K OWN WT=83K. 9/25/2017 9/25/2017 1.25 PROD3 CASING BHAH P - Monitor well for 10 min then lay down 306.0 0.0 15:30 16:45 BHA as per SLB rep. 9/25/2017 9/25/2017 0.50 PROD3 CASING BHAH P Clean dg floor and clear all tools. 0.0 0.0 16:45 17:15 9/25/2017 9/25/2017 0.25 COMPZ3 FISH SFTY P PJSM for BHA handling. 0.0 0.0 17:15 17:30 9/25/2017 9/25/2017 1.50 COMPZ3 FISH BHAH P MU whipstock retrieving assym as per 0.0 230.0 17:30 19:00 Baker rep. 9125/2017 9/25/2017 1.00 COMPZ3 FISH TRIP P RIH with BHA # 15 to retrieve 230.0 1,638.0 19:00 20:00 whipstock. monitor disp via TT. 9/25/2017 9/25/2017 0.50 COMPZ3 FISH DHEQ P Shallow pulse test SLB BHA for 1,638.0 1,638.0 20:00 20:30 communications. 250 GPM (411,060 PSI DPP. 18% F/O. UP WT = 67K. OWN WT 70K. 9/25/2017 9/25/2017 3.00 COMPZ3 FISH TRIP P Continue to RIH from 1,638' MD to 1,638.0 7,828.0 20:30 23:30 7,828' MD. Monitor disp via #5. Fill pipe every 20 STNDS. 9/25/2017 9/26/2017 0.50 COMPZ3 FISH FISH P Mousehole botm single stand 82. 7,828.0 7,848.0 23:30 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 9/26/2017 0.50 COMPZ3 FISH FISH P Pull whipstock free per Baker. Jar as 7,848.0 7,750.0 00:00 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 9/26/2017 1.50 COMPZ3 FISH CIRC P Circulate 2 x bottoms up at 253 gpm, 7,750.0 7,750.0 00:30 02:00 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 9/26/2017 0.50 COMPZ3 FISH OWFF P Monitor well for flow -observe fluid 7,750.0 7,750.0 02:00 02:30 level drop -1 It over 30 minutes. Drop 2.1" OD hollow drift on stand #80. 9/26/2017 9/26/2017 5.00 COMPZ3 FISH TRIP P Pull out of hole on elevators racking 7,750.0 231.0 02:30 07:30 back 4" DP and HWDP from 7750' to 231' MD, monitoring displacement via trip tank. 9126/2017 9/26/2017 2.25 COMPZ3 FISH BHAH P Lay down whipstock retrieval BHA #15 231.0 0.0 07:30 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 COMPZ3 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 run 4-1/2" lower 0.0 0.0 10:30 12:00 completion. Page 44179 Report Printed: 10/30/2017 . Operations Summary (with Timelog L/epths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Star)Tme End Time ( r) ouch Phase O Code p Adw Code aY TX Time P-- Operafion Start oeplh a e) EM Depth ((tKe) 9/26/2017 9/26/2017 0.75 COMPZ3 CASING RURD P Mobilize pups to dg 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 PUTS 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 4-112" 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 ft -lbs. MUT for 4-1/2" TXPm of -7000 ft -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, dg 5,338.0 5,368.0 21:30 22:30 - up false bowl, and install SLB slimpulse in string. Make up Baker "B- 3" Flanged Hook Hanger assembly and scribe. 130° too8ace 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 9/26/2017 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 clow 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 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, 19/27/2017 _ monitoring displacement via trip tank. 9/27/2017 9/27/2017 0.50 COMPZ3 CASING CIRC P Break circulation above 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 9/27/2017 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 ReportPrinted: 10/30/2017 . ' Operations Summary (with Timelog uepths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (tr) Phase Op Code Activity Cade Tme P -TA Operation (W13) End Depth (fd(B) 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 29132" 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 seal 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 4650 psi (pinned for 4000 psi shear). Pick up above hook hanger to 7835' MD, PUW 142k. 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 9/27/2017 3.75 COMPZ3 WELLPR TRIP P Trip out of hole on elevators, racking 7,835.0 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 9/27/2017 0.50 COMPZ3 WELLPR SHAH P Lay down Baker hook hanger running 0.0 0.0 10:30 11:00 tools and SLB SlimPulse. 9/27/2017 9/27/2017 0.25 COMPZ3 WELLPR BHAH P Clean and clear rig floor of running 0.0 0.0 11:00 11:15 tools. 9/27/2017 9127/2017 0.50 COMPZ3 RWRID RURD 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 uepths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tine End Time our (hr) Phase Op code Ao Wy coda Time P -T -X Operation Start Depth (N(B) End Depth mKB) 9/27/2017 9/27/2017 2.75 COMPZ3 RWRID PUTB P Make up LEM / ZXP assembly for L2 0.0 242.0 11:45 14:30 lateral to 242' MD with SLB SlimPulse 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. 9/27/2017 9/27/2017 0.75 COMPZ3 RWRID CIRC P Run in hole on 1 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 lopddve. 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 COMPZ3 RWRID DHEQ P Shallow hole test MWD SlimPulse with 2,137.0 2,137.0 16:45 17:00 92 gpm, 320 psi, 10% 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% F/O. 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, Pickup to 155k (12k overpull) and confirm latched. 9/27/2017 9/27/2017 1.25 COMPZ3 RWRID PACK P Drop 1.626" 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 47179 ReportPrinted: 10 012 01 7 Operations Summary (with Timelog Liepths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stert Time End Time our (hr) Phase Do Code Hchvity Code Time P -T -X Operation (ftKB) End Depth(11KB) 9/27/2017 9/27/2017 0.50 COMPZ3 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 tap 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 rale. 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 losses for past 24 hours = 53 bbls. 9/28/2017 9/28/2017 0.25 COMPZ3 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 COMPZ3 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 / ZXP 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 clear rig floor of running 0.0 0.0 06:45 07:15 tools. 9/28/2017 9/28/2017 1.25 PROD4 WHPST SHAH P Mobilize whipstock BHA to rig floor, 0.0 0.0 07:15 08:30 confirm spaceout, and mobilize spaceoul 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/O - 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: 10130120171 Operations Summary (with Timelog Liepths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tuna End Tome our(hr) Phase Op Code Activity Coda Time P -T-% Operation Stan Depth (ftKB) End Depth(ftKB) 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 11 Ok. 7,625.0 7,647.0 18:15 18:45 Observe -1 k drag as seals entered top of liner. Locate 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 Btm 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. 9/28/2017 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 00:00 7647'to 7657' MD per Baker with 300 gpm, 1880 psi, 21% F/0, 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 FloPro 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 FloPm 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 TO with 300 7,685.0 7,637.0 0745 0815 gpm, 1850 psi, 21%f/0, 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: 10130120171 Operations Summary (with Timelog Liepths) 114-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Start Time End Time Dur(hr) Phase Op Code ArAvity Code Time PJA Opere4en (ftKB) EM Depth (Ka) 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 12.9ppg 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-observe fluid 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 PROD4 WHPST CIRC P Pump dry job, install stripping rubbers, 7,436.0 7,436.0 10:30 10:45 1 1 and blow down lopdrive. 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 BHAH P Lay down milling BHA from 231' 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 9/29/2017 0.50 PROD4 WHPST BHAH P Clean and clear rig floor of BHA tools. 0.0 0.0 15:45 16:15 9/29/2017 9/29/2017 0.75 PROD4 WHPST W W WH 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. 9/29/2017 9/2912017 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" milltoolh bit and 1.5` motor as they are both in good shape and low hours. 9/29/2011 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 I 2087' MD, monitoring displacement via trip tank. Page 50/79 Report Printed: 10/30/2017 Operations Summary (with 'Timelog Uepths) f s_ 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log S�tice pth d De Snarl Tine Er -tl Time our (hr) Phase Op Code Activity Cade me TiP-T-X operaton End Depth (r1K3) 9/29/2017 9/29/2017 0.50 PROD4 WHPST DHEQ P Fill pipe and shallow hole test MWD 2,087.0 2,087.0 20:00 20:30 tool at 270 gpm, 1235 psi, 21 % F/O - good test. Blow down top drive. 9/29/2017 9/29/2017 2.75 PROD4 WHPST TRIP P Trip in hole on 4" DP and 4" HWDP 2,087.0 7,556.0 20:30 23:15 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 9/29/2017 0.50 PROD4 WHPST CIRC P Kelly up and orient motor to 22' left 7,556.0 7,675.0 23:15 23:45 with 275 gpm, 2010 psi, 22% F/O. Kill pump and trip in from 7556'to 7675' MD - no drag observed tripping through window. Observed string start taking 1-2k drag at 7668' MD, end of gauge hole. Continue tripping in and observe 5-6k weight at 7675' MD. Pick up 7 ft and trip in, setting down 5-6k weight at 7675' MD. 9/29/2017 9/30/2017 0.25 PROD4 WHPST WASH P Wash down from 7675'to 7685' MD 7,675.0 7,685.0 23:45 00:00 with 250 gpm, 1760 psi, 18% F/O, 4- 7k WOB. Observe hard spot between 7675'- 7677' MD. OA pressure at midnight = 0 psi Downhole lasses for past 24 hours = 20 bbls 9/30/2017 9/302017 3.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 7,685.0 ' 7,918.0 00:00 03:00 lateral from 7685' to TO of 7918' MD, 3882' TVD. TD 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 Tq on-btm, 3.5k Tq off-btm. 5-8k WOB. Max gas 39 units. PUW 138k, SOW 11 Ok, 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: 1013012017 . Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -x Op..U.n 0913) End Depth(fIKB) 9/30/2017 9/30/2017 0.50 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 Slowdown 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 9/30/2017 9/30/2017 0.50 PROD4 DRILL TRIP P Trip out of hole 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 7550'to 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 PROEM DRILL OWFF P Monitor well for flow at top of BHA - 895.0 895.0 08:00 08:15 well static. 9/30/2017 9/30/2017 2.25 PROD4 DRILL SHAH 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. 9/30/2017 9/30/2017 0.50 PROD4 DRILL SHAH P Clean and clear 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 stack washer and jet stack 0.0 0.0 11:00 11:45 with 20 bpm, 130 psi, 38% F/0, 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 SHAH 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. 9/30/2017 9/30/2017 0.25 PROD4 DRILL DHEQ P Fill pipe and shallow hole test MWD 2,195.0 2,195.0 14:30 14:45 with 200 gpm, 760 psi, 16% FIO - good test. Blow down top drive. 9130/2017 9/30/2017 1.50 PROD4 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 62/79 Report Printed: 1 013 012 01 7 Operations Summary (with Timeiog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Tena End Time Dur(hn Phase Op Cade Acfi {ty Code Time P -T -X OperaYon (flKB) End Depth (WB) 9/30/2017 9/30/2017 1.50 PROD4 DRILL SVRG P Servicetopdrive. Inspectsaversub 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 PROEM DRILL TRIP P Run in hole from 7601' 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 lop 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 OLOG 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 to wash 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 c@ 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 53179 Report Printed: 10130120171 . Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stert Time ad Time Dur(hr) Phase Op Cade Ac ivdy Code Time P -T -X Operation (fiKB) End Depth (r1KB) 9/30/2017 10/1/2017 1.50 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 7,918.0 8,043.0 22:30 00:00 lateral from 7918'to 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 his, Bit 1.24 hrs, Jars 43.22 hrs. OA pressure at midnight = 220 psi. Downhole losses for past 24 hours = 10 bbls. 10/1/2017 10/1/2017 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 8,043.0 8,357.0 00:00 06:00 lateral in WestSak B sand from 8043' to 8357' MD, 3816' TVD. Pump at 269 gpm, 1729 psi, 21% NO, 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'- 8096', 8125' - 8140', 8190'- 8204', and 8331' - 8343'. SPRs @ 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 10/1/2017 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production 13 8,357.0 8,871.0 06:00 12:00 lateral in WestSak B sand from 8357' to 8871' MD, 3817' TVD. Pump at 272 gpm, 1837 psi, 22% NO, 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 54/79 ReportPrinted: 1 013 012 01 7 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Time our (hr) Phase Op Code Activity Cade Time P -T -X Opemfion (RKS) End Depth (RKB) 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 Bsand 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 81 k, 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 - trim. 2-3k WOB. Max gas 150 units. PUW 121 k, SOW 62k, ROT 92k. ADT 4.48 hrs, Bit 19.48 hrs, Jars 61.46 hrs. Concretions drilled at 9713'- 9716', 9725'- 9748', 9770' - 9796', 9812' - 9815', 9824' - 9834', 9859' - 9876', 9900' - 9904', 9973'- 9974', and 10185'- 10191'. 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' TVD. Pump at 281 gpm, 2254 psi, 21% F/0, ECD 11.2 ppg, MW 9.25ppg. Rotate at 180 rom with 8k on-btm Tq, 7.5k off- btm 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' - 10671'.10667'- 10674', 10680' - 10687', 10712'- 10716', and 10723'- 10727'. Page 55/79 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operafion Start Depth (ftK8) End Depth(ftKa) 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, 8k 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 hrs. 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. Performed 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 66179 Report Printed: 10130/2017 Operations Summary (wino Timeiog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Siad Depth start Time End Time our (M) Phase Op Code Activity Code Time P -T -X Operation (11K13) End Depth (flKS) 10/2/2017 10/3/2017 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 12,360.0 12,964.0 18:00 00:00 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 10/3/2017 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 12,964.0 13,519.0 00:00 06:00 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 -trim. 2-5k WOB. PUW 164k, unable to slack off, ROT 107k. 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 10/3/2017 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 13,519.0 14,079.0 06:00 12:00 lateral in WestSak B sand from 13519' to 14079' MD, 3852' TVD. Pump at 272 gpm, 2735 psi, 21 % F/0, 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', 136861- 13692',137311- 137391, 13750'- 13762', and 13771'- 13774'. Page 57179 Report Printed: 1013012017 Operations Summary (with Timeiog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sled -hole EM Tme Our (hr) Phese Op Code Activity Code Time P -T -X Operation ft Depth Si (flKe) End Depth (nxe) 10/3/2017 10/3/2017 6.50 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 14,079.0 14,686.0 12:00 18:30 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 - him. 3k WOB. 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',14116' - 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 powerdrive 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 10/3/2017 0.50 PROD4 CASING OWFF P Monitor well for flow -observe fluid 14,615.0 14,615.0 20:00 20:30 level fall -4 ft over 30 minutes. 10/3/2017 10/4/2017 3.50 PROD4 CASING BKRM P Backream out of hole from 14615' to 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 160k, 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 P 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: 1013012017 Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Sam Time End Time our (hr) Phase Op Code Activity Code 'rima P -T -X Operation (ftKS) End Depth (WB) 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 inlout 9.2ppg. Total of 3905 strokes pumped. PUW 112k, SOW 86k. 10/4/2017 10/4/2017 0.50 PROD4 CASING OWFF P Monitor 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 SLPC P Sliplcut drilling line. Calibrate blocks 7,593.0 7,593.0 14:00 15:30 and service rig. 10/4/2017 10/4/2017 2.50 PROD4 CASING TRIP P Trip out of hole on elevators racking 7,593.0 306.0 15:30 18:00 back 4" DP from 7593' to 306', monitoring displacement via trip tank. 10/4/2017 10/4/2017 1.00 PROD4 CASING BHAH 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.Stabllizers were in gauge and bit looked good with no damaged/worn teeth and was in gauge. Graded 0 -0 - NO -A -X -0 -NO -TD. 10/4/2017 10/42017 0.50 PROD4 CASING BHAH P Clean and clear floor of BHA 0.0 0.0 19:00 19:30 1 1 1 equipment. 10/4/2017 10/4/2017 1.00 COMPZ4 FISH SHAH P PJSM. Make up L-3 whipstock 0.0 229.0 19:30 20:30 retrieval BHA, scribe MWD, and RIH to 229' MD - 348.48° toolface offset obtained. Monitor displacement via trip tank. 10/4/2017 10/4/2017 1.00 COMPZ4 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. 10/42017 10/4/2017 0.25 COMPZ4 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% FIC, - good test. 10/42017 10/5/2017 2.25 COMPZ4 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 59179 Report Printed: 1 013 012 01 7 Operations Summary (with Timelog Depths) . IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Oepm sled Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (eKB) End nepih (111(9) 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 lop of whipstock). Pick up above top of whipstock and orient to 22° left. RIH and set down 8k on bottom of relreival slot with hook right on depth. Pick up and confirm latched. Kill pump and start jarring 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 , 7,647.0 02:15 02:30 - on stand #79. Pull up and rack back stand per Baker. 10/5/2017 10/5/2017 0.50 COMP24 FISH OWFF P Monitor well for flow -observe fluid 7,647.0 7,647.0 02:30 03:00 level 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 fl/min max. 10/5/2017 10/5/2017 3.00 COMPZ4 FISH SHAH 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 (-1 ft). 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) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log then Time Ertl Time D. (hr) Phase Op Code Activity Code Time P -T -X operation start Depth (ftKB) End Depth(ftKB) 10/5/2017 10/5/2017 4.00 COMPZ4 WHDBOP BOPE P Test BOPE 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 Kill, 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 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. 10/5/2017 10/5/2017 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 10/6/2017 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 4-1/2" 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 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. PUW 87k, SOW 70k. OA pressure at midnight = 0 psi Downhole losses over past 24 hours = 74 bbls Page 61179 Report Printed: I( 012 01 7 Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log stat Time End Time Our(hr) Phase Op Code ActiNty Code Time P -T -X Opnalion Start Depth (flKB) Eml Depth(MKB) 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 TXPnn 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- 118" 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 13 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 lest MWD tool with 90 gpm, 260 psi, 11 % F/0 - good test. 10/6/2017 10/6/2017 4.00 COMPZ4 CASING RUNL P Run L3 lower completion in hole on 4" 7,600.0 14,622.0 03:00 07:00 DP 14" HWDP stands from derrick from 7600' to 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 20k. Confirm orientation at 8° left. 10/6/2017 10/612017 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/0 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, 6% F/O. Top of hook hanger at 7644.62' MD. Page 62179 Report Printed: 10130120171 Operations Summary (with Tirnelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time DW(hr) Phase op Corte Ar ity Cone Time P -T -X Operation Sten Depth (INKS) End Deplh(INKS) 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 lank. 10/6/2017 1016/2017 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 SHAH 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 P PJSM. Make up LEM I ZXP assembly 0.0 328.0 14:00 16:30 for L3 lateral with SLB SlimPulse installed. GBR utilize torque turn 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 CIRC P 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 topdnve. 10/6/2017 10/6/2017 1.00 COMPZ4 RWRID 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 test MWD 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 turn 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% FIC, 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 ReportPrinted: 10 IM017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth start Toe End Time Dur (hr) Phase Op Code Activity Code Time P-T-X operation (ftKB) End Depth (WEI) 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/O. OA pressure at midnight = 0 psi Downhole losses for past 24 hours = 53 bbis 10/7/2017 1077/2017 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/O, setting down max of 15k weight. Once seals worked in and moving down, observe -61k 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. 10f7/2017 10!712017 0.50 COMPZ4 RWRID PACK P Set ZXP liner top packer, drop 1 5/8" 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!7/2017 10/7/2017 0.50 COMPZ4 RWRID PRTS P P/U 3'@ 143K PIU, 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. 101712017 10!7/2017 0.75 COMPZ4 RWRID CRIH P Spot corrosion inhibited brine if 7751' 7,751.0 7,639.0 01:30 02:15 MD to 7639' MD(calc TOW @ 7376' MD) Pumped 25 bbis of Cl brine followed by 73 bbis of drilling mud, pumped @ 255 gpm=870 psi. 1017/2017 1017/2017 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. 10/7/2017 1017/2017 2.50 COMPZ4 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 bbis. (4.7 bbl loss) 10/7/2017 10/7/2017 1.00 COMPZ4 RWRID BHAH P UD Baker running tools and SLB 0.0 0.0 0515 06:15 1 MWD. 10/7/2017 10/7/2017 1.50 PRODS WHPST BHAH P Mobilize L4 whipstock BHA to rig floor. 0.0 0.0 06:15 07:45 1 Page 64179 Report Printed: 1013012017 . Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depm Start Time EM Time Dur (hr) Phase Op Code Afivity Code Tune P -T -X Operation (ftl(e) EM Depth(aXB) 10/7/2017 10/7/2017 3.00 PRODS WHPST BHAH P PJSM. 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 assy 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 PRODS WHPST DHEQ P Shallow hole lest MWD tool with 205 1,350.0 1,350.0 11:30 11:45 gpm, 490 psi, 15% F/O - good test. Blow down top drive. 10/72017 1017/2017 4.25 PRODS WHPST TRIP P Trip in hole on 4" DP /4" HWDP 1,350.0 7,360.0 11:45 16:00 stands from 1350' to 7360' MD, running speed of 60 f tmin, 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 WHPST WPST 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 SlimPulse. 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 1ok weight, observing good indication of anchor shear at 8k 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 @ 7377.00' MD Btm of window @ 7390.60' MD Page 65/79 Report Printed: 10/30/2017 . Operations Summary (with Timelog Depths) 111-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Tlme Our (hr) Phase Op code ActivityCode Time P-T-X Operation (Id(B) End Depth (flKB) 10/7/2017 10/8/2017 6.25 PROD5 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/O, 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 PROD5 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% F/O, 100 rpm, 3-5k Tq, 2-8k WOB, PUW 131k, SOW 108k ROT 111 k. Pump super sweep at TD. Top of window @ 7377.00' MD Btm of window @ 7390.60' MD -5' of gauge hole @ 7396' MD Rathole to 7412' MD 10/8/2017. 10/8/2017 0.75 PROD5 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% FIC, 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 D-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 PROD5 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 Wis. Blowdown lines. 10/8/2017 10/8/2017 0.50 PROD5 WHPST OWFF P Monitor well for flow -well static. 7,348.0 7,346.0 06:15 06:45 10/8/2017 10/8/2017 0.25 PROD5 WHPST TRIP P Trip OOH from 7348'to 6810' MD, 7,348.0 6,810.0 06:45 07:00 monitoring displacement via trip tank. 10/8/2017 10/8/2017 0.25 PROD5 WHPST CIRC P Pump dry job. 6,810.0 6,810.0 07:00 07:15 10/8/2017 10/8/2017 2.25 PROD5 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 66/79 ReportPrinted: 10/30/2017 Operations Summary (with Timeiog Depths) 111-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Slat Time End Time our (hr) Phase Op code Activity Code Time PJA Operation (ftKB) End Depth (WS) 10/8/2017 10/8/2017 1.50 PROD5 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 jet stack. 0.0 0.0 11:00 11:30 SIMOPS - Clean and clear rig 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. 10/8/2017 10/8/2017 3.00 PROD5 WHPST SHAH P PJSM. 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 Milltooth bit. Run new 1.5" mud motor. MWD scribed to 182' toolface offset. 10/8/2017 10/8/2017 0.25 PROD5 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 PROW WHPST DHEQ P Shallow hole lest MWD with 209 gpm, 1,840.0 1,840.0 15:15 16:00 782 psi, 18% F/O - good test. Blowdown top drive. 10/8/2017 10/8/2017 3.00 PRODS WHPST TRIP P Trip in hole from 1840'to 7244' MD, 1,840.0 7,244.0 16:00 19:00 monitoring displacement via trip tank, filling pipe every 20 z 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 228 gpm, 1356 psi, 18% F/O. 10/8/2017 10/8/2017 0.25 PROD5 WHPST TRIP P Trip in hole from 7300' to 7412' MD, 7,300.0 7,412.0 19:30 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 10k weight. Page 67179 ReportPrinted: 10/30/2017 Operations Summary (with TimeEog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start DepN Start Time EM Time ourm Phase Op Code Activity CMe Time P -T -X Opetatien (fixe) EM Depth (fixe) 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 00:00 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 his, 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 10/92017 10/9/2017 2.00 PRODS 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 hs, ADT 1.09 hrs, Total Bit 13.68 hrs, Jars 95.16 hrs.. SPRs @ 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. 10/9/2017 10/9/2017 0.50 PROD5 DRILL BKRM P Backream OOH V 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. 10/9/2017 10/92017 0.25 PRODS 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 PROD5 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 68179 Report Printed: 10/3012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dar (hr) Phew Op Code ActiWty Code Time P -T -X Op.wn Sten Depth dtKir) End Depth (19<13) 10/9/2017 10/9/2017 4.50 PROD5 DRILL TRIP P Pull OOH on elevators from 7146'to 7,146.0 897.0 03:30 08:00 897', 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 DRILL SHAH 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 stackwasher and jet stack. 0.0 0.0 09:30 10:00 UD same. 10/9/2017 10/9/2017 1.00 PRODS DRILL SHAH P PJSM. Make up L4 RSS drilling BHA 0.0 307.0 10:00 11:00 per SLB to 307' MD, monitoring displacement via trip tank. 10/9/2017 10/9/2017 0.75 PROD5 DRILL PULD P Run in hole on 4" DP singles from pipe 307.0 1,254.0 11:00 11:45 shed from 307'to 1254' MD, monitoring displacement via trip tank. 10/9/2017 10/9/2017 0.50 PROD5 DRILL DHEQ P Shallow hole test MWD with 210 gpm, 1,254.0 1,254.0 11:45 12:15 755 psi, 16% F/O - good test. Blow down top drive. 10/9/2017 10/9/2017 0.75 PROD5 DRILL PULD P Run in hole on 4" DP singles from pipe 1,254.0 2,106.0 12:15 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. 10/9/2017 10/9/2017 2.75 PROD5 DRILL TRIP P Trip in hole on 4" DP from 2106'to 2,106.0 7,210.0 13:00 15:45 7210' MD, monitoring displacement via trip tank, filling pipe every 20 x stands. PUW 11 Ok, SOW 81k 10/9/2017 10/9/2017 1.25 PRODS DRILL SLPC P Slip and cut 58' of drill line. Calibrate 7,210.0 7,210.0 15:45 17:00 blocks. Monitor well via hole fill. 10/9/2017 10/9/2017 0.25 PRODS DRILL TRIP P Trip in hole on 4" DP from 7210'to 7,210.0 7,400.0 17:00 17:15 7400' MD, monitoring displacement via trip tank. No dreg observed tripping bit across window. PUW 114k, SOW 83k. Calculated displacement = 53 bbls, Actual displacement = 53.6 bbls. 10/9/2017 10/9/2017 0.25 PRODS DRILL CIRC P Fill pipe and obtain slow pump rates. 7,400.0 7,400.0 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 psi. 10/9/2017 10/9/2017 1.75 PROD5 DRILL DLOG P Perform MAD pass from 7400'to 7,400.0 7,650.0 17:30 19:15 7650' MD at 300 Whir with 200 gpm, 1000 psi, 14% F/O. Stop and shoot surveys per DD. Observe 1-6 k drag while washing down. Page 69179 ReportPrinted: 1 013 012 01 7 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time EM Time Dur hr ( ) Phase Op Cade Activity Code Time P -T -X Operation epth Start B) (ft e) End Depth (flKa) 10/9/2017 10110/2017 4.75 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 7,650.0 7,976.0 19:15 00:00 - 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 It, 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 10/10/2017 6.00 PRODS DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 7,976.0 8,338.0 00:00 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 11Ok, 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 10/10/2017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 8,338.0 8,650.0 06:00 12:00 from 8338' to 8650' MD, 3753' TVD. Pump at 275 gpm, 1885 psi, 21 % F/0, ECD 10.58 ppg, MW 9.2+ ppg. Rotate at 120-140 rpm with 3-6k 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. 10/10/2017 10/10/2017 6.00 PRODS DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 8,650.0 9,265.0 12:00 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. 1-1 Ok WOB. PUW 118k, SOW 71k, ROT 93K. Max gas 425 units. ADT 5.9 hrs, Bit 18.13 hrs, Jars 113.29 hrs. SPRs QD 7,728' MD 3,753' TVD, MW=9.3 ppg, 13:30 hours MP#1: 20 spm=460 psi, 30spm=650 psi. MP #2:20 spm=460 psi, 30 spm=640 psi. Page 70179 Report Printed: 1 013 0/2 01 7 -- ;- Operations Summary (with Timelog Depths) * IH-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time U (hn) Phase Op Code Activity Code Time P-T-X Opendion (fl)03) End Depth(XKa) 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 TO off-btm. 1-5K WOB. UP WT = 117K, OWN WT = 72K, ROT 93K. Max gas 303 units. ADT 4.7 hrs, Bit 22.83 his, Jars 117.99 hrs. 10/11/2017 10/11/2017 6.00 PRODS 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/O, ECD 10.61 ppg, MW 9.3 ppg. Rotate at 150 rpm with 6k TO on-btm, 5k TQ off-btm. 1-5K 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 PRODS 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 % F/O, ECD 10.52 ppg, MW 9.2+ ppg. Rotate at 120 rpm with 6k TQ on-btm, 5k TO off-btm. 1-51K 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 PRODS 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% NO, ECD 10.52 ppg, MW 9.2+ ppg. Rotate at 120 rpm with 7K TQ on-btm, 6K TO off -btm. 2K WOB. UP WT= 122K, DWN WT = 68K, ROT 93K. Max gas 259 units. ADT 4.48 his, 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 71179 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Op.nA.n start Depth (ftKa) End Depth (aKa) 10/11/2017 10/12/2017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 10,537.0 10,792.0 18:00 00:00 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, 6K TQ off-btm. 2-5K WOB. UP WT = 123K, DWN WT = 67K, ROT 94K. Max gas 185 units. ADT 5.21 his, Bit 41.44 hrs, Jars 136.6 hrs. 10/12/2017 10/12/2017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 10,792.0 10,980.0 00:00 06:00 from10,792' 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 10/12/2017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 10,980.0 11,535.0 06:00 12:00 fmm10,980' MD 3,791' TVD - 11,535' MD 3,802' TVD. 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 10/12/2017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 11,535.0 12,249.0 12:00 18:00 froml 1,535'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 72179 ReportPrinted: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (m) Phase Op Code Activity Code Time P -T -X Operation (WS) End Depth(nKS) 10/12/2017 10/13/2017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 12,249.0 12,503.0 18:00 00:00 from 12,249' MD 3,789' TVD - 12,503 MD 3,789' TVD. Pump at 272 gpm, 2.390 psi, 21% F/0, 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 2-51K 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 10/13/2017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 12,503.0 12,921.0 00:00 06:00 from12,503 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 91K TQ on-btm, 7K TQ off -trim. 2,380 PSI off BTM 2-51K 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 10/1312017 6.00 PROD5 DRILL DDRL P Directionally drill 6.3/4" L4 "D" lateral 12,921.0 13,217.0 06:00 12:00 froml2,921' 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 91K TQ on-btm, 7.51K TO 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 @ 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 10/13/2017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 13,217.0 13,476.0 12:00 18:00 froml3,217' 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: 1 013 012 01 7 Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Tame End Time Dur(hr) Phase Op Code A Iffy Code Time P -T -X Operation Stan Depth (OKS) Erd Depth(WS) 10113/2017 10/14/2017 6.00 PROD5 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/0, ECD 11.62 ppg, MW 9.2+ ppg, Rotate at 120 RPM with 9K TO on-btm, 8K TQ off- - btm. 2,680 PSI off BTM 1-6K WOB. UP WT = 165K, OWN WT = K, ROT 109K. Max gas 669 units. ADT 4.17 hrs, Bit 79.90 hrs, Jars 175.06 hrs. 10/14/2017 10/1412017 6.75 PROD5 DRILL DDRL P Directionally drill 6-314" L4 "D" 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 TQ on- btm, 8K TQ off-btm. 2,750 PSI off BTM 1-6K WOB. UP WT = 178K, OWN WT= K, ROT 119K. Max gas 150 units. ADT 5.07 his, 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 TQ with 11.45 ECD. STKS PUMPED=4,618. MW1/0=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 10114/2017 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 PROD5 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. 10/14/2017 10/14/2017 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/0 @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: 1013012017, Operations Summary (with Timeiog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sr Depth Slam Time End Time Dur (hr) Phase op Code Aclivily Code Time P-T-X Operation (MKB) End Depth JIKa) 10115/2017 10/15/2017 1.75 PRODS CASING TRIP P POOH on elevators. F/7,690' MD UP 7,690.0 7,314.0 00:00 01:45 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 fillrjunk. 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. 10/15/2017 10/15/2017 1.25 PRODS CASING CIRC P Circ while rotating from 7,309' to 7,314.0 7,223.0 01:45 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 PRODS CASING OWFF P OWFF. 7,223.0 7,223.0 03:00 03:15 10/15/2017 10/15/2017 0.25 PRODS CASING SVRG P Service crown / top drive. 7,223.0 7,223.0 03:15 03:30 10/15/2017 10/15/2017 0.50 PRODS CASING TRIP P STND BK 2 stands DP to 7,125' MD. 7,223.0 7,125.0 03:30 04:00 Pump dry job / install stripping rubber. 10/15/2017 10/15/2017 6.50 PRODS CASING PULD P PULD drill pipe sideways from 7,125' 7,125.0 306.0 04:00 10:30 to 306' MD. Monitor disp via TT. UP wt=49K DWN WT=54K. 10/15/2017 10115/2017 1.50 PRODS CASING BHAH P Lay down BHA #26 as per DD. 306.0 0.0 10:30 12:00 Monitor disp via TT. 10/15/2017 10/15/2017 0.75 PRODS 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 10/15/2017 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 10/15/2017 3.75 COMPZ5 FISH TRIP P RIH with HOOK asym from 225'to 225.0 7,391.0 14:15 18:00 7,351' MD. UP WT= 136K DWN WT = 111 K. Monitor disp via TT. Shallow holw test MWD at 1,650' with 252 GPM PSI 1,681. 28% F/O. (PASSED). 10/15/2017 10/15/2017 0.50 COMPZ5 FISH FISH P Orient hook to 160 DEG R. with 233 7,391.0 7,350.0 18:00 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. 10/1512017 10/15/2017 1.50 COMPZ5 FISH CIRC P Circulate 2X BU. 7,350' MD with 246 7,350.0 7,350.0 18:30 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 10116/2017 3.50 COMPZ5 FISH TRIP P POOH from 7,350' MD -2,220' MD 7,350.0 2,220.0 20:30 00:00 UP WT = 75K. Monitor Disp via TT. 10/16/2017 10/16/2017 1.50 COMPZ5 TRIP P Continue to POOH with Whipstock 2,220.0 319.0 00:00 01:30 IRISH fishing assym from 2,200' MD to 319' MD. Monitor disp via TT. Page 75/79 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Time our (hd Phase Op Code Activity Code Time PJA Operation IN(B) End Depth (WB) 10/16/2017 10/16/2017 2.25 COMPZ5 FISH SHAH P LD Whipstock and all Baker fishing 319.0 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 P Mak up lower sompletion assy. Pick 0.0 0.0 05:00 05:30 up and test handeling equipment. Make up same. 10/16/2017 10/16/2017 0.75 COMPZ5 CASING PUTS P RIH with 41/2" 11.6# L-801BTMfTXP - 0.0 254.0 05:30 06:15 slotted / Blank lower liner asym as per detail to 254' MD. Installing Canton all joints as per program. TQ IBTM to 4.5K FT1LB 10/16/2017 10/16/2017 0.50 COMPZ5 CASING EQRP T Change out to spare GBR casing 254.0 254.0 06:15 06:45 power unit. Was on location. Quick changeover. 10/16/2017 10/16/2017 8.50 COMPZ5 CASING PUTS P Continue to RIH with 4 112" 11.6# 254.0 7,252.0 06:45 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 TO = 4.5 FT/LB. TXP TQ = 7K FT/LB. 10/16/2017 10/1612017 0.75 COMPZ5 CASING OTHR P PU hook hanger assym, slim pulse 7,252.0 7,285.0 15:15 16:00 MWD and scribe as per BOT/ SLB. 10/16/2017 10/16/2017 2.00 COMPZ5 CASING RUNL P Continue to RIH with liner as per tally. 7,285.0 8,795.0 16:00 18:00 Monitor disp via TT. 10/16/2017 10/16/2017 0.50 COMPZ5 CASING DHEQ P Shallow hole test MWD. 100 GPM @ 8,795.0 8,795.0 18:00 18:30 353 PSI DPP. 10% F/O (PASSED). 10/16/2017 10/16/2017 4.00 COMPZ5 CASING RUNL P Continue to RIH with 4" DP / HWDP 8,795.0 14,591.0 18:30 22:30 from 8,795' MD to 14,591' MD. Monitoring disp via TT. UP WT = 169K DWN WT = 87K. 10/16/2017 10/16/2017 1.00 COMPZ5 CASING OTHR P Kelly up and orient to 157 DEG R high 14,591.0 14,655.0 22:30 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 10117/2017 0.50 COMPZ5 CASING CIRC P Drop 29/32 ball and pump down at 85 14,655.0 14,652.0 23:30 00:00 GPM 515 PSI DPP. 8% F/0. slow rate to 62 GPM, 375 PSI with 7 112 FO/ at 400 SKS. 10/17/2017 10/17/2017 0.50 COMPZ5 CASING CIRC P Continue to pump 29/32" ball on seat 14,652.0 7,351.0 00:00 00:30 at 1 BPM @ 605 strokes pressure up to 3,800 PSI and release. PU 114K UP WT. Pressur eup 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 0.25 COMPZ5 WELLPR OWFF P OWFF 10 min. Dropped 1'. 7,351.0 7,351.0 00:30 00:45 10117/2017 10/17/2017 0.75 COMPZ5 WELLPR CIRC P PUH to 7,190' MD and pump dryjob. 7,351.0 7,190.0 00:45 01:30 Install stdppin rubbers + BD TD. 10/17/2017 10/17/2017 3.50 COMPZ5 WELLPR TRIP P POOH from 7,190' MD to 90' MD 7,190.0 90.0 01:30 05:00 monitor DISP via TT. Page 76179 Report Printed: 1 013 012 01 7 . Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tim EM Time Dur (IV) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKS) Ertl Depth(fll(e) 10/17/2017 10/17/2017 0.75 COMPZ5 WELLPR BHAH P LD liner running tools and confirm pins 90.0 0.0 05:00 05:45 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 COMPZ5 RWRID SFTY P PJSM 0.0 0.0 07:00 07:15 10/17/2017 10/17/2017 2.25 COMPZ5 RWRID PUTB 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 COMPZ5 RWRID 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 P Shallow hole test MWD at 103 GPM 1,667.0 1,667.0 10:30 11:00 350 PSI w/10%F/0. (PASSED) BD - TO 10/17/2017 10/17/2017 3.25 COMPZ5 RWRID RCST P Continue to RIH from 1,667' MD - 1,667.0 7,459.0 11:00 14:15 7,459' MD. UP WT = 137K OWN WT = 107K Monitor disp via TT. 10/17/2017 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 Q 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 COMPZ5 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 TO 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 10/17/2017 10/18/2017 4.75 COMPZ5 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 rig _ floor. Monitor Disp via TT. UP WT = 88K. OWN WT = 80K. 10/18/2017 10/18/2017 5.50 COMPZ5 RWRID PULD P Continue pulling out of 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) ALL 4W 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log De Start DeDepthun Shad Te End Tape Dur (M) Phase Op Cada Aefivity Cade Time P -T-% Operation (rt End Depth (ftK8) 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 Wis. 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. 10/18/2017 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 COMPZ5 WHDBOP RURD 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 10/19/2017 2.00 COMPZ5 WHDBOP BOPE P BOPR test. ((AOGCC Brian Bixby 0.0 0.0 22:00 00:00 waived witness at 1630 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 as per permit to drill with 4 1/2" 1- 80 test joint. Kill HCR failed initial test / greased and passed. 10/19/2017 10/19/2017 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. TO all connections in To TURN modeto7Kft/LB. UPWT=98K DWN WT = 76K. Witnessed drag as stinging into seal asym and tagged up at 7,292' with 10K 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 V500 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 Cl 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 superviser. Test IA to 1,000 psi for 5 min. All tests good - Charted. 10/2012017 10/20/2017 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 ReportPrinted: 10/3012017 . Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slav Time End Time Dm(hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (WO) EM Depth (MKB) 10/20/2017 10/20/2017 0.50 COMPZ5 RPCOMP RURD P Rig down test equipment, Pull landing 0.0 0.0 03:15 03:45 joint & lay down. Drain stack & blow down choke, kill and hole fill lines. 10/20/2017 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 10/20/2017 1.75 COMPZ5 WHDSOP NUND P Clean out hanger void. Nipple up 0.0 0.0 07:30 09:15 1 production tree. 10/20/2017 10/20/2017 0.75 COMPZ5 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 PRTS P Flood lines and tree with diesel. Test 0.0 0.0 10:45 12:00 25015,000 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 COMPZ5 WHDBOP FRZP P Engage LRS to pump 135 BBLS of 0.0 0.0 12:30 14:00 diesel freeze protect. 3 BPM @ 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 0.0 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 10/20/2017 10/21/2017 8.00 COMPZ5 MOVE MOB P Move to 1H-111 0.0 0.0 16:00 j 00:00 Page 79179 Report Printed: 1 013 012 01 7 NADConversion Kuparuk River Unit Kuparuk 1H Pad 1H -102L3 1H -102L3 ConocoPhillips Definitive Survey Report 09 October, 2017 ConocoPhillips = ,. ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 11-1-102 Project Kupamk River Unit TVD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-102 actual Q 92.62usft (Doyon 142) Wen: Rig: 1 H-102 North Reference: True Wellbons: 11-1-1021-3 Survey Calculation Method: Minimum Curvature Design: 11-1-1021-3 Database: 0AKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US Stale Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Rig: 11-1-102 Well Position +NI -S 0.00 usft Northing: 5,980,662.56 usft Latitude: 70° 21'28.630 N Version: 1.0 +E/ -W 0.00 usft Easting: 549,577.46 usft Longitude: 149° 35'50.423 W Position Uncertainty Depth From (TVD) 0.00 usft Wellhead Elevation: usft Ground Level: 54.00 usft Wellbore 1H-10213 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (`) 0 (nT) BGGM2017 9/30/2017 17.47 80.95 57,490 Design 1H-1021-3 Date Audit Notes: To Version: 1.0 Phase: ACTUAL Tie On Depth: 7,576.96 Vertical Section: Depth From (TVD) -NI-S +E/ -W Direction 1,050.36 (usft) (usft) (usft) (1) 1,777.33 38.62 0.00 0.00 0.00 7,646.06 7,762.811H-10213 Srvy 1-SLB_MWD-INC_Filler MWD -INC ONLY MWD-INC_ONLY_FILLER 9/30/2017 9:28:, Survey Program Date From To (usft) (waft) Survey (Wellbore) Tool Name Description Survey Date 67.62 1,009.26 1 H-102 Srvy 1 - SLB_GWD70 (1 H-102) GYD-GC-SS Gyrodata 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 8/24/201710:12 1,777.33 7,576.961H-102 Srvy 3- SLB _MWD+GMAG(1 H- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 6/27/201712:16 7,646.06 7,762.811H-10213 Srvy 1-SLB_MWD-INC_Filler MWD -INC ONLY MWD-INC_ONLY_FILLER 9/30/2017 9:28:, 7,782.81 14,625,811H-1021-3 Srvy 2- SLB _MWD+GMAG(1 MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 9/30/2017 9:36: - Survey Map Map vertical MD Inc AN TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (waft) (0) (`) (usft) (usft) (usft) (usft) (ft) (it) (°Mogi (ft) Survey Tool Name 38.62 0.00 0.00 38.62 -54.00 0.00 0.00 5,980,66256 549,577.46 DAD 0.00 UNDEFINED 67.62 0.19 41.29 67.62 -25.00 0.04 0.03 5,980,66260 549,577.49 066 0.04 GYD-GC-SS(1) 165.90 0.45 132.01 165.90 73.28 -0.10 0.43 5,980,66246 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 5,980,66112 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 5,98D,659.14 549,581.34 2.46 -3.44 GYD-GCSS(1) 447.17 4.61 135.26 446.86 354.24 -8.10 8.28 5,980,654.51 549,585.79 1.39 -8.10 GYD-GCSS(1) 539.82 517 132.42 539.13 446.51 -13.89 14.34 5,980,648.77 549,591.89 1.28 -13.89 GYD-GC-SS(1) 632.84 7.61 134.49 631.51 538.89 -21.36 22.19 5,9Q 1.35 549,599]9 1.99 -21.36 GYD-GC-SS(1) 725.82 8.77 137.82 723.64 630.92 -30.93 31.34 5,980,63184 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 5,980,61959 549,619.52 2.15 43.25 GYD-GC-SS(1) 10192017 4:12:07PM Page 2 COMPASS 5000.14 Build 65 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1 H-102 Project: Kuparuk River Unit TVD Reference: iH-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1 H Pao MD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Well: Rig: 1H-102 North Reference: True Wellbore: 1H-10213 Survey Calculation Method: Minimum Curvature Design: 11-1-1021-3 Database: OAKEDMP2 Survey IOA/2017 4: 12 07P Page 3 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Axi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS $sof" (usft) (1) (9 (usft) (usft) (usft) (usft) (ft) (ft) ('11001 (ft) Survey Tool Name 914.20 12.89 139.61 908.57 815.95 -57.91 53.90 5,980,605.01 549,631.74 2.35 -5791 GYD-GC-SS(1) 1,009.26 14.89 136.85 1,000.84 908.22 -74.90 69.13 5,950,588.13 549,647.08 2.22 -74.90 GYD-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 -0275 MWD+1FR-AK-CAZSC(2) 1,144.89 17.17 134.37 1,131.15 1,038.53 -101.72 95.49 5,980,56149 549,67361 1.61 -101.72 MWD+IFR-AK-CAZ-SC(2) 1,239.16 20.84 13425 1,220.26 1,12764 -123.16 117.46 5,980,540.20 549,695.72 3.89 -123.16 MWD+IFR-AI(-CAZ-SC(2) 1,334.20 24.71 136.54 1,30288 1,215.26 -149.38 143.24 5,98,514.14 549,721.67 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 5,960,483.80 549,750.31 3.02 -179.92 MWD+IFR-AK-CAZSC(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-CAZSC(2) 1,618.09 28.94 137.33 1,559.64 1,467.02 -245.96 231.84 5,980,418.16 549,810.90 090 -245.96 MWD+IFR-AK-CAZ-SC(2) 1,678.04 29.99 135.80 1,611.84 1,51922 -267.37 252.11 5,950,396.89 549,831.31 2.15 -267.37 MWD+IFR-AK-CAZ-SC(2) 1,771.00 33.38 13572 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 10 314" x 13112^ 1,777.33 33.61 135.72 1,696.21 1,603.59 -304.85 288.61 5,980,359.66 549,868.03 365 504.85 MWD+IFR-AK-CAZSC(3) 1,801.61 34.53 134.79 1,716.32 1,62370 -314.50 298.19 5,980,350.07 549,87769 4.35 -314.50 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-CAZ-SC(3) 1,991.93 40.86 131.83 1,86672 1,774.10 -394.45 382.87 5,98,270.70 549,962.89 3.39 -394.45 MNQI+IFR-AK-CAZ-SC (3) 2,086.48 43.97 130,99 1,936.52 1,843.90 -035.61 430.70 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 -481.73 484.03 5,980,184.09 550,064.65 3.44 481.73 MWD+IFR-AK-CAZSC(3) 2,27623 50.08 128.77 2,065.76 1,973.14 525.22 537.53 5,980,140.96 550,118.40 3.23 -525.22 MW)+IFR-AK-CAZSC(3) 2,371,48 53.12 127.35 2,124.92 2,032.30 -571.22 596.31 5,980,095.36 550,17748 3.40 -57122 MWD+IFR-AK-CAZ-SC(3) 2,464.98 55.35 124.47 2,179.57 2,086.95 515.68 657.76 5,950,051.30 550,239.21 3.45 615.68 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-CA7-SC(3) 2,653.87 5879 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 85895 5,979,923.27 550,441.23 0.88 -745.06 MWD+IFR-AK-CAZSC(3) 2,843.07 6140 121,48 2,378.07 2,285.45 -788.24 929.11 5,979,880.56 550,511.67 2.16 -788.24 MNDAFR-AK-CA -$C (3) 2,937.25 65.11 121.93 2,420.45 2,327.83 -832.44 1,000.65 5,979,836.84 550,583.50 3.96 -83244 MND+IFR-AK-CAZSC(3) 3,032.88 69.13 121.16 2,457.62 2,365.00 -078.52 1,075.72 5,979,791.27 550,658.87 4.27 578.52 MWD+IFR-AK-CAZ-SC (3) 3,126.86 71.43 121.37 2,489.33 2,396.71 -92443 1,151.34 5,979,745.86 550,73478 2.46 -924.43 MWD+IFR-AK-CAZ-SC(3) 3221.95 7262 121.37 2,518.67 2,426.05 -971.51 1,228.56 5,979,699.29 55,812.31 1.25 571.51 MWD+IFR-AK-CAZ-SC(3) 3,31646 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 MND+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 2,50867 -1,116.05 1,458.78 5,979,556.30 551,043.45 0.21 -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 5,979,50759 551,120.65 0.15 -1,165.27 MWD+IFR-AK-CAZSC(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 MND+IFR-AK-CAZ-SC(3) 3,791.46 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 11895 2,711.17 2,618.55 -1,30743 1,768.88 5,979,36699 551,354.78 2.05 -1,307.43 MWD+IFR-AK-CA2-SC(3) 3,981.94 73.09 119.64 2,738.82 2,646.20 -1,352.00 1,84832 5,979,322.95 551,434.51 070 -1,352.00 MND+IFR-AK-CAZ-SC(3) 4,076.41 73.30 119.87 2,766.13 2,673.51 -1,39688 1,926.84 5,979,278.59 551,513.31 0.32 -1,396.88 MND+IFR-AK-CA7-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 MND+IFR-AK-CAZ-SC(3) 4,266.02 73.05 119.53 2,821.02 2,728.40 -1,485.83 2,085.04 5,979,19071 551,672.08 0.56 -1,485.83 MWD+IFR-AK-CAZ-SC(3) 4,360.46 73.01 119.04 2,848.57 2,75595 -1,530.01 $163.83 5,979,14705 551,751.15 050 -1,530.01 MND+IFR-AK-CAZ-SC(3) IOA/2017 4: 12 07P Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 11-1-1102 Project: Kuparuk River Unit TVD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Well: Rig: 1H-102 North Reference: True Wellbore: 1H-1021-3 Survey Calculation Method: Minimum Curvature Design: 1H-1021-3 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +El -W Northing Easting DLS Section (usft) (1) (1 (usft) (usft) (usft) (usft) (ft) (R) (-irlow) (ft) Survey Tool Name 4,455.58 72.90 11977 2,87645 2,783.83 -1,574.66 2,243.05 5,979,102.93 551,830.65 0.74 -1,574.66 MWD11FR-AK-CAZ-8C (3) 4,549.81 72.87 12006 2,909.19 2,811.57 -1,619.57 2,321.11 5,979,058.54 551,909.01 030 -1,61957 MWD+IFR-AK-CAZ-SC(3) 4,644.52 73.20 118.40 2,931.82 2,839.20 -1,663.81 2,400.16 5,979,01484 551,988.35 1.71 -1,663.81 MWD+IFR-AK-CAZ-SC(3) 4,739.99 72.42 114.51 2,960.05 2,867.43 -1,704.44 2,481.79 5,978,974.75 552,070.24 3.98 -1,704.44 MWD+1FR-AK-CAZ-SC(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-CAZSC(3) 4,833.76 72.48 108.23 2,988.44 2,895.82 -1,736.30 2,56524 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 5,978,91924 552,240.42 4.50 -1,761.08 MWD+IFR-AK-CAZ-SC(3) 5,022.87 71.11 100.68 3,096.89 2,954.27 -1,780.14 2,739.52 5,978,900.76 552,328.44 331 -1780.14 MWD+IFR-AK-CAZ-SC(3) 5,070.23 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 -1,787.68 MWD+1FR-AK-CAZSC(3) 5,116.77 71.68 96.97 3,076.95 2,984.33 -119369 2,827.43 5,978,887.79 552,416.42 3.61 -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 5,978,87999 552,505.81 3.25 -1,802.09 MWD+IFR-AK-CAZ-SC(3) 5,305.75 71.74 88.59 3,135.64 3,043.02 -1,803.94 3,006.61 5,978,876.73 552,595.65 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 -1,797.98 MWD+IFR-AK-CAZ-SC(3) 5,49528 72.32 81.29 3,194.64 3,102.02 -1,786.21 3,185.70 5,978,897.65 552,774.60 2.56 -1,786.21 MWD+IFR-AK-CAZ-SC(3) 5,590.01 72.15 76.05 3,223.57 3,130.95 -1,768.49 3,274.13 5,978,915.95 552,86291 5.27 -116849 MW3+1FR-AK-CAZ-SC(3) 5,685.45 72.61 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+1FR-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-AK-CAZSC(3) 5,874.02 73.87 63.54 3,30723 3,214.61 -1,667,90 3,525.49 5,979,018.19 553,113.57 1.39 -1,667.90 MWD+IFR-AK-CAZ-SC(3) 5,968.69 74.38 63.99 3,333.12 3,240.50 -1,62764 3,607.17 5,979,058.98 553,194.97 0.71 -1,62764 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 5,979,099.49 553,276.50 0.25 -1,587.68 MWD+IFR-AK-CAZ-SC(3) 6,156.96 7468 58.30 3,383.23 3,290.61 -1,544.01 3,768.12 5,979,143.67 553,355.35 5.79 -1,544.01 MWDHFR-AK-CAZ-SC(3) 6,252.33 74.03 54.53 3,408.96 3,316.34 -1,49322 3,894.61 5,979,194.96 553,431.50 3.87 -1,49322 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 3,464.71 3,372.09 -1,379.79 3,985.58 5,979,30931 553,571.69 3.07 -1,379.79 MWD+IFR-AK-CAZSC(3) 6,537.27 73.10 45.02 3,493.23 3,400.61 -1,317.09 4,051.72 5,979,372.44 553,637.42 3.18 -1,317.09 MW0+1FR-AK-CAZ-SC(3) 6,58521 73.18 41.30 3,507.14 3,414.52 -1,283.63 4,083.10 5,979,406.11 553,66857 7.43 -1,283.63 MWD+IFR-AK-CAZ-SC(3) 6,632.17 72.64 38.72 3,520.94 3,428.32 -1,249.25 4,111.96 5,979,440.67 553,697.19 5.38 -1,249.25 MWD+1FR-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 -1,17560 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 -1,09723 MWD+IFR-AK-CAZ-SC(3) 6,915.59 72.83 23.59 3,606.48 3,513.86 -1,01727 4,248.88 5,979,673.53 553,832.57 3.94 -1,01727 MWD+IFR-AK-CAZ-SC(3) 7,011.34 72.49 19.50 3,835.02 3,542.40 -932.28 4,282.44 5,979,758.73 553,865.56 4.09 -932.28 MWD+IFR-AK-CAZ-SC(3) 7,104.01 73.90 18.26 3,661.a2 3,569.20 -848.34 4,311.14 5,979,842.85 553,893.70 1.99 648.34 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 67164 4,352.87 5,980,019.81 553,934.25 5.75 67164 MWD+IFR-AK-CAZ-SC(3) 7,367.86 74.53 4.10 3,740.79 3,648.17 -581.33 4,%2.35 5,980,110.17 553,943.13 3.90 581.33 MWD+IFR-AK-CAZ-SC(3) 7,481.81 74.18 4.40 3,766.13 3,673.51 491.11 4,36905 5,980,20043 553,949.24 0.48 491.11 MWD+IFR-AK-CAZ-SC(3) 7,576.% 74.34 2.50 3,791.94 3,699.32 -399.70 4,374.56 5,980,29186 553,954.15 1.93 -399.70 MWD+IFR-AK-CAZ-SC(3) 7,646.00 75.99 2.54 3,80362 3,717.00 333.02 4,377.50 5,980,358.55 553,956.64 2.39 -333.02 NOT an Actual Survey 7518" x 9.718" 7,646.06 75.99 2.54 30963 3,717.01 -332.97 4,377.50 5,980,358.60 553,956.64 2.39 -332.97 MM -INC _ONLY (4) f0i&2017 4.12.07PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 1 H-102 Project: Kuparuk River Unit TVD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1H Pao MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Well: Rig: 1H-102 North Reference: True Wellbore: 1 H-10213 Survey Calculation Method Minimum Curvature Design: 1 H-10213 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1S *EFW Northing Easting DLS Section (usft) (°) (% (usft) (usft) (usft) (Irsft) (ft) (ft) (°11001 (ft) Survey Tool Name 7,661.35 77.16 1.83 3,813.18 3,720.56 -318.11 4,378.06 5,980,37347 553,957.11 889 -318.11 MWD -INC _ONLY (4) 7,689.89 79.34 2.34 3,818.99 3,726.37 -290.18 4,379.08 5,980,401.39 553,957.94 7.84 -290.18 MWD -INC _ONLY (4) 7,736.46 8421 3.13 3,825.65 3,733.03 -244.16 4,381.28 5,980,447.43 553,959.84 10.59 -244.16 MWD -INC _ONLY (4) 7,782.81 88.69 3.49 3,828.52 3,735.90 -197.99 4,383.95 5,980,493.61 553,962.20 9.70 -19799 MWD -INC _ONLY (4) 7,828.10 91.81 3.55 3,828.33 3,73571 -152.79 4,386.73 5,980,538.82 653,964.68 6.89 -15279 MWD+IFR-AK-CAZ-SC(5) 7,91734 92.12 3.52 3,825.27 3,732.65 63.77 4,392.23 5,980,627.86 553,969.59 0.35 6317 MWD+IFR-AK-CAZ-SC (5) 7,962.47 91.54 3.19 3,82382 3,731.20 -18.74 4,394.87 5,98,672.91 553,971.93 1.48 -18.74 MWD+1FR-AK-CAZ-SC(5) 8,012.52 91.06 1.69 3,822.69 3,730.07 31.25 4,39700 5,98,722.90 553,973.73 3.15 31.25 MWD+IFR-AK-CAZ-SC(5) 8,059.42 90.79 0.92 3,821 93 3,729.31 78.13 4,398.07 5,980,769.79 553,974.49 1.74 78.13 MWD+1FR-AK-CAZ-SC (5) 8,106.77 90.68 359.56 3,821.32 3,728.70 125.47 4,398.27 5,980,817.13 553,974.37 2.88 12547 MWD+IFR-AK-CAZSC(5) 8,156.58 90.71 358.75 3,820.72 3,728.10 175.27 4,397.53 5,980,866.92 553,973.31 1.63 175.27 MWD+IFR-AK-CAZ-SC(5) 8,201.93 91.59 359.54 3,819.81 3,727.19 220.61 4,396.86 5,980,912.24 553,972.33 2.61 220.61 MWD+IFR-AK-CAZSC(5) 8,296.99 90.82 359.72 3,817.81 3,725.19 31565 4,396.24 5,981,007.26 553,971.09 0.83 31565 MWD+IFR-AK-CAZSC(5) 8,391.15 90.20 1.51 3,81697 3,724.35 40979 4,397.25 5,981,101.41 553,971,48 2.01 409.79 MWD+IFR-AK-CAZ-SC(5) 8,486.62 89.93 0.% 3,81886 3,724.24 505.24 4,399.31 5,981,196.86 553,972.90 0.64 50524 MWD+IFR-AK-CAZ-SC(5) 8,579.86 8970 1.71 3,817.17 3,724.55 598.45 4,401.48 5,981,290.07 553,974.46 0.84 598.45 MWD+IFR-AK-CAZ-SC(5) 8,627.48 90.30 0.66 3,817.17 3,724.55 646.06 4,402.47 5,981,337.68 553,975.13 2.54 646.06 MWD+IFR-AK-CAZ-SC (5) 8,674.57 90.29 359.54 3,81692 3,724.30 693.15 4,402.55 5,981,384.77 553,974.90 2.38 693.15 MWD+FR-AK-CAZ-SC(5) 8,769.70 89.62 358.37 3,81700 3,724.38 788.26 4,400.82 5,981,47985 553,972.54 1.42 78826 MWD+IFR-AK-CAZ-SC(5) 8,864.54 88.83 357.37 3,818.28 3,725.66 883.03 4,397.29 5,981,574.58 553,968.38 1.34 883.03 MWD+IFR-AK-CAZ-SC(5) 8,960.45 88.68 357.09 3,820.36 3,727.74 978.80 4,39266 5,981,670.32 553,963.12 0.33 97880 MWD+IFR-AK-CAZ-SC(5) 9,055.10 87.19 359.04 3,823.78 3,731.16 1,073.33 4,389.46 5,981764.81 553,959.30 2.59 1,073.33 MWD+IFR-AK-CAZ-SC(5) 9,14982 87.94 358.94 3,827.80 3,735.18 1,167.95 4,387.80 5,981,859.41 553,95700 0.80 1,167.95 MWD+IFR-AK-CAZ-$C(5) 9,245.39 88.64 358.74 3,830.65 3,738.03 1,263.46 4,385.86 5,981,954.89 553,954.44 0.76 1,263.46 MWD+IFR-AK-CAZ-SC(5) 9,339.41 88.52 0.09 3,832.98 3,740.36 1,35744 4,384.90 5,982,04886 553,952.86 144 1,35744 MWD+IFR-AK-CAZ-SC(5) 9,434.35 88.72 359.99 3,835.27 3,742.65 1,452.35 4,384.97 5,982,14376 553,952.29 0.24 1,452.35 MWD+IFR-AK-CAZ-SC(5) 9,52781 90.16 359.62 3,836.18 3,743.56 1,545.80 4.384.65 5,982,237.20 553,951.36 1.59 1,545.80 MWD+FR-AK-CAZ-SC(5) 9,622.31 90.53 359.84 3,83561 3,742.99 1,640.30 4,384.20 5,982,331.68 553,95D29 0.46 1,640.30 MWDAFR-AK-CAZSC(5) 9,717.26 9024 357.05 3,834.97 3,742.35 1,73520 4,381.63 5,982,426.56 553,947.08 2.95 1,73520 MWD+IFR-AK-CAZ-SC(5) 9,812.51 90.63 353.91 3,834.25 3,74163 1,830.14 4,374.12 5,982,521.43 553,938.95 3.32 1,830.14 MWD+IFR-AK-CAZSC(5) 9,907.44 90.73 351.74 3,833.12 3,740.50 1,924.32 4,362.27 5,982,615.52 553,926.47 2.29 1,924.32 MWD+IFR-AK-CAZSC(5) 10,002.27 90.22 350.65 3,832.34 3,739.72 2,018.03 4,347.75 5982,709.12 553,911.34 1.27 2,018.03 MWD+IFR-AK-CAZ-SC(5) 10,09695 88.84 34960 3,833.11 3,740.49 2,111.30 4,331.52 5,98260227 553,894.49 1.83 2,111.30 MWD+IFR-AK-CAZ-SC(5) 10,192.81 89.39 34886 3,834.60 3,741.98 2,205.45 4,313.61 5,982,896.30 553,875.96 0.96 2,205.45 MWD+IFR-AK-CA7-SC(5) 10,267.83 89.48 346.36 3,835.53 3,742.91 2,298.25 4,293.22 5,982,98895 553,854.96 2.63 2,298.25 MWD+IFR-AK-CAZ-SC(5) 10,381.89 89.54 345.19 3,836.34 3,743.72 2,389.42 4,270.11 5,983,07996 553,83125 1.25 2,389.42 MWD+IFR-AK-CAZ-SC(5) 10,477.13 88.47 347.20 3,83799 3,745.37 2,481.89 4,247.39 5,963,17226 553,807.92 2.39 2,481.89 MWD+IFR-AK-CAZ-SC(5) 10,572.69 8929 349.51 3,839.86 3,747.24 2,575.46 4,228.10 5,983,26569 553,788.02 2.55 2,57546 MWD+IFR-AK-CAZ-SC(5) 10,656.29 89.51 352.07 3,840.84 3,748.22 2,667.64 4,213.13 5,983,357.96 553,77243 2.74 2,667.84 MWD+IFR-AK-CAZSC(5) 10,761.05 88.24 355.86 3,842.70 3,750.08 2,762.04 4,203.17 S,983,452.08 553,761.85 4.22 2,762.04 MWD+IFR-AK-CAZ-SC(5) 70/92017 4: 12.07PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co -aminate Reference: Well Rig: iH-102 project: Kuparuk River Unit TVD Reference: IH -102 actual @ 92.62usft (Doyon 142) Sipa: Kuparuk 1H Pao MD Reference: IH -102 actual @ 92.62usft (Doyon 142) Well: Rig: 1H-102 North Reference: True We"Ibm: 1H-10213 Survey Calculation Method: Minimum Curvature Design: 1 H-10213 Database: OAKEDMP2 Survey Map Map, vertical MD Into Azi TVD TvDSS +N1S +E14111 Nordling pasting DLS Section (usft) 0 0 (usft) (usft) (usft) (usft) Ift) (ft) (97001 (ft) Survey Tool Name 10,65604 85.03 359.83 3,848.28 3,755.66 2,856.76 4,199.60 5,983,546.78 553,75765 5.37 2,856.76 1AWD+1FR-AK-CAZSC(5) 10,950.31 83.30 2.18 3,857.86 3,76524 2,950.52 4,201.24 5,983,64053 553,758.67 3.09 2,950.52 MWD+IFR-AK-CAZ-SC(5) 11,046.10 84.10 1.46 3,868.37 3,775.75 3,045.68 4,204.26 5,983,73570 553,761.06 1.12 3,045.68 MWD+IFR-AK-CAZSC(5) 11,140.41 86.98 0.23 3,875.71 3,783.09 3,139.66 4,205.65 5,983,629.70 553,761.83 3.32 3,139.68 MWD+IFR-AK-CAZSC(5) 11,235.63 90.45 358.64 3,877.84 3,785.22 3,234.86 4,204.71 5,983,924.86 553,760.26 4.01 3,234.86 MWD+IFR-AK-CAZSC(5) 11,330.49 90,8 368.00 3,877.07 3,78445 3,329.67 4,201.93 5,984,01965 553,758.85 0.68 3,32967 MWD+IFR-AK-CAZSC(5) 11,424.69 90.63 359.37 3,876.16 3,783.54 3,423.84 4,199.76 5,984,113.79 553,754.06 1.46 3,423.84 MWD+IFR-AK-CAZSC(5) 11,518.98 92.53 0.39 3,873.56 3,780.94 3,518.09 4,193.57 5,984,208.03 553,753.24 229 3,518.09 MWD+IFR-AK-CAZSC(5) 11,613.53 93.55 2.39 3,868.55 3,775.93 3,612.47 4,201.85 5,984,30241 553,754.91 2.37 3812.47 MWD+IFR-AK-CAZSC(5) 11,703.96 92.13 5.69 3,864.06 3,771,4 3,702.55 4,208.22 5,984,39252 553,760.67 3.97 3,702.55 MWDAFR-AK-CAZSC(5) 11,796.48 90.59 5.92 3,861.87 3,769.25 3,794.57 4,217.57 5,984,48459 553,769.42 1.88 3,794.57 MWD+IFR-AK-CAZSC(5) 11,888.04 91.21 6.88 3,860.43 3,767.81 3,885.55 4,227.78 5,98,57562 553,779.02 125 3,885.55 MWD+IFR-AK-CAZSC(5) 11,979.75 91.06 7.95 3,858.61 3,76599 3,976.47 4,239.61 5,984,656.62 553,790.25 1.18 3,976,47 MWD+IFR-AK-CAZSC(5) 12,071.78 90.96 7.57 3,856.99 3,764.37 4,067.64 4,252.04 5,984,757.86 553,802.07 0.43 4,067.64 MWD+IFR-AK-CAZSC(5) 12,161.75 90.80 7.00 3,855.61 3,762.99 4,155.88 4,263.44 5,984,847.16 553,812.88 0.66 4,155.88 MWD+IFR-AK-CAZ-SC(5) 12,255.20 90,15 5.95 3,854.83 3,762.21 4,249.73 4,273.98 5,98,940.07 553,822.81 1.32 4,249.73 MWD+IFR-AK-CAZSC(5) 12,347.71 88.31 2.31 3,856.08 3,763.46 4,341.97 4,280.64 5,985,032.34 553,828.86 4.41 4,341.97 MWD+IFR-AK-CAZSC(5) , 12,440.90 8986 359.72 3,857.57 3,764.95 4,435.12 4,282.29 5,985,125.49 553,829.89 3.24 4,435.12 MWD+IFR-AK-CAZSC(5) 12,532.79 89.85 358.54 3,657.79 3,765.17 4,527.00 4,280.90 5,985,21735 553,827.89 128 4,527.00 MWD+IFR-AK-CAZSC(5) 12,623.89 90.19 365.39 3,857,75 3,765.13 4,617.96 4,276.07 5,985,30827 553,822.46 348 4,617.% MWD+IFR-AK-CAZSC(5) 12,716.14 89.18 353.72 3,858.26 3,765.64 4,709.79 4,267.32 5,985,40003 553,813.10 2.12 4,709.79 MWD+IFR-AK-CAZSC(5) 12,80891 8799 350.29 3,860.55 3,767.93 4,801.61 4,254.42 5,985,491.76 553,799.60 3.91 4,80161 MWD+IFR-AK-CAZ-SC(5) 12,902.83 85.66 345.91 3,865.75 3,773.13 4,893.34 4,235.10 5,985,583.35 553,779.67 5.28 4,893.34 MWD+IFR-AK-CAZ-SC(5) 12,991.33 87.16 342.83 3,871.30 3,778.68 4,978.39 4,211.30 5,985,668.23 553,755.31 3.86 4,978.39 MWD+IFR-AK-CAZ-SC(6) 13,064.51 91.52 344.00 3,872.37 3,779.75 5,067.67 4,184.71 5,985,757.32 553,728.14 4.84 5,067.67 MWD+IFR-AK-CAZ-SC(5) 13,176.87 91.10 339.29 3,870.26 3,777,64 5,155.28 4,155.65 5,985,844.73 553,698.49 5.12 5,155.28 MWD+IFR-AK-CAZ-SC(5) 13,269.09 90.75 332.94 3,868.77 3,776.15 5,23955 4,118.33 5,985,928.74 553,660.62 6.90 5,239.55 MWD+IFR-AK-CAZSC(5) 13,360.43 90,0 327.57 3,867.85 3,77523 5,318.82 4,073.03 5,986,007.70 553,614.80 5.89 5,318.82 MWD+IFR-AK-CAZSC(5) 13,45323 91Al) 322.82 3,856.32 3,773.70 5,394.98 4,020.08 5,966,083.51 553,561.36 5.25 5,394.98 MWD+IFR-AK-CAZSC(5) 13,54632 9171 319.21 3,853.72 3,771.10 5,467.30 3,961.55 5,986,155.43 553,502.36 3.88 5,467.30 MWD+IFR-AK-CAZSC(5) 13,638.36 92.34 315.76 3,M0.46 3,767.84 5,535.09 3,899.40 5,986,22280 553,439.77 3.81 5,53509 MWD+IFR-AK-CAZ-SC(5) 13,73067 92.23 310.92 3,856.78 3,764.16 5,59.38 3,832.34 5,986,285.64 553,372.29 524 5,598.38 MWD+IFR-AK-CAZ-SC(5) 13,822.54 92.64 306.99 3,85288 3,760.26 5,666.08 3,760.9 5,99,34285 553,300.56 4.30 5,65.08 MWD+IFR-AK-CAZ-SC(5) 13,914.50 91.25 303.60 3,849.76 3,757.14 5,709.17 3,65.9 5,986,395.44 53,225.21 3.9 5,709.17 MWD+IFR-AK-CAZ-SC (5) 14,004.35 88,89 302.78 3,849.65 3,757.03 5,75.35 3,610.79 5,99,444.12 553,149.71 2.78 5,75.35 MWD+IFR-AK-CAZ-SC(5) 14,09]9 90.12 301.87 3,850.44 3,757.82 5,80778 3,532.68 5,986,49302 M3,071.28 1.66 5,807.78 MWD+IFR-AK-CAZ-SC (5) 14,188.71 9068 302.23 3,849.80 3,757.18 5,866.55 3,454.77 5,99,541.28 552,99.06 0,72 5,85.55 MWD+IFR-AK-CAZ-SC(5) 14,281.10 90.9 303.01 3,848.46 3,755.84 5,905.35 3,376.97 5,986,590.56 552,914.93 0.91 5,99.35 MWD+IFR-AK-CAZ-SC(5) 14,373.18 91.27 303.58 3,846.64 3,754.02 5,95.89 3,300.01 5,986,64058 552,97,9 0.69 5,95.89 MWD+IFR-AK-CAZSC(5) 14,465,23 91.57 305.20 3,844.36 3,751.74 6,009.52 3,224.54 5,99,692.70 552,761.84 286 6,009.52 MWD+IFR-AK-CAZ-SC(5) 10/92017 4:12:07PM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Surface Coordinates U Local Coordinate Reference: Well Rig: 1 H-102 Project; Kuparuk River Unit p� TVD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Site; Kuparuk 1 H Pad Digitally sign ed by Brandon Temple SLB DE p MD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Well; Rig: 111-102 Date. 10103/17 North Reference: True Wellbore: 1H-1021_3 Survey Calculation Method: Minimum Curvature Design: IH -1021_3 Database: OAKEDMP2 Survey Map hap Vertical MD Inc AZI TVD TVDSS MUS +El•W Northing Easting DLS Section (usft) (") (°) (usft) (usiq (usft) (usft) (ft) (ft) C11001 (ft) Survey Tool Name 14,557.47 90.24 309.01 3,842.90 3,7W.28 6,065.79 3,151.48 5,9.74849 552,688.42 3.37 6,065.79 MND+IFR-AK-CAZ-SC(5) 14,625.81 89.16 308.79 3,843.26 3,750.64 6,108.71 3,098.30 5,986,791.04 552,634.96 1.61 6,108.71 MWD+IFR-AK-CAZ-SC(5) 14,668.00 89.16 308.79 3,643.88 3,751+26 6,135.13 3,065.42 5,986,817.25 552,601.91 0.00 6,135.13 NOT an Actual Survey 4.112" x 6-314" 14,685.00 89.16 308.79 3,844.14 3,751.52 6,146.41 3,051.39 5,986,828.43 552,587.81 0.00 6,146.41 PROJECTEDio TD Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. E] Yes [] No 1 have checked to the best of my ability that the following data is correct: �J Surface Coordinates U Declination & Convergence Q GRS Survey Corrections p� Survey Tool Codes Brandon Temple Digitally sign ed by Brandon Temple SLB DE p Date: 2017.10.0914:02:07-013'00' Client Representative: Kelsey Hallford ayar�".eMr,°Imwr"a Date. 10103/17 10A92017 4'12:07PM Page 7 COMPASS 5000.14 Build 85 Cement Detail Report 1H-102 String: Conductor Cement Job: DRILLING ORIGINAL, 81221201718:00 Cement Details Description Conductor Cement Cementing Start Date 1/11/2016 18:15 Cementing End Date IWGIlbom 1/11/2016 22:15 Name 11-1-102 Comment Cement Stages Stage # 1 Description Conductor Cement Objective cement 20" x 34" Insulated conductor in 42" hole Top Depth (ftKB) 43.1 Bottom Depth (ftKB) 118.6 Full Return? No Vol Cement... Top Plug? No Btm Plug? No Q Pump Init (bbl/m... Q Pump Final (bbll... O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB)Tag 105.0 Method Drill Bit Depth Plug Drilled Out To (ftKB) Drill 118.6 Out Diameter (in) 131/2 Comment Cement Fluids 8 Additives Fluid Fluid Type 3500 mix Fluid Description Estimated Top (ftKB)Est 43.1 Bon (ftKB) 118.6 Amount (sacks) Class Volume Pumped (bbl) Yield (ft'isack) Mix H2O Ratio (galea... Free Water (°h) Density (lb/gal) Plastic Viscosity (Pan) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 111 ReportPrinted: 1111412017 V Cement Detail Report 11-1-102 qW String: Surface Casing Cement Job: DRILLING ORIGINAL, 8/22/201718:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 8/25/2017 18:15 8/25/2017 22:07 11-1-102 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 298 BBLS of 11# cement ( yield 1.91 cuft1sx, 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 cuft/sx, mix water 5.733 gaVsx, 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 his. 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 stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Stan Plug? Surface Casing Cement Cement 10 3/4" 42.0 1,777.0 Yes 9.0 Yes Yes Q Pump Init (bbl/m.. Q Pump Final (bbl/... Q Pump Avg (bbU... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 3 5 286.0 1,082.01 Yes I No Tagged Depth IRKS) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Bit 1,777.0 9 718 Comment Stage pumps up to 8 BPM 290 PSI DPP with 268 PSI FDPP. 23% 1710. While reap 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 = 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/0. 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 cuft/sx, mix water 6.828 gaVsx, 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 cuft/sx, mix water 5.733 gaVsx, 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 bbis of good 11. ppg cement to surface. CIP 2207 hrs 8/25/2017. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MudPush II 1 1 1 1 1 1 77.4 Yield (ft'/sack) Mix H2O Ratio (gailsa... Free Water I%) Density (Iwgal)Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStrf (psi) 10.60 Additives Additive Type Concentration I Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Fst Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 42.0 1,250.2 876 298.0 Yield (IP/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa4i) Thickening Time (hr) CmprStr 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 gal/sx Fluid Fluid Type Fluid Description Estimated Top (ftKB) I Est Stan (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 1,250.2 1,777.0 211 61.9 Yield (tPlsack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ih/gal)Plastic Viscosity (Pa-s) Thickening Time (hr) Cmprstr 1 (psi) 1.65 5.73 12.02 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 gaVsx Page 112 ReportPrinted: 1111412017 Cement Detail Report AM 1H-102 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 8/221201718:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 9/3/2017 03:00 9/3/2017 06:10 1H-102 Comment Pump cement job as follows: SLB pump 5 bbis 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 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 "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 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 Q 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? Son Plug? Intermediate Casing Cement Intermediate 4,250.0 8,591.0 No Yes Yes I Cement casing O Pump Init (bbl/m... Q Pump Final (bbil... Q Pump Avg (bbll... P Pump Final (psi). P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 3 6 1,423.0 2,085.0 Yes 1 5.00 No Tagged Depth IRKS) Tag Method Depth Plug Drilled Out To IRKS) Drill Out Diameter (in) 6 3/4 Comment Pump cement job as follows: SLB pump 5 bbis freshwater and pressure test lines to 400 / 3500 psi - good lest. Pump 50 bbis 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 "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 bbls Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push 3,317.0 4,250.0 1 1 50.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density ptirgal) Plastic Viscosity (Pa.") Thickening Time (hr) CmprStr 1 (psi) 12.50 I Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ft(B) Est Stm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Cement 4,250.0 8,591.0 l 1,159 G 239.3 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%)Density (Ib/gal) Plastic Viscosity (Pa•s) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.72 15.80 4.30 Additives Additive Type ConcentrationConc Unit label D255 aFluid Loss 0.5 %BWOC Additive Type Concentration ConeUnit label D047 Antifoam 0.05 gal/sx Additive Type Concentration I Cone Unit label D065 Dispersant 0.3 %BWOC Page 1/1 ReportPrinted: 11/14/2017 RECEIVED umbergerAOGcc Transmittal#: 260CT17-SP04 Drilling & Measurements DATA LOGGED Product Delivery kk 1 % 1201-1 M. K. BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well Name: 1H -102L3 Date Dispatched: 26 -Oct -17 Service Order #: 17AKA0021 Dispatched By: Stephanie Pacillo Product Description Handcopy Digital Copy Logging Date Color Log Prints: 4 Contents on CD 4 -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 Osterkamo(cDconocoohillios com Alaska PTS PrintCenter(aa)slb com Attn: Tom Osterkamp Attn: Stephanie Pacillo // Received By: 21 7103 28 75 1 FINAL NADConversion Kuparuk River Unit Kuparuk 1H Pad 1H -102L3 1H -102L3 NAD 27 RECEIVED OCT 2 6 2017 A®GCC ConocoPhillips Definitive Survey Report 09 October, 2017 21 71 03 28 75 1 ConocoPhillips ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 1H-102 Project: Kuparuk River Unit TVD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Well: Rig: 1H-102 North Reference: True Wellbore: 1H-10213 Survey Calculation Method: Minimum Curvature Design: 1H-10213 Database: OAKEDMP2 ,reject Kuparuk River Unit, North Slope Alaska, United States lap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level ieo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point lap Zone: Alaska Zone 04 Using geodetic scale factor Well Rig: 11-1-102 Audit Notes: To Well Position +NAS 0.00 Usk Northing: 5,980,662.56 usft Latitude: 70" 21'28,630 N 7,576.96 +E/ -W 0.00 usft Easting: 549,577.46 usft Longitude: 149° 35'50A23 W Position Uncertainty (usft) 0.00 usft Wellhead Elevation: usft Ground Level: 54.00usft Nellbore 111-1021.3 Aagnetics Model Nam Sample Date Declination Dip Angle Field Strength V) 1°I (nT) BGGM2017 9/30/2017 1.47 80.95 57,490 Design 1H-1021-3 Date Audit Notes: To Map Map Version: 1.0 Phase: ACTUAL Tie On Depth: 7,576.96 Vertical Section: Depth From (TVD) -NI-S +E/ -W Direction 1,050.36 (usft) (usft) (usft) (°) 1,777.33 38.62 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 1H-102 Srvy 1 - SLB GWD70 (11H-102) GYD-GC-SS Gyrodata gyro single shots 8/24/2017 10:04 1,050.36 1,678.041H-102 Srvy 2- SLB _MWD+GMAG(1H- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/24/201710:12 1,777.33 7,576.961H-102 Srvy 3 -SLB MWD+GMAG(1 H- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/27/201712:16 7,646.06 7,782.811H-1021-3 Srvy 1 -SLB MWD-INC_Filler MWD-INC_ONLY MWD -INC _ONLY -FILLER 9/30/2017 9:28: 7,782.81 14,625,811H- 1021-3 Srvy 2 -SLB MWD+GMAG(1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/30/2017 9:36: Survey 11092017 4:12:07PM Page 2 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 38.62 0.00 0.00 38.62 -5400 0.00 0.00 5,980,662.56 549.577.45 0.00 000 UNDEFINED 67.62 0.19 41.29 67.62 -25.00 0.04 0.03 5,980,662.60 549,577.49 0.66 0.04 GYD-GC-SS(1) 165.90 0.45 132.01 165.90 7328 -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) 447.17 461 135.26 446.86 354.24 -8.10 8.28 5'M'654.51 549,585.79 1.39 -8.10 GYD-GC.SS(1) 539.82 5.]7 132.42 539.13 446.51 -13.89 14.34 5.980.648.77 549,591.89 1.28 -13.89 GYD-GC-SS(1) 632.84 7.61 134.49 631,51 538.89 -21.36 22.19 5,980,641.35 549,599.79 199 -21.36 GYD-GC-S$(1) 725.82 8.77 137.82 723.54 630.92 -30.93 31.34 5,980,63184 549,609.00 1.35 -30.93 GYD-GC-SS(1) 821.24 10.73 141.32 817.58 724.96 43.25 41.78 5,98061959 549,619.52 2.15 -43.25 GYD-GC-SS(1) 11092017 4:12:07PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1H-102 Project: Kuparuk River Unit TVD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kupamk 1 H Pad MD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Well: Rig: 1H-102 North Reference: True Wellbore: 11H-10213 Survey Calculation Method: Minimum Curvature Design: 1H-10213 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Elating DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 914.20 1289 139.61 908.57 815.95 -5].91 53.90 5,980,605.01 549,631.74 2.35 -5].91 GYD-GC-SS(1) 1,009.26 14.89 13685 1,000.84 908.22 -74.90 69.13 5,980,588.13 549,647.08 2.22 -74.90 GYD-GC-S$(1) 1,D50.36 1572 135.96 1,040.49 947,87 -82.75 7661 5,980,580.32 549,654.61 2.10 -8235 MWD+IFR-AK-CAZ-SC(2) 1,144.89 17.17 134.37 1,131.15 1,038.53 -101.72 9549 5,98056149 549,67361 161 -101.72 MWD+IFR-AK-CAZ-SG(2) 1,239.16 20.84 134.25 1,220.26 1,127.64 -123.16 117.46 5,980,54020 549,695.72 3.89 -123.16 MWD+IFR-AK-CAZ-SC(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 2754 137.49 1,392.97 1,30035 -179.92 17168 5,980,48380 549,750.31 3.02 -179.92 MWD+IFR-AK-CAZ-SC(2) 1,523.25 28.14 13793 1476.33 1,383]1 -21249 201.30 5,980,451.43 549,780.14 0.67 -212.49 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 MWD+IFR-AK-CAZ-SC(2) 1,678.04 29.99 135.80 1,611.84 1,519.22 -267.37 252.11 5,980396.89 549,831.31 2.15 -267.37 MWD+IFR-AK-CAZ-SC (2) 1,771 OD 3338 135.72 1,690.93 1,598.31 -302.34 286.17 5,980362.15 549,865.60 3.65 -302.34 IIi1Ta0 AChi1$IIf1M(f 10 3/4" x 13-112' 1,777.33 3361 135.72 1,696.21 1,603.59 -304.85 28861 5,980,359.66 549,868.06 3.65 -304.85 MWD+IFR-AK-CAZ-SC(3) 1,801.61 34.53 134.79 1,716.32 1,623.70 -314.50 298.19 5,980,350.07 549,877.69 4.35 -314.50 MWD+IFR-AK-CAZ-SC(3) 1,896.66 37.81 133.50 1,79304 1,70D 42 -353.55 338.45 5,980,311.29 549,918.21 3.54 -353.55 MWD+IFR-AK-CAZ-SC(3) 1,991.93 40.86 131.83 1,8W,72 1,774.10 -394.45 382.87 5,980,270.70 549,962.89 339 -394.45 MWD+IFR-AK-CAZ-SC(3) 2,085.48 43.97 130.99 1,936.52 1.843.91) 436.61 43070 5.980,228.85 550,011.00 3.34 -436.61 MWD+IFR-AK-CAZ-$C(3) 2,184.36 47.16 129.49 2,00504 1,91242 481.73 484.06 5,980,18409 550,064.65 3.44 -481.73 MWD+1FR-AK-CAZ-SC(3) 2,276.23 50.08 12837 2,065.76 1,973.14 -525.22 537.53 5,980,140.96 550,118.40 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 5,980,095.36 550,177.48 3.40 -57122 MWD+IFR-AK-CAZ-SC(3) 2,464.98 55.35 124.47 2,179.57 2,086.95 -615.68 657.76 5,980,051.30 550,239.21 345 $15.68 MWD+IFR-AK-CAZ-SC(3) 2,559.60 5673 122.73 2,232.43 2,13981 -659.10 723.12 5,980,008.32 550.304.85 2.11 -659.10 MWD+IFR-AK-CAZ-SC(3) 2,653.87 58.79 122.43 2282.72 2,190.10 -702.03 790.31 5,979,965.84 550,372.32 2.20 -702.03 MWD+IFR-AK-CAZ-SC (3) 2,748.30 59.37 121.74 2,331.24 2,238.62 -745.06 858.95 5,979,92327 550,441.23 0.88 -745.06 MWD+IFR-AK-CAZ-SC (3) 2,84307 61.40 121.48 2,37807 2,28545 -788.24 929.11 5,979,880.56 550,511.67 2.16 -78824 MWD+IFR-AK-CAZ-SC (3) 2,937.25 65.11 121.93 2.420.45 2,327.83 -83244 1,000.65 5,979,83684 550,583.50 3.96 -832.44 MWD+IFR-AK-CAZ-SC(3) 3,032.88 69.13 121.16 2,457.62 2,365.00 -878.52 1,075.72 5,979,79127 550,658.87 427 -878.52 MWD+IFR-AK-CAZ-SC(3) 3,126.86 71.43 12137 2,489.33 2,396.71 -924.43 1,151.34 5,979,745.86 550,73478 2.46 -924.43 MWD+IFR-AIC-CAZ-SC(3) 3,221.95 72.62 121.37 2,518.67 2,426.05 -971.51 1,228.56 5,979,69929 550,812.31 1.25 -971.51 MWD+IFR-AK-CAZ-SC(3) 3,316.46 73.03 121.69 2,546.58 2,453.96 -1,018.73 1,305.53 5,979,652.59 550,889.57 0.54 -1,018.73 MWD+IFR-AK-CAZ-SC(3) 3410.86 73.34 122.71 2,573.89 2,481.27 -1,066.89 1,381.99 5,979,60495 550,966.35 1.09 -1,066.89 MWD+IFR-AK-CAZ-SC(3) 3,505.07 73.21 122.55 2,601.29 2,508.67 -1,116.05 1,458.78 5,979,556.30 551,043.45 0.21 -1,116.05 MWD+IFR-AK-CAZ-$C(3) 3,60142 7321 122.70 2,628.83 2,536.21 -1,165.27 1,535.65 5,979,507.59 551,12065 0.15 -1,165.27 MWD+IFR-AK-CAZ-SC(3) 3,696.85 73.21 12229 2,656.40 2,563.78 -1,214.35 1,612.72 5,979,459.03 551,19803 0.41 -1,214.35 MWD+IFR-AK-CAZ-SC(3) 3,791.46 73.30 120.98 2,683.66 2,591.04 -1,2618] 1,689.85 5,979,412.03 551,27546 1.33 -1,261.87 MWD+IFR-AK-CAZ-SC(3) 3,886.74 73.14 148.95 2,711.17 2.618.55 -1,307.43 1,768.88 5,979,366.99 551.354.78 2.05 -1,30743 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 5,979,32295 551,434.51 0.70 -1,352.00 MWD+IFR-AK-CAZ-$C(3) 4,07641 73.30 119.87 2,766.13 2,673.51 -1,396.88 1,92684 5,979,278.59 551,513.31 0.32 -1,39888 MWD+IFR-AK-CAZ-SC(3) 4,1]1.02 73.17 118.99 2,793.42 2,700.80 -1,441.40 2,005.73 5,979,234.61 551,59249 0,90 -1,441.40 MWD+IFR-AK-CAZ-SC(3) 4,266.02 73.08 119.53 2,821.02 2,72840 -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 7301 119.04 2,848.57 2,755.95 -1,530.01 2,163.83 5,979,147.05 551,751.15 0.50 -153001 MWD+IFR-AK-CAZ-SC(3) 10192017 4: 12.07PM Page 3 COMPASS 5000.14 Build 85 ConocoPhiliips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 1H-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: Rig: 1H-102 North Reference: True Wellbore: 11-1-1021-3 Survey Calculation Method: Minimum Curvature Design: 11-1-1021-3 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVo TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) 1`) P) (usft) (usft) (usft) (usft) (It) (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 5,979,102.93 551,830.66 074 -1,57466 MWD+IFR-AK-CAZ-SC(3) 4,549.81 72.87 12006 2,904.19 2,811.57 -1,619.57 2,321.11 5,979,058.54 551,90801 0.30 -1,619.57 MWD+IFR-AK-CAZ-SC(3) 4,644.52 73.20 118.40 2,931.82 2,83920 -1,663.81 2,400.16 5,979,01484 551,988.35 1.71 .1,663.81 MWD+IFR-AK-CAZ-SC(3) 4.739.99 72.42 114.51 2,960.05 2,867.43 -1,704.44 2,481.79 5,978,974.75 552,070.24 398 -1.704.44 MWD+IFR-AK-CAZ-SC(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+1FR-AK-CAZ-SC(3) 4,833.76 72.48 108.23 2,988.44 2,895.82 -1,736.30 2,58524 5,978,94345 552,15389 4.51 -1,736.30 MWD+IFR-AK-CAZ-SC(3) 4,928.09 72.21 103.78 3,017.06 2,92444 -1,761.08 2,651.62 5,978,919.24 552,24042 4.50 -1,76108 MWD+IFR-AK-CAZ-SC(3) 5,022.87 71.11 10068 3.046.89 2,954.27 -1780.14 2,739.52 5,978,900.76 552,328.44 3.31 -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 -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 3.61 -1,793.69 MWD+IFR-AK-CAZ-SC(3) 5,211.19 72.12 93.77 3,106.29 3,013.67 -1,802.09 2,916.77 5,978,879.99 552,505.81 3.25 -1,80209 MWD+IFR-AK-CAZ-SC(3) 5,305.75 71.74 88.59 3.13564 3,043.02 -1,803.94 3,0D6.61 5,978,878.73 552,595.65 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 5.978,88529 552,684.94 4.85 -1,79798 MWD+IFR-AK-CAZ-SC(3) 5,495.26 72.32 81.29 3,194.64 3,102.02 -1786.21 3,185.70 5,978.897.65 552,774.60 2.56 -1,786.21 MWD+IFR-AK-CAZ-SC(3) 5,590.01 72.15 76.05 3,223.57 3,130.95 -1768.49 3,274.13 5,978,915.95 552,862.91 5.27 -1,768.49 MWD+IFR-AK-CAZ-SC(3) 5,685.45 7261 70.23 3,252.48 3,159.86 -1,742.11 3,351.14 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 -1,707.48 3,444.24 5,978,978.08 553,032.59 5.80 .1,707.48 MWD+IFR-AK-CAZ-SC(3) 5,874.02 73.87 63.54 3,307.23 3,214.61 -1667.90 3,525.49 5,979,01819 553,113.57 1.34 -1.667.90 MWD+IFR-AK-CAZ-SC (3) 5,96869 74.38 63.99 3,333.12 3,240.50 -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 74.61 63.93 3,358.38 3,265.76 -1,587,68 3,688.97 5,979,09949 553,276.50 0.25 -1,58766 MWD+IFR-AK-CAZ-SC(3) 6,15696 7468 58.30 3,383.23 3,29061 -1.544.01 3,768.12 5,979,143.67 553,355.35 5.79 -1,544.01 MWD+IFR-AK-CAZ-SC(3) 6,252.33 7403 54.53 3,408.96 3,316.34 -1,49322 3,844.61 5,979,194% 553,431.50 3.87 -1493.22 MWD+IFR-AK-CAZ-SG(3) 6,346.97 72.68 5105 3.436.08 3,34346 -1,43841 3,916.82 5,979,25025 553,503.33 3.80 -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 3,985.58 5,979,309.31 553,571.69 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 5,979,372.44 553,63742 3.18 -1,317.09 MWD+IFR-AK-CAZ-SC(3) 6,58521 73.18 41.30 3,507.14 3,414.52 -1,283.63 4083.10 5,979,406.11 553,668.57 7.43 -1,28363 MWD+1FR-AK-CAZ-SC(3) 6,632.17 72.64 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 13) 6,727.59 71,99 32.96 3,54995 3,457.33 -1,17560 4165.17 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 2359 3,606.48 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 4,28244 5,979,758.73 553,865.56 4.09 -93228 MWD+IFR-AK-CAZ-SC(3) 7,104.01 73.90 18.26 3,661.82 3,569.20 -848.34 4,311.14 5,979,84285 553,893.70 199 -848.34 MWD+IFR-AK-CAZ-SC (3) 7,198.95 7327 13.49 3,688.66 3,596.04 -760.78 4,338.05 5,979,93067 553,918.03 4.86 -76078 MWD+IFR-AK-CAZ-SC(3) 7,293.52 74.08 7.89 3,715.26 3,622.64 -67164 4,352.87 5,980,019.81 553,934.25 5.75 -671.64 MWD+IFR-AK-CAZ.SC(3) 7,38786 74.53 4.10 3,740.79 3,648.17 -581.33 4,362.35 5,980,110.17 553,943.13 3.90 -581.33 MWD+IFR-AK-CAZ-SC(3) 7,481.81 74.18 440 3,766.13 3,673.51 -491.11 4,369.05 5,98D,200.43 553,949.24 048 -491.11 MWD+IFR-AK-CAZ-SC(3) 7,576.96 74.34 2.50 3,791.94 3,699.32 -399.70 4,374.% 5,980,291.86 553,954.15 1.93 -399.70 MWD+IFR-AK-CAZ-SC (3) 7,646.00 75.99 2.54 3,80962 3,717.00 -333.02 4,377.50 5.980,358.55 553,956.64 2.39 -333.02 NOT an ACfwl Survey 7-6/8" x 9-7/8" 7,646.06 7599 2.54 3,809.63 3,717.01 -332.97 4,37750 5,980,358.60 553,956,64 2.39 -332.97 MWD-INC_ONLV(4) 101,32017 4: 12:07PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1 H-102 Project: Kuparuk River Unit TVD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1H Pao MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Well: Rig: 111-102 North Reference: True Wellbore: 1H-10213 Survey Calculation Method: Minimum Curvature Design: 1 H-10213 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +El -W Northing Easting DLS Section (usft) (°) (1) Wall) (usft) (usft) (usft) (ft) (ft) (°/100-) (ft) Survey Tool Name 7,661.35 77.16 1.83 3,813.18 3,720.56 -318.11 4,378.06 5,980,37347 553,957.11 8.89 -318.11 MWD-INC_ONLV(4) 7,689.89 79.34 2.34 3,818.99 3,726.37 -290.18 4,379.08 5,980,401.39 553,95794 7.84 -290.18 MWD-INC_ONLY (4) 7,73646 84.21 3.13 3,825.65 3,733.03 -244.16 4,381.28 5,98,44143 553,959.84 10.59 -244.16 MWD-INC_ONLV(4) 7,782.81 88.69 3.49 3,828.52 3,735.90 -197.99 4,383.95 5,960,49361 553,98220 9.70 -19.99 MWD-INC_ONLV(4) 7,828.10 91.81 3.55 3.828.33 3,735.71 -15239 4,386.73 5.980,538.82 553.964.68 6.89 -15239 MWD+IFR-AK-CAZ-SC(5) 7,917.34 92.12 3.52 3,825.27 3.732.65 -63.77 4,392.23 5,980,627.86 553,969.59 0.35 -63.77 MWD+IFR-AK-CAZ-SC(5) 7,96247 91.54 3.19 3,823.82 3,731.20 -1874 4,394.87 5,980,87291 553,971.93 1.48 -18.74 MWD+IFR-AK-CAZ-SC(5) 8,012.52 91.06 169 3,822.69 3,730.07 31.25 4,397.00 5,98,722.90 553,97373 3.15 31.25 MWD+IFR-AK-CAZ-SC(5) 8,05942 90.79 0.92 3,821.93 3,729.31 78.13 4,398.07 5,980,76979 553,97449 174 78.13 MWD+IFR-AK-CAZ-SC(5) 8,10677 90.68 359.56 3,821.32 3,726.70 125.47 4,398.27 5,980,817.13 553,974.37 2.88 12547 MWD+IFR-AK-CAZ-SC(5) 8,156.58 90.71 35875 3,820.72 3,728.10 17527 4,397.53 5,980,866.92 553.973.31 1.63 175.27 MWD+IFR-AK-CAZ-SC(5) 8,201.93 91.59 359.54 3,81981 3,727.19 220.61 4,396.86 5,980,912.24 553.972.33 261 220.61 MWD+IFR-AK-CAZ-SC(5) 8,296.99 90.82 359.72 3,817.81 3,725.19 315.65 4,396.24 5,981,007.26 553,971.09 0.83 31565 MWD+IFR-AK-CAZ-SC(5) 8,391.15 9020 1.51 3,816.97 3,724.35 409.79 4,397.25 5.981,101.41 553,971.48 2.01 409.79 MWD+IFR-AK-CAZ-SC(5) 8,48662 89.93 0.% 3,816.86 3,724.24 505.24 4,399.31 5,981,19886 553.972.90 0.64 50524 MWD+IFR-AK-CAZ-SC(5) 8,579.86 89.70 1.71 3,817.17 3,724.55 598.45 4,40148 5.981,290.07 553,974.46 0.84 598.45 MWD+1FR-AK-CAZ-SC(5) 8,627.48 90.30 0.66 3,817.17 3,724.55 646.06 4,40247 5,981,33768 553,975.13 2.54 64606 MWD+IFR-AK-CAZ-SC(5) 8,674.57 90.29 359.54 3,816.92 3,724.30 693.15 4,402.55 5,981,384.77 553,974.90 2.38 693.15 MWD+IFR-AK-CAZ-SC(5) 8,76970 8962 358.37 3,817.00 3.724.38 788.26 4,400.82 5,981,479.85 553,972.54 1.42 788.26 MWD+IFR-AK-CAZ-SC(5) 8,864.54 88.83 357.37 3,818.28 3,72566 863.03 4,39.29 5,981,574.58 553,968.38 1.34 883.03 MWD+1FR-AK-CAZ-SC(5) 8,96045 8868 357.09 3,820.36 3,727.74 978.80 4,39266 5,981,670.32 553,963.12 0.33 978.80 M`ND+IFR-AK-CAZ-SC(5) 9,055.10 87.19 359.04 3,823.78 3,731.18 1073.33 4,389.46 5,981,764.81 553,959.30 2.59 1,073.33 MWD+IFR-AK-CAZ-SC(5) 9,14982 87.94 358.94 3,827.80 3,735.18 1,16].95 4,387.80 5,981,859.41 553,957.00 0.80 1,167.95 MWD+IFR-AK-CAZ-SC(5) 9,245.39 88.64 35834 3,830.65 3,738.03 1,263.46 4,385.86 5,981,95489 553,954.44 076 1.263.46 MWD+IFR-AK-CAZ-SC(5) 9,339.41 88.52 0.09 3,832.98 3,740.36 1,357.44 4,384.90 5.982,04886 553,952.86 1.44 1,357.44 MWD+IFR-AK-CAZ-SC(5) 9,434.35 88.72 359.99 3,835.27 3,742.65 1,452.35 4,384.97 5,982,14376 553,952.29 024 1452.35 MWD+IFR-AK-CAZ-SC(5) 9,52781 90.16 359.62 3,836.18 3,743.56 1,545.80 4,384.65 5,982.237.20 553,951.36 1.59 1,545.80 MWD+IFR-AK-CAZ-SC(5) 9,622.31 90.53 35984 3.835.61 3,742.99 1,640.30 4,384.20 5,982,33168 553,950.29 046 1,640.30 MWD+IFR-AK-CAZ-SC(5) 9,717.26 90.24 357.05 3,834.97 3,742.35 1,73520 4,381.63 5,982426.56 553,947.08 2.95 1.735.20 MWD+IFR-AK-CAZ-SC(5) 9,812.51 90.63 353.91 3,83425 3,74163 1,830.14 4,374.12 5,982,52143 553,936.95 3.32 1,830.14 MWD+IFR-AK-CAZ-SC(5) 9,907.44 90.73 351.74 3,833.12 3,740.50 1,924.32 4,362.27 5,982,615.52 553,926.47 2.29 1,924.32 10WD+1FR-AK-CAZ-SC (5) 10,00227 9022 350.65 3,832.34 3,73972 2,018.03 4,347.75 5,982,709.12 553,911.34 1.27 2,018.03 MWD+1FR-AK-CAZ-SC(5) 10,096.95 88.84 349.60 3,833.11 3,74049 2,111.30 4,331.52 5,982,80227 553,894.49 1.83 2,111.30 MWD+IFR-AK-CAZ-SC(5) 10,192.81 89.39 348.86 3,834.60 3,741.98 2,205.45 4,31361 5,982,896.30 553,875.96 0,96 2,205.45 MWD+1FR-AK-CAZ-SC(5) 10,287.83 89.48 346.36 3,835.53 3,742.91 2,29825 4,293.22 5,982,988.95 553,854.96 2.63 2,298.25 MWD+IFR-AK-CAZ-SC(5) 10,381.89 89.54 345.19 3,836.34 3,74372 2,389.42 4,270.11 5,983,07996 553,831.25 1.25 2,38942 1vWD+IFR-AK-CAZ-SC(5) 10,477.13 88.47 347.20 3,837.99 3,745.37 2,481.89 4,247.39 5,983,17226 553,807.92 2.39 2,481.89 MWD+IFR-AK-CAZ-SC(6) 10,572.69 89.29 349.51 3,839.86 3,747.24 2,575.46 4,228.10 5,983,265.69 553,788.02 2.56 2,57546 MWD+IFR-AK-CAZ-SC(5) 10,666.29 89.51 352.07 3,840.84 3,748.22 2,667.84 4,213.13 5,983,357.96 553,77243 2.74 2,667.84 1vWD+1FR-AK-CAZ-SC(5) 10,761,05 8824 355.86 3,842.70 3,750.08 2,762.04 4,203.17 5,983,45208 553,761.85 4.22 2,762.04 MWD+IFR-AK-CAZ-SC(5) 101912017 4:12:07PM Page 5 COMPASS 5000.14 Build 85 Survey i Conocolohillips Definitive Survey Report Map Company: NADConversion Local Co-ordinate Reference: Well Rig: 1 H-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) Well: Rig: 1H-102 North Reference: True Wellbore: 1H-10213 Survey Calculation Method: Minimum Curvature Design: 1 H-10213 Database: OAKEDMP2 Survey 10/9/2017 4: 12:07PM Page 6 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc AN TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (') (') (usft) (usft) (usft) (usft) (ft) (ft) ('/100') (ft) Survey Tool Name 10,85604 8503 359.83 3,84828 3,75566 2,856.76 4,199.60 5,983,54678 553.757.65 5.37 2.856.76 MWD+IFR-AK-CAZ-SC(5) 10,950.31 63.30 2.18 3,857.86 3,765.24 2,950.52 4,201.24 5,983,640.53 553,75867 309 2,950.52 MWD+IFR-AK-CAZ-SC(5) 11,046.10 84.10 146 3,868.37 3,775.75 3,045.68 4,204.26 5,983,73570 553,761.06 1.12 3,04568 MWD+IFR-AK-CAZ-SC(5) 11,140.41 86.98 0.23 3,875.71 3,783.09 3,139.68 4,205.65 5,983,82970 553,761.83 3.32 3,139.68 MW13+1FR-AK-CAZ-SC(5) 11,235.63 90.45 35864 3,877.84 3,785.22 3,234.86 4,20471 5,983,924.86 553,760.26 4.01 3,234.86 MWD+IFR-AK-CAZ-SC(5) 11,330.49 90.48 358.00 3,877.07 3,784.45 3,329.67 4,201.93 5,984,019.65 553,756.85 Des 3,329.67 MWD+1FR-AK-CAZ-SC(5) 11,424.69 9063 359.37 $,876.16 3,783.54 3.423.84 4,19976 5,984.113.79 553,754.06 1.46 3,423.64 MWD+IFR-AK-CAZ-SC(5) 11,518.98 92.53 0.39 3,873.56 3,780.94 3,518.09 4,199.57 5,984,208.03 553,753.24 2.29 3,51809 MWD+IFR-AK-CAZ-SC(5) 11,613.53 93.55 2.39 3868.55 3,775.93 3,612.47 4,20185 5.984,30241 553,754.91 2.37 3,612.47 MM/D+IFR-AK-CAZ-SC(5) 11,703.96 92.13 5.69 3,864.06 3,771.44 3,702.55 4,208.22 5,984,392.52 553,760.67 3.97 3,702.55 MWD*IFR-AK-CAZ-SC(5) 11,79648 90.59 5.92 3,861.87 3,769,25 3,79457 4,217.57 5,984,484.59 553.769.42 1.68 3,794.57 MWD+IFR-AK-CAZ-SC(5) 11,888.04 91.21 6.88 3,860.43 3,767.81 3,885.55 4,227.78 5,984,57562 553,779.02 1.25 3,88555 MWD+IFR-AK-CAZ-SC(5) 11,979.75 9106 7.95 3,858.61 3,76599 3.976.47 4,239.61 5,984.66662 553.790.25 1.18 3,97647 MWD+IFR-AK-CAZ-SC(5) 12,071.78 90% 7.57 3,856.99 3,764.37 4,067.64 4,252.04 5,984)57 .86 553802.07 0.43 4,067.64 MWD+IFR-AK-CAZ-SC(5) 12,161.75 90.80 ].00 3,855.61 3,762.99 4,156.88 4,263.44 5,984,847.16 553,812.88 0.66 4,15688 MWD+IFR-AK-CAZ-SC(5) 12,255.20 90.15 5.95 3,854.83 3,762.21 4,249.73 4,273.98 5,984,940.07 553,822.81 132 4,24973 MWD+IFR-AK-CAZ-SC(5) 12,347]1 88.31 2.31 3,856.08 3,76346 4,34197 4,28064 5,985,032.34 553,828.86 4.41 4,341.97 MWD+IFR-AK-CAZ-SC(5) 12,440.90 89.86 359.72 3,857.57 3,764.95 4,435.12 4,28229 5,985,125.49 553,829.89 3.24 4,435.12 MWD+IFR-AK-CAZ-SC(5) 12,532.79 89.86 358.54 3,85739 3,765.17 4,52].00 4,280.90 5,985,217.35 553,827.89 1.28 4,52700 MWD+IFR-AK-CAZ-SC (5) 12,623.89 90.19 355.39 3,857.75 3,765.13 4,617.% 4,276.07 5,985,308.27 553,82246 348 4,617.96 MWD+IFR-AK-CAZ-SC(5) 12,716.14 89.18 353.72 3,858.26 3,765.64 4,709.79 4,267.32 5,985,400.03 553,813.10 2.12 4,709.79 MWD+IFR-AK-CAZ-SC(5) 12,808.91 87.99 350.29 3,860.55 3,767.93 4,801.61 4,254.42 5,985,491.76 553,799.60 3.91 4,801.61 MWD+IFR-AK-CAZ-SC(5) 12,902.83 85.66 345.91 3,865.75 3,773.13 4,893.34 4,235.10 5,985,583.35 553,779.67 5.28 4,893.34 MWD+1FR-AK-CAZ-SC(5) 12,991.33 87.16 342.83 3,871.30 3,77868 4,978.39 4,211.30 5,985,668.23 553,755.31 3.86 4,978.39 MWD+IFR-AK-CAZ-SC(5) 13,084.51 91.52 344.00 3,872.37 3,779.75 5,067.67 4,184.71 5,985,757.32 553,728.14 484 5,6]67 MWD+IFR-AK-CAZ-SC(5) 13,17687 91.10 339.29 3,870.26 3.77764 5,155.28 4,155.65 5,985,84473 553,698.49 5.12 5.155.28 MWD+IFR-AK-CAZ-SC(5) 13,269.09 90.75 332.94 3,868.77 3,776.15 5,239.55 4,118.33 5,985,92874 553,660.62 6.90 5,239.55 MWD+1FR-AK-CAZ-SC(5) 13,36043 90.40 327.57 3,867.85 3,775.23 5,318.82 4.073.03 5,986,00770 553,614.80 5.89 5,318.82 MWD+IFR-AK-CAZ-SC(5) 13,453.23 9149 322.82 3,866.32 3,773.70 5,394.98 4,020.08 5,986,083.51 553,561.35 5.25 5,394.96 MWD+IFR-AK-CAZ-SC (5) 13,546.32 91.71 319.21 3,863.72 3,771.10 5,467.30 3,961.55 5,986,15543 553,502.36 3.68 5,467.30 MWD+IFR-AK-CAZ-SC (5) 13,638.36 92.34 31576 3,860.46 3,767.84 5,535.09 3,89840 5,988,222.80 553,439.77 3.81 5,535.09 MWD+IFR-AK-CAZ-SC(5) 13,73067 92.23 310.92 3,856.78 3,764.16 5,598.38 3,832.34 5,986,285.64 553,372.29 5.24 5,598.38 MW0+IFR-AK-CAZ-SC(5) 13,82254 92.64 306.99 3,852.88 3,760.26 5,656.08 3,76098 5,986,342.85 553,300.56 4.30 5,656.08 MWD+IFR-AK-CAZ-SC(5) 13,914.50 91.25 303.60 3,849.76 3,757.14 5,709.17 3,685.98 5,986,395.44 553,225.21 3.98 5,709.17 MWD+IFR-AK-CAZ-SC(5) 14,004.35 68.89 302.78 3,84965 3,757.03 5,758.35 3.610.79 5,988,444.12 553.149.71 2.78 5,758.35 MWD+IFR-AK-CAZ-SC(5) 14,096.79 90.12 301.87 3,850.44 3,757.82 5,807.78 3,532.68 5,986,49302 553,071.28 1.66 5,807.78 MWD+IFR-AK-CAZ-SC(5) 14,188.71 90.68 302.23 3,849.80 3,757.18 5,856.55 3,454.77 5,986,54126 552,993.06 0.72 5,856.55 MWDHFR-AK-CAZ-SC(5) 14,281.10 90.99 303.01 3,848.46 3,755.84 5,906.35 3,376.97 5,986,590.56 552,91493 0.91 5,906.35 MWD+IFR-AK-CAZ-SC(5) 14,373.18 91.27 303.58 3,84664 3,754.02 5;956.89 3,300.01 5986,64058 552 83]68 0.69 5,956.89 MWD+IFR-AK-CAZ-SC(5) 14,465.23 91.57 30620 3,844.36 3.751]4 6,009.52 3,224.54 5,986,692.70 552,761.84 2.86 6,009.52 MWD+IFR-AK-CAZ-SC(5) 10/9/2017 4: 12:07PM Page 6 COMPASS 5000.14 Build 85 Company: NADConversion Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Rig: 1H-102 Wellbore: 1H-1021_3 Design: 1H-1021_3 Survey MD Inc Azi TVD TVDSS (usft) (o) (°) (usft) (usft) 14,55]47 9024 309.01 3,842.90 3.750.28 14,625.81 89.16 308.79 3,84326 3,750.64 14,66600 89.16 308.79 3,843.88 3,75126 4-1/2" z 6-3/4" 6,146.41 PROJECTED to TD 14.66600 89.16 308.79 3.844.14 3,751.52 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: 6,146.41 3,051.39 5,986,82843 Well Rig: 1 H-102 IH -102 actual @ 92.62usft (Doyon 142) 1 H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 Map Final Definitive Survey Map +N/S +E/ -W Northing (usft) (usft) (ft) 6,065.79 3,15148 5,985,748.49 6,10671 3,098.30 5,98679104 6,135.13 3.065.42 5,986,817.25 6,146.41 3,051.39 5,986,82843 Well Rig: 1 H-102 IH -102 actual @ 92.62usft (Doyon 142) 1 H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 Map Final Definitive Survey Vertical Verified and Signed -off Easting DLS Section 1 have checked to the best of my ability that the following data is correct - (ft) (o/100') (ft) Survey Tool Name 552,688.42 337 6,065]9 MWD+IFR-AK-CAZ-SC(5) 552,634.% 1.61 6,108.71 MWD+IFR-AK-CAZ-SC(5) 552,60191 000 6,135.13 riDT all ACrDaI $UIYly 552,587.81 0.00 6,146.41 PROJECTED to TD 10192017 4 1207PM Page 7 COMPASS 5000.14 Build 85 Final Definitive Survey Verified and Signed -off All targets andbr well position objectives have been achieved. [,I Yes ❑ No 1 have checked to the best of my ability that the following data is correct - E] Surface Coordinates 0 Declination & Convergence P GRS Survey Corrections F4 Survey Tool Codes Brandon Temple Digitally signed by Brandon Temple SLB DE: N Date: 2017.10.0914:02:07-08'00' Client Representative. R9arr9rotlh'14b%'Mea4 Kelsey Hallford .niraamyl.0vbrnawrn rxA Date. 10103/17 10192017 4 1207PM Page 7 COMPASS 5000.14 Build 85 RECEIVED OCT 2 6 2017 FINAL AOGCC ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad 1H -102L3 1H -102L3 NAD 83 ConocoPhillips Definitive Survey Report 09 October, 2017 21 7103 28 75 1 fy ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Rig: 1H-102 Wellbore: 1H-1021.3 Design: 1H-1021-3 ConocoPhillips Definitive Survey Report Local Cc -ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Rig: 111-102 1 H-102 actual @ 92.62usft (Doyon 142) 1H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well Rig: 1H-102 Audit Notes: Well Position +NI -S 0.00 usft Northing: 5,980,414.37 usft Latitude: 70° 21'27.583 N ACTUAL +E/ -W 0.00 usft Easting: 1,669,609.08 usft Longitude: 149" 36' 1.638 W Position Uncertainty Direction 0.00 usft Wellhead Elevation: usft Ground Level: 54.00 usft Wellbore 1H-10213 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 0 1°I (nT) BGGM2017 9/30/2017 17.47 80.95 57,489 Design 1H -102L3 Date 10/9/2017 Audit Notes: To Map Map Version: 1.0 Phase: ACTUAL Tie On Depth: 7,576.96 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 1,050.36 (usft) lush) (usft) (°) 1,777.33 38.62 0.00 0.00 0.00 Survey Program Date 10/9/2017 From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 67.62 1,009.261H-102 Srvy 1 -SLB GWD70 It H-102) GYD-GC-SS Gyrodata gyro single shots 8124/201710:04 1,050.36 1,678.041H-102 Srvy 2 -SLB MWD+GMAG(1 H- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 8/24/201710:12 1,777.33 7,576.961H-102 Srvy 3-SLB_MWD+GMAG(1H- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 8/27/201712:16 7,646.06 7,782.811H-10213 Srvy 1-SLB_MWD-INC_Filler MWD -INC -ONLY MWD -INC -ONLY -FILLER 9/30/2017 9:28: 7,782.81 14,625.811H-10213 Srvy 2-S B_MWD+GMAG(1 MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 9/30/2017 9:36: Survey 10/92017 2:40.39PM Page 2 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EAW Northing Easting DLS Section (usft) (1 (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 38.62 0.00 0.00 38.62 -54.00 0.00 0.00 5,980,414.37 1,689,609.08 0.00 0.00 UNDEFINED 67.62 0.19 41.29 67.62 -2500 0.04 0.03 5,980.41440 1,689,609.12 0.66 0.04 GYD-GC-SS(1) 165.90 0.45 132.01 165.90 7328 -0.10 0.43 5,980,414.27 1,889,60851 0.50 -0.10 GYD-GC-SS(1) 258.98 1.01 128.15 258.97 166.35 -0.85 1.34 5,980,413.52 1,689,61043 0.60 -0.85 GYD-GC-SS(1) 354.48 3.34 138.19 354.40 26178 -3.44 3.86 5,980,410.95 1,689,612.97 2.46 -3.44 GYD-GC-SS(1) 447.17 4.61 13526 446.86 354.24 -8.10 8.28 5,980,40632 1,689,61]42 1.39 -8.10 GYD-GC-SS(1) 539.82 5.77 132.42 539.13 446.51 -13.89 14.34 5,980,400.57 1,689,623.51 1.28 -13.89 GYD-GC-SS(1) 632.84 7.61 134.49 631.51 538.89 -21.36 22.19 5,9W,393 15 1,689,631 Al 1.99 -21 36 GYD-GC-SS (1) 725.82 877 137.82 723.54 630.92 -30.93 31.34 5,980,38365 1,689,64D62 1.35 -30.93 GYD-GC-SS(1) 82124 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) 10/92017 2:40.39PM Page 2 COMPASS 5000.14 Build 85 Company: Project: Site: Well: Wellbore: Design: Survey ConocoPhillips(Alaska) Inc.-Kupi Kuparuk River Unit Kuparuk 1H Pad Rig: 1H-102 1H-10213 1H-10213 MD Inc AZI (usft) (9 (9 91420 12.89 13961 1,009.26 14.89 136.85 1,050.36 15.72 135.96 1,144.89 17.17 134.37 1,239.16 20.84 13425 1,334.20 24.71 136.54 1,428.98 27.54 13749 1,523.25 28.14 137.93 1,618.09 28.94 137.33 1,678.04 29.99 135.80 1.77100 33.38 135.72 10 314" x 13-1/2" 1,777.33 33.61 135.72 1,801.61 34.53 134.79 1,896.66 37,81 133.50 1,991.93 40.86 131.63 2,086.48 43.97 130.99 2,184.36 47.16 129.49 2,276.23 50.08 12877 2,37148 53.12 127.35 2,464.98 55.35 124.47 2,55960 56.73 122.73 2,653.87 58.79 122.43 2,74880 59.37 121.74 2,843.07 61.40 121.48 2,937.25 65.11 121.93 3,032.88 69.13 121.16 3,126.86 71.43 121.37 3,221.95 72.62 121.37 3,316.46 73.03 121.69 3,410.86 73.34 12271 3,503.07 7321 122.55 3,601.42 73.21 12210 3,696.85 73.21 122.29 3,791.46 73.30 120.98 3,886.74 73.14 118.95 3,981.94 73.09 11964 4,076.41 73.30 119.87 4,171.02 73.17 118.99 4,266.02 73.06 119.53 4,360.46 73.01 119.04 ConocoPhillips Definitive Survey Report TVD TVDSS +N/ -S (usft) (usft) (usft) 908.57 815.95 -57.91 1.000.84 908.22 -74.90 1,040.49 947.87 -82.75 1,131.15 1,038.53 -10172 1,220.26 1,127.64 -123.16 1,307.88 1,215.26 -149.38 1,392.97 1.300.35 -179.92 1,476.33 1,383.71 -212.49 1,559.64 1,467.02 -24596 1.611.84 1.519.22 -267.37 1,690.93 1,598.31 -302.34 1,696.21 1,603.59 -304.85 1,716.32 1,623.70 -314.50 1,793.04 1700.42 -353.55 1,866.72 1,774.10 -394.45 1,936.52 1,84390 -436.61 2,005.04 1,912.42 481.73 2,065.76 1,973.14 -525.22 2,124.92 2,032.31) -571.22 2,179.57 2,086.95 -615.68 2,23243 2,139.81 -659.10 2,282.72 2,190.10 -702.03 2,331.24 2,238.62 -74506 2,378.07 2,285.45 -788.24 2,420.45 2,327.83 -832.44 2,457.62 2,365.00 -878.52 2,489.33 2,396.71 -924.43 2,51867 2,426.05 -971.51 2,546.58 2,453.96 .1,01873 2,573.89 2,481.27 .1066 89 2,601.29 2,508.67 -1,116.05 2,628.83 2,536.21 -1,16527 2,656.40 2,553.78 -1,214.35 2,683.66 2,591.04 A M1.87 2,711.17 2,618.55 -1,307.43 2,738.82 2,646.20 -1,352.00 2,766.13 2,673.51 -1,396.88 2,793.42 2,700.80 -1,441.40 2,821.02 2,728.40 -1,485.83 2,848.57 2,755.95 -1,530.01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Rig: 1 H-102 1 H-102 actual @ 92.62usft (Doyon 142) 1 H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 288.61 5,980.111 45 1889.899 66 298.19 5,980,101.86 1,689,909.30 338.45 5,980,063.08 1,689,949.82 382.87 5,98(1,02248 1,689,994.50 430.70 5,979,980.63 1890,04260 484.06 5,979,93587 1,690,09625 537.53 5,979,892.74 1,690,15000 596.31 5.979,847.13 1,69.209.07 657.76 5,979,803.07 1,690,270.80 723.12 5,979.760.09 1,690,336.45 790.31 5, 979, 717 61 1.690,403 91 858.95 5,979,675.03 1,690,472.82 929.11 5,979.632.32 1,690,543.26 1,000.65 5,979,588.60 1,690,615.08 1,075.72 5,979,54302 1,690,690.45 1,151.34 5,979,497.61 1,690,766.35 1,228.56 5,979,451.04 1,690,843.66 1,305.53 5,979,404.33 1,69.921.15 1,381.99 5,979,356.68 1,690,997.92 1,458.78 5,979,308.03 1,691,07502 1,535.66 5,979,259.32 1,691,152.22 1,612.72 5,979,210.75 1,691,229.59 1,689.85 5,979,163.75 1,691,307.03 1768.88 5,97.118.71 1,691,38834 1,848.32 5,979,074.66 1,691,466.07 1,926.84 5,979,030,30 1,691,544.67 2,005.73 5,978,986.31 1,691,62405 2,085.04 5,978,942.41 1,691,703.63 2,163.83 5,978,898.75 1,691,78270 DLS Map Map +E/ -W Northing Easting (usft) (ft) (ft) (°f 5390 5,980,35882 1,689,663.36 69.13 5,980,339.93 1,689,678.70 76.61 5, 980, 332.13 1, 689, 686.23 95.49 5,980,313.29 1,689,705.23 117.46 5,980,292.00 1,689,727.33 143.24 5,980,265.94 1,689,753.29 171.68 5,980,23560 1,689,781.92 201.30 5,980,203.23 1,689,811.75 23184 5,980,169.96 1,689,842.51 252.11 5,980,146.69 1,689,662.92 286.17 5,980,113.94 1,689,897.21 288.61 5,980.111 45 1889.899 66 298.19 5,980,101.86 1,689,909.30 338.45 5,980,063.08 1,689,949.82 382.87 5,98(1,02248 1,689,994.50 430.70 5,979,980.63 1890,04260 484.06 5,979,93587 1,690,09625 537.53 5,979,892.74 1,690,15000 596.31 5.979,847.13 1,69.209.07 657.76 5,979,803.07 1,690,270.80 723.12 5,979.760.09 1,690,336.45 790.31 5, 979, 717 61 1.690,403 91 858.95 5,979,675.03 1,690,472.82 929.11 5,979.632.32 1,690,543.26 1,000.65 5,979,588.60 1,690,615.08 1,075.72 5,979,54302 1,690,690.45 1,151.34 5,979,497.61 1,690,766.35 1,228.56 5,979,451.04 1,690,843.66 1,305.53 5,979,404.33 1,69.921.15 1,381.99 5,979,356.68 1,690,997.92 1,458.78 5,979,308.03 1,691,07502 1,535.66 5,979,259.32 1,691,152.22 1,612.72 5,979,210.75 1,691,229.59 1,689.85 5,979,163.75 1,691,307.03 1768.88 5,97.118.71 1,691,38834 1,848.32 5,979,074.66 1,691,466.07 1,926.84 5,979,030,30 1,691,544.67 2,005.73 5,978,986.31 1,691,62405 2,085.04 5,978,942.41 1,691,703.63 2,163.83 5,978,898.75 1,691,78270 DLS Vertical Section toll (ft) Survey Tool Name 2.35 -57.91 GVD-GC-SS(1) 2.22 -74.90 GVD-GC-SS(1) 2.10 -82.75 MWD+IFR-AK-CAZ-SC(2) 161 -101.72 MWD+IFR-AK-CAZ-SC (2) 3.89 -123.16 MWD+IFR-AK-CAZ-SC (2) 4.18 -149.38 MWD+IFR-AK-CAZ-SC(2) 3.02 -079.92 MWD+IFR-AK-CAZ-SC (2) 0.67 -212.49 MWD+IFR-AK-CAZ-SC(2) 0.90 -245.96 MWD+IFR-AK-CAZ-SC(2) 2.15 -267.37 MWD+IFR-AK-CAZ-SC(2) 3.65 -302.34T 8i1 �10DIi( $DN@}) 3.65 -304.85 MWDHFR-AK-CAZ-$C(3) 4.35 -314.50 MWD+IFR-AK-CAZ-SC(3) 3.54 -353.55 MWD+IFR-AK-CAZ-SC (3) 3.39 -39445 MWD+lFR-AK-CAZ-SC(3) 3.34 436.61 MWD+IFR-AK-CAZ-SC(3) 3.44 -481 73 MWD+IFR-AK-CAZ-SC (3) 3.23 -525.22 MWD+IFR-AK-CAZ-SC(3) 3.40 -57122 MWD+IFR-AK-CAZ-SC(3) 3.45 -615.68 MWD+IFR-AK-CAZ-SC (3) 2.11 -659.10 MWD+IFR-AK-CAZ-SC(3) 2.20 -702.03 MWD+IFR-AK-CAZ-SC(3) 0.88 -745.06 MWD+IFR-AK-CAZ-SC(3) 2.16 -788.24 MWD+IFR-AK-CAZ-SC (3) 3.96 -832.44 MWD+IFR-AK-CAZ-SC(3) 4.27 -876.52 MWD+IFR-AK-CAZ-SC(3) 2.46 -924.43 MWD+IFR-AK-CAZ-SC (3) 1.25 -971.51 MWD+IFR-AK-CAZ-SC (3) 0.54 -1,018.73 MWD+IFR-AK-CAZ-SC(3) 1.09 -1,065.69 MWD+IFR-AK-CAZ-SC(3) 0.21 -1.116.05 MWD+IFR-AK-CAZ-SC (3) 0.15 -1,165.27 MWD+IFR-AK-CAZ.SC(3) 0.41 -1.214.35 MWD+IFR-AK-CAZ-SC (3) 1.33 -1,261.87 MWD+IFR-AK-CAZ-SC (3) 2.05 -1,307.43 MWDHFR-AK-CAZ-SC (3) 070 -1,352.00 MWD+IFR-AK-CAZ-SC(3) 0.32 -1,396.88 MWD+IFR-AK-CAZ-SC(3) 0.90 -1,441.40 MWD+IFR-AK-CAZ-SC (3) 0.56 -1,485.83 MWD+IFR-AK-CAZ-SC(3) 0.50 -1,530.01 MW0+IFR-AK-CAZ-SC(3) 10/92017 2.'4D39PM Page 3 COMPASS 500014 Build 85 Company: Project: Site: Well: Wellbore: Design: Survey ConowPhillips(Alaska) Inc.-Kupl Kuparuk River Unit Kuparuk 1 H Pad Rig: 11-1-102 1H -102L3 1H-1021-3 MD Inc (usft) (") 4.455.58 72.90 4,549.81 72.87 4,644.52 73.20 4,739.99 72.42 4,785.24 72.31 4,833.76 72.48 4,928.09 72.21 5,022.87 71.11 5,070.23 7127 5,116.77 71.68 5,211.19 72.12 5,305.75 71.74 5,400.08 71.70 5,495.26 72.32 5,590.01 72.15 5,68545 7261 5,779.73 73.02 5,874.02 73.87 5,968.69 74.38 6,063.17 74.61 6,156.96 7468 6,252.33 74.03 6,346.97 72.68 6,441,76 72.16 6,53727 73.10 6,585.21 73.18 6,632.17 72.64 6,727.59 71.99 6,822.80 72.62 6,915.59 72.83 7,011.34 72.49 7,104.01 73.90 7,19895 73.27 7,293.52 74.08 7,387.86 74.53 7,481.81 74.18 7,576.96 74.34 7,646.00 75.99 7-618" x 9-718" 7,646.06 75.99 ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Rig: 1 H-102 1 H-102 actual @ 92.62usft (Doyon 142) 1H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 Map Map Azi TVD TVDSS +N/ -S +El -W Northing Easting 0 (usft) (usft) (usft) (usft) (ft) (ft) 119.77 2,876.45 2,783.83 -1,57466 2,243.05 5,978,85462 1,691,862.21 120.06 2,904.19 2,811.57 -1,819.57 2,321.11 5,978,810.23 1,69194055 118.40 2,931.82 2,839.20 -1,663.61 2,400.16 5,978,766.52 1,692,019.89 114.51 2,960.05 2,867.43 -1.704,44 2,481.79 5,978,726.43 1,692,101.78 110.47 2.974.06 2,881.44 -1,721.29 2,522.51 5,978,709.84 1.692,142.60 108.23 2,98844 2,895.82 -1,736.30 2,565.24 5,978,695.12 1,692,18542 10378 3,017.06 2,92444 -1,761.08 2,651.62 5,978,670.91 1,692,271.95 100.68 3,046.89 2.954.27 -1,780.14 2,739.52 5,978,65243 1692,359.97 98.69 3,062.16 2,969.54 -1,787.68 2,783.71 5,978,645.18 1,692.4N 21 96.97 3,07695 2,984.33 -1,793.69 2,827.43 5,978,639.46 1,692,447.96 93.77 3,106.29 3,013.67 -1,802.09 2,916.77 5,978,631.65 1,692,537.34 88.59 3,13564 3,043.02 -1,803,94 3,0%.61 5,978,630.38 1,692,627.18 63.77 3,165.24 3,072.62 -1.797.98 3,095.95 5,978,63693 1,692,716.47 81.29 3,19464 3,102.02 -1,786.21 3.185.70 5,978,649.29 1,692,806.13 76.05 3,223.57 3,130.95 -1,768.49 3,274.13 5,978,667.59 1692,894.44 7023 3,252.48 3.159.86 -1,742.11 3,361.14 5,978,694.53 1,692,98127 64.52 3,280.36 3,187.74 -1,70748 3,444.24 5,978,729.71 1,693,064.13 63.54 3,307.23 3214.61 -1,667.90 3,525.49 5,978,769.82 1,693,145.11 63.99 3,333.12 3,240.50 -1,627.64 3,607.17 5,978,81060 1,693,226.51 63.93 3,358.38 3,265.76 -1,587.88 3,688.97 5,978,851.10 1,693,308.04 58.30 3,383.23 3,290,61 -1,544.01 3,768.12 5,978,895.29 1,693,386.90 54.53 3,408.96 3,316.34 -1,493.22 3.844.61 5,978,946.57 1,693,463.05 51.05 3,436.08 3,343.46 -1,438.41 3,916.82 5.979,001.85 1,693,53489 48.05 3,484.71 3,372.09 -1,379.79 3,985.58 5,979,060.91 1,60,603.25 45.02 3,493.23 3,400.61 .1,317.09 4,051.72 5,979,12d 04 1,693,668.97 41.30 3,507.14 3,414.52 -1,283.63 4,083.10 5,979,157.70 1,693,700.13 38.72 3,520.94 3,428.32 -1,249.25 4,111.96 5,979,19226 1,693,728.76 32.96 3,549.95 3,457.33 -1,175.60 4,165.17 5,979,26626 1,693,781.48 2741 3,578.91 3,486.29 -1,097.23 4,210.74 5,979,344.92 1,693,826.53 23.59 3,605.48 3,513.86 -1,01727 4,248.88 5,979,425.12 1,693,864.14 19.50 3,635.02 3,54240 -932.28 4,282.44 5,979,510.32 1,693,897.14 1826 3,66162 3,569.20 -848.34 4,311.14 5,979,59444 1,693,92528 1349 3,688.66 3,598.04 -760.78 4,336.05 5,979,662.15 1,693,949.61 7.89 3,715.26 3,622.64 -671.64 4,352.87 5,979,77140 1,693,965.84 4.10 3,740.79 3,648.17 -581.33 4,362.35 5.978,861.76 1,693,974.73 4.40 3,766.13 3,673.51 491.11 4,369.05 5,979,95201 1,693,98084 2.50 3,791.94 3,699.32 -39970 4,374.56 5,980,043.45 1,693,985.75 2.54 3,809.62 3,717.00 -333.02 4,377.50 5,980,110.13 1,693,988.25 2.54 3,80963 3,717.01 -332.97 4,377.50 5.980,110.19 1,693.98825 10/92017 2:40.39PM Page 4 COMPASS 5000.14 Build 85 Vertical DLS Section (°1100') IN) Survey Tool Nam 074 -1,574.66 MWD+IFR-AK-CAZ-SC(3) 0.30 -1,619.57 MWD+IFR-AK-CAZ-SC(3) 171 -1,663.81 MWD+IFR-AK-CAZ-SC (3) 3.96 -1,704.44 MWD+IFR-AK-CAZ-SC (3) 8.33 -1,721.29 MWD+IFR-AK-CAZ-SC(3) 4.51 -1736.30 MWD+IFR-AK-CAZ-SC(3) 450 -1,761.08 MWD+IFR-AK-CAZ-SC(3) 3.31 -1,780.14 MWD+IFR-AK-CAZ-SC(3) 3.99 -1,787.68 MWD+IFR-AK-CAZ-SC(3) 3.61 -1,793,69 MWD+IFR-AK-CAZ-SC (3) 3.25 -1,802.09 MWD+IFR-AK-CAZ-SC (3) 5.22 -1,803.94 MWD+IFR-AK-CAZ-SC 13) 4.85 -1,797.98 MWD+IFR-AK-CAZ-SC(3) 2.56 -1,786.21 MWD+IFR-AK-CAZ-SC(3) 5.27 -1,768.49 MWD+IFR-AK-CAZ-SC (3) 5.83 -1,742.11 MWD+IFR-AK-CAZ-SC 13) 5.80 -170748 MWD+IFR-AK-CAZ-SC(3) 1.34 -1,667.90 MWD+IFR-AK-CAZ-SC (3) 071 -1,627.64 MWD+IFR-AK-CAZ-SC (3) 0.25 -1,58768 MWD+IFR-AK-CAZ-SC(3) 5.79 -1,544.01 MWD+IFR-AK-CAZ-SC(3) 3.87 -1,493.22 MWD+IFR-AK-CAZ-SC (3) 3.80 -1,43841 MWD+IFR-AK-CAZ-SC(3) 3.07 -1,379.79 MWD+IFR-AK-CAZ-SC(3) 3.18 -1,317.09 MWD+IFR-AK-CAZ-SC(3) 743 -1,283.63 MM+IFR-AK-CAZ-SC(3) 5.38 -1,249.25 MWD+IFR-AK-CAZ-5C(3) 579 -1,175.60 MWD+IFR-AK-CAZ-SC (3) 5.59 -1,097.23 MWD+IFR-AK-CAZ.SC(3) 3.94 -1017.27 MWD+IFR-AK-CAZ-SC(3) 4.09 -932.28 MWD+IFR-AK-CAZ-SC(3) 1.99 -848.34 MWD+IFR-AK-CAZ-SC(3) 4.86 -760.78 MWD+IFR-AK-CAZ-SC(3) 5.75 -671.64 MWD+IFR-AK-CAZ-SC (3) 3.90 -581.33 MWD+IFR-AK-CAZ-SC (3) 0.48 -491.11 MWD+IFR-AK-CAZ-SC(3) 1.93 -399.70 MWD+IFR-AK-CAZ-SC(3) 2.39 -333.02 NOT 88 Aeluei $BNBy 2.39 -332.97 MWD -INC ONLV(4) 10/92017 2:40.39PM Page 4 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Rig: 1H-102 Wellbore: 1 H-10213 Design: 1H-1021-3 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Rig: 11-1-102 1 H-102 actual @ 92.62usft (Doyon 142) 1H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 1"12017 2 40: 39PM Page 5 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +NIS +El -W Northing Easting DLS Section (usft) (1) (1 (usft) (usft) (usft) (usft) (ft) (ft) (.1100') (ft) Survey Tool Name 7.661.35 77.16 1.83 3,813.18 3,720.56 -318.11 4,378.0 5,980,125.05 1,693,988.72 8.89 -318.11 MWD-INC_ONLY(4) 7.689.89 79.34 2.34 3,818.99 3,726.37 -290.18 4,379.08 5,98,15297 1.693.989 55 7.84 -290.18 MWD -INC -ONLY (4) 7,736.46 84.21 3.13 3,82565 3,733.03 -244.16 4,381.28 5,980,19901 1,693,991.45 10.59 -244.16 MWD-INC_ONLY (4) 7,78281 88.69 349 3,828.52 3,735.90 -197.99 4,383.95 5,980,245.19 1,693,993.82 9.70 -197.99 MWD-INC_ONLY(4) 7,828.10 91.81 3.55 3,828.33 3,73531 -152.79 4,386.73 5,980,29040 1,693,996.30 6.89 -152.79 MWD+1FR-AK-CAZ-SC (5) 7,917.34 92.12 3.52 3,825.27 3,732.65 -63.77 4,392.23 5,980,37945 1,694.00121 0.35 -6377 MWD+IFR-AK-CAZ-SC(5) 7,962.47 91.54 3.19 3,823.82 3,731.20 -18.74 4,394.87 5,980,424.49 1,694,0356 1.48 -18.74 MWD+IFR-AK-CAZ-SC(5) 8,012.52 91.06 1.69 3,82269 3,730.07 31.25 4,39700 5,980,47449 1.694.005 36 3.15 3125 MWD+IFR-AK-CAZ-SC(5) 8,05942 90.79 0.92 3,821.93 3,729.31 78.13 4,398.07 5,980,521.37 1.694,006.12 134 78.13 MWD+IFR-AK-CAZ-$C(5) 8,106.77 90.68 359.56 3,821.32 3,728.70 12547 4,39827 5,980,56871 1,694,0D6.01 2.88 125.47 MWD+IFR-AK-CAZ-SC(5) 8,156.58 90.71 358.75 3,82072 3.728.10 175.27 4,397.53 5,980,618.50 1,694,0495 1.63 17527 MWD+IFR-AK-CAZ-SC(5) 8,201.93 91.59 359.54 3,819.81 3.727.19 220.61 4,30.86 5,9W 66182 1,694,003.97 2.61 220.61 MWD+IFR-AK-CAZ-SC (5) 8,296.99 90.82 359.72 3,817,81 3,725.19 315.65 4,3024 5,980,75884 1,694,002.73 0.83 315.65 MWD+IFR-AK-CAZ-SC(5) 8,391.15 90.20 1.51 3,816.97 3,724.35 409.79 4,397.25 5,980,852.99 1,694,003.13 2.01 40939 MWD+IFR-AK-CAZ-SC(5) 8.486.62 89.93 0.96 3,816.86 3,724.24 505.24 4,399.31 5,980,948.44 1,694,004.56 0.64 505.24 MWD+IFR-AK-CAZ-SC (5) 8,579.86 89.70 131 3,817.17 3,724.55 598.45 4,40148 5,981,04165 1,694,006.12 0.84 598.45 MWD+IFR-AWCAZ-8C(5) 8,62748 90.M 066 3,817.17 3,724.55 646.06 4,402.47 5,981.089 26 1,69,0039 2.54 646.06 MWD+IFR-AK-CAZ-SC(5) 8,67457 90.29 359.54 3,816.92 3,724.30 693.15 4,40255 5,981,136.35 1,694,006.56 2.38 693.15 MWD+IFR-AK-CAZ.SC(5) 8,769.70 89.62 358.37 3,817.00 3,724.38 788.26 4,400.82 5.981 231.44 1,694,004.20 1,42 788.26 MWD+1FR-AK-CAZ-SC (5) 8,864.54 88.83 35737 3,818.28 3.725.65 883.03 4,397.29 5,981,326.17 1,694,000.06 1.34 883.03 MWD+IFR-AK-CAZ-SC (5) 8,960.45 88.68 357.09 3,820.36 3,727.74 978.80 4,392.66 5,98142190 1,693,99439 0.33 978.80 MWD+IFR-AK-CAZ-SC(5) 9,055.10 87.19 359.04 3,623.78 3,731,16 1,073.33 4,389.46 5,981,516.39 1,693,990.98 2.59 1,073.33 MW0+1FR-AK-CAZ-SC(5) 9,149.82 87.94 358.94 3,827.80 3.735.18 1,167.95 4,38.80 5,981,61099 1,693,988.69 0.80 1,167.95 MWD+IFR-AK-CAZ-SC (5) 9,245.39 8864 358.74 3,830.65 3,738.03 1263.46 4,385.86 5,981,70.47 1693,986.13 036 1,26346 MWD+IFR-AK-CAZ-SC(5) 9,339.41 88.52 0.09 3,832.98 3,740.36 1,357.44 4,384.0 5,981,800.44 1,693,984.55 1.44 1,357.44 MWD+IFR-AK-CAZ-SC (5) 9,434.35 8872 359.99 3.835.27 3,742.65 1,452.35 4,384.97 5.981,895.34 1,693,983.99 024 1452.35 MWD+IFR-AK-CAZ-SC(5) 9,527.81 90.16 35962 3,836.18 3.743.56 1,54580 4,384.65 5,981,988.78 1693,9830 1.59 1,545.80 MWD+1FR-AK-CAZ-SC(5) 9,622.31 90.53 359.84 3835.61 3,742.99 1,640.30 4,384.20 5,982,083.26 1,693,98200 0.46 1,640.30 MWD+IFR-AK-CAZ-SC(5) 9,71726 90.24 357.05 3,834.97 3,742.35 1,73520 4,381.63 5,982,178.14 1,693.978.80 2.95 1,735.20 MWD+IFR-AK-CAZ-SC(5) 9,812.51 90.63 353.91 3,834.25 3,741.63 1,830.14 4,374.12 5,982,27302 1,693,97067 3.32 1.830.14 MWD+IFR-AK-CAZ-SC(5) 9,907.44 90.73 351.74 3,833,12 3,740.50 1,924.32 4,362.27 5,982.367.10 1,693,958.20 2.29 1,924.32 MWD+IFR-AK-CAZ-SC(5) 10,02.27 9022 350.65 3,832.34 3,739.72 2,018.03 4,347.75 5,982,46030 1,693.943.07 1.27 2,018.03 MWD+IFR-AK-CAZ-SC(5) 10,00.95 68.84 349.60 3,833.11 3,740.49 2,111.30 4,331.52 5,982.55386 1,693,92622 1.83 2,111.30 MWD+IFR-AK-CAZ-SC(5) 10,192.81 89.39 348.86 3,83460 3,741.98 2,205.45 4,313.61 5,982,647.89 1,693,907.69 0.96 2,20545 MWD+IFR-AK-CA2-SC(5) 10,287.83 8948 346.36 3,835,53 3,742.91 2,298.25 4,293.22 5,982,740.54 1,693,886,70 2.63 2,298.25 MWD+IFR-AK-CAZ-SC(5) 10,381.89 89.54 345.19 3,836.34 3,743.72 2,38942 4,270.11 5.982,831.55 1,693,862.99 125 2,389.42 MWD+IFR-AK-CAZ-SC(5) 10,477.13 88.47 347.20 3,837.99 3,745.37 2.481,89 4,247.39 5,982,92385 1.693,83967 2.39 2,481.89 MWD+IFR-AK-CAZ-SC(5) 10,572.69 89.29 349.51 3,839.86 3,74724 2.575.46 4,228.10 5,983,017,28 1,693,819.77 2.56 2,575.46 MWD+IFR-AK-CAZ-SC(5) 10,666.29 89.51 352.07 3,84084 3,748.22 2,867.84 4,213,13 5,983,109,56 1,693,804.19 2.74 2,667.84 MWD+IFR-AK-CAZ-SG(5) 10,761.05 88.24 355.86 3,84230 3,750.08 2,76204 4,203.17 5,983,20368 1,693,79361 4.22 2,762.04 MWD+IFR-AK-CAZ-SC(5) 1"12017 2 40: 39PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Coordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1 H Pad MD Reference: Well: Rig: 1H-102 North Reference: Wellbore: 1H-10213 Survey Calculation Method: Design: 1H-10213 Database: Well Rig: 1 H-102 1H-102 actual @ 92.62usft (Doyon 142) 1H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc Azl TVD TVDSS +N/ -S +El -W Northing Easting DLS Section (usft) (1) (1 (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 10,856.04 85.03 359.83 3,848.28 3,755.66 2,856.76 4,19860 5,983,298.37 1,693,789.42 5.37 2,85676 MWD+IFR-AK-CAZ-SC(5) 10.950.31 83.30 2.18 3,857.86 3,765.24 2,950.52 4,201.24 5,983,392.13 1,693,790.45 3.09 2,950.52 MWD+IFR-AK-CAZ-5C (5) 11846.10 84.10 146 3,868.37 3,775.75 3,04568 4,204.26 5,983,487 30 1,693,792.84 1:12 3,04568 MWD+IFR-AK-CAZ-SC(5) 11,140.41 86.98 023 3,875.71 3,783.09 3,139.68 4,205.65 5,983,581.30 1,693,79361 3.32 3,139.68 MWD+IFR-AK-CAZ-$C(5) 11,235.63 90.45 358.64 3,877.84 3,785.22 3,234.86 4,204.71 5,983,676.45 1,693,792.05 4.01 3,234.86 MWD+IFR-AK-CAZ-SC(6) 11.330.49 90.48 358.00 3,877.07 3,784.45 3,329.67 4,201.93 5,983,771.24 1,693,78564 068 3,329.67 MWD+IFR-AK-CAZ-SC(5) 11,424.69 9083 359.37 3,876.16 3,783.54 3,423.84 4,199.76 5,983,865.38 1,693,785.86 1.46 3,423.84 MWD+IFR-AK-CAZ-SC(5) 11,518.98 92.53 0.39 3,87356 3,780.94 3,518.09 4,199.57 5,983,959.62 1,693,78505 2.29 3,518.09 MWD+IFR-AWCAZ-SC(5) 11,613.53 93.55 2.39 3,868.55 3,775.93 3,61247 4,201.85 5,964,054.01 1,693.786.72 2.37 3612.47 MWD+IFR-AK-CAZ-SC(5) 11]03.96 92.13 569 3,864.06 3,771.44 3,702.55 4,208.22 5,984,144.12 1,693,]9249 3.97 3,702.55 MWD+IFR-AK-CAZ-SC 15) 11,796.48 90.59 5.92 3,861.87 3,769.25 3,794.57 4,217.57 5,984,236.18 1,693,80124 168 3,794.57 MWD+IFR-AK-CAZ-SC(5) 11,888.04 91.21 6.88 3,860.43 3,767.81 3,885.55 4,227.78 5,984.327.22 1,693,810.84 1.25 3,885.55 MWD+IFR-AK-CAZ-SC(5) 11,979.75 9106 7.95 3,858.61 3,765.99 3,97647 4,239.61 5,984418.21 1,693,822.08 1.18 3,976.47 MWD+IFR-AK-CAZ-SC(5) 12,071.78 90% 7.57 3,856.99 3,764.37 4.067.64 4,252.04 5,984509.45 1,693,833.90 0.43 4,067.64 MWD+IFR-AK-CAZ-SC(5) 12,161.75 90.80 7.00 3,855.61 3,762.99 4,156.88 4,263.44 5.984598]5 1,693,844.72 0.66 4,156.88 MWD+1FR-AK-CAZ-SC(5) 12,25520 90.15 5.95 3,854.83 3,762.21 4,249.73 4,273.98 5,984,691.65 1,693,85485 132 4,249.73 MWD+1FR-AK-CAZ-SC (5) 12,347]1 88.31 2.31 3,856.08 3,763.46 4,341.97 4,280.64 5,984,783.93 1693,86070 441 4,341.97 MWD+IFR-AK-CAZ-SC(5) 12,440.90 89.86 359.72 3,85].5] 3,]64.95 4,435.12 4,282.29 5,984.877.08 1,693,861.74 3.24 4,435.12 MWD+IFR-AK-CAZ-SC(5) 12,532.79 89.86 35854 3.857.79 3,765.17 4,527.00 4,280.90 5,984,968.94 1,693,859.74 1.28 4,52700 MWD+IFR-AK-CAZ-SC(5) 12,623.89 90.19 355.39 3,857.75 3.765.13 4,617.96 4,276.07 5,985,059.86 1,693,854.32 3.48 4,617.96 MWD+IFR-AK-CAZ-SC(5) 12,716.14 89.18 353.]2 3858.26 3,765.64 4,]09.]9 4,267.32 5,985,15162 1,693,844.97 2.12 4,709.79 MWD+1FR-AK-CAZ-SC(5) 12,808.91 87.99 350.29 3,860.55 3,767.93 4,801.61 4,25442 5,985,243.35 1.693.831.47 3.91 4,80161 MWD+IFR-AK-CAZ-SC(5) 12,902.83 85.66 345.91 3,86575 3,773.13 4,893.34 4,235.10 5,985,334.94 1,693,81154 5.28 4,893.34 MWD+IFR-AK-CAZ-SC(5) 12,99133 87.16 342.83 3,871.30 3,778.68 4,978.39 4,211.30 5,985,419.82 1693,787.19 3.86 4,978.39 MWDHFR-AK-CAZ-SC(5) 13,084.51 91.52 344.00 3,87237 3,779.75 5,067.67 4,184.71 5,985,508.91 1,693,760.02 484 5,067,67 MWD+IFR-AK-CAZ-SC(5) 13,176.87 91.10 339.29 3,870.26 3,777.64 5,15528 4,155.65 5,985,596.32 1693.730.38 5.12 5,155.28 MWD+1FR-AK-CAZ-8C(5) 13,269.09 9075 332.94 3,868.77 3,776.15 5,239.55 4,118.33 5,985,680.34 1,693,69252 6.90 5,239.55 MWD+IFR-AK-CAZ-SC(5) 13,36063 90.40 327.57 3,867.85 3,775.23 5,318.82 4,073.03 5,985,759.30 1 693,646 70 5.89 5,318.82 MWD+IFR-AK-CAZ-SC (5) 13,453.23 91.49 322.82 3,866.32 3,773.70 5,394.96 4,020.08 5,985,835.11 1.693,593 26 5.25 5,39498 MWD+IFR-AK-CAZ-SC (5) 13,546.32 91.71 319.21 3,86372 3,771.10 5,467.30 3,96155 5,985.907.04 1,693,534.26 3.88 5,467.30 MWD+IFR-AK-CAZ-SC(5) 13,638.36 92.34 315.76 3,860.46 3,767.84 5,535.09 3,899.40 5,985,97441 1,693,471.68 3.81 5,535.09 MWD+IFR-AK-CAZ-SC(5) 13,730.67 92.23 310.92 3,85678 3,764.16 5,598.38 3,832.34 5,986,03725 1,693,404.20 5.24 5,598.38 MWD+IFR-AK-CAZ-SC(5) 13,822.54 9284 306.99 3.85288 3,760.26 5,656.08 3.760.98 5,98609447 1,693,332.47 4.30 5,656.08 MWDaIFR-AK-0AZ-SC(5) 13,914.50 91.25 303.60 3,84976 3,757.14 5,709.17 3,685.98 5,986,14706 1,693,257.13 3.98 5,709.17 MWD+IFR-AK-CAZ-SC(5) 14.004.35 88.89 302.78 3,849.65 3,757.03 5,758.35 3,610.79 5,986,195 74 1,693,181.63 2.78 5,758.35 MWD+IFR-AK-CAZ-SC(5) 14,098.79 90.12 301.87 3,850.44 3,757.82 5,807.78 3,532.68 5,986,24465 1,693,103.21 1.66 5,807.78 MWD+IFR-AK-CAZ-SC(5) 14,188.71 90.68 302.23 3,849.80 3,757.18 5,856.55 3,454.77 5,985,292.91 1,693,02499 0.72 5,856.55 MWD+IFR-AK-CAZ-SC(5) 14,281.10 90.99 303.01 3.848.46 3,755.84 5,906.35 3,376.97 5,986,342.19 1,692,94686 0.91 5,906.35 MWD+IFR-AK-CAZ-SC(5) 14,373.18 91.27 303.58 3.846.64 3,754.02 5,956.89 3,300.01 5,986,39222 1,692,869.59 069 5,956.89 MWD+IFR-AKCAZ-SC(5) 14,465.23 91.57 30620 3,844.36 3,751.74 6,009.52 3,224.54 5,986,444.35 1,692,793.78 286 6,009.52 MWD+IFR-AK-CAZ-SC (5) 10/92017 2:40.39PM Page 6 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: Rig: 1H-102 Wellbore: 1 H-1021.3 Design: 1H-1021_3 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Rig: 1 H-102 1 H-102 actual @ 92.62usit (Doyon 142) 1 H-102 actual @ 92.62usit (Doyon 142) True Minimum Curvature OAKEDMP2 Survey Surface Coordinates Declinabon & Convergence GRS Survey Corrections (1 Survey Tool Codes Brandon Tem„ le Digitally signed by Brandon Temple SLB DE: N Date: 2017.10.0914:02:07-08'00' Map Map nyWyijroGMlWy'MHu° Vertical 10103117 MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (9 (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 14,557.47 90.24 309.01 3.842.90 3,750.28 6,065.79 3,151.48 5,986,500.13 1692,72036 3.37 6,06579 M0iD+IFR-AK-CAZ-SC(5) 14,625.81 89.16 308.79 3,843.26 3,750.64 6,108.71 3,098.30 5,986,54269 1,692,666.90 1.61 6,108]1 MVJD+IFR-AK-CAZ-SC(5) 14,66800 89.16 308.79 3,843.88 3,751.26 6,135.13 3,065.42 5,986,56880 1.69263385 0.00 6,135.13 lgTen AcdW Survey 4-1/2" x 6-3/4" 14,686.00 89.16 308.79 3,844.14 3,751.52 6.14641 3,051.39 5,986,58008 1692,619.75 0.00 6,14641 PROJECTEDto TD Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. 0 Yes ❑ No 1 have checked to the best of my ability that the following data is correct., Surface Coordinates Declinabon & Convergence GRS Survey Corrections (1 Survey Tool Codes Brandon Tem„ le Digitally signed by Brandon Temple SLB DE: N Date: 2017.10.0914:02:07-08'00' Client Representative: Kelsey Hallford nyWyijroGMlWy'MHu° Date: 10103117 10192017 2:40 39PM Page 7 COMPASS 5000.14 Build 85 THE STATE °fALASKA GOVERNOR BILL WALKER G. Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Kuparuk River Field, West Sak Oil Pool, KRU 1H -102L3 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-103 Surface Location: 40.52' FNL, 764.65' FEL, SEC. 33, T12N, RIOE, UM Bottomhole Location: 4259.5' FNL, 2861.79' FEL, SEC. 22, T12N, R10E, 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, a" ! lta!�" _ Cathy P. Foerster Commissioner DATED this day of July, 2017. STATE OF ALASKA A KA OIL AND GAS CONSERVATION COMM ,ON µ� PERMIT TO DRILL �.` 20 AAC 25.005 nr.40MI V Coe JUL 122017 Al R7QQ 1a. Type of Work:�/ ' 1 b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp ❑ 1 c. Specify if well is proposed for: Drill L Lateral LJ Straligraphic Test ❑ Development - Oil 0 Service - Winj ❑ Single Zone ❑� Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Single Well1n1�,�r 11. Well Name and Number: ConocoPhillips Bond No. 59-52-180 ' 40 KRU 11-1-1021-3 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 14444 - TVD: 3859 Kuparuk River Field West Salk Oil Pool , 4a. Location of Well (Governmental Section): 7. Property Designation: el? Surface: 40.52' FNL, 764.65' FEL, Sec 33, T 12N, R010E, UM ADL025639 Oro 2.51.36 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 297.81' FNL, 1676.2' 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, 2861.79' FEL, Sec 22, T 12N, R010E, UM 2560 SHL - 4515'; BHL - 584' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 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: 982' 16. Deviated wells: Kickoff depth: 7472 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 92.2 degrees Downhole: 1696 psi - Surface: 1314 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# 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 7472 Surface Surface 7472 3820 644 sx 15.8 Class G 6.75" 4.5" 11.6# L-80 IBTM 7122 7322 3780 14444 3859 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 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes❑ No ❑- 20. Attachments: Property Plat ❑ BOP Sketch Diverter Sketch a Drilling Program Seabed Report B Time v. Depth Plot Drilling Fluid Program a Shallow Hazard Analysi'sB 20 AAC 25.050 requirements 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. 9 Contact Name: cx-c•� Authorized Name: G. Alvord Contact Email: keIsey.haIIfor4@konocopIAl1ns.com Authorized Title: Alaska Drilling Manager Contact Phone: 1-907-2654577 Authorized Signature: A C - ON Date: 71(e/ 17 10 -Jul -17 ' Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: - 3 ppyyo� �1 50- Qa - SCIS - �01- OCA Date: . 2le - �-( requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: � � 3 P 5 / Samples req'd: Yes ❑ No Lw Mud log mq'd: Yes No2 ,SOD -Yl Cir /f rY �'N f + Z �7�/�.VlzSgpra¢ures: Yes [� No,❑( r❑] Directional svy req'd: Yes LJ No ❑ 14 n //� 12 Spacing exception req'd: Yes ❑ No LI Inclination -only svy req'd: Yes ❑ No,V_,/ Post initial injection MIT req'd: Yes❑ NoFR' Approved by. APPROVED BY COMMISSIONER THE COMMISSION Date: 7-2G^ il(Uevi 12?(7 n � %1_ A�1�� Submit Form and For 10-401 Revis !2017 '�If(`S et`rnJ� 1atY�1 months from the date o approval per 20 AAC 25.005(8) attachments in Duplicate ?lq Vit 17- x �7wq Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone(907)265-1577 Email: kelsev.hallfordnaconocoohillioscom July 10, 2017 Alaska Oil and Gas Conservation Commission 333 West 7'^ Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Producer, 1H-10214 Dear Commissioner: Application for Permit to Drill, Well 1H-10214 Saved: 10 -Jul -17 ConocoPhillips RECEIVE® JUL. 12 2017 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 fifth 6-3/4" production lateral, 1H-IO2L4, will be milled out of the 1 H-102 intermediate casing and be geo-steered in the West Sak D sand, lined with 4-1/2" slotted liner. A separate PTD application will be submitted for each lateral: 1H-102, 1H -102L1, 1H-IO2L2, IH -102L3, and 1H - 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)conocophillips.com) or Chip Alvord at 265-6120. Si Gere y, Kelsey Hallf d Drilling Engr eer Application for Permit to Drill Document Kuparuk Well 1H-1021-3 Well Name Requirements of 20 AAC 25.005 (U The well for which this application is submitted will be designated as 1H -102L3 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill anus, be accompanied by each of the follomving items. except.fin an item already an file with the commission and identified in the application: (2) a plat identifying the property and the properp's owners and shorting (A)the coordinates of the proposed location ofthe well at the surface. at the lop of each objective fornmtion. and at total depth, referenced to governmental section lines. (B) the coordinates oj'lite proposed location of lite it ell en the surface, referenced to the state plane coordinate s)'stem jor this stale as maintained by the National Geodetic Surrey in The National Oceanic and Anuospheric Administration: (C) the proposed depth of the well at the top id each abactive fonnotion and at total depth: Location at Surface 40.52' FNL, 764.65' FEL, Sec 33, T 12N, ROl0E, UM NGS Coordinates Northings: 5980662.56' Eastings: 549577.46' RKB Elevation 93' AMSL Pad Elevation I 54' AMSL Location at Surface Casing 1349.45 FNL, 466.77 FEL, Sec 33, T12N, ROME, UM NGS Coordinates Northings: 5980355.65' Eastings: 549878.04' IMeasured Depth, RKB: 1794' Total Vertical Depth, RKB: 1700' Total Vertical De [h, 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 Depth, RKB, 4004' Total Vertical Depth, SS: 3911' Location at Total De th 4259.5' FNL, 2861.8' FEL, Sec 22, T12N, R010E, UM NCS Coordinates Northings: 5987024.4' Eastings: 552703.9' MeasuredDe th, RKB: 14444' Total Vertical De th, RKB: 3859' Total Vertical De th, SS: 3766' and (D) whir infwvnation required b)20AAC25.050(b): Requirements of 20 AAC 25.050(b) {fa well is to be intentionally deviated, the application for a Permit to Drill (Form 10-{01) most (1) include a plat, drawn to it suitable scale, shoo ing Ire path of the proposed it etlbore. including all adjacent wellbores within 200 feet of any portion of the proposed well: Please see Attachment: Directional Plan And (2) for all it ells ii Won 200 feet of the proposed is (A) list the names of the operators oj'those wells, to the extent that those names are knorrn or discoverable in public reco, ds. and show that each named operator has beets furnished a cop)' oj'the application by cert fed mail; or (B) ,state that the applicant is the only' m7eeted owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) a application for o Pcrtnu at Drill must be accompanied by each of the following items. esc'epi fav an item already on file milh the commission and identified in the application: (3) a diagram and description of die blmrom prevention equipment (BOPS) as, equirealby 10 AAC 25.035, 20 AAC 15.036, a 20 AAC 15.037. 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 for a Permit to Drill trust be accompanied by each of the following items, except for an item already on file wadi the commission and identified in the application: (4) information air drilling karat, us. including (A) the masinmm downhole pressure that mqv be encountered criteria used to determine a. and irarimuurt potential surface pressure hosed on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 1H -102L3 is calculated using an estimated maximum reservoir pressure of 1696 psi (based on 1H -05A pressure at a 4005.2' TVD reference datum), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Sak B sand window at 3871' TVD: A3 Sand Estimated. BHP A3 Sand estimated depth Gas Gradient Hydrostatic of full gas column MPSP = BHP — gas column (B) than on potential gas tunes.' = 1,696 psi = 3820' TVD = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) = 382 psi (3,820' TVD * 0.10 psi/ft) = 1,314 psi (1,696 psi — 382 psi) The wellbore is not expected to penetrate any shallow gas zones. And (C) data concerning polential causes chole problems such as abnormally geo-pressured strata, lost circulation =ones, and cones that have a propensity for d f a entad sticking; See attached 1H -102L3 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application far a Pen nit to Drill it, be accompanied by each of the, following items, a cepi for an hent already ar file with the commission and identified in the appheadonr (5) a description of the procedure for corductingformation integrov tests, (is required under 20 AAC 25.0306): A procedure is on file with the commission for performing FIT/LOT'S. Casing and Cementing Program Reauirements of 20 AAC 25.005(c)(6) . bt applicalion for a inertial to Drill must be accompanied lar each of the,follmving items, except for an item alread; on file with the commission and idenirfied in the application (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description ofan) sloped hnei, pre -perforated liner. or screen to be installed Casing and Cement Program 18. Casing Program Specifications Top - Setting Depth - Bottom Cerrent Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20" 94# H40 Wtld 80 Surface Surface 80 80 Existing, cemenitosurface 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 7472 Surface Surface 7472 3820 644 sx 15.8 Gass G 6.75" 4.5" 11.6# L-80 IBTM r 7122 7322 3780 14444 3859 WA: Un -cemented slatted liner Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applicalioq/or a Permit to In num be acconryanied by each of the /allmring items, except far an item alreadjon file with the connnission and identified in the application: (7) a diagram and description of the diverter system as required by 20 A4C25.035, 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 far a Permit to Drill nmsl be accompanied by each of the£Whining items. except for an item ahead) on file it the commisdin, and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033,' 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" Casing 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 30-50 < 20 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 application for a Per int to Drill must be accompanied by each gfthefollmeing items, ercep(for an item already on file with the commission and identified in the application: The proposed drilling program follows. Please refer to attachment for proposed well schematic. Note: Previous operations are covered under the IH -102, 1H -102L1, and 1H -102L2 Application for Permit to Drill. 1. With 6-3/4" bit, motor, GR/Res, and magnets, and drill —200' of new hole in the B sand. POOH. 2. Pick up 6-3/4" RSS lateral drilling assembly with GR, Res, periscope and RIH. 3. Drill lateral to B 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. Run & set Baker whipstock system, placing the top of the windovejust below the top of the D sand orienting with MWD. 9. Mill 6-3/4" window until top mill across face & clean up window. 10. Perform formation integrity test to minimum of 12.0 ppg, maximum of 13.0 ppg EMW, recording results. 11. POOH with milling BHA. 12. PU 6-3/4" bit, motor, MWD (GR/Res), and magnets to perform a clean out run & land the well. 13. RIH, orient through window and tag bottom. 14. End 1H -102L3 PTD & begin 1H -102L4 PTD. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied by each of the folloming items, escepi for an item already on file with tie commission and identified in the application: (14) a general description citchou the operatorplans to dispose of drilling noted and cuttings and a .statement of iv/tether the operator intends to request authorization under 20 AAC 25.030 for an annular disposal operation in the tell.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well at the 1 B Facility. All cuttings generated will be hauled to the Pmdhoe 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 Kupamk 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 Diasram Attachment 4 Directional Plan Attachment 5 Drilline Hazards Summary Attachment 6 Cement Summaries Fixed BOP configuration for West Sak Operations Class 2 BOP Op ion;rl Fixe mu Casing, 20", 94#, K55 x 34", 0.312" WT @ +/- 80' MD 10-3/4",45.5#, L-80, Hyd563 MD/ 1700' TVD ZXP Packer � Landing nipple profile Wellhead / Tubing Head / Tree, 13-3/8" x 4-'/_", 5,000 ksi _- Tubing String: 4-1/2", 12.6 #, L-80 TXP 4 Stacked Baker Hook Hanger Level Junction Systems ZXP Packer Gas Lift Mandrel, 4-1/2"x I" w/dummy valve Gas Lift Mandrel, 4-12"x I" w/ SOV 4-%" SSD with 3.812" DB Nipple profile emmnent Down Hole Gauge r-- Tubing Seal Assembly 1H-102 Producer Schematic DRAFT L4 "D" Sand Window @ 7204' MD / 3753' TVD 75.570 ine ,_—� 4-1/2", 11.6# IBTM L80, Slotted Liner L3 "B" Sand Window a 7472' MD / 3820' TVD 75.570 ine Lateral EntSent Module Seal \\\ Tubing Assembly �//�\\y�' Landing nipple profile ZXP packer 7-5/8", 29.74, 1.80, Hyd563, Csg 8325' MD / 4004' TVD L2 "A4" Sand Window @ 7677' MD / 3871' TVD 75.570 ine � 4-1/2" Slotted Liner, 11.6# 1BTM L80 LI "A3" Sand Window @ 7834' MD / 3910' TVD, 75.57 0 inc '•b� 4-12"Slotted Liner, 11.6# IBTM L80 Slotted Liner, 11.64 IBTM L80 6-3/4" D sand lateral 14425'MD/380V TVD .......................... -- -•— Swell Packers —/ 6-3/4" B sand lateral --v14444' MD / 3859' TVD 6-3/4" A4 send lateral 12522' MD / 3905' TVD 6-3/4" A3 sand lateral 12526' MD / 3964' TVD 6-3/4" A2 sand lateral 12526MD / 4015' TVD 0 Drill Site 1 H 9 0 o �- ConocoPilllll=75 TITLE: DS1H LAYOUT DRAWING Maska,lDc. DRAWN BY: ALKET MICI DATE: W-01-2017 REV: 1 1 H-102L3wp23 SurveyMlan Depth Relerenw. Plan: 54+39 C 93.OWsO (Doyon 142) DDI 7.1184 0 UGC I L 700.00 1794.10 1H-102"23 (Plan, 11+102) d5]- 7-6.15 _ __. WS A4 v W _A4 m to U o tData•• 1�-1n' 0 3500 10500 14000 0 2000 4000 6000 8000 10000 SURVEY PROGRAM M From Depth To SurveyMlan Depth Relerenw. Plan: 54+39 C 93.OWsO (Doyon 142) 39.00 0 1H-102wp23(Plan: 1&102) oyon 14 Rig: D2 700.00 1794.10 1H-102"23 (Plan, 11+102) MWD+IFR-AK-CAZSC 1794.10 7471.76 n ,g 67/8" 412" 26.3/4' 144-1020"23(Plan: 11+10213) MWD -INC 7821.76 9321.76 o _ONLY MWD � o.• a ^ o c o 0 w 3W.79 ?� •- .moo .- 0 1500 3000 4500 6000 7500 9000 ° 10500 12W 77.61 0.00 Horizontal Departure -220.93 0 2000 4000 6000 8000 10000 SURVEY PROGRAM M From Depth To SurveyMlan Tool 39.00 700.00 1H-102wp23(Plan: 1&102) GYD-GGSS 700.00 1794.10 1H-102"23 (Plan, 11+102) MWD+IFR-AK-CAZSC 1794.10 7471.76 1H-102wp23(Plan: 11}102) MWD+IFR-AK-CAZSC 7471.76 7821]6 144-1020"23(Plan: 11+10213) MWD -INC 7821.76 9321.76 iH-102L3w;,M(PMn' 11+10213) _ONLY MWD 7821.76 14443.97 11 102L3neaM (Plan: 1H-1021.3) MID+IFR-AKLAZSC 12000 Pad Elevation: 54.00 CASING DETAILS TVD MD Name 3819.82 7471.77 7-M8" X6741- 3858.86 14443.97 412' x 6-3/4' Plan Summary 07472 0 74M - 7860 „ 7660 - 7850 _ 7850 - 8040 Bow - 8230 8230 - 8420 60 8420 - x10 Old 0x0 NO - 9040 9040 9280 9280 - %10 f0 9510 - 9750 97M - 9890 Mae - 1022] 10220 - 1048] 10,160 - 107N 10700 - 11171 120 11170 - 116m 11640 - 1210 12100 - 12571 u 160 125]0 - 13041 30 0 x11 10 13510 - 13981 13980 - 1444 Mp.. M WcM1: BG aW2017 1 Mpnetic MOM/ Dale22.62117 Ma9na0c 1].61° CDeadlbn: To conMK a Me9Mlk Dvetllnn IO a TNe pKgion. "41].82° Eafl SECTION DETNLS Sec MD IncAi TVD +WS 41 r W Oleg TF.. VSem Tablet 1 7471.76 75.57 0.00 %19.82 -252.92 4369.05 0.00 0.00 -252.92 27484.56 77.61 0.00 3W.79 -240.46 4369.05 15.90 0.00 -240.6 3 7504. 56 77.61 0.00 302].08 -220.93 4369.05 0.00 0.00 -220.93 4 7798.61 92.29 031 3852.90 71.17 4370,89 5.00 2.81 71.17 6 80]9.]0 9229 0.71 3841.67 352.01 4374.39 0.00 0.00 %2.01 89.96 0.39 3840.13 430.60 4375.14 3.00 -172.00 430.50 11+1MI.3 M.T1 020817 RP 7 88]3. 99 89.96 0.30 38 10.65 1146.26 4379.96 0.00 0.001146.26 11+19213 W.T2020917 RP 8 8803M 90.24 0.38 3840.62 1160.50 4380.06 2.00 -1.381160.50 9 9557.34 90.24 0.38 383739 1829.58 4384.0 0.00 0.00 1829.59 10 9581.81 88.]8 0.22 383738 1051.08 4384.61 2.00 -180.641854.06 10+102130313=917 RP 11 9592." 8938 0.22 383].80 1864.51 4384.65 200 -0.091864.51 12 9096.]] 89.99 O. 3&1].85 2169.02 4385.80 0.00 0.00 2169.02 13 9989.82 87.80 0.22 38379.26 2242.05 4386.08 3.00 179.81 2242.06 11+1021.304.T4=917 RP 14 10269.84 87.89 318.21 %50.58 2079.79 4355.92 4.00 -89.78 2539.79 15 1030238 8>.69 348.21 3851]] 2571.52 4349.29 9,0 0.00 2571.52 16 10359.64 =7 8727 346.00 3854.19 2527.38 036.50 4.00 -105.]4 2827.38 1 +1021.3 0535 020917 RP 17 .6q 8]2] 348.00 3859.90 2743.68 4397.51 0.00 0.00 2743.60 179 11002.9] 90.00 0.00 3872.42 3M1.62 4243.95 2.]2 79.19 3261.62 19 111".64 W.00 359.99 3872.42 %79.29 4243.94 0.01 -85.54 3379.29 114102L307.W OM91] RP 20 1118638 91.92 O.44 3871.32 3445.02 4244.19 3.00 13.19 3445.02 21 11338.11 91.92 0.44 3866.23 3590.88 4245.37 0.0 0.00 35796.60 22 11344.98 82.04 0.38 %N NO %03.53 4245.41 2.00 -29.13 %03.53 11+10213 x.T5 020917 RP 23 11959.01 9230 0.30 3855.70 3611.55 4245.17 2.00 0.00 3611.55 24 11778.]492.20 0.38 3849.35 4035.96 4248.26 0.00 0.00 4030.% 25 11852.10 90.00 0.30 3847.94 4110.30 4248.74 3.00 -180.00 4110.30 111.1021,309.T9=917 RP M 11913.23 88.78 0.38 Made 4171./3 4249.14 2.00 -180.00 4171.43 27123"1] 88.]8 0.38 307.49 4588.26 4261.88 0.00 0,045BB.M 11+1021.310.T1002097 RP 20 13273.63 08.64 317.36 %77939 5447.52 3919.80 4.x -90.68 5447.52 29 13383.43 88.64 317.36 3982.39 562027 3845.44 0.00 0.00 5528.27 301342623 90.00 317.89 3882.90 5559.09 Weed 3.0 21.21 5559.89 11+1021911.T110NM1] RP 31 1]492.06 91.32 317.89 3882.14 5808]2 37]2.8 2.00 0.00 5606.72 32 13953.9] 91.32 317.89 3871.53 5951.30 3462.00 0.00 0.00 5951.30 11+1021312.TI2 020917 RP 33 1"18.39 91.62 327.63 3859.58 63".6 3182.17 2.10 88.07 6320.45 34 14443.97 91.62 327.63 38NO 8342.04 3168.48 0.00 0.00 6312,4 11+10M313.TD 0"917 RP Plan Summary 07472 0 74M - 7860 „ 7660 - 7850 _ 7850 - 8040 Bow - 8230 8230 - 8420 60 8420 - x10 Old 0x0 NO - 9040 9040 9280 9280 - %10 f0 9510 - 9750 97M - 9890 Mae - 1022] 10220 - 1048] 10,160 - 107N 10700 - 11171 120 11170 - 116m 11640 - 1210 12100 - 12571 u 160 125]0 - 13041 30 0 x11 10 13510 - 13981 13980 - 1444 Mp.. M WcM1: BG aW2017 1 Mpnetic MOM/ Dale22.62117 Ma9na0c 1].61° CDeadlbn: To conMK a Me9Mlk Dvetllnn IO a TNe pKgion. "41].82° Eafl 1620.4 A at.ka PFROST KOP:15.9°1100• MS. 9° W,, M 128' IbM Mr2P 1788.6 T-3 HM tar 679.6Y By signing that I acknowledge that I have been Informed of all asks, checked that the data is mnect, ensured d•s completeness, and all wrm.nding wells are assigned t0 the proper Prap2md by: GheckBd by: Acceptetl by j Approved by: Bnj Potnis Huy Bu Anh Edk Sleds ! Halford. Phar 1-15 3135.4 UG_C 3362.6 40B 34 UGf x10.7 Na 37 11P.04 Mi.ahe e the sten and 1aCOMPA55-EDM PrOOucuOn File Fee ViewMWda Plar ReFoltT ft He4 �� I►bMm � I. Tii * O+. LL® 93® •A ®l_ L1.h: qv1-L55vn<v rant pay;JPan...Pvn3 ft1lb ,< r .Sntem Locel: t56t J NarN:lux J e%m FAor-pWelH 10 ROmte11y31)IPhO1K10Y3AH 1M13wpD �. l'® �Legbq �� L]'.. 13 E35adon View -Plan 1H-10L3wp33 (plen:lH-103 RPrr0WY313/Plen lK10313) o _1 vx d d D. 3637." 3744." alm.A) S .v n 0.]] 3537.8 37M.M 1)51.% 4311.61 i9. 0.22 M'.. 3H1H1 155x.51 4355.65 A 0.22 313/" 3M.85 21/9.02 AU11S 0 M, 0.22 MN.M 3]58.26. N42,OS. 1 w 6' N 2t 3650.59. YF70 ISM al 13 N 19 3 21 9051." 3"5."' 25)1.52 439.A i7 355.0] 9654.39' 1T51.ro TS".30 13%.50 24369 W7.51 p C.CO S3R.2 9"9.42 3263.62 44395 I"nQ 3]A.4 3J"." 44344 R 0.44 30]1.32 37x4 SN5.02 445.39 12 O.M .W66.A 3"AA 3999.66. 4215.3) M 0.39 9Kd.W 37M. 3E03.53'. 445"1 9 0.38 ASS." 3MM 35iL55 145.1] 61 O.M , AM.35 9756." YY.% 4M.A I9 0. 3617.94, 3]55,91 41MX 1 Y.N 9 0.98 $8.59 3"5.59 13]3.13 SM. 14 9 0.2 453.8 3441.13 4w.A 42SIM N .17.38 39A.A 9A3" 447.52 .11 IS_ 11).Y. 3"2.". "M.A %%A.27 3IMS44 q 31'44 3M3% )A9.M SSM.M "16.44 13 3ll.6 3102.1. J1d9.11 smn 3"2.16 Q 31).44 3171.53 3719.53 "51,30 MIM 3 22].63 36"" 34459 63ID 45 3m I, a 3"A9' 9858.44 316SJ6'i Wi.01' 'IsIv c.5- «ae- MDndn N6,a ludt3 MAIN.TIOMIM - W&302.T20"i7w 0.% ON MIA Od0 KIM '13wp23 IH45, IH45 V5 IH-IM.IK105 V6 I 1K0a,1H-09V1 1HdI,1K110 1Kt; 2Ku V1 IK13, 1K13 N IH-14,IK14VI IHd5.IKIS V2 IH.31.IH-AVl WAM.. III 40L ... 4103 0wmetl�I... 1101 Oneida 1... 't ® la h D a El it R5 a. � 7, 1b Qt T A n 4 O.M 3.4] 21.]1 W-tOa)ILT3101M])Rp Leo169].35 MX.tl AX..E'PFt05T 1%].OS 1]44.44 IMM T3 IMM.M OTrerelM1ng CyM1ndp Yien ® � Q 0 Im � % % so vz ® + ii Q,1 Q _ 3.0] O.W OM O.M O.M W.MX312T12W1I%7 P 2-was.0 bf) 2295.05 ]3%.10 K.15 0.M O.M W.10%] ll.1D0'Y9t)RP 51%.CA D35.V 3135.tl "]5,61 1312.60 }").M u4 9 6329.91 31".M M5.)O WJ 5T60 MAX "3O.A Ne 5OO O ]2W.91 3"2.93 T)52".1V5 C Suvq/Pa. M1VeMrt) Sant' iwY '3 ]39).62 3"9.10 3]" M .IS_C N6B.8] 3)19.4 361910 A5 9 10 W,1 3153" t5>. 31O j j IQ61.1K1L>17 F. 1H I[g3a1A35 HYiD54.41rC�3'-5[ MIUM _ 106))1 "]I.M B)IM '45 A9 W1Kp'.! , 3Ra 1HIO23A1AA HWDHfl9Mtl w 31%.A _ MIPs IH10 74721MI4 M4D IKk ONLY 3953" 'V9 A3 W%[9ro AO 7822176 9321M Wlkh3np23Fed : 1H 10L1))4TFiNM MWD A79.% WSA2 '82176 tut397.1H102L1g23Ra;tH 1p2L13 )1Th14M4 MWD -IFF -A39 K ®0 Inn -1 O f ForHelp,p fl 00 Trava g Cylinder AAmuth (TFO+AZn (7 YS Centre to Centre Separation prsfij Q Common WNl Name Unit Sy4arn API US Sum Feet Angles' DepMn unit Map'. uM 1R-25 1R-16 1RR-01gBLL1-01 11F2 -8--18L 1-01 PBI 1R1R0 1R -29L1 %1R -29L1-01 1R-24 1 R-27 1H-102L3wp 3 % 1f'11G-12L1 1H - Easting (2500 usttlin) 1 1H-125wp20 /1H-124wp20 - 1H-123wp20 1H-122wp20 1H-121 n^1 . 1H-1 ✓/ / 1H-120wp21 7- 1NC-ONLY toolcode) j 1H-115wp21 16wp21 1H -12 1H-113wp21 111wp21 JIG -12 1H -151H- - 1H -104v I 1H -107w H-106wp21 - 1C-1 1C-1 1 4L1 - 1H-01 1 - 16-102 t ic H-08 1H-02 - 1H-Y\1C-1 1C\17 Easting (2500 uattlin) I C-154wp06 1C-155 1f 1C 9 wp0[11C-156(1'fwp0CCl146; 57 1 \ i xpo05 1 1 R-02 1 H-20 '*PBI ¶ 9( 1 C Y� H-19AL1 N c g 1G-07 1 119A 1H 16A 1 H-1' H-17 c L1 1H-16AL1 Z 1H-19AL2 1H- L1 1G-10BPR1 1 _ 1 Kuparuk 1H Pa 1113' � 1Hl4Q�1-U1 i % 1f'11G-12L1 1H - Easting (2500 usttlin) 1 1H-125wp20 /1H-124wp20 - 1H-123wp20 1H-122wp20 1H-121 n^1 . 1H-1 ✓/ / 1H-120wp21 7- 1NC-ONLY toolcode) j 1H-115wp21 16wp21 1H -12 1H-113wp21 111wp21 JIG -12 1H -151H- - 1H -104v I 1H -107w H-106wp21 - 1C-1 1C-1 1 4L1 - 1H-01 1 - 16-102 t ic H-08 1H-02 - 1H-Y\1C-1 1C\17 Easting (2500 uattlin) I C-154wp06 1C-155 1f 1C 9 wp0[11C-156(1'fwp0CCl146; 57 1 \ i xpo05 1 1 H-102L3wp23 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 4-1/2" x 6-3/4"�-�q O� 6000 ADO 1 FY ,t 2L3 13.TD 020917 P 1 02L3 1AT12 020917 P Q23 11 L3 11.T11 020917 P 4500 11H UW3 10.T10 020917 P 1 H-1 62L3 09.T9 020917 P + P 000 3 07.T7 020917 P 0 ? LH -102006.T6 020917 P 3 05.T5 020917 P 00 1 H -102L3 0434 020917 P 1500 1H -102L3 03.T3 020917 P 9000 1H -102L3 02.T2 020917 P O� 0 20" x 42"- - - - - -� po 1 H- 02L3 01.T1 020917 P 00 7-5/8" x 9-7/8" i MO O 10-3/4" x 13-1/2" 7000 0 0 0 -1500 0 -3000 -1500 0 1500 3000 0 4500 6000 7500 West( -)/East(+) 1 H-102L3wp23 Section View 3680 J N r f N W 3760-' io 7-5/8" x 9-7/8" 4-1/2" x 6-3/4" o 0 0 0 0 0 0 a a� o oo � 03840- 0) o CO a --- U O O O o 'C o O � ° A A M N o O A 3920 CL O N J N O r = M r N O. 3 4000- 04 O_ 2 ' S O N 4080- ^� w 0 850 1700 2550 3400 4250 5100 5950 6800 Vertical Section at 0.000 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk1H Pad Plan: IH -102 (formerly 31) Plan: 11-1-1021-3 Plan: 1 H-102L3wp23 Standard Proposal Report 29 June, 2017 Tier Cr' 3 steering Failed Anti -Collision Minor Risked Database: EDM Production Company: ConowPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1H Ped Well: Plan: 11-1-102 (formerly 31) Wellbore: Plan: 111-1021-3 Design: iH-102L3wp23 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 Kuparuk River Unit North Slope Alaska, United States System Datum: Mean Sea Level Using Well Reference Point Phase: PLAN Using geodetic scale factor Vertical Section. Depth From (TVD) +N/ -S SIM Kuparuk I Pad (usft) Site Position: (usft) (') From: Map 0.00 0.00 Position Uncertainty: 0.00 usft Slot Radius: 0.. Well Plan: iH-102(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-10213 Magnetics Model Name Sample Date Declination Dlp Angle Field Strength BGGM2017 6/22/2017 17.62 80.95 57,498 Design 1H-102L3wp23 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,471.76 Vertical Section. Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (') 39.00 0.00 0.00 0.00 6292017 10:45:04AM Page 2 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. -Kupl TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kupamk River Unit MD Reference: Plan: 54+39 (03 93.00usft (Doyon 142) Site: Kuparuk 1 H Pad North Reference: True Well: Plan: 1 H-102 (formedy 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-10213 Depth Inclination Design: 1H-102L3wp23 System +N/ -S Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/ -S +E/ -W Rate Rate Rate Tool Face (usft) (°) (1 (usft) usft (usft) (usft) ('/100usft) (°/100usft) (°HOOusft) (°) 7,471.76 75.57 0.00 3,819.82 3,726.82 -252.92 4,369.05 0.00 0.00 0.00 0.00 7,484.56 77.61 0.00 3,822.79 3,729.79 -240.46 4,369.05 15.90 15.90 0.00 0.00 7,504.56 77.61 0.00 3,827.08 3.734.08 -220.93 4,369.05 0.00 0.00 0.00 0.00 7,798.61 92.29 0.71 3,852.90 3,759.90 71.17 4,370.89 5.00 4.99 0.24 2.81 8,079.70 92.29 0.71 3,841.67 3,748.67 - 352.01 4,374.39 0.00 0.00 0.00 0.00 8,158.22 89.96 0.39 3,840.13 3,747.13 430.50 4,375.14 3.00 -2.97 -0.42 -172.00 8,873.99 89.96 0.39 3,840.65 3,747.65 1,146.26 4,379.96 0.00 0.00 0.00 0.00 8,888.23 90.24 0.38 3,840.62 3,747.62 1,160.50 4,380.06 2.00 2.00 -0.05 -1.38 9,557.34 90.24 0.38 3,837.79 3,744.79 1,829.59 4,384.48 0.00 0.00 0.00 0.00 9,581.81 89.78 0.22 3,837.78 3.744.76 1,854.06 4,384.61 2.00 -1.89 -0.66 -160.64 9,592.26 89.99 0.22 3,837.80 3,744.80 1,864.51 4,384.65 2.00 2.00 0.00 -0.09 9,896.77 89.99 0.22 3,837.85 3,744.85 2,169.02 4,385.80 0.00 0.00 0.00 0.00 9,969.82 87.80 0.22 3,839.26 3,746.26 2,242.05 4,386.08 3.00 -3.00 0.00 179.91 10,269.84 87.89 348.21 3,850.58 3,757.58 2,539.79 4,355.92 4.00 0.03 4.00 -89.78 10,302.28 87.89 348.21 3,851.77 3,758.77 2,571.52 4,349.29 0.00 0.00 0.00 0.00 10,359.64 87.27 346.00 3,854.19 3,761.19 2,627.38 4,336.50 4.00 -1.08 -3.85 -105.74 10,479.64 87.27 346.00 3,859.90 3,766.90 2,743.68 4,307.51 0.00 0.00 0.00 0.00 11,002.97 90.00 0.00 3,872.42 3,778.42 3,261.62 4,243.95 2.72 0.52 2.68 79.19 11,120.64 90.00 359.99 3,872.42 3,779.42 3,379.29 4,243.94 0.01 0.00 -0.01 -88.54 11,166.38 91.92 0.44 3,871.32 3,778.32 3,445.02 4,244.19 3.00 2.92 0.68 13.19 11,338.11 91.92 0.44 3,866.23 3.77323 3,596.66 4,245.37 0.00 0.00 0.00 0.00 11,344.98 92.04 0.38 3,866.00 3,773.00 3,603.53 4,245.41 2.00 1.75 -0.97 -29.13 11,353.01 92.20 0.38 3,865.70 3,772.70 3,611.55 4,245.47 2.00 2.00 0.00 0.00 11,778.74 92.20 0.36 3,849.35 3,756.35 4036.96 4,248,26 0.00 0.00 0.00 0.00 11,852.10 90.00 0.38 3,847.94 3,754.94 4,110.30 4,248.74 3.00 -3.00 0.00 180.00 11,913.23 88.78 0.38 3,848.59 3,755.59 4,171.43 4,249.14 2.00 -2.00 0.00 -180.00 12,330.17 88.78 0.38 3,857.49 3,764.49 4,588.26 4,251.88 0.00 0.00 0.00 0.00 13,273.63 88.64 317.36 3,879.79 3.78679 5,447.52 3,919.80 4.56 -0.01 -4.56 -90.68 13,383.43 88.64 317.36 3,882.39 3,789.39 5,528.27 3,845.44 0.00 0.00 0.00 0.00 13,426.23 90.00 317.89 3,882.90 3,789.90 5,559.89 3,816.60 3.40 3.17 1.23 21.21 13,492.06 91.32 317.89 3,882.14 3,789.14 5,608.72 3,772.46 2.00 2.00 0.00 0.00 13,953.97 91.32 317.89 3,871.53 3,778.53 5,951.30 3,462.80 0.00 0.00 0.00 0.00 14,418.39 91.62 327.63 3,859.58 3,766.58 6,320.45 3,182.17 2.10 0.07 2.10 88.07 14,443.97 91.62 327.63 3,858.86 3,765.86 6,342.04 3,168.48 0.00 0.00 0.00 0.00 6/292017 10:45,04AM Page 3 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. -Kupl TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 @ 93.00ush (Doyon 142) She: Kuparuk 1 H Pad North Reference: True Well: Plan: 1 H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-1021-3 (usft) usft Design: 111-1021-3wp23 3,726.82 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/.W DLS Vert Section (usft) (I (°) (usft) usft (usft) (usft) 3,726.82 7,471.76 75.57 0.00 3,819.82 3,726.82 -252.92 4,369.05 560.61 -252.92 KOP: 15.9°/100' DLS, 0° TF, for 12.8' 7,471.77 75.57 0.00 3,819.82 3,726.82 -252.91 4,369.05 0.01 -252.91 7418" x 9-7/8" 7,474.78 76.05 0.00 3,820.56 3,727.56 -249.99 4,369.05 15.95 -249.99 Hold for 20' 7,484.56 77.61 0.00 3,822.79 3,729.79 -240.46 4,369.05 15.90 -240.46 Hold for 20' 7,494.78 77.61 0.00 3,824.98 3,731.98 -230.48 4,369.05 0.00 -230.48 Start 4°/100' DLS, 0° TF, for 283.99' 7,500.00 77.61 0.00 3,826.10 3,733.10 -225.38 4,369.05 0.00 -225.38 7,504.56 77.61 0.00 3,827.08 3,734.08 -220.93 4,369.05 0.00 -220.93 7,600.00 82.37 0.24 3,843.67 3,750.67 -126.97 4,369.25 5.00 -126.97 7,700.00 87.37 0.48 3,852.61 3,759.61 -27.41 4,369.87 5.00 -27.41 7,778.77 91.30 0.67 3,853.53 3,760.53 51.34 4,370.65 5.00 51.34 Start 3°1100' DLS, -0.61° TF, for 117.12' 7,798.61 92.29 0.71 3,852.90 3,759.90 71.17 4,370.89 5.00 71.17 7,800.00 92.29 0.71 3,852.85 3,759.85 72.56 4,370.91 0.00 72.56 7,895.88 92.29 0.71 3,849.02 3,756.02 168.36 4,372.10 0.00 168.36 Hold for 131.73' 7,900.00 92.29 0.71 3,848.85 3,755.85 172.47 4,372.15 0.00 172.47 8,000.00 92.29 0.71 3,844.85 3,751.85 272.38 4,373.40 0.00 272.38 8,027.61 92.29 0.71 3,843.75 3,750.75 299.97 4,373.74 0.00 299.97 Start 3°1100' DLS, 178.76° TF, for 117.14' 8,079.70 92.29 0.71 3,841.67 3,748.67 352.01 4,374.39 0.00 352.01 8,100.00 91.69 0.63 3,640.96 3,747.96 372.30 4,374.63 3.00 372.30 8,144.75 90.36 0.44 3,840.17 3,747.17 417.04 4,375.05 3.00 417.04 Start 2°1100' DLS, 180° TF, for 2.09' 8,146.84 90.30 0.43 3,840.15 3,747.15 419.13 4,375.06 3.00 419.13 Hold for 713.68' .8,158.22 89.96 0.39 3,840.13 3,747.13 430.50 4,375.14 3.00 430.50 8,200.00 89.96 0.39 3,840.16 3,747.16 472.29 4,375.42 0.00 472.29 8,300.00 89.96 0.39 3,840.23 3,747.23 572.28 4,376.10 0.00 572.28 8,400.00 89.96 0.39 3,840.30 3,747.30 672.28 4,376.77 0.00 672.28 8,500.00 89.96 0.39 3,840.38 3,747.38 772.28 4,377.44 0.00 772.28 8,600.00 89.96 0.39 3,840.45 3,747.45 872.28 4,376.12 0.00 872.28 8,700.00 89.96 0.39 3,840.52 3,747.52 972.27 4,378.79 0.00 972.27 8,800.00 89.96 0.39 3,840.60 3,747.60 1,072.27 4,379.47 0.00 1,072.27 8,860.52 89.96 0.39 3,840.64 3,747.64 1,132.79 4,379.87 0.00 1,132.79 Start 2°1100' DLS, 4.66° TF, for 13.96' 8,873.99 89.96 0.39 3,840.65 3,747.65 1,146.26 4,379.96 0.00 1,146.26 8,874.48 89.97 0.39 3,840.65 3,747.65 1,146.76 4,379.97 2.00 1,146.76 Hold for 679.52' 8,888.23 90.24 0.38 3,840.62 3,747.62 1,160.50 4,380.06 2.00 1,160.50 8,900.00 90.24 0.38 3,840.57 3,747.57 1,172.27 4,380.14 0.00 1,172.27 6292017 10,45:04AM 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: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Plan: 54+39 @ 93,00usft (Doyon 142) Project: Kupamk 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: 111-10213 DLS Vert Section Design: 1H-1021-3wp23 (usft) usft Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/.W DLS Vert Section (usft) (1) (1 (usft) usft (usft) (usft) 3,747.15 9,000.00 90.24 0.38 3,840.15 3,747.15 1,272.27 4,380.80 0.00 1,272.27 9,100.00 90.24 0.38 3,839.73 3,746.73 1,372.26 4,381.46 0.00 1,372.26 9,200.00 90.24 0.38 3,839.30 3,746.30 1,472.26 4,382.12 0.00 1,472.26 9,300.00 90.24 0.38 3,838.88 3,745.88 1,572.26 4,382.78 0.00 1,572.26 9,400.00 90.24 0.38 3,838.45 3,745.45 1,672.25 4,383.44 0.00 1,672.25 9,500.00 90.24 0.38 3,838.03 3,745.03 1,772.25 4,384.11 0.00 1,772.25 9,554.00 90.24 0.38 3,837.80 3,744.80 1,826.25 4,384.46 0.00 1,826.25 Start 2.1100' DLS, 445.85' TF, for 14.34' 9,557.34 90.24 0.38 3,837.79 3,744.79 1,829.59 4,384.48 0.00 1,829.59 9,568.35 90.04 0.31 3,837.76 3,744.76 1,840.60 4,384.55 2.00 1,840.60 Adjust TF to 180', for 11.09' 9,579.43 89.83 0.23 3,837.77 3,744.77 1,851.68 4,384.60 2.00 1,851.68 Hold for 376.91' 9,581.81 89.78 0.22 3,837.78 3,744.76 1,854.06 4,384.61 2.00 1,854.06 9,592.26 89.99 0.22 3,837.80 3,744.80 1,864.51 4,384.65 2.00 1,864.51 9,600.00 89.99 0.22 3,837.80 3,744.80 1,872.25 4,384.68 0.00 1,872.25 9,700.00 89.99 0.22 3,837.82 3,744.82 1,972.25 4,385.06 0.00 1,972.25 9,800.00 89.99 0.22 3,837.84 3,744.84 2,072.25 4,385.44 0.00 2,072.25 9,896.77 89.99 0.22 3,837.85 3,744.85 2,169.02 4,385.80 0.00 2,169.02 9,900.00 89.89 0.22 3,837.85 3,744.85 2,172.25 4,385.81 3.00 2,172.25 9,956.34 88.20 0.22 3,838.79 3,745.79 2,228.58 4,386.03 3.00 2,228.58 Start 4.03°/100' DLS, -104.84° TF, for 369.09- 9,969.82 87.80 0.22 3,839.26 3,746.26 2,242.05 4,386.08 3.00 2,242.05 10,000.00 87.80 359.01 3,840.42 3,747.42 2,272.20 4,385.88 4.00 2,272.20 10,100.00 87.83 355.01 3,844.23 3,751.23 2,371.98 4,380.67 4.00 2,371.98 10,200.00 87.86 351.01 3,847.99 3,75499 2,471.14 4,368.50 4.00 2,471.14 10,269.84 87.89 348.21 3,850.58 3,757.58 2,539.79 4,355.92 4.00 2,539.79 10,300.00 67.89 348.21 3,851.69 3,758.69 2,569.29 4,349.76 0.00 2,569.29 10,302.28 87.89 348.21 3,851.77 3,758.77 2,571.52 4,349.29 0.00 2,571.52 10,315.43 87.75 347.70 3,852.27 3,759.27 2,584.37 4,346.55 4.00 2,584.37 Hold for 14.15' 10,329.58 87.60 347.16 3,852.85 3,759.85 2,598.17 4,343.47 4.00 2,598.17 Start 4-/100' DLS, 18.18' TF, for 16.73' 10,346.31 87.42 346.51 3,853.57 3,760.57 2,614.44 4,339.67 4.00 2,614.44 Start 3.5°/100' DLS, -8T TF, for 61.25' 10,349.11 87.39 346.41 3,853.70 3,760.70 2,617.16 4,339.01 4.00 2,617.16 WS -A4 10,359.64 87.27 346.00 3,854.19 3,761.19 2,627.38 4,336.50 4.00 2,627.38 10,397.56 87.27 346.00 3,856.00 3,763.00 2,664.13 4,327.34 - 0.00 2,664.13 Adjust TF to 74.95°, for 375.59' 10,400.00 87.27 346.00 3,856.11 3,763.11 2,666.49 4,326.75 0.00 2,666.49 10,479.64 87.27 346.00 3,859.90 3,766.90 2,743.68 4,307.51 0.00 2,743.68 10,500.00 87.38 346.55 3,860.85 3,767.85 2,763.44 4,302.68 2.72 2,763.44 10,600.00 87.89 349.22 3,864.98 3,771.98 2,861.12 4,281.71 2.72 2,861.12 10,700.00 88.41 351.90 3,868.21 3,775.21 2,959.70 4,265.32 2.72 2,959.70 8/2912017 10:45.04AM 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: 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: Kupamk 1H Pad North Reference: True Well: Plan: 11-1-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-1021-3 3,777.00 Design: 1H-102L3wp23 3,870.00 3,777.00 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W DLS Vert Section (usft) C) P) (usft) usft (usft) (usft) 3,777.00 10,773.15 88.79 353.86 3,870.00 3,777.00 3,032.26 4,256.26 2.72 3,032.26 Hold for 326' 10,800.00 88.93 354.57 3,870.53 3,777.53 3,058.97 4,253.55 2.72 3,058.97 10,827.11 89.08 355.30 3,871.00 3,778.00 3,085.97 4,251.16 2.72 3,085.97 WS_A4_Objective 10,900.00 89.46 357.25 3,871.93 3,778.93 3,158.70 4,246.42 2.72 3,158.70 11,000.00 89.98 359.92 3,872.42 3,779.42 3,258.66 4,243.95 2.72 3,258.66 11,002.97 90.00 0.00 3,872.42 3,779.42 3,261.62 4,243.95 2.72 3,261.62 11,098.15 90.00 359.99 3,872.42 3,779.42 3,356.80 4,243.94 0.01 3,356.80 Start 2.1100' DLS, 84.02° TF, for 66.65' 11,100.00 90.00 359.99 3,872.42 3,779.42 3,358.66 4,243.94 0.01 3,358.66 11,120.64 90.00 359.99 3,872.42 3,779.42 3,379.29 4,243.94 0.01 3,379.29 11,166.70 91.35 0.31 3,871.88 3,778.88 3,425.35 4,244.06 3.00 3,425.35 Hold for 36.09' 11,186.38 91.92 0.44 3,871.32 3,778.32 3,445.02 4,244.19 3.00 3,445.02 11,200.00 91.92 0.44 3,870.86 3,777.86 3,458.63 4,244.30 0.00 3,458.63 11,202.79 91.92 0.44 3,870.77 3,777.77 3,461.42 4,244.32 0.00 3,461.42 Start 2'1100' DLS, 41.68° TF, for 127.47' 11,300.00 91.92 0.44 3,867.51 3,774.51 3,558.57 4,245.07 0.00 3,558.57 11,330.26 91.92 0.44 3,866.50 3,773.50 3,588.81 4,245.30 0.00 3,588.81 Adjust TF to 0°, for 13.28' 11,338.11 91.92 0.44 3,866.23 3,773.23 3,596.66 4,245.37 0.00 3,596.66 11,343.54 92.02 0.39 3,866.05 3,773.05 3,602.09 4,245.40 2.00 3,602.09 Hold for 378.54' 11,344.98 92.04 0.38 3,866.00 3,773.00 3,603.53 4,245.41 2.00 3,603.53 11,353.01 92.20 0.38 3,865.70 3,772.70 3,611.55 4,245.47 2.00 3,611.55 11,400.00 92.20 0.38 3,863.89 3,770.89 3,658.51 4,245.78 0.00 3,658.51 11,500.00 92.20 0.38 3,860.05 3,767.05 3,758.43 4,246.43 0.00 3,758.43 11,600.00 92.20 0.38 3,856.21 3,763.21 3,858.35 4,247.09 0.00 3,858.35 11,700.00 92.20 0.38 3,852.37 3,759.37 3,958.28 4,247.74 0.00 3,958.28 11,722.08 92.20 0.38 3,851.53 3,758.53 3,980.34 4,247.89 0.00 3,980.34 Start 2'/100' DLS, -180' TF, for 116.3' 11,778.74 92.20 0.38 3,849.35 3,756.35 4,036.96 4,248.26 0.00 4,036.96 11,800.00 91.56 0.38 3,848.65 3,755.65 4,058.21 4,248.40 3.00 4,058.21 11,837.38 90.44 0.38 3,848.00 3,755.00 4,095.58 4,248.65 3.00 4,095.58 Start 3.76°/100' DLS, 105.61° TF, for 126.82' 11,852.10 90.00 0.38 3,847.94 3,754.94 4,110.30 4,248.74 3.00 4,110.30 11,900.00 89.04 0.38 3,848.34 3,755.34 4,158.20 4,249.06 2.00 4,158.20 11,913.23 88.78 0.38 3,848.59 3,755.59 4,171.43 4,249.14 2.00 4,171.43 11,964.20 88.78 0.38 3,849.68 3,756.68 4,222.38 4,249.48 0.00 4,222.38 Hold for 33.61' 11,997.71 88.78 0.38 3,850.40 3,757.40 4,255.89 4,249.70 0.00 4,255.69 Start 3.76'/100' DLS, -90.66° TF, for 318.66' 12,000.00 88.78 0.38 3,850.44 3,757.44 4,258.17 4,249.71 0.00 4,258.17 12,100.00 88.78 0.38 3,852.58 3,759.58 4,358.15 4,250.37 0.00 4,358.15 6!29/2017 1045:04AM Page 6 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 11-1-102 (formerly 31) Company: ConowPhillips (Alaska) Inc. -Kupt TVD Reference: Plan: 54+39 Q 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 Q 93.00usft (Doyon 142) Site: Kupamk 1H Pad North Reference: True Well: Plan: 1 H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 11-1-1021-3 TVDss +Nl-S Design: 1H-102L3wp23 Vert Section (usft) Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +Nl-S +E1 -W DLS Vert Section (usft) (1 (•) (usft) usft (usft) (waft) 3,761.71 12,200.00 88.78 0.38 3,854.71 3,761.71 4,458.12 4,251.03 0.00 4,458.12 12,300.00 88.78 0.38 3,856.85 3,763.85 4,558.10 4,251.68 0.00 4,558.10 12,316.37 88.78 0.38 3,857.19 3,764.19 4,574.46 4,251.79 0.00 4,574.46 Adjust TF to -92.52°, for 379.81' 12,330.17 88.78 0.38 3,857.49 3,764.49 4,588.26 4,251.88 0.00 4,568.26 12,400.00 88.74 357.19 3,859.00 3,766.00 4,658.05 4,250.40 4.56 4,658.05 12,500.00 88.70 352.63 3,861.24 3,768.24 4,757.60 4,241.54 4.56 4,757.60 12,600.00 88.66 348.07 3,863.55 3,770.55 4,856.14 4,224.79 4.56 4,856.14 12,696.18 88.63 343.69 3,865.82 3,772.82 4,949.36 4,201.35 4.56 4,949.36 Hold for 141.11' 12,700.00 88.63 343.52 3,865.91 3,772.91 4,953.03 4,200.27 4.56 4,953.03 12,800.00 88.61 338.96 3,868.31 3,775.31 5,047.66 4,168.12 4.56 5,047.66 12,837.29 88.61 337.26 3,869.22 3,776.22 5,082.25 4,154.22 4.56 5,082.25 Start 3.76.1100' DLS, -84.92° TF, for 556.94' 12,900.00 88.60 334.40 3,870.74 3,777.74 5,139.44 4,128.55 4.56 5,139.44 13,000.00 88.60 329.84 3,873.18 3,780.18 5,227.76 4,081.81 4.56 5,227.78 13,100.00 88.61 325.28 3,875.62 3,782.62 5,312.12 4,028.19 4.56 5,312.12 13,200.00 88.62 320.72 3,878.03 3,785.03 5,391.94 3,968.04 4.56 5,391.94 13,273.63 88.64 317.36 3,879.79 3,786.79 5,447.52 3,919.80 4.56 5,447.52 13,300.00 88.64 317.36 3,880.42 3,787.42 5,466.92 3,901.94 0.00 5,466.92 13,383.43 88.64 317.36 3,882.39 3,789.39 5,528.27 3,845.44 0.00 5,526.27 13,396.22 89.05 317.52 3,882.65 3,789.65 5,537.70 3,836.79 3.40 5,537.70 Start 2'1100' DLS, 0° TF, for 65.83' 13,400.00 89.17 317.57 3,882.71 3,789.71 5,540.46 3,834.24 3.40 5,540.48 13,426.23 90.00 317.89 3,882.90 3,789.90 5,559.89 3,816.60 3.40 5,559.89 13,462.06 90.72 317.89 3,882.68 3,789.68 5,586.47 3,792.58 2.00 5,586.47 Hold for 461.91' 13,492.06 91.32 317.89 3,882.14 3,789.14 5,608.72 3,772.46 2.00 5,608.72 13,500.00 91.32 317.89 3,881.96 3,788.96 5,614.61 3,767.14 0.00 5,614.61 13,600.00 91.32 317.89 3,879.66 3,786.66 5,688.78 3,700.10 0.00 5,688.78 13,700.00 91.32 317.89 3,877.37 3,784.37 5,762.94 3,633.06 0.00 5,762.94 13,800.00 91.32 317.89 3,875.07 3,782.07 5,837.11 3,566.02 0.00 5,837.11 13,900.00 91.32 317.89 3,872.77 3,779.77 5,911.27 3,498.98 0.00 5,911.27 13,923.97 91.32 317.89 3,872.22 3,779.22 5,929.05 3,482.92 0.00 5,929.05 Start 2.1°1100' DLS, 88.07° TF, for 464.42' 13,953.97 91.32 317.89 3,871.53 3,778.53 5,951.30 3,462.80 0.00 5,951.30 14,000.00 91.35 318.85 3,870.46 3,777.46 5,965.69 3,432.23 2.10 5,985.69 14,100.00 91.42 320.95 3,868.04 3,775.04 6,062.16 3,367.85 2.10 6,062.16 14,200.00 91.48 323.05 3,865.51 3,772.51 6,140.93 3,306.30 2.10 6,140.93 14,300.00 91.55 325.14 3,862.86 3,769.86 6,221.90 3,247.68 2.10 6,221.90 14,388.38 91.61 327.00 3,860.43 3,767.43 6,295.20 3,198.37 2.10 6,295.20 Hold for 25.58' 14,400.00 91.61 327.24 3,860.10 3,767.10 6,304.95 3,192.07 2.10 6,304.95 14,413.96 91.62 327.53 3,859.71 3,766.71 6,316.71 3,184.54 2.10 6,316.71 TD: 14413.96' MD, 3868.86' TVD 6292017 10:45:04AM Page 7 COMPASS 5000.1 Build 74 Database: EDM Production Local Co-ordinate Reference: Company: ConomPhillips (Alaska) Inc. -Kupl TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kupawk 1 H Pad North Reference: Well: Plan: 1 H-102 (formerly 31) Survey Calculation Method: Wellbore: Plan: 1H-10213 Design: 1H-102L3wp23 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +EbW (usft) O (^) lush) usft (usft) (usft) 14,418.39 91.62 327.63 3,859.58 3,766.58 6.32045 3,182.17 14,443.97 91.62 327.63 3,858.86 3,765.86 6,342.04 3,16848 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 DLS Vert Section 3,766.56 2.10 6,320.45 0.00 6,342.04 6292017 10.45:04AM Page 8 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Coordinate Reference: Well Plan: 1 H-102 (formerly 31) Company: ConowPhillips (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 I Pad North Reference: True Well: Plan: 11H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 11H-1021-3 3,816.60 - plan hits target center Design: 1H-1021-3wp23 - Circle (radius 100.00) Targets Target Name -hitimiss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W - Shape (I V) lush) lush) (usft) 1H-102B02.T216Febl5 BW 0.00 0.00 3,850.00 2,695.12 4,390.14 - plan misses target center by 68.75usft at 10412.14usft MD (3856.69 TVD, 2678.26 N, 4323.82 E) - Circle (radius 100.00) 1H-1021-311.711020917 RP 0.00 0.00 3,882.90 5,559.89 3,816.60 - plan hits target center - Circle (radius 100.00) 1H-102004.T416Febl 5 BW 0.00 0.00 3,873.00 3,425.18 4,394.93 - plan misses target center by 150.87usft at 11167.49usft MD (3871.86 TVD, 3426.14 N, 4244.07 E) - Circle (radius 100.00) 1H -102B O1 T1 150015 BW 0.00 0.00 3,834.99 578.96 4,376.24 - plan misses target center by 5.25usft at 8306.68usft MD (3840.24 TVD, 578.96 IN, 4376.14 E) - Circle (radius 100.00) 1H-1021307.77020917 RP 0.00 0.00 3,872.42 3,37929 4,243.94 - plan hits target center - Circle (radius 100.00) iH-102B 09.T915OC115 BW 0.00 0.00 3,860.95 5,009.30 4,405.34 - plan misses target center by 213A 5usft at 12696.45usft MD (3865.82 TVD, 4949.63 N. 4201.27 E) - Circle (radius 100.00) 1 HA 0213 05.75 020917 RP 0.00 0.00 3,654.19 2,627.38 4,336.50 - plan hits target center - Circle (radius 100.00) IH-102L313.TD 020917 RP 0.00 0.00 3,858.86 6,342.04 3,168.48 - plan hits target center - Circle (radius 100.00) 1H -102B 02.T2150c115 BW 0.00 0.00 3,842.00 1,207.01 4,380.36 - plan misses target center by 1.57usft at 8934.74usft MD (3840.43 TVD, 1207.00 N, 4380.37 E) - Circle (radius 100.00) 1H-1021303.73020917 RP 0.00 0.00 3,837.78 1,654.06 4,384.61 - plan hits target center - Circle (radius 100.00) 1H -1021308.T8020917 RP 0.00 0.00 3,866.00 3,603.53 4,245.41 - plan hits target center - Circle (radius 100.00) 1H -102B 01 T1 16Feb15 BW 0.00 0.00 3,842.00 1,207.01 4,380.36 - plan misses target center by 1.57usft at 8934.74usft MD (3840.43 TVD, 1207.00 N, 4380.37 E) - Circle (radius 100.00) 1H -102B 0636 150C 5 BW 0.00 0.00 3,663.57 3,711.20 4,396.81 - plan misses target center by 150.69usft at 11453.66usft MD (3861.83 TVD, 3712.12 N, 4246.13 E) - Circle (ratlius 100.00) 1H-1021-310.710020917 RP 0.00 0.00 3,857.49 4,588.26 4,251.88 - plan hits target center - Circle (radius 100.00) 1H-1021309.79020917 RP 0.00 0.00 3,847.94 4,110.30 4,248.74 - plan hits target center - Circle (radius 100.00) 1H -1021304.T4020917 RP 0.00 0.00 3,839.26 2,242.05 4,386.08 - plan hits target center - Circle (radius 100.00) iH-102B 033315Octl5 BW _ .,ice., ..,eee. ..,...e...,._.,..... �e e..._.. 0.00 0.00 3,849.41 2,695.12 _. ,,,.,. ,..._....,. ,....�„ ,,., r, .....,.�.. ...... ....._ __ _. 4,390.14 6292017 10.45:04AM Page 9 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. -Kupi TVD Reference: Plan: 54+39 @ 93.0Ousft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 @ 93.0Ousft (Doyon 142) Site: Kuparuk 1 H Pad North Reference: True Well: Plan: 11-1-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H -102L3 - Circle (radius 100.00) Design: lH-102L3wp23 - plan hits target center 1H-1021-312.712020917 RP 0.00 0.00 3,871.53 5,951.30 3,462.80 - plan hits target center - Circle (radius 100.00) 1H -102B 10.T7015Oct15 BW 0.00 0.00 3,888.17 5,282.32 4,407.13 - plan misses target center by 313.57usft at 12900.00usft MD (3870.74 TVD, 5139.44 N, 4128.55 E) - Circle (radius 100.00) 111-102607.T716Fe1b15 BW 0.00 0.00 3,862.00 4,789.28 4,403.89 - plan misses target center by 165.21 usft at 12504.05usft MD (3861.33 TVD, 4761.61 N. 4241.01 E) - Circle (radius 100.00) 1H -102B 08.T8150ctl 5 BW 0.00 0.00 3,861.87 4,789.28 4,403.89 - plan misses target center by 165.21 usft at 12504.04usft MD (3861.33 TVD, 4761.81 N, 4241.01 E) - Circle (radius 100.00) 1H-1021-301.71020917 RP 0.00 0.00 3,840.13 430.50 4,375.14 - plan hits target center - Circle (radius 100.00) 1H-1021302.72020917 RP 0.00 0.00 3,840.65 1,146.26 4,379.96 - plan hits target center - Circle (radius 100.00) 1H -102B 04.T4150ci15 BW 0.00 0.00 3,873.86 3,003.15 4,392.16 - plan misses target center by 131.63usft at 10727.51 usft MD (3868.94 TVD, 2986.96 N, 4261.62 E) - Circle (radius 100.00) 1H -102B 07.T715Oc115 BW 0.00 0.00 3,852.02 4,403.25 4,401.35 - plan misses target center by 150.69usft at 12146.07usft MD (3853.58 TVD, 4404.21 N, 4250.67 E) - Circle (radius 100.00) 1H -1021306.T6020917 RP 0.00 0.00 3,868.60 2,921.34 4,265.47 - plan misses target center by 5.80usft at 10662.16usft MD (3867.10 TVD, 2922.31 N, 4270.98 E) -Circle (radius 100.00) 1 H-1 02B 05.75 16Febl5 BW 0.00 0.00 3,864.00 3,711.20 4,396.81 - plan misses target center by 150.70usft at 11453.64usft MD (3861.83 TVD, 3712.11 N, 4246.13 E) - Circle (radius 100.00) 1H -102B 03 T316Feb15 BW 0.00 0.00 3,874.00 3,003.15 4,392.16 - plan misses target center by 131.63usft at 10727.52usft MD (3868.94 TVD, 2986.96 N, 4261.62 E) - Circle (radius 100.00) 1H -102805.75150c115 BW 0.00 0.00 3,873.35 3,425.18 4,394.93 - plan misses target center by 150.87usft at 11167.48usft MD (3871.86 TVD, 3426.13 N, 4244.07 E) - Circle (radius 100.00) 1H -102B 06.T616Febl5 BW 0.00 0.00 3,852.00 4,403.25 4,401.35 - plan misses target center by 150.69usft at 12146.07usft MD (3853.56 TVD, 4404.21 N, 4250.67 E) - Circle (radius 100.00) 7,471.77 3,819.82 7-5/8" x 9-7/8" 7-5/8 9-7/8 14,443.97 3,858.86 4-1/2"x6-3/4" 4-1/2 6-3/4 629/2017 10:45: 04AM Page 10 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 1 H-102 (formerly 31) Company: ConowPhillips (Alaska) Inc. -Kupl TVD Reference: Plan: 54+39 Q 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: 1H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-1021-3 3,819.10 WS_B Design: 1H-102L3wp23 WS_ A4_ Objective 7,388.62 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology V) O 10,349.11 3,853.70 WS—A4 1,697.35 1,620.40 PFROST 6,319.91 3,486.80 UG A 5,166.08 3,135.40 UG—C 7,468.87 3,819.10 WS_B 10,827.11 3,871.00 WS_ A4_ Objective 7,388.62 3,799.10 VVS_C 7,200.81 3,752.30 WS_D 5,975.61 3,382.60 UG—B 6,706.09 3,610.70 Na 2,195.08 2,008.40 K-15 1,903.05 1,788.60 T-3 6292017 10.45..04AM Page 11 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. -Kupt TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project Kuparuk River Unit MD Reference: Plan: 54+39 @ 93+00usft (Doyon 142) Site: Kuparuk 1 H Pad North Reference: True Well: Plan: IH -102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 11-1-1021-3 KOP: 13.56°/100' DLS, 0" TF, for 16.5' Design: 1 W102L3wp23 -252.92 4,369.05 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 7,458.28 KOP: 13.56°/100' DLS, 0" TF, for 16.5' 7,471.76 3,819.82 -252.92 4,369.05 KOP: 15.9°/100' DLS, 0° TF, for 12.8' 7,474.78 3,820.56 -249.99 4,369.05 Hold for 20' 7,484.56 3,822.79 -240.46 4,369.05 Hold for 20' 7,494.78 3,824.98 -230.48 4,369.05 Start 4°/100' DLS, 0° TF, for 283.99' 7,778.77 3,853.53 51.34 4,370.65 Start 3°/100' DLS, -0.61° TF, for 117.12' 7,895.88 3,849.02 168.36 4,372.10 Hold for 131.73' 8,027.61 3,843.75 299.97 4,373.74 Start 3°/100' DLS, 178.76° TF, for 117.14' 8,144.75 3,840.17 417.04 4,375.05 Start 2°/100' DLS, 180° TF, for 2.09' 8,146.84 3,840.15 419.13 4,375.06 Hold for 713.68' 8,860.52 3,840.64 1,132.79 4,379.67 Start 2'/100' DLS, -1.65° TF, for 13.96' 8,874.48 3,840.65 1,146.76 4,379.97 Hold for 679.52' 9,554.00 3,837.80 1,826.25 4,384.46 Start 2°/100' DLS, -145.85° TF, for 14.34' 9,568.35 3,837.76 1,840.60 4,384.55 Adjust TF to 180°, for 11.09' 9,579.43 3,837.77 1,851.68 4,384.60 Hold for 376.91' 9,956.34 3,838.79 2,228.58 4,386.03 Start 4.03°/100' DLS, -104.84° TF, for 359.09' 10,315.43 3,852.27 2,584.37 4,346.55 Hold for 14.15' 10,329.58 3,852.85 2,598.17 4,343.47 Start 4°/100' DLS, 18.18° TF, for 16.73' 10,346.31 3,853.57 2,614.44 4,339.67 Start 3.5°/100' DLS, -97° TF, for 51.25' 10,397.56 3,856.00 2,664.13 4,327.34 Adjust TF to 74.95°, for 375.59' 10,773.15 3,870.00 3,032.26 4,256.26 Hold for 325' 11,098.15 3,872.42 3,356.80 4,243.94 Start 2°/100' DLS, 84.02° TF, for 68.55' 11,166.70 3,871.88 3,425.35 4,244.06 Hold for 36.09' 11,202.79 3,870.77 3,461.42 4,244.32 Start 2°A00' DLS, 41.88° TF, for 127.47' 11,330.26 3,866.50 3,588.81 4,245.30 Adjust TF to 0°, for 13.28' 11,343.54 3,866.05 3,602.09 4,245.40 Hold for 378.54' 11,722.08 3,851.53 3,980.34 4,247.89 Start 2°/100' DLS, -180° TF, for 115.3' 11,837.38 3,848.00 4,095.58 4,248.65 Start 3.75°/100' DLS, 105.61° TF, for 126.82' 11,964.20 3,849.68 4,222.38 4,249.48 Hold for 33.51' 11,997.71 3,850.40 4,255.89 4,249.70 Start 3.75°/100' DLS, -90.56° TF, for 318.66' 12,316.37 3,857.19 4,574.46 4,251.79 Adjust TF to -92.52°, for 379.81' 12,696.18 3,865.82 4,949.36 4,201.35 Hold for 141.11' 12,837.29 3,869.22 5,082.25 4,154.22 Start 3.75°/100' DLS, -84.92` TF, for 558.94' 13,396.22 3,882.65 5,537.70 3,836.79 Start 2°/100' DLS, 0° TF, for 65.83' 13,462.06 3,882.68 5,586.47 3,792.58 Hold for 461.91' 13,923.97 3,872.22 5,929.05 3,482.92 Start 2.1°/100' DLS, 88.07" TF, for 464.42' 14,388.38 3,860.43 6,295.20 3,198.37 Hold for 25.58' 14,413.96 3,859.71 6,316.71 3,184.54 TD: 14413.96' MD, 3858.86' TVD 6/29201710:45:04AM Page 12 COMPASS 5000.1 Build 74 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-102 (formerly 31) Plan: 1 H-1021_3 50103xxxxx00 1 H-102L3wp23 Clearance Summary Anticollision Report 29 June, 2017 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk lH Pad -Plan: IH -102 (formerly 31) -Plan: 111-10213-1H-102L3wp23 Well Coordinates: Datum Height: Plan: 54«39@93.00usft(Doyon 142) Scan Range: 7,471.76 to 14,443.97 usft. Measured Depth. Scan Radius is 1,640.50 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 Failed Anti -Coll,' ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Plan: 11-1-102 (formerly 31) - 1H-102L3wp23 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kupamk 1H Pad - Plan: IH -102 (formerly 31) - Plan: 1H -102L3 - iH-102L3wp23 Scan Range: 7,471.76 to 14,443.97 usft. Measured Depth. Scan Radius is 1,640.50 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 12,116.55 10,569.17 1,452.31 10,569.17 1,250.38 6,950.00 7.192 Clearance Factor Pass -Major Risk 11-1-05-1H-105-11-1-105 1,203.72 10,449.05 366.29 10,449.05 257.70 7,350.00 3.373 Centre Distance Pass -Major Risk 1H -05 -IH -105-1H-105 12,042.50 10,474.37 373.97 10,474.37 251.43 7,425.00 3.052 Clearance Factor Pass -Major Risk 1H -12 -1H -12-1H-12 878.21 7,912.34 1,610.44 7,912.34 1,441.74 6,350.00 9.546 Clearance Factor Pass -Major Risk 1H -12 -1H -12-1H-12 6,500.00 7,915.39 1,610.29 7,915.39 1,441.86 6,375.00 9.562 Centre Distance Pass - Major Risk Plan: 1 H-101 (formerly 103, 29) - Plan: 1H-101 - 1H-10 14,241.64 1,163.90 14,241.64 982.30 11,975.00 6.409 Clearance Factor Pass - Major Risk Plan: 1 H-1 01 (formerly 103,29) -Plan: 1H -101L1 -1H 14,200.00 1,194.95 14,200.00 1,006.15 11,900.00 6.329 Clearance Factor Pass - Major Risk Plan: 1 H-1 01 (formerly 103, 29) -Plan: iH-101 L2 -1H 14,168.41 1,216.98 14,16841 1,030.77 11,850.00 6.536 Clearance Factor Pass - Major Risk Plan: I H-1 01 (formerly 103, 29) -Plan: 1H-101 L3 -1H 14,147.24 1,237.62 14,147.24 1,058.71 11,800.00 6.918 Clearance Factor Pass - Major Risk Plan :IH-101(formerly 103, 29) -Plan: 1H -101L4 -1H 14,100.00 1,302.30 14,100.00 1,116.79 11,700.00 7.020 Clearance Factor Pass - Major Risk Plan: 1 H-102 (formerly 3l)- Plan:1 H-102- 1 H-102wp2 — Plan :1H-102(formerly 3l) -Plan: IH -10211 -1H -102L — Plan: iH-102(formerly 3l) -Plan: IH -10212 -1H -102L — Pian: 1 H-102 (formerly 3l)- Plan: 1 H-10212- 1H -102L — Plan: iH-102(formerly 3l) -Plan: 11 -1 -10214 -1H -102L 7,473.17 28.92 7,473.17 22.98 7,475.00 4.870 Centre Distance Pass -Major Risk Plan: 1 H-102 (formerly 31) - Plan: 1 H-1021-4 - 1 H-1 02L - — PIan: 1H-103 (formerly 104, 33) - Plan: 1 H-1031-1 - I 12,116.55 1,201.14 12,116.55 1,009.56 13,750.00 6 270 Clearance Factor Pass - Major Risk Plan: 1H-103 (formerly 104, 33) - Plan: 1 H-1031_3 - I 12,081.09 1,203.72 12,081.09 1,017.37 13,675.00 6.459 Clearance Factor Pass - Major Risk Plan: 1H-103 (formerly 104, 33) - Plan: 1 H-1031.4 - I 12,042.50 1,209.25 12,042.50 1,024.75 13,575.00 6.554 Clearance Factor Pass - Major Risk Plan : 1H-109 (formerly 110, 30C) - Plan: 1H-109 - 1 H-1 8,224.44 1,001.53 8,224.44 878.21 6,375.00 8.121 Centre Distance Pass- Major Risk Plan :1H-109(formerly 110, 30C) -Plan: 1H -109-1H-1 8,338.88 1,002.87 8,338.88 877.01 6,500.00 7.968 Clearance Factor Pass - Major Risk Plan: 1 H-111 (formerly 109, 32D) - Plan: 1H-111 - 1H-1 8,045.47 399.63 8,045.47 303.09 6,375.00 4.139 Centre Distance Pass- Major Risk Plan :1H-111(formerly 109, 32D) -Plan: 1H -111-1H-1 8,048.62 401.80 8,048.62 301.20 6,425.00 3.994 Clearance Factor Pass - Major Risk Plan :1H-113(formerly 112, 34B) -Plan: IH -113-1H-1 8,199.55 738.20 8,199.55 644.11 6,325.00 7.846 Centre Distance Pass -Major Risk Plan* 1H-113(formerly 112, 34B) -Plan: 1H -113-1H-1 8,204.03 739.41 8,204.03 643.17 6,375.00 7.683 Clearance Factor Pass -Major Risk Plan* 1H-114(formerly 30B,116) -Plan: 1H -114-1H-1 10,700.00 941.81 10,700.00 801.76 7,200.00 6.725 Clearance Factor Pass -Major Risk Plan: iH-115 (formerly 115, 34A, 114) - Plan: 1 H-115 - 9,232.11 691.11 9,232.11 590.32 6,500.00 6.857 Centre Distance Pass - Major Risk Plan* 1H-115 (formerly 115, 34A, 114) - Plan : 1 H-115 - 9,248.11 692.92 9,248.11 588.62 6,550.00 6.643 Clearance Factor Pass - Major Risk 29 June, 2017 - 10:47 Page 2 of 6 COMPASS ConocoPhillips (Alaska) inc. -Kupl Kuparuk River Unit Anticollision Report for Plan: 11-1-102 (formerly 31) -1 H-102L3wp23 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kupamk IN Pad - Plan: 1H-102(formerly 31) -Plan: 11-1-1021-3-[H-1020Wp23 Scan Range: 7,471.76 to 14,443.97 usft Measured Depth. Scan Radius is 1,640.50 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Survey tool program From Measured Minimum @)Measured Ellipse @Measuretl Clearance Summary Based on 39.00 Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft 7,821.76 9,321.76 1H-102L3wp23 Plan :1H-116(formerly 114, 328, 115) -Plan: iH-116- 9,306.20 44849 9,306.20 344.77 6,550.00 4.324 Centre Distance Pass - Major Risk Plan: 11-1-116 (formerly 114,32B, 115) - Plan: IH -116- 9,321.10 450.55 9,321.10 342.27 6,600.00 4.161 Clearance Factor Pass- Major Risk Plan: 1 H-11 8 (formerly 30A,119) -Plan: 1H -118-1H-1 13,479.55 766.59 13,479.55 622.34 8,275.00 5.314 Clearance Factor Pass - Major Risk Plan : 11-1-120(A1035,formerly 117) -Plan: iH-120-iH 9,921.03 755.99 9,921.03 658.37 ,6,650.00 7.744 Centre Distance Pass - Major Risk Plan :1H -120(A1035, formerly 117) - Plan : 1H -120-1H 9,935.10 757.37 9,935.10 657.41 6,700.00 7.577 Clearance Factor Pass - Major Risk Plan :1H-121(A1034,formery 119) -Plan: iH-121-iH 10,473.02 672.53 10,473.02 572.63 6,800.00 6.732 Centre Distance Pass -Major Risk Plan : 1H -121(A1034, formerly 119) -Plan: 1H -121-1H 10,479.76 673.24 10,479.76 572.09 6,825.00 6.656 Clearance Factor Pass -Major Risk Plan: 1H -122(A1033, formerly At 040) -Plan: 11-1-122 11,360.24 529.25 11,360.24 418.00 7,200.00 4.757 Centre Distance Pass -Major Risk Plan :1H -122(A1033, formerly At 040) -Plan: 11-1-122 11,403.67 532.98 11,403.67 414.07 7,275.00 4.482 Clearance Factor Pass -Major Risk Plan: 1H -123(A1032, formerly At 033) - Plan : 11-1-123 12,229.36 345.30 12,229.36 229.86 7,700.00 2.991 Centre Distance Pass -Major Risk Plan: 1H -123(A1032, formerly At 033) -Plan: iH-123 12,314.46 356.51 12,314.46 220.75 7,825.00 2.626 Clearance Factor Pass -Major Risk Plan 111-124(A1031, formery A1036)-PIan: 1H-124 13,169.61 214.91 13.169.61 100.75 8,125.00 1.882 Centre Distance Pass - Major Risk Plan :1H-124(Al 031, formerly A1036) - Plan : 1H-124 13,175.05 216.79 13,175.05 98.72 8,150.00 1.836 Clearance Factor Pass - Major Risk Plan :1H-125(Al 030, formerly At 039) -Plan: 11-1-125 14,150.29 176.02 14,150.29 52.08 8,250.00 1.420 Centre Distance Pass - Major Risk Plan :IH -125(A1030, formerly At 039) -Plan: 11-1-125 14,168.39 184.90 14,168.39 47.51 8,300.00 1.346 Clearance Factor Pass - Major Risk Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 39.00 700.00 GYD-GC-SS 700.00 1,794.10 MWD+IFR-AK-CAZ-SC 1,794.10 7,471.76 MWD+IFR-AK-CAZ-SC 7,471.76 7,821.76 1H-10213wp23 MWD -INC _ONLY 7,821.76 9,321.76 1H-102L3wp23 MWD 7,821.76 14,443.97 IH-102L3wp23 MWD+IFR-AK-CAZ-SC 29 June, 2017 - 10,47 Page 3 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit AnticolIision Report for Plan: 11-1-102 (formerly 31) - 1 H-1 O2L3wp23 Ellipse error terns 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 I (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 29 June. 2017 - 10:47 Page 4 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-102 (formerly 31) Plan: 1 H-1021_3 50103xxxxx00 1H-102L3wp23 Clearance Summary Anticollision Report 29 June, 2017 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) I Minor Risked I Reference Design: Kuparuk 1H Pad -Par: 1H-102 (formerly 31) -Plan: 1H-1021_3 - 1H-102L3wp23 Well Coordinates: Datum Height: Plan: 54+39 @ 93.00usft (Doyon 142) Scan Range: 7,471.76 to 14,443.97 usft. Measured Depth, Scan Radius is 1,640.50 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 Kuparuk 1H Pad 1H -05 -1H -05-1H-05 ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Plan: 1H-102 (formerly 31) - 1H-102L3wp23 10,569.17 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) 6,950.00 Reference Design: Kuparuk lH Pad - Plan: IH -102 (formerly 31) -Plan: 1H-1021-3-1H-102L3wp23 Clearance Factor Scan Range: 7,471.76 to 14,443.97 usft. Measured Depth, 1 H-05 - 1 H-105 - 1 H-105 Scan Radius is 1,640.60 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited 366.29 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 Pass - Major Risk Kuparuk 1H Pad 1H -05 -1H -05-1H-05 10,569.17 1,452.31 10,569.17 1,250.38 6,950.00 7.192 Clearance Factor Pass - Major Risk 1 H-05 - 1 H-105 - 1 H-105 10,449.05 366.29 10,449.05 257.70 7,350.00 3.373 Centre Distance Pass - Major Risk 1H -05 -1H -105-1H-105 10,474.37 373.97 10,474.37 251.43 7,425.00 3.052 Clearance Factor Pass - Major Risk 1H -12 -1H -12-1H-12 7,912.34 1,610.44 7,912.34 1,441.74 6,350.00 9.546 Clearance Factor Pass -Major Risk 1H -12 -1H -12-1H-12 7,915.39 1,610.29 7,915.39 1,441.88 6,375.00 9.562 Centre Distance Pass - Major Risk Plan: 1 H-101 (formerly 103, 29) - Plan: 1H-101 - 1H-10 14,241.64 1,163.90 14,241.64 962.30 11,975.00 6.409 Clearance Factor Pass - Major Risk Plan: 1 H-1 01 (formerly 103, 29) -Plan: 1H -101L1 -1H 14,200.00 1,194.95 14,200.00 1,006.15 11,900.00 6.329 Clearance Factor Pass - Major Risk Plan :1H-101(formerly 103,29) -Plan: 1H-101 L2 -1H 14,168.41 1,216.98 14,168.41 1,030.77 11,850.00 6.536 Clearance Factor Pass - Major Risk Plan :1H-101(formerly 103,29) -Plan: 1H-101 L3 -1H 14,147.24 1,237.62 14,147.24 1,058.71 11,800.00 6.918 Clearance Factor Pass - Major Risk Plan: 1H-101(formerly 103,29) -Plan: 1H-101 L4 -1H 14,100.00 1,302.30 14,100.00 1,116.79 11,700.00 7.020 Clearance Factor Pass - Major Risk Plan: IH -102 (formerly 31) - Plan: IH -102 - 1 H-102wp2 ® _ Plan: 1 H-102 (formerly 31) - Plan: 1 H-10211 - 1 H-1 02L Plan: 1 H-102 (formerly 31) - Plan: 1 H-1 02L2 - 1 H-1 02L Plan: 1 H-1 02 (formerly 31) -Plan: 1H -102L4 -1H -102L 7,473.17 28.92 7,473.17 26.50 7,475.00 11.951 Clearance Factor Pass - Minor 1/50 Plan* 1H-103(formerly 104, 33) -Plan: 1H -1031-1-1H 12,116.55 1,201.14 12,116.55 1,009.56 13,750.00 6.270 Clearance Factor Pass -Major Risk Plan: 1H-103(formerly 104, 33) -Plan: 1H -10313-1H 12,081.09 1,203.72 12,081.09 1,017.37 13,675.00 6.459 Clearance Factor Pass - Major Risk Plan :1H-103(formerly 104, 33) -Plan: 1H -10314-1H 12,042.50 1,209.25 12,042.50 1,024.75 13,575.00 6.554 Clearance Factor Pass -Major Risk Plan* 1H-109(formerly 110, 30C) -Plan: 1H -109-1H-1 8,224.44 1,001.53 8,224.44 878.21 6,375.00 8.121 Centre Distance Pass - Major Risk Plan* 1H-109(formerly 110, 30C) -Plan: 1H -109-1H-1 8,338.88 1,002.87 8,338.88 877.01 6,500.00 7.968 Clearance Factor Pass - Major Risk Plan* 1H-111 (formerly 109, 32D) - Plan: 1H-111 - 11-1-1 8,045.47 399.63 8,045.47 303.09 6,375.00 4.139 Centre Distance Pass - Major Risk Plan : 1H-111 (formerly 109, 32D) - Plan: 1H-111 - 11-1-1 8,048.62 401.80 8,048.62 301.20 6,425.00 3.994 Clearance Factor Pass - Major Risk Plan :1H-113(formerly 112, 34B) -Plan: 1H -113-1H-1 8,199.55 738.20 8,199.55 644.11 6,325.00 7.846 Centre Distance Pass - Major Risk Plan: 1H-113(formerly 112, 34B) -Plan: 1H -113-1H-1 8,204.03 739.41 8,204.03 643.17 6,375.00 7.663 Clearance Factor Pass - Major Risk Plan : 1H-114(formerly 308, 116) -Plan: 1H -114-1H-1 10,700.00 941.81 10,700.00 601.76 7,200.00 6.725 Clearance Factor Pass - Major Risk Plan: 1H-115(formerly 115, 34A, 114) -Plan* 1H-115- 9,232.11 691.11 9,232.11 590.32 6,500.00 6.857 Centre Distance Pass -Major Risk Plan* 1H-115 (formerly 115, 34A, 114) - Plan: 1H-115 - 9,248.11 692.92 9,248.11 588.62 6,550.00 6.643 Clearance Factor Pass - Major Risk Plan : 1H-116 (formerly 114, 32B, 115) - Plan: 1 H-116 - 9,306.20 448.49 9,306.20 344.77 6,550.00 4.324 Centre Distance Pass - Major Risk Plan: 1H-116 (formerly 114, 32B, 115) - Plan: 1 H-116 - 9,321.10 450.55 9,321.10 342.27 6,600.00 4.161 Clearance Factor Pass - Major Risk 29 June, 2017 - 15:36 Page 2 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Plan: 1H-102 (formerly 31)-1H-1O2L3wp23 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad - Plan: 1H-102(formarly 31) -Plan: 1H.102L3 - 1H.102L3wp23 Scan Range: 7,471.76 to 14,443.97 usft. Measured Depth. Scan Radius is 1,640.60 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited 29 June, 2017 - 15:36 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: 1 H-118 - 11-1-1 13,479.55 766.59 13,479.55 622.34 8,275.00 5.314 Clearance Factor Pass - Major Risk Plan : 1H-120(At 035, formerly 117) -Plan: 1H -120-1H 9,921.03 755.99 9,921.03 658.37 6,650.00 7.744 Centre Distance Pass -Major Risk Plan :1H-120(At 035, formerly 117) -Plan: 1H -120-1H 9,935.10 757.37 9,935.10 657.41 6,700.00 7.577 Clearance Factor Pass -Major Risk Plan : lH-121(A1034,formerly119)-PIan: 1H -121-1H 10,473.02 672.53 10,473.02 572.63 6,800.00 6.732 Centre Distance Pass -Major Risk Plan: 1H-121(Al 034, formerly 119) -Plan: 1H -121-1H 10,479.76 673.24 10,479.76 572.09 6,825.00 6.656 Clearance Factor Pass - Major Risk Plan : 1 H-122 (Al 033, formerly A1040) - Plan: 11-1-122 11,360.24 529.25 11,360.24 418.00 7,200.00 4.757 Centre Distance Pass - Major Risk Plan: 1 H-122 (Al 033, formerly A1040) - Plan : 1H-122 11,403.67 532.98 11,403.67 414.07 7,275.00 4.482 Clearance Factor Pass - Major Risk Plan: 1 H-123 (Al 032, formerly A1033) - Plan : 11-1-123 12,229.36 345.30 12,229.36 229.86 7,700.00 2.991 Centre Distance Pass - Major Risk Plan: 1 H-123 (Al 032, formerly A1033) - Plan : 11-1-123 12,314.46 356.51 12,314.46 220.75 7,825.00 2.626 Clearance Factor Pass - Major Risk Plan: 1H-124(Al 031, formerly A1036) - Plan : 1H-124 13,169.61 214.91 13,169.61 100.75 8,125.00 1.882 Centre Distance Pass - Major Risk Plan :1H -124(A1031, formerly A1036)-PIan: 11-1-124 13,175.05 216.79 13,175.05 98.72 8,150.00 1.836 Clearance Factor Pass - Major Risk Plan* 1H -125(A1030, formerly A1039)-PIan: 11-1-125 14,150.29 176.02 14,150.29 52.08 8,250.00 1.420 Centre Distance Pass - Major Risk Plan: 1 H-1 25 (Al 030, formerly Al 039) - Plan : 11-1-125 14,166.39 184.90 14,168.39 47.51 8,300.00 1.346 Clearance Factor Pass - Major Risk Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 39.00 700,00 GYD-GC-SS 700.00 1,794.10 MWD+IFR-AK-CAZ-SC 1,794.10 7,471.76 _ MWD+IFR-AK-CAZ-SC 7,471.76 71821.76 1H-102L3wp23 MWD -INC _ONLY 7,821.76 9,321.76 1H-102L3wp23 MWD 7,821.76 14,443.97 1 H-102L3wp23 MWD+IFR-AK-CAZ-SC 29 June, 2017 - 15:36 Page 3 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Plan: 11-1-102 (formerly 31) - 1H-1O2L3wp23 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 - 15:36 Page 4 or 6 COMPASS Ladder View 1 H-102L3wp23 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. 3 300 — - - - --- 0 CL m g d k 150 o � 3 E4uivdam Ma9nerc o..... 0 8000 9000 10000 11000 12000 13000 14000 Displayed interval could be less than entire well:Measured Depth7471.76 To 14443.97 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 700.00 1H-102wp23 (Plan: 11-1-102) GYD-GC-SS 3819.82 7471.77 7-5/8" x 9-7/8" 700.00 1794.10 1H-102wp23 (Plan: 11-1-102) MWD+IFR-AK-CAZ-SC 3858.8614443.97 4-1/2"x6-3/4" 1794.10 7471.76 1H-102wp23 (Plan: 11-1-102) MWD+IFR-AK-CAZ-SC 7471.76 7821.76 1H-102L3wp23 (Plan: 1H-1021-3) MWD-INC—ONLY 7821.76 9321.76 1H-102L3wp23 (Plan: 11-1-1021-3) MWD 7821.76 14443.97 1H-102L3wp23 (Plan: 11-1-1021-3) MWD+IFR-AK-CAZ-SC so x i ------ .2 is i a 00 l m 4c 30- 0 7500 7500 8000 8800 9000 9500 10000 10500 11000 Partial Measured Depth Ladder View 1 H-102L3wp23 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. Minor Risked D. 3 300— 00 C p f0 V�Ij✓ Ri d i it d � 150 lug s d i U i Equivalence Magnetic Distance 0 8000 9000 10000 11000 12000 13000 14000 Displayed interval could be less than entire well:Measured Depth7471.76 To 14443.97 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 700.00 1H-102wp23(Plan:11-1-102) GYD-GC-SS 3819.82 7471.77 7-5/8"x9-7/8" 700.00 1794.10 1H-102wp23 (Plan: 11-1-102) MWD+IFR-AK-CAZ-SC 3858.86 14443.97 4-1/2"x6-3/4" 1794.10 7471.76 1H-102wp23 (Plan: 11-1-102) MWD+IFR-AK-CAZ-SC 7471.76 7821.76 1H-102L3wp23 (Plan: 1H-1021-3) MWD-INC—ONLY 7821.76 9321.76 1H-102L3wp23 (Plan: 111-1-1021-3) MWD 7821.76 14443.97 1H-102L3wp23 (Plan: 1H-1021-3) MWD+IFR-AK-CAZ-SC S x z so— c O .� t F A a w U 2 30 U 0 v c v U Eamvwm Meyn.�i. walen<e 0- 7500 7500 8000 8500 9000 9500 10000 10500 11000 Partial Measured Depth 1 H-1 02L3wp23 Toace Ta''-` 7472 7660 47,,MD 7sInc apes 3879782 0 a 7471.76 To 14443.97 7484.56 77.61 0.00 3822.79 15.90 0.00 7660 7850 7504.56 7798.61 77.61 92.29 0.00 0.71 3827.08 3852.90 0.00 5.80 0.00 2.81 7850 8040 8079.70 92.29 0.71 3841.67 0.00 0.00 8040 8230 8158.22 89.96 0.39 3840.13 3.00 -172.00 1H-102L3 01.71 020917 RP 8873.99 89.96 0.39 3840.65 0.00 0.00 7H-102L3 02.T2 020917 RP 8230 8420 CASING DETAILS 8888.23 9557.34 90.24 90.24 0.38 0.38 3840.62 3837.79 2.00 0.00 -1.38 0.00 8420 8610 TVD MD mane 3819.82 7471.77 7-5/8' x 9-7/8' 9581.81 89.78. 0.22 3837.78 2.00 -160.64 1H-102L3 03.T3 020917 RP 3858.86 14443.97 4-112' x 6-314' 9592.26 89.99 0.22 3837.80 2.00 -0.09 8610 8800 9896.77 89.99 0.22 3837.85 0.00 0.00 9969.82 87.80 0.22 3639.26 3.00 179.91 IH-102L3 04.T4 020917 RP 8800 9040 10269.84 10302.28 10359.64 87.89 87.89 87.27 348.21 348.21 346.00 3850.58 3851.77 3854.19 4.00 0.00 4.00 -89.78 0.00 -105.74 1H-102L3 05.T5 020917 RP 9040 9260 9280 9510 .v nw«x 10479.64 87.27 346.00 3859.90 0.00 0.G0 1x .ea:c 11002.97 90.00 0.00 3872.42 2.72 79.19 9510 9750 .w m..:.x.oxu� 11120.64 90.00 359.99 3872.42 0.01 -88.54 1H-102L3 07.T7 020917 RP ..xs ux«.ai ii.iwrov tr,.::: a-«xu� w.xmax.vx 11186.38 91.92 0.44 3871.32 3.00 13.79 9750 9990 11338.77 91.92 0.44 386.23 0.00 0.00 11344.98 92.84 0.38 38666.88 2.80 -29.13 IH-102L3 08.78 020977 RP 9980 10220 11353.01 92.20 0.38 3665.70 2.00 0.00 - 10220 10460 11852.10 90.00 0.38 3847.94 3.00 180.00 1H-102L3 09.T9 020917 RP 11913.23 88.78 0.38 3848.59 2.00 -180.00 10460 _ - 10700 12330.17 88.78 0.38 3857.49 0.00 0.00 1H-102L3 10.770 026917 RP 10700 11170 13273.63 88.64 317.36 3879.79 4.56 .90.68 13383.43 88.64 317.36 981G3609 0.00 0.00 11170 11640 1H-124Wp20 . 13426.23 90.00 317.8 90 3.40 21.21 7H-102L3 17.771 020917 RP 13492.06 91.32 317'.8 0'.BO 11640 12100 13953.97 91 Y. ';, H-102L3 12.T12 020917 RP 14418.39 bY62�--S�7. 'i2?Ti3 63 • 5 iD 13L 3%TlH-125Wp20 12100 12570 -301330 14443<m gr;? 3 5 $ 12570 13040 i 4 13040 13510 13510 13960 13980 14444 -120/240 -150/ -180/180 120 H-1 11 H -102L1 wo231 -120/240 \ \ \ \ \ \ \ -i' / / / / / / / 120 -150/210 z7u / 150 -180/180 Minor Risked - u /4R 1 H-1 02L3wp23 MD Inc nz1 TO Dleg TFace Ta. _t 7472 7660 7471.76 75.57 0.00 3819.82 0.00 0.00 TO 14443.97 7484.56 77.61 0.00 3822.79 15.90 0.00 7660 7850 ;39.00 7504.56 77.61 92.29 0.00 0.71 3827.08 0.00 3852.90 5.00 0.007798.61 2.817650 8040 8079.70 92.29 0.71 3841.67 0.00 0.008040 8230 8158.22 89.96 0.39 3840.13 3.00 -172.00 1H-102L3 01.71 020917 RPca51NG 8873.99 89.96 0.39 3840.65 0.00 0.00 1H-10213 02.T2 020917 RP 8230 8420 DETRILS 8888.23 90.24 9557.34 90.24 0.38 0.38 3840.62 2.00 3837.79 0.00 -1.38 0.00 8420 8610 MD Nana 3819.62 7471.77 7-5/8' x 9-7/8' 9581.81 89.78 0.22 3837.78 2.00 -160.64 IH-102L3 03.T3 020917 RP 3856.86 14443.97 4-1/2' x 6-3/4' 9592.26 89.99 0.22 3837.80 2.00 -0.09 8610 8800 9896.77 89.99 0.22 3837.85 0.00 0.00 9969.82 87.80 0.22 3839.26 3.00 179.91 iH-1021-3 04.T4 620917 RP 8800 9040 10269.84 87.89 10302.28 87.89 10359.64 87.27 348.21 348.21 346.00 3850.58 4.00 3851.77 0.00 3854.19 4.00 -105.74 -89.78 0.00 1H-10213 05.T5 020917 RP 9040 _ 9280 9280 9510 « w.ay. «...p.r.rcJ.n .«r inauwi �n� iw iui nw.ian: ax-ne«a ,n«: ax-aur ru:0.:ux- 10479.64 87.27 11902.97 90.00 346.00 0.00 3859.90 0.00 3872.42 2.72 0.00 79.19 9510 9750 11120.64 90.00 359.99 3872.42 0.01 -88.54 1H-102L3 07.77 020917 RP za.n v«..n ax.nu+.m rn«:.nuvur �.a-ru-.x- 11186.38 91.92 0.44 3871.32 3.00 13.19 9750 - 9990 11338.11 91.92 0.44 3866.23 0.00 9.09 11344.98 92.04 0.38 3866.98 2.00 -29.13 1N-10213 08.78 020917 RP 9990 10220 11353.01 92.20 0.38 3865.76 2.00 0.00 - 10220 10460 11852.10 90.00 0.36 3847.94 3.00 180.00 U-19213 09.T9 020917 RP 11913.23 88.78 0.38 3848.59 2.00 -180.08 10460 10700 12330.17 88.78 0.38 3857.49 0.00 0.00 1H-1021-3 10.T10 026917 RP 10700 11170 13273.63 88.64 317.36 3879.79 4.56 -90.68 13383.43 88.64 317.36 04,8g6b9 0.00 0.00 11170 11640 1H-124wp20 - - - -13426.23 90.00 317. EQ J8 90 3.40 21.21 IH-10213 11.T11 020917 RP 13492.06 91.32 13953.97 91 317.8 - . 6 32-3 tit, j, 9 .00 H-10213 12.T12 020917 RP 11640 - 12100 14418.33-91'4,f,7 3 5 .5 �� - - 12100 12570 -30/330 1444 1 .,-9% '127.'63 a 5 ,$ L.3Vs 1H-125wp20 ' 12570 13040 1 � � � �� V 13040 13510 80 13510 13980 15 13980 - - 14444 rt, _ �� - � � 1300 60 -60 0/ / �l_.. 9 _ ---�' H-1 11 H -102L1 wo231 -120/240 \ \ \ \ \ \ \ -i' / / / / / / / 120 -150/210 z7u / 150 -180/180 Minor Risked a Spider) Kuparuk 1H Pad Easting (2500 usft/in) Easting (2500 usit/in) iwp20 1H-120wp21 3 AC Flipbook ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-102 (formerly 31) 50103xxxxx00 Plan: 1H -102L3 Plan: 1 H-102L3wp23 Error Ellipse Survey Report 29 June, 2017 Company: ConocoPhillips (Alaska) Inc. -Kupt Project: Kupamk River Unit Site: Kuparuk 1H Pad Well: Plan: 11-1-102 (formerly 31) Wellbore: Plan: 1H-1021-3 Design: 1H-1021-3vi SLB Error Ellipse Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1H-102 (formerly 31) Pian: 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 (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 700.00 1 H-102wp23 (Plan 11-1-102) GYD-GC-SS Gyrodata gyro single shots 700.00 1,794.10 1 H-1 02wp23 (Plan: 1 H-102) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 1,794.10 7,471.76 1 H-1 02wp23 (Plan: 1 H-102) MWD+IFR-AK-CAZ-SC MWD+I FR AK CAZ SCC 7,471.76 7,821.76 1 H-1 02L3wp23 (Plan: 1 H-1021-3) MWD -INC -ONLY MWD-INC_ONLY_FILLER 7,821.76 9,321.76 1 H-1 02L3wp23 (Plan: 1 H-1021-3) MWD MWD -Standard 7,821.76 14,443,97 1 H-1 02L3wp23 (Plan: 1 H-10213) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC Position uncertainty and blas at survey station Measured Inclination Azimuth vol Hlghsie, Lateral Vntical Ma9Mutlu S.ori em or Semiminor Depth Depth Error Bias Error Bias Error Bias ofBe. Error Error Azimuth Tool (usft) (1) IT (haft) (usft) loan) (.011 loan) lush 1.011 lush (mft) Imft) 0 7,47176 75.57 0.00 3,81982 10.85 .144 9.80 244 885 1.55 290 24.42 8.25 10330 MWD+IFR-AK-CA SC(1, 3) 7.471.77 75.57 0,00 381982 10.85 -1A4 9.80 244 8.85 1.55 290 24.42 8.25 103.30 AW INC _ONLY (, 4) 7.47/78 7605 000 3,820.% 10,74 -1,45 980 244 8.83 155 290 2453 882 10295 MW41NC_ONLY (1,4) 7.484.56 77.61 0.00 3.822.79 1042 -146 9.80 244 883 1.55 290 24.53 8.33 10295 MlN0.1NO_ONLY(1, 4) 7,4N.78 7761 000 3,824.98 10.42 -146 9.81 244 8.83 1.55 290 2653 8.33 102.96 MW61NC_ONLY (1. 4) 7,504.56 77.61 - 0.00 3.827.08 1042 -146 9.91 2.44 883 155 2.90 2653 8.33 102.06 MWD-INC_ONLY n. 4) 7,778.77 91.30 0.67 3,053.53 8.86 -159 16.93 243 e.% 157 293 24.81 1578 109.37 MWD-INC_ONLY(1. 4) 7798,61 92.29 071 3,85290 886 -1.59 1883 2.43 8.90 157 293 24.81 1578 109.37 MWD -INC ONLY n. 4) 7,095.00 92.29 071 3,849.02 8.89 -159 20.59 235 894 157 287 25.10 19.30 117.20 him (1, 5) 8,027,61 9229 071 3,843]5 893 -1S9 20.80 205 8.97 1m 264 24.67 2007 113.14 BOND (1, 5) 8,079.70 9229 071 3,941.67 893 .1.59 20.80 205 8.97 IN 2.84 2467 2007 113.14 Sim (1, 5) 8.144.75 9039 044 3,840.17 901 -156 20.93 1.92 9.01 158 2.55 24.50 2039 110.69 MWD(, 5) 8.146.84 90.30 0.43 3,040.15 901 -1.56 20.93 1.92 9.01 156 255 24.50 20.39 110.69 MWD(, 5) 8.158.22 Sees 0.38 3,840.13 9.01 -156 20.93 1.92 901 156 2.55 2450 20.39 11059 MWD(1, 5) 8.860.52 89.% 0.39 3,84064 969 -1S6 25.02 070 969 1m 1.97 25.05 23.16 3492 Shoo (1, 5) 8,873.99 89.% 0.39 3,84065 9.69 -1,56 2502 070 969 1.56 197 25.05 23.16 3492 MWD(1, 5) 8,87448 6997 0.39 3,840.65 969 -1.56 2502 070 969 1.56 107 25.05 23.16 34.92 MAD (1. 5) 8.888.23 90.24 0.38 3.84062 970 -1.57 25.14 0.67 9.71 156 1.97 2597 23.15 34.10 MWD(1. 5) 9 woo 9024 0.38 3,93780 943 AS7 22.50 2.44 944 1.56 318 24.25 22.29 108.76 1JWD+IFR-AK-CAZ-SC(2, 5) 9.55734 9024 0.38 3,83779 943 -1.57 22.50 244 944 156 3A8 2425 22.29 M.76 MWD+IFR-AK-CAZ-SC(2. 5) 9,56835 90.04 031 3,83776 947 -1.56 2252 244 946 1.55 3.19 2424 2233 108.35 MWD+IFR-AK-OAZ-SC(2. 5) 9.57943 69,83 023 3,837.77 947 -1.56 22.52 244 9.46 1.56 3.19 2424 22.33 100.35 MWD+IFR-AK-OAZ-SC(2.5) 9,581.81 89.78 0.22 3.83778 947 -1.56 2252 2.44 946 158 3.19 2424 2233 108.35 MVVD+IFR-AK-CAZ-SC(2.5) 9.592.26 8999 022 3,837.80 9,446 -1.66 22.54 244 9.46 1.56 319 2423 22.35 108.17 MWD+iFR-AK-CAZ-SC(2, 5) %896.77 8999 0.22 3.837.85 966 -1.56 23.31 2.44 9.66 1.58 326 24.13 2325 105.34 MWDHFR-AK-CAZ-SC(2.5) 9,956.34 Be." 022 3,93879 982 -1.50 23.29 2.44 971 1.56 327 2409 23.26 10039 1WWD+1FR-AK-CAZSC(2, 5) 8,969.82 8700 022 3,839.26 982 -1.50 23.29 244 971 1.56 327 2409 2326 10039 MVVD+IFR-AK-CAZ-SC(2,5 10269.84 97.89 348.21 3,85058 1001 -1,53 2366 2.72 9.93 157 3.35 2407 23.65 6830 MWD+1FR-W-CAZSC(2, 5) 10,30228 07.09 34821 3,051.77 10.03 .1.53 23.72 272 9.% 1.57 3,35 2409 23.68 61A7 MWD+1FR-AK-0AZ-SC(2,5) 10,31543 07,75 34770 3.052.27 1011 -1.52 23.00 217 10.00 157 3,36 24.15 2372 49.99 MWD+1FR-AR-CAZ-SC(2, 5) 10,329.58 87.60 WAS 3.852.05 10.11 -152 23.80 277 10.00 1.57 336 24.15 2372 49.99 MWD+IFR-AKCAZ-SC(2. 5) 10,346.31 0742 316.51 3.853.57 10.11 -1.52 2380 2.77 loco 1.57 3.36 24.15 23.72 4999 1AWD+IFR-AR-CAZ-SC(2.5) 10,349.11 87.39 345A1 3,85370 10.11 4.52 23.00 277 10% 1.57 338 24.15 23.72 4999 MWD+IFR-AK-CAZ-SC(2,5) 10,35964 87.27 346.00 3,854.19 10.11 -1.52 23.80 277 1e0O 1.57 3.36 24.15 23.72 49.99 MWWIFR-AK-CAZ-SC(2.5) 10,39756 87.27 346.00 3,85800 1014 -1.52 23.87 2.77 10.03 157 3.37 2421 23.72 4327 MWDHFR-AK-CAZSC(2.5) 10,47984 9727 346.00 3,859.90 1020 -1.52 2406 277 10.10 1,57 339 24.39 2374 3159 MWD+iFR-AK-CAZSC(2,5) 10.773.15 88.79 35386 3.87000 1042 -1.55 2471 2.55 1038 1.58 3.47 26.05 2357 2380 MWD+1FR-AK-CAZSC(2,5) 10.827.11 8908 355.30 3,871.00 1049 AM 24.96 2.40 10.47 1.58 3,60 25.28 23.53 23.08 MWD -IFR -MK AZ -SC (2, 5) 11,02.97 90.50 0.00 3.871.42 10.57 -1.58 2524 237 10.57 1.58 3.53 25.54 23.49 22.61 MWD+1FR-AK-CAZ-SC(2.5) 11,098.15 90.00 36999 3,072.42 10.66 .1.58 25.43 237 1068 1.58 3.56 2576 23.45 22.54 MWD+IFR-AK-CAZ-SO(2.5) 11,120sa. 90.00 359.99 3,872.42 1088 -1.58 2547 237 10.68 1.58 3.% 2580 2344 22.58 MWD+IFR-AK-CAZ-SC(2,5) 6/2912017 12:10:39PM Page 2 COMPASS 5000.1 Build 74 Company: ConowPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: Plan: IH -102 (formerly 31) Wetlbom: Plan: 11-1-1021-3 Design: 1H-102L3wp23 Position uncertainty and bias at survey station SLB Error Ellipse Report Local Co-ordinate Reference: ND 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 Measured Inclination AzimNM1 Vertical eignside lateral whim hie,hi 6e Sao imajor 3emlminor Depth Depth Error Bias Error Bias Enor Bias of Biae Error Error Azimuth Tool (oan) P) V) (thm haft) (waft) hom lural (usm (oan) (uaft) lush! heal (9 11,166]0 91.35 031 3,871.88 1071 -165 2565 2.35 1075 1.56 3.58 2599 2343 22.21 MM-IFR-AK-CAZ-SC(2, 5) 11,186.38 91.92 D44 3,871.32 10.71 -165 25.65 235 10.75 1.50 358 25.99 23.43 22.21 MM0FR-AK-CA2-SC(2, 5) 11,20279 91.92 044 3,870. ] 10.82 -165 26.04 2.35 1068 1.50 361 26.39 2341 2103 IJMOFR-AK-CAZ-SC(25) 11,330.26 9192 OM 3,868.50 to," -165 26.7 2.35 1090 1.58 362 2853 2340 20.69 MVVDNFR-AK-CAZ-W(2. 5) 11,338.11 9192 044 3.865.23 1085 -165 2617 2.35 1090 1.58 3.62 26.53 2340 21,69 MWDMFR-AK-CAZ-SC(2,5) 11,343.54 92.02 0.39 3,865.05 1087 -188 26.19 235 Well 1.58 363 2655 23.40 20.64 MV IFR-AK-CAZ-SC(2. 5) 11.34498 92.04 on 3,866.00 10.87 -1.66 26.19 235 10.91 1S0 363 26.55 23.40 2064 MVVDHFR-AK-CAZ-SC(2, 51 11,35301 9220 0.30 3.865]0 loss -166 2822 235 10.92 1.58 363 26.58 2340 2058 MVrUHFR-AK-CAZ-SC(2.51 11,72208 92.20 0.38 3.851.53 11.33 -186 27.79 235 11.37 157 375 28.19 23.34 7.80 MVVDeIFR-AK-CAZ-SC(25) 11,778.74 9220 0.36 3,849.35 11.33 -166 27.79 235 11.37 157 3.75 28.19 2334 17,80 14M.1FR-AK-CAZ-SC(2, 5) ' 11,837.38 9044 0.30 3.848.00 11.45 -1.57 27,84 235 11,45 1.57 3.77 2827 2330 is 26 MVr➢MFR-AK-CAZ-SC(2,5) 11,B52.10 8000 0.38 3,847.94 1145 -1.57 27.84 235 1145 1.57 377 2827 2330 1826 MVaWIFR-AK-CAZ-SC(2,5) 11,91323 8878 on 3,040.59 11.57 -1.52 27.86 2.35 11.52 1.57 3.79 20.32 23.27 1874 MVVC+IFR-AK-CAZ-SC(2,5) 11,984.21) 8078 D.3B 3.849.68 1167 -1.52 2804 2.35 1162 1.57 3.82 28.52 2324 1860 MVUDHFR-AK-CAZ-SC(2. 5) 11,997.71 08.78 0.38 3,850.40 1167 -1.52 28.04 2.35 1162 1.57 3.82 2862 23.24 18.80 MVVDHFR-AK-C7 -W(2, 5) 12,31637 0878 0.30 3,857.19 12.05 -1.52 2934 235 12.01 157 3.95 2SM 23.20 1718 MVVDHFR-AK-CAZ-SC (2,5) 12,330.17 U78 0.30 3,85749 1205 .1.62 29.34 235 12.01 157 3.95 29.84 23.20 17.18 MVUDHFR-AK-CAZ-SC (2. 5) 12,696.18 88.83 34369 3.86582 12.49 -1.53 28.73 308 12.48 150 4.08 30.80 23.05 16.42 MwDHFR-AK-CAZ-SC(2,5) 12,837.29 M61 33726 3,869.22 1273 -1.54 2801 339 12.71 1.50 4.13 3129 2295 1535 MVvDNFR-AK-CAZ-SC(2,5) 13273.63 Mae 317.36 3.87979 13.19 -157 28.22 379 1320 1.59 420 32.12 22.77 1234 MV0+1FR-AK-CA2-SC(2. 5) 13,383,43 8864 37.35 388239 13.33 4.57 26.52 379 13.34 1.59 4.21 32.39 22.74 11.10 MM+IFR-AK-CAZ SC (2, 5). 13,396.22 89.05 317.52 3,882.65 1336 -1.57 26.60 3.78 13.37 1.59 4.21 3243 22.73 10.92 MM+IFR-AK-CS-SC(2,5) 13.426.23 90.00 31789 3.882.90 1340 -1.59 MM 778 13.40 1.59 4.22 32.50 2232 10.63 MVVD+IFR-AK-CP eC (2,5) 13.462.06 9072 317.89 3.88268 1353 -1,61 26.91 378 1349 159 623 52.67 2270 992 MVVD+IFR-AK-CAZ-SC (2, 5) 13,492.06 91.32 317.89 3.882.14 13.53 -1.61 2691 3.78 13.49 1.58 4.23 32.67 22.70 9.92 MM+IFR-AK-C/S-SC(2, 5) 13,92397 91.32 317.89 3.87222 14.16 -161 2838 3.78 14.12 1.58 4.28 33.97, 2257 5.32 MO0HFR-AK-CAZ-SC (2, 5) 13,95397 91.32 317,89 3,871.53 14.16 1.61 28.M 370 14.12 1.58 428 3397 2257 532 MM+IFR-AK-CAZ-SC(2.5) 14.388.38 91.61 327,00 3.860.43 14.77 -164 31.35 3.51 1475 158 4.38 3509 22.38 2.92 MVV+IFR-AK-CPZ-SC (2, 5) 1441398 9182 32753 3,95871 1460 -1.64 3147 3.49 14.77 1.58 4.36 35.13 2237 2.84 MVVDHFR-AK-CAZ-SC (2,5) 14.418.39 91.62 327.63 3.859.58 14.80 -1.64 3147 349 1477 1.55 4.35 35.13 2237 2.84 MVVDHFR-AK-CAZ-SC(2, 5) 14,44397 9162 327,63 3858.88 14.83 -164 31.56 349 14.81 1.58 4.37 35.22 2237 270 UNDEFINED 612912017 12:10'39PM Page 3 COMPASS 5000.1 Build 74 Pool Report 1H-102L3wp23 Surface Location M CPAI Coordinate Converter From: -- Datum: NAD83 Region:alaska r Latitude/Longitude IDecimalDegrees C UTM Zone: F— r South C•` State Plane Zone: q3 Units: us•ft (- Legal Description (NAD27 on(p) MIN To: Datum: NAD27 Region: alaska r Latitude/Longitude IDecimalDegrees (- UTM Zone: True r South State Plane Zone: q Units: us -ft D r Legal Description (NAD27 only) Ir- Starting Coordinates: -- - Ending Coordinates: -------- - - - X: 1689609.08 X: 549577.455558541 Y: 5980414.37 Y: —F5980662.56352101 - _. Transiorm�� i Quit Help 1 H-102L3w 23 Surface Location M CPAI Coordinate Converter From--- --- - Datum. NAD83 - Region: rlaska J r Latitude/Longitude IDecimalDegrees, (- UTM Zone: r South C% State Plane Zone: q Units: us -fl r Legal Description (NAD27 only) Starting Coordinates: X: 1689609.08 Y: 5980414.37 To:__ -_--- Datum NAD27 - Region: alaska r Latitude/Longitude IDecimalDegrees r UTM Zone: True r- South C State Plane Zone: 4 . Units: ush.7 t- Legal Description (NAD27 only) Township: 012 N , Range: Dlo Meridian: U Sections 33 FNL 40.519229 FEL 764.65061 Transform i Out Help 1 H-102L3wp23 Surface Casing M CPA[ Coordinate Converter s, From: Datum: NAD83 . Region: alaska r Latitude/Longitude IDecimal Degrees r UTM Zone: [_ r South [: State Plane Zone: rq� Units: us -ft r- Legal Description (NAD27 only) -To: - ---- Datum: FNA -DET -7- Region: alaska f Latitude/Longitude IDecimalDegrees C UTM Zone: True I- South l: State Plane Zone: F-----3 Units: us -ft r Legal Description (NAD27 only) Starting Coordinates: - End'ngCoordinates: X: 1689909.67 X: 549878.038975245 Y: 15980107.45 Y: 5980355.64507016 Trmrafam Quit Help 1 H-102L3w 23 Surface Casing L'1 CPAI Coordinate Converter From: ---- ---- Datum: NAD83 Region: alaska 7 C Latitude/Longitude Decimal Degrees (" UTM Zone: F_ r South (: State Plane Zone: q Units: us -ft r Legal Description (NA.D27 only) Starting Coordinates: X: 11689909.67 Y: 15980107.45 -To: --- _ Datum: NAD27 . Riegion: alaska r Latitude/Longitude IDecimalDegrees, r UTM Zone: True r South r State Plane Zone: q Units: us•ft !- Legal Description W27only) Township: 072 FN--,] Range: 010 E Meridian: U Section:33 FRFE 349.44826 FEF.] 466.76527 i ---Transform — _� Quit Heb 1 H-102L3wp23 Kick-off Point IM CPAICoordinate Converter Dotum: NAD83 . Rogion alaska + f- Latitude/Longitude IDecimalDegrees r' UTM Zone: F— r South G State Plane Zone: i4 J Units: us -it + (- Legal Description (NAD27 only) To: Datum: NAD27 . Region: alaska . C' Latitude/Longitude IDecimalDegrees + C UTM Zone: True F South (- State Plane Zone: q + Units: us -k + r Legal Description (NAD27 only) Starting Coordinates: — Ending Coordinates: - X�. 1693979.28 X: 553947.587703032 Y: 598D438.28616948 L Y: 5980190.17 i......._.._.._Transform.................: Quit Help 1H-102L3w 23 Kick-off Point f`i CPAI Coordinate Converter o From: Dale NAD83 Region: alaska t Latitude/Longitude (Decimal Degrees J r UTM Zone: �— r South C• State Plane Zone: ---4 . Units: u . r Legal Description (NAD27 onlyl Starling Coordinates: X: 11693979.28 Y: 15980190.17 To: Daharrc FN -AD -2-7- Region: alaska r Latitude/Longitude IDecimaiDegrees r UTM Zone: True F" South f State Plane Zone: q + Urrh: rm-ft . r Legal Description (NAD27 only) Township: 012 N . Range: oto E Meridian: U Section:34 FRF --3 295.00208 FEF— 1676.2411 ( � Transform � Quit Help 1H-102L3wp23 Top of Production • a CPAI Coordinate Converter Fran: -- Datum: NAD83 . Rogion: alaska r' Latitude/Longitude IDecimaiDegrees i r' UTM Zone: F— r South r• State Plane Zone: I' Units: us -ft I (- Legal Description (NAD27 only) L. Starting Coordinates: e@ To: - - Datum: NAD27 . Rogiore alaska f Latitude/Longitude Decimal Degrees —� C UTM Zone: True r South r State Plane Zone: q Units: us -ft r Legal Description (NAD27 only) Ereding Coordinates: X 11693979.30 X: F553947 607682853 y 15980187.37 Y: 5980435.48623554 _,Transform Quit I Help 1H-102L3w 23 Top of Production fM CPA] Coordinate Ccmerer r From -- Datum: NAD63 J Region:alaska r Latitude/Longitude IDecimalDegrees * UTM Zorx: F— r- South G Stale Plane Zone: F---] Units: us -ft r Legal Description (NAD27 only) Starting Coordinates: X: 11693979.30 Y: 59801B7.37 To: D&txrr NAD27 Region: alaska C Latitude/Longitude DecimalDegrees f UTM Zone: TfUe F South r State Plane Zone: FT--.] Units: us -ft r- Legal Description (NAD27 only) Township: o12 IW:,:] Range: 010 F_] Meridian: LI Section: 34 FF . 297.81323 FEL - 1676.2457 ... __._......... _........................- l .............. ...Transform,,..,......,.,...1 Quit Help 11H-102L3wp23 TD M M CPAI Coordinate Converter El Datum: NAD133 - Region: alaska -1 f• Latitude/Longitude IDecimalDegrees • UTM Zone: F— r South G Stale Plane Zone: F-73 Units: us -ft r" Legal Description (NAD27 only) L [ Starting Coordinates: To: Datum: NAD27 _�-] Region: alaska • Latitude/Longitude IDecimalDegrees • UTM Zone: True r South G State Plane Zone: q Units: us -ft r Legal Description (NAD27 ordy) ------ Ending Coordinates: X; 11692735.54 X 552703.912252341 Y: 15986776.46 Y: 5987024.44441838 _,..Transfrxm _! Quit: Help 1 H-102L3w 23 TD [`1- CPAI Coordinate Converter o CEI -Froin: -----.. Daum: NApg3 Region: alaska r Latitude/Longitude IDecimaiDegrees .� C UTM Zone:— r South G State Plane Zone:q Units: us -ft r Legal Description [NAD27only) Starting Coordinates: X: 11692735.54 Y: 15986776.46 To: Datum NAD27 Region alaska • Latitude/Longitude IDecimalDegrees • UTM Zone: ITrue r South C State Plane Zone:q - Units: -.g C• Legal Description (NAD27 only) Legal Description - - Township: 012 Rama 010 E Meridian: IU Seclion:22 FNL 4259.4999 IFEL 2861.7877 I Transform Quit Help 15'.29, June 29 2017 WELLBORE TARGE DETAILS (MAP co -o Name No West( -)/East(+) (2000 usft/inl WELLBORE TARGET DETAILS (MAP CO-ORDINATES) 1 1-102L3wp23 jAs—H;00 N° B°aea 1H-102001.Tt D209P RP 36a0.t3 Circle )R3EIus: 100.00) 1H-tO21302.T202091TRP 384085 Circle (Radius 1W OD) Quarter Mile View 021303 3020919 RP 3&9]8 Circle )Retllus 10000) 111-1021304.74020919 RP 3639.26 Cirtle )Rados: 100.00) 1H-102005.95020919 RP 3054.19 Circle Radius: 100.00) 1H-102009.T9017 RP 3872,42 CINe(Radiva: 10000) 1H-1021308.T8020917 RP 3006.00 Circle (Retllus: 100.00) 1H-102003.99020919RP 304794 CVde(Ratlim: 100.00) 1H-1021310.T1 D 02097 RP 3059.49 Clmb(red. 1m.00) 111-0021.3 11.T11 020819 RP 3802.90 Clyde (RA ear 100.00) 1H-102012.T12020919 RP 3891.53 CZ:(Redux: tOD.00) 1H-102013.M 020919 RP 3850.66 Clyde (Rade MOO) 111-1020 O1.T10M17 RP CImle 38W.13 Circle (Radius 132000) - -. ....._....._— _-1H•102E366 T6O209ftRP 3M ill dalRatius-10P0Or. 1141021.313 TD OZl19l 9 RP circle 3850.6fi QrGe (Radius 1320.00) 8000 O 1 1a• c:6000- CD 6000 O O sy -4000-1 + 'y L 'os I O Z X000-, ---� ._ O U) Z N 0 �e vol y -2000 - _ NI o r r = -4000 -2000 0 2000 4000 6000 8000 10000 12000 C U, 1 H-102L3wp23 Quarter Mile View Nerve WD shape 1H- 102L301.TI 020917 RP 3540.13 Oirde(Radius '. 100.00) 1H-102L30Q.T2020917 RP 3840.65 CIrd* (Radius 100.00) IH- 102L303.T302091T RP 383]]8 CM9(Radus'. 100.00) 1H-102L304.T4020017 RP 3839.28 CZ:(Redua: 1W.00) 1 H-1 WL305.T502N7 RP 3554.19 'W.(Radus. 100A0) 1M102L30].T] 010817 RP ]B]2 /2 CYda is mus: 100. W) 1K1@LJ OB.T00209P RP 3566.00 CWe(ia61us: 100.00) 1K102L3)9.T40=7 RP 3BQ.94 G.I.(Ra01us: 100.00) 11410]W 10.T10020917 RP N5].49 Cftj:(Radue: 100.00) 11+10Wi1.T11 =917 RP 3882.90 Cft (Radus: 100.00) 1K102L312.T12020917RP 3571.53 Ceule (Ra01us'. 100.00) 1K102J-3 10213.TD 020917 RP 3555.85 CWa(Radius 100.00) 1K102L301T1020917 RP OWe 3040.13 CIRI.(Rci 1320.00) ••• •'••• • "• �• "•.••••• ^.P-- 9585.80. --Ci,".cftus IW.00J— --- tPOirde 3858.88 Cide(Radius'. 1320.00) -4000 -2000 0 2000 4000 6000 8000 10000 12000 1 H-102L3wp23 Section View 3660- 6603720t3780a 3720- =3780- CL m i WS A4 WS A4 p L o ° o o o WS AA Objective WS A4 tive _ r CD o 7-5/8" x -7/8" Nm - WS A31� o w 0 3 F 0 0 o i ° -1/2" x A 4" A WS_ A3_ Objective ° o 3900 WS_A2 3960- 9601H-21 1H 21 I x -850 0 0 1700 2550 3400 4250 5100 5950 6800 Vertical Section at 0.00° I T-3 i K-15 1H-102L3wp2 WS_A4_Obi,, Tollerable Collision Risk Worksheet ConocoPlvllips Alaska ATolerable Collision Risk Worksheet based on Rev. 1 - 29 Jul 99 Use this sheet to describe a well interference scenario where QRA may be applicable. Check first that the scenario really is different from those described on existing worksheets. Prepared by: Kelsey Hanford - Authorized by: Dan Bearden ConocoPhillips Alaska, Inc Drilling Anti -Collision Management Generic name of scenado: Collision with other Islands In multi -lateral well (A3 with A2. A4 with A3 and A2, B with A4, A3, 80 A21 0 with B. A4. A3 and A2 Description: (Be specific. Include all factors which affect either the cost of collision or the cost of reducing the risk Well 1H-102 A3, A4, B and D laterals fall anti collision with one another In the horizontal legs or the well base on WP21. The four upper laterals will be geosteered using periscope so risk of leaving the zone is minimal. There is no immediate danger to life or impact on the environment g well 1 H- 1021nlersecls itseff. If 1H402 Intersects Itself there would be damage to the liner and swell peckers. No risk of a well control Issue exists because well 1H-102 lateral that Is being drilled is above the previous placed laterals (upper laterals have the same or slightly higher PP) and Is �eing drilled from the main bare with kill weight mud In the hole. The laterals fall with the mother bore at the Kuck off point, but we are Intentionally side tracking. We will be kloWng off with motors to keep us In the target sands. Do the consequences Are the of collision include a �"_ _< risk to personnel or the consequences environment? of collision List all the consequences of collision and the necessary remedial action: No HSE risks exist with 1H-102Intersecting Itself while drilling. An economic concern exists and It would be the cost of damage to the completion equipment that has already been placed in the lower laterals prior to tldlMg the upper Islands and the Impact it may have on future production from the well If necessary the lateral that had been drilled into can be isolated and produclion shut off (loss of lateral) which is worst case sconarl The biggest chance of getting "lost" is when crossing faults, there are three fault crossings in 1H-102, but since the lower laterals will have already drilled across the fault the exact throw of the fault will be known so the fault crossing can be planned for. If we do gel out of zone we can determine what zone we are in based on real lime logs and cuttings and (hen steer back into the correct zone. How could the probability of collision or the severity of the consequences be reduced? How might this impact the drilling operation? Coal. substantially reducing V = $0 Given the uncertainty in the above estimates, 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 prs to substantially reduce either either thee probability of collision or the severity of the consequences? n:. w,--, I C= $10,000,000 1 0 I V = $42,650,000 1 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 lolerances need Iron be set C It VF C < I then Toiemble Collision Risk - I in C / V F Tolerable Collision Risk = 1 in 23 Minor Risk 1/50 applied to all laterals substantially reducing V = $0 Given the uncertainty in the above estimates, 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 prs to substantially reduce either either thee probability of collision or the severity of the consequences? n:. w,--, I C= $10,000,000 1 0 I V = $42,650,000 1 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 lolerances need Iron be set C It VF C < I then Toiemble Collision Risk - I in C / V F Tolerable Collision Risk = 1 in 23 Minor Risk 1/50 applied to all laterals As -built 1 12/05/01 MRT I CC I IRev. Per K05014ACS 12 02/01/11 JAH I LGM I Rev. Per K170005ACS 25 30 29 20 27 2 25 N G — rrQ PROM 36 31 18 36 32 33 34 35 36 j N 10 /� It T11N OE 5 4 3 6 2 1 ®120 i a ASGRID NORTH ®1118 12 7 e CPF1T22 0 9 1z 0117 0116 0115 18 17 1613 0114 1ELEGEND ®113 ®112 1F 2a 24 19 20 21 0 AS—BUILT CONDUCTOR 0111 0110 VICINITY MAP • EXISTING CONDUCTOR 0109 SCALE: 1" = 2 MILES 0104 0108 0103 28 27 + _ 33 34 0102 0106 0101 DS1H *20 *19 *22 *17 *16 •15 e1 02 03 *UGNU 01 o14 05 •12 011 010 06 o21 913 e9 07 o18 •8 •4 SEE SHEET 2 & 3 FOR COORDINATE TABLE nimps Alaska, Inc. NOTES: 1. BASIS OF LOCATION AND ELEV. IS DS1H MONUMENTATION PER LOUNSBURY & ASSO 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. 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS 28 AND 33, TOWNSHIP 12 NORTH, RANGE 10 EAST, UMIAT MERIDIAN, ALASKA. 5. DATES OF SURVEY: 12-26-16 THRU 1-31-17 FIELD BOOKS L16-35, L16-40, L17-02 & L17-03. 6. ALL DISTANCES SHOWN ARE GROUND. GRAPHIC SCALE 0 100 200 400 1 inch = 200 ft. LOUNSBURY & A330CIATSS, INC. S4 VETORS ENGINEERS PLANNERS MODULE: XXXX UNIT: D DS1H WELL CONDUCTOR 0:111�tv1671 � iftiT�cf �a 1 102/01/17 JAH I LGM I ICreote Per K170005ACS I I I I I I CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 28, T. 12 N.. R. 10 E.. UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geographic 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 5,981,111.42' 549,544.52' N 70' 21' 33.047" W 149' 35' 51.299" 408' 794' 48.0' 54.2' *120 5,981,141.33' 549,542.48' N 70' 21' 33.341" W 149' 35' 51.353" 438' 795' 48.0* 54.1' * CONDUCTOR ASBUILT THIS SURVEY 49th AH F. CO LS -12663 SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF 0 ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY •� DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION ARE. CORRECT AS OF JANUARY 31, 2017. LOUNSBURY & ASSOCIATES, INC. !VETOES ENGINEERS PWNNERE Im ConocoPhillips DS1H WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. 1 DRANING NO. PART: REV: LK6108d31 12/27/16 CEA-D1HX-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 ■ Consider 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: ■ Consider all Tier 2 & 3 mitigations 7ifin 1jjLqUMjUM*ConocoPhillips , F be 1 H-102L4wp23 ADD- Plan Summary I Depth Reference: Plan'. 54F39 ® 93.Wusfi (Doyon 142) 10 Rig: Doyon 142 11066 10314" x 131/2' _o__ 0,Q0�$ 0 7518" x 9-710" 4-12" x B-3/4" oc o m o oc h om oc 0 1500 3000 4500 6000 7500 9000 10500 0 2000 4000 6000 8000 10000 SURVEY PROGRAM open From Depth To Sunv ylPlan Tool 39.00 700.00 111-102wp23 (Plan: 11+102) GVD-GC-SS 700.00 1794.10 111-102wp23 (Plan: 11+102) MWD+IFR-AK-CAZSC 1794.10 7204.22 1H-102"23 (Plan: 11+102) MIND. FR-AK-CAZSC 7204.22 7554.22 1H-102L4wp23(Plan: 11+1021-4) MWD -INC ONLY 7554.22 9054.22 1H-102L4wp23(Plan: 111-10214) MWD 7554.22 14425.15 111-10214wp23(Plan: 11+10214) MWD*IFR-AK-CAZ-SC Prepared by: Bnj Potnis x>0 12000 14000 Pad Elevation'. 54.00 CASING DETAILS TVD MO Name 3753.15 7204.23 7-518" x 9-718" 3800.66 14425.15 4 -12"x6 -3k" 0 SECTION DETAILS Sec MD Inc Ad ND +N/ -S +E W Dleg TFace Vain Target 1 7204.22 75.57 0.00 3)53.15 -512.01 4369.05 0.00 000 -512.01 2 7217.02 7).61 O.1+ 3756.12 -499.56 436905 15.90 000 499.55 3 ]237.02 77.6 0.00 3760.41 -400.03 436905 0.00 000 480.03 4 7553.)8 90.00 2.65 3794.55 -165.05 4378.40 4.00 12.17 -165.85 5 7677.39 93.53 359.19 3790.74 -42.36 4378.39 4.00 44.37 42.% fi ]921.]0 93.53 359.19 3775.69 201Afi 437093 0.00 0.00 201.46 7 8014.]3 90.00 0.30 3.4282 294.44 43]4.5) 4.00 161.80 294.44 1H -102D 01.T1020617 RP 8 8025.30 8939 0.36 3772.84 305.09 4374.64 2.00 -1]9.9) 305.09 9 8794.34 89.79 0.36 3]]5.70 10]4.03 4379.49 0.00 0.00 1074.03 10 8805.02 90.00 0.38 3))5.72 1084.)0 4379.56 2.00 3.92 1084.70 1H -102D 027202020 RP 11 8871.34 90.1) 1.69 3775.62 1151.01 4380.76 2.00 8266 H5161 129260.93 90.0 1.69 3)14.45 154043 439249 0.00 000 1548.43 13 958162 90.00 355.44 3))3.98 188108 4384.66 2.00 -91.54 1861-06 1H -102D 0373020217 RP 1496]8.20 89.51 357.30 3))4.40 1957.24 4378.55 2.00 104.80 195734 15 10104.46 89.51 357.30 3778.06 2383.01 4350.40 0.00 0.00 2383.01 16 10422.64 87.34 34000 3)00.83 2690.10 4317.85 3.00 -103.22 2698.10 1H -102D 04.75020217 RP 1) 10652.64 07.34 348.00 3]97.50 2922.83 4270.08 0.00 0.00 2922.03 18 10992.06 90.00 0.00 3805.41 3259.65 4234.70 3.62 )).0 3259.65 1911174.28 90.00 3.67 3805.41 3441.75 4240.53 2.01 09.96 344135 20 11184.54 90.00 3.67 3805.41 3451.99 4241.19 0.00 000 3451.99 1H -102D 07.78020217 RP 21 11354.39 93.58 35).08 3800.09 3621.84 4243.49 4.01 -58.21 3621.64 22 11381.0) 93.58 35).88 3]99.08 W28.30 424315 0.00 0.00 3620.30 1H -102D 08.7902UI7 RP 23 11498.90 91.14 1.22 3794.01 3765.98 4242.17 3.00 126.15 3785.98 24 11780.35 91.14 1.22 3788.2) 4055.31 4248.32 D.00 0.00 4055.31 25 11915.99 90.00 350.93 3787.00 4182.93 4248.49 2.00 -118.40 4182.93 1H -102D 0971002021) RP 26 11929.18 89.94 359.05 3787.01 4198.12 424816 100 115.91 4196.12 27 12239.99 89.94 359.05 3787.32 4507.69 4243.11 0.00 0.00 4506.89 20 12332.89 8).88 35800 3789.09 4599.53 424032 2.50 -163.05 4599.53 1H -102D 91.711020217 RP 29 13290.40 89.02 310.73 3816.12 5472.13 3894.54 4.10 -88.96 502.13 30 13352.11 8902 310.]3 3817.18 5518.45 3853.89 0.00 0.00 5510.45 31 1]40].08 91.12 31).85 3817.11 15(1 Weed 4.10 -2235 5560.07 1H -102D 13.114020717 RP 32 13935.58 91.12 31).85 3006.76 5951.23 3452]2 0.00 0.00 5951.23 iH-1020 14.715020717 RP 33 14160.10 90.59 324.56 3803.40 6126.10 3322.15 3.00 94.48 6126.10 34 14425.15 90.59 324.56 380.66 6342.04 3168.48 0.00 0.00 6342.04 1H -102D 15.71802071] RP I adle owledoe that I have been informed of all risks. cracked! that the data Is Checked by: Huy Sul Anh Accepted by: 07204 721+ - )390 7399 - 7570 7570 - T780 7760- 7940 7940 - 0130 8130 - 0310 8310 - 0500 8500 - 8750 8750 moo 9000 - 9250 9260 - 9500 9500 - 9750 9750 - 1000 10000 - 1025 10250 - 1050 10500 - to99 10990 - 1148 11480 - 1197 11970 - 1246 2460 - 12% 12960 IU5 IU60 1394 13940 - 1442 Magnetic Model: BGGM2017 r Date'. Date Magnetic IJ 4, Declination Magri. Model 17.62- 12.02° To wren a Magnellc Dlrechon 10 a Two Direction. Add 17.62° East {\�[✓Lp} 1620A PFROST Annotation KOP: 15.9°/tOP DLS. W TF, for 12.8' 1788.6 Hold for 20' T-3 ooe.4 K-15 'Minor Risked Hold for 310.01' 31354 UG -C 3382.6 UG_B 3485.8 UG A 3810.) No Approved by: scan and 0comp SS -EOM Pmdlrcotir, ",121 • of < .s Su' .tLx� tiT.�il� i7 ki^". ,INS_ •b .bwl File Edit Yew Analysis Plot Report Instilling Cylinder Wev Tools Windar Hesp Pd R I V I. 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(formedyl... pelmedYl... 8..„ NM - •w w nr �_. r.. uxerxJJl I •� ,•• a:x uw •v •.e: 8 Q TraVelll gCylinder Yew FL_i raJ`Y -t n my moron WNl Name Unit System: API US Survey feet Angle::' Oeplh, usft n[Ugfl] 16:24, June 29 2017 Easting (2500 ustt/in) ou 1 R-25 1 R-24 R-16 1H-125wp20 1H-124wp20 i R-01 BL1-01 1 RR p gg 1 H-123wp20 R- 816L1 -01P61 1 H-121 wp20 1H-122wp20 1 R-01 - 6 1H-120wp21 1R-27 -� p03) 1R-29 L1 1H-102L4wp 3 R -29L1-01 1R-02 1H-20 -102L3 p23 Bn 9 VON t-WP61 1 1$9 _1 1 p .1 H-19AL1 1 N 00 1 G-07 11H-H�1g 1 H 16A 1H- wp2 H•1 1- JNC-ONLY toolwde) 21 N, Est 19A 10 � G 11G-11U[iL1 1H-16AL1 1H- p21 1H-115wp21 0 1 H-19AL2 1 H- L1 Z 116wp21 1G-10BPB1 1 - �r_ Kuparuk 1H PaA 11 9wp21 1H-12 1H-113wp21 1 -111 wp21 1H- 0 H-21 -04 1 H-108wp2 1 ifl a ip21 1 116-12L7 -11A 1H 1H-15 1H -104w 'hr 1'ILgq��1$ 1H -107w 1 H-106wp21 1C-1 = 1C-1 1 4L1 1H-01 1B-102 1C- 1G-12 H-08 1 H-02 1H- 1 C-1 1c -l1 L -0 C-11 L 02 1C 17 Easting (2500 ustUin) 1C-154wp06 1C-155 C1C 9 wp0 1C-156wp0r66 6677 55 �'TCl75 g 1 1 H-102L4wp23 7 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 4-1/2" x 6-3/4" 6000 1 "1 2D 15316 020717 P 1414DLMJ,J15 020717 4P Q�3 4500 1+d _ 02 South Fa It fH2U ED 10.T11 020217 P 1 H-1 02D 09310 020217 P P P 3000 P o z kH-102D 05.T6 020 P 04.T5 00 P 0 0 15001H -102D 03.T3 020217 P 9000 1H -102D 02.T2 020217 P 000 0 °o° 20" x 42"- - - - - - o° 1 H -102D 0131 020617 P 7-5/8" x 9-7/8" P7000 10-3/4" x 13-1/2" �� a o 0 -1500 0 0 -3000 -1500 0 1500 3000 4500 6000 7500 West( -)/East(+) 1 H-102L4wp23 E. Section View 7-5/8" x 9-7/8" O 0 0 0O O ---------------- _O ----------------- ____fl0---------------------------- O 0), Cb W �I O p0 _O______________O____„ L 0 3840 U \\p\ > 3920 F X111 M� .. N N N W O O 0 850 1700 2550 3400 4250 5100 5950 6800 Vertical Section at 0.000 0 r W N Q 3 N J 0 � M N a 3 = J N i O O `— N � U N 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: 1H -102L4 Plan: 1 H-102L4wp23 Steering Standard Proposal Report 29 June, 2017 Minor Risked Database: EDM Production Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: Plan: 1 H-102 (formerly 31) Wellbore: Plan: 1H-1021-4 Design: 1H-102L4wp23 SLB Standard Proposal Report Local Co-ordinate Reference: Well Plan: 1H-102 (formerly 31) TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk 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-102 (formerly 31) Well Position +NIS 0.00 usft +E/ -W 0.00 usft Position Uncertainty 0.00 usft Ground Level: 54.00 usft Wellbore Plan: 11-1-10214 Magnetics Model Name BGGM2017 Design 1H-102L4wp23 Sample Date Declination Dip Angle Field Strength V) r) W) 6/22/2017 17.62 Was 57,498 Audit Notes: Version: Phase: Vertical Section: Depth From (NO) (usft) 39.00 PLAN Tie On Depth +N/ -S +E/ -W (usft) (usft) 000 0.00 7,204.22 Direction (1) 0.00 6/292017 4:05:52PM Page 2 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. -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 1 H Pad North Reference: True Well: Plan: 1 H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-10214 Depth Inclination Design: 1H-102L4wp23 System +N/ -S Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/ -S +FJ -W Rate Rate Rate Tool Face (usft) (°) (I (usft) usft (usft) (usft) (°1100usft) (°1100usft) (°1100usft) (°) 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 3,772.62 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 3,682.72 1,084.70 4,379.56 2.00 2.00 0.14 3.92 8,671.34 90.17 1.69 3,775.62 3,682.62 1,151.01 4,380.76 2.00 0.26 1.98 82.88 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 89.96 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 89.02 318.73 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 3,168.48 0.00 0.00 0.00 0.00 6292017 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. -Kupi TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Site: Kuparuk I Pad North Reference: True Well: Plan: 1H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: iH-1021_4 usft (usft) Design: 1H-102L4wp23 7,204.22 75.57 0.00 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +NIS +E/.W DLS Vert Section (usft) V], (_) (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' DLS, 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 7-5/8" x 9-7/8" 7,212.80 76.93 0.00 3,755.19 3,662.19 -503.68 4,369.05 15.92 -503.66 Start 4'1100' DLS, 0.02' TF, for 308.25' 7,217.02 77.61 0.00 3,756.12 3,663.12 -099.56 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 -54.29°, 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 4,378.07 0.00 -19.79 7,800.00 93.53 359.19 3,783.18 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°/100' 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 WAS 0.20 3,772.87 3,679.67 281.78 4,374.51 4.00 281.78 Start 2°/100' DLS, 479.97" TF, for 10.65' 8,012.73 90.08 0.34 3,772.82 3,679.82 292.43 4,374.56 4.00 292.43 Hold for 768.96' 8,014.73 90.00 0.36 3,772.82 3,679.82 294.44 4,374.57 4.00 29444 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 89.79 0.36 3,77349 3,680.49 479.70 4,375.74 0.00 479.70 8,300.00 89.79 0.36 3,773.86 3,680.86 579.70 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 89.79 0.36 3,774.60 3,661.60 779.69 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 10.68' 8,792.36 89.79 0.36 3,775.69 3,682.69 1,072.04 4,379.46 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 6/29/2017 4: 05:52PM Page 4 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 I Pad North Reference: True Well: Plan: 1H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 111-1021-4 +N/ -S +E/ -W Design: 1 H-102L4wp23 (usft) (I Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W DLS Vert Section (usft) (I (^) (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 397.69' 8,871.34 90.17 1.69 3,775.62 3,682.62 1,151.01 4,380.76 2.00 1,151.01 8,900.00 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'/100' DLS, -91.64' TF, for 312.69' 9,268.93 90.17 1.69 3,774.45 3,681.45 1,548.43 4,39249 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 3,680.96 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 4,372.82 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 3.1100' DLS, -103.22° TF, for 318.18' 10,100.00 89.51 357.30 3,778.02 3,685.02 2,378.56 4,358.69 0.00 2,378.56 10,104.46 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' DLS, 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 3,802.87 3,709.87 3,068.07 4,246.06 3.62 3,068.07 10,900.00 89.27 356.75 3,804.83 3,711.83 3,167.65 4,237.31 3.62 3,167.65 6/292017 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: 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: 1H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-1021-4 Design: 1H-102L4wp23 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W DLS Vert Section (usft) (°) (°) (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°/100' 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 fit 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 °/100' 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 3,626.30 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 3,765.98 4,242.17 3.00 3,765.98 11,500.00 91.14 1.22 3,793.98 3,700.98 3,767.06 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°/100' 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 4,246.70 2.00 4,170.27 Start i°/100' DLS, 115.91° TF, for 13.2' 11,915.99 90.00 358.93 3,787.00 3,694.00 4,162.93 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, -153.05° 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 3,695.06 4,566.68 4,241.76 2.50 4,566.88 6/292017 4:05 52P 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. -Kupi TVD Reference: Plan: 54+39 Q 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 @ 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: 1H-1021-4 TVDss +NIS Design: 1 H-102L4wp23 Vert Section (usft) Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +NIS +E/ -W DLS Vert Section (usft) (I (I (usft) usft (usft) (usft) 3;695.65 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 967.79' 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 3,81446 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°/100' DLS, -22.76° TF, for 56.75' 13,352.11 89.02 318.73 3,817.18 3,724.18 5,518.45 3,853.89 0.00 5,518.45 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 527.72' 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 5,924.85 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 266.05' 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 6/292017 4: 05 52P 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: 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: Kuparuk 1H Pad North Reference: True Well: Plan: 1 H-102 (formerly 31) Survey Calculation Method- Minimum Curvature Wellbore: Plan: 11-1-1021-4 1H -102D 067615Octl 5 BW 0.00 0.00 3,798.51 3,711.20 4,396.81 Design: 1 H-102L4wp23 - Circle (radius 100.00) Targets Target Name -hitlmiss target Dip Angle Dip Dir. TVD +Nbs +E/ -W -Shape (°) P) (usft) (usft) (usft) iH-102D 10.711 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 0272150ct15 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) 1 H-1 02D 03 T3 020217 RP 0.00 0.00 3,773.98 1,861.06 4,384.66 - plan hits target center - Circle (radius 100.00) 1H -102D 067615Octl 5 BW 0.00 0.00 3,798.51 3,711.20 4,396.81 - plan misses target center by 155.20usft at 11443.63usft MD (3795.57 TVD, 3710.74 N, 4241.64 E) - Circle (radius 100.00) 1H-1020033316Febi 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. T1 150ctl5 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.T4150ctl5 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.T5150ct15 BW 0.00 0.00 3,808.21 3,425.18 4,394.93 - plan misses target center by 15&16usft at 11167.22usft MD (3805.41 TVD, 3434.70 N. 4240.09 E) - Circle (radius 100.00) 1H -102D 07.T715OGtl5 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) iH-102D 15.716020717 RP 0.00 0.00 3,800.66 6,342.04 3,168.48 - plan hits target center - Circle (radius 100.00) iH-102D 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) 1H -102D 07.T8020217 RP 0.00 0.00 3,805.41 3,451.99 4,241.19 - plan hits target center - Circle (radius 100.00) iH-102D 06.T616Febl5 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) 1 H-1 02D 09.T9150ct15 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 4,360.36 - 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.T2020217 RP 0.00 0.00 3,775.72 1,084.70 4,379.56 6292017 4:05:52PM Page 8 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 1H-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 1H Pad North Reference: True Well: Plan: 1H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-1021_4 - Polygon Design: lH-102L4wp23 Point 1 - Circle (radius 100.00) 1H -102D 04.75020217 RP 0.00 0.00 3,786.83 2,698.10 4,317.85 - plan hits target center - Circle (radius 100.00) 1 H-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) - Polygon 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 3,600.66 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 31800.66 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 O8.T9 020217 RP 0.00 0.00 3,799.68 3,628.30 4,243.25 - plan hits target center - Circle (radius 100.00) 1 H-1 02D 08.T8 150ctl5 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) 1 H-1 02D 14.T15 020717 RP 0.00 0.00 3,806.76 5,951.23 3,462.72 - plan hits target center - Circle (radius 100.00) 111-102D 073716Feb15 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.T315Oct15 BW 0.00 0.00 3,764.29 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) 1 H-1 02D 053516Febl5 BW 0.00 0.00 3,799.00 3,711.20 4,396.81 - plan misses target center by 155.2lusft al 11443.61 usft MD (3795.57 TVD, 3710.72 N, 4241.64 E) 6292017 4:05:52PM Page 9 COMPASS 5000.1 Build 74 Database: EDM Production Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1 H-102 (formerly 31) Wellbore: Plan: 111-1021-4 Design: 111-1021-4wp23 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: SLB Standard Proposal Report Well Plan: 1 H-102 (formerly 31) Plan: 54+39 @ 93.00usft(Doyon 142) Plan: 54+39 @ 93.00usft (Doyon 142) True Minimum Curvature 1H -102D 047416Feb15 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) 5,975.61 - Circle (radius 100.00) 7,200.81 3,752.30 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) 1,903.05 - Circle (radius 100.00) 1,697.35 1,620.40 111-102D 13.714020717 RP 0.00 0.00 3,817.11 5,560.07 3,816.80 - plan hits target center 6,319.91 3,486.80 - Circle (radius 100.00) 111-102D 01.71 020617 RP 0.00 0.00 3,772.82 294.44 4,374.57 - plan hits target center - Circle (radius 100.00) 1H -102D 10.T1015Oct15 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) - Circle (radius 100.00) 1H -102D 09.T10020217 RP 0.00 0.00 3,787.00 4,182.93 4,248.49 - plan hits target center - Circle (radius 100.00) 1H-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 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 4-1/7'x6-3/4" 4-1/2 6-3/4 Formations Measured. Vertical Depth Depth tusft) Waft) 5,975.61 3,382.60 7,200.81 3,752.30 2,195.08 2,008.40 5,166.08 3,135.40 1,903.05 1,788.60 1,697.35 1,620.40 10,688.95 3,799.10 6,706.09 3,610.70 6,319.91 3,486.80 Vertical Depth 38 UG -13 WS D K-15 UG -C T-3 PFROST WS_C Na UG -A Name Dip Dip Direction Lithology (1) (9 6/292017 4:05:52PM Page 10 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Coordinate Reference: Well Plan: 1H-102 (formerly 31) Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Plan: 54+39 r@ 93.00usft (Doyon 142) Project: Kupawk 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 Wellborn: Plan: 1H-10214 Design: 1H-102L4wp23 Plan: Annotations Measured Vertical Local Coordinates Depth Depth -NAS +E/ -W (usft) (usft) (usft) Nall) Comment 7,176.30 KOP: 13.56°/100' OLS, 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' DI -S, 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 -09.05 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' DI -S, -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°/100' OILS, 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' OILS, -91.54° TF, for 312.89' 9,569.16 3,773.98 1,846.44 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' OILS, -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' DI -S, 77.68° TF, for 339.42' 10,979.40 3,805.40 3,246.99 4,234.75 Start 2.01°/100' DI -S, 89.96° 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 3,609.02 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' OILS, -153.05° TF, for 92.69' 12,320.03 3,788.65 4,586.89 4,241.15 Start 4.1°/100' OILS, -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°/100' DLS, -22.75° TF, 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 6/29/2017 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: 1 H-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: 1HA02(formerly 31) -Plan: 11-1-10214-1H-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 usR. 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. -Kup] Kuparuk River Unit Anticollision Report for Plan: 11-1-102 (formerly 31)-1H-102L4wp23 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 ust4 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 2 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 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 :IH-101(formerly 103, 29) -Plan: 1H -101-1H-10 14,211.()9 1,176.25 14,211.09 995.52 11,975.00 6.508 Clearance Factor Pass - Major Risk Plan: IH-101(formerly 103, 29) -Plan: 1H-101 L1 -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: 1H-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(fonnedy 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 :IH-101(formerly 103, 29) -Plan: 1H-101 L4 -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-1021_1 - 1 H-1 02L - -_ Plan: 1 H-1 02 (formerly 3l) -Plan: 1H -1021.2 -1H -102L - Plan: 1 H-102 (formerly 31) - Plan: 1 H-1021.3 - 1 H-1 02L - Plan: 1 H-102 (formerly 31) - Plan: 1 H-1 0213 - 1 H-1 02L - Plan: 1H-103 (formerly 104, 33) - Plan: 1 H -1 03L1 - 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: 1H -103L3 -1H 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 -103L4 -1H 12,006.72 1,211.71 12,006.72 1,029.56 13,575.00 6.652 Clearance Factor Pass - Major Risk Plan: 1H-109 (formerly 110, 30C) - Plan: IH -109 - 1 H-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 8,194.73 677.61 6,350.00 8.029 Clearance Factor Pass - Major Risk Plan: 1H-111 (formerly 109, 32D) - Plan: IH -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 - 1H-1 8,023.D0 334.78 8,023.00 234.26 6,400.00 3.331 Clearance Factor Pass- Major Risk Plan: 1H-113(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: 1H-113(fornedy 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: 1H-114(formerly 30B,116) -Plan: IH -114-1H-1 10,700.D0 963.36 10,70D.00 826.06 7,175.00 7.016 Centre Distance Pass - Major Risk Plan: 111-114 (formerly 30B, 116) - Plan: IH -114 - 1HA 10,728.15 963.71 10,728.15 825.91 7,225.00 6.994 Clearance Factor Pass- Major Risk Plan: 111-115 (formedy 115, 34A, 114) -Plan 1H-116- 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: 11-1-115 - 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: 1 H-116 - 9,300.00 383.94 9,300.00 284.94 6,550.00 3.878 Centre Distance Pass - Major Risk Plan: 11-1-116 (fornedy 114, 32B, 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-102L4wp23 Tmv. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad -Plan: 111-102 (formerly 31) -Plan: 1H-1021-4-1H-102L4wp23 Scan Range: 7,204.22 to 14,426.15 ustL Measured Depth. Scan Radius is 1,636.61 usft. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is Unlimited Survey toot program From Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on 39.00 Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft 7,554.22 9,054.22 1H-102L4wp23 Plan: 1 H-118 (formerly 30A, 119) - Plan: iH-118 - 1 H-1 13,460.12 792.91 13,460.12 650.31 8,275.00 5.560 Clearance Factor Pass - Major Risk Plan: 1H-120(Al 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(Al 035, formerly 117) - Plan : 1H -12D -1H 9,909.14 700.41 9,909.14 602.00 6,650.00 7.118 Clearance Factor Pass - Major Risk Plan : 1 H-121 (Al 034, formerly 119) - Plan: 1 H-121 - 1H 10,464.62 603.24 10,464.62 504.47 6,775.00 6.107 Centre Distance Pass - Major Risk Plan: 1H -121(A1034, formerly 119) -Plan 1H -121-1H 10,479.89 604.89 10,479.69 503.39 6,825.00 5.959 Clearance Factor Pass - Major Risk Plan :1H-122(Al 033, formerly Al 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, formerly A1040) -Plan: 11-1-122 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 Al 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(A1032, formerly A1033) -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(A1031, formerly A7036)-PIan: 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, formerly Al 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 Al 039) - Plan: 1 H-125 - Plan: 111-125 (A1030, formerly A1039) -Plan: 1H-125 - Survey toot program From To Survey/Plan Survey Tool (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 1 H-102L4wp23 MWD+IFR-AK-CAZ-SC 29 June, 2017 - 16.06 Page 3 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kup] Kuparuk River Unit AnticolIision 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 o/6 COMPASS ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-102 (formerly 31) Plan: 1 H-1021_4 5O1O3xxxxxOO 1 H-1O2L4wp23 Clearance Summary Anticollision Report i 29 June, 2017 Minor Risked Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad -Plan: 1H-102 (formerly 31) -Plan: 111-1021-4-11-1-1021-4wp23 Well Coordinate.: 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: 11-1-102 (formerly 31)-1H-102L4wp23 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk lH Pad -Plan:1H-102(formerly 31) -Plan: 114-1021-4-1H-102L4wp23 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 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 1 H-05 - IH -105 - 1 H-105 10,436.06 297.44 10,436.06 190.76 7,325.00 2.788 Centre Distance Pass - Major Risk 1 H-05 - IH -105 - 1 H-105 10,473.04 309.96 10,473.04 178.33 7,425.00 2.355 Clearance Factor Pass - Major Risk Plan: 1 H-1 01 (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 L1 -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 11,700.00 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: 1H-102LI - 1H -102L - Plan : i H-102 (formerly 31) - Plan: i H-10212 - 1 H-1 02L Plan: i H-102 (formerly 31) - Plan: 1 H-10213 - 1 H-1 02L Plan: iH-103(formerly 104, 33) -Plan: 1H -10311-1H 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: 1H -1031.3-1H 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: 1 H-1031.4 - 1 H 12,006.72 1,211.71 12,006.72 1,029.56 13,575.00 6.652 Clearance Factor Pass- Major Risk Plan :1H-109(formedy 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 PIan: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: 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 :1H-113(formerly 112, 34B) -Plan: IH-113-iH-1 8,190.15 673.22 8,190.15 578.98 6,325.00 7.144 Centre Distance Pass - Major Risk Plan: IH-113(formerly 112, 34B) -Plan: 11-1-113-iH-1 8,192.40 673.99 8,192.40 578.53 6,350.00 7.061 Clearance Factor Pass - Major Risk Plan: 11-1-114 (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 : 1 H-114 (formerly 30B, 116) - Plan: 1H-114 - 1 H-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: iH-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* 1H-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 : 1H-116- 9,306.90 364.99 9,306.90 263.56 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: 1H-102 (formerly 31)-1H-1O2L4wp23 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk1H Pad -Plan: 11,1-102(formerly 31) -Plan: 1H-1021-4-111-1021-4wp23 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 29 June, 2017 - 16:17 Page 3 of 6 COMPASS Measured Minimum @Measuretl 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: 1H -120(A1035, formerly 117) -Plan: iH-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(A1035, 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(A1034, formerly 119) - Plan : 1H -121-1H 10,464.62 603.24 10,464.62 504.47 6,775.00 6.107 Centre Distance Pass - Major Risk Plan: 1H -121(A1034, formerly 119) -Plan: IH -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(A1033, formerly A1040) -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, formerly A1040) -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(A1032, formery, A1033) -Plan* 1H-123 12,208.30 263.30 12,208.30 165.79 7,675.00 2.411 Centre Distance Pass - Major Risk Plan: 1 H-123 (A1032, formerly A1033) - Plan* 1 H-123 12,255.78 289.69 12,255.78 157.74 7,750.00 2.195 Clearance Factor Pass - Major Risk Plan: 1H-124(Al 031, formerly A1036) -Plan: 1H-124 13,149.61 155.18 13,149.61 4D.90 8,100.00 1358 Centre Distance Pass - Major Risk Plan: 1H-124(Al 031, formerly A1036) -Plan: 1H-124 13,156.08 157.57 13,156.08 3717 8,125.00 1.315 Clearance Factor Pass - Major Risk Plan: 1 H-125 (Al 030, formerly A1039) - Plan: 1 H-125 - Plan: 1 H-125 (A1030, formerly A1039) - Plan: 1 H-125 - - Survey toot program From To Survey/Plan Survey Tool (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 1 H-102L4wp23 MWD+IFR-AK-CAZ-SC 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) - 1 H-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 - 16.17 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 x x ' 300 I � I � N ly N !n d U 150 'Y O d � U EquiveM Magnetic 4isOnce I I 11111 'II 0 7500 9000 10500 12000 13500 Displayed interval could be less than entire well:Measured Depth72O4.22 To 14425.15 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 700.00 1H-102wp23 (Plan: 11-1-102) GYD-GC-SS 3753.15 7204.23 7-5/8"x 9-7/8" 700.00 1794.10 1H-102wp23 (Plan: 1H-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: 1H-1021-4) MWD-INC—ONLY 7554.22 9054.22 1H-102L4wp23 (Plan: 11-1-1021-4) MWD 7554.22 14425.15 1H-102L4wp23 (Plan: 11-1-1021-4) MWD+IFR-AK-CAZ-SC 60 — -- 1 Equ lam Magnetic Oinencc ' - - - C tllJ. I � � I � II 75 IIIIII IIIIII �.U_1111! lL.lso— w U 0 5 . U 1. 0 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. 7 -- Minor Risked 00 300-- 1n U) Gl 150 -- U � I � Equivela 1 M gnef[ Distance 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: 11-1-102) GYD-GC-SS 3753.15 7204.23 7-5/8" x 9-7/8" 700.00 1794.10 1H-102wp23(Plan:11-1-102) 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: 1H-102L4) MWD-INC _ONLY 7554.22 9054.22 1H-102L4wp23 (Plan: 1H-102L4) MWD 7554.22 14425.15 1H-102L4wp23 (Plan: 1H-102L4) MWD+IFR-AK-CAZ-SC x x so Equivelanl Magli i[ OiA na C O I I m m n to) v 0130 o v c v U 0 7500 8000 8500 9000 9500 10000 10500 Partial Measured Depth 1 H-1 02L4wp23 7390 MD Inc Azi TO Dleg TFace To -_t 8130 8130 - 8310 8310 - 7204.22 8500 - 75.57 8750 0.00 9000 - 3753.15 9250 - 0.00 0.00 9750 9750 - 10000 10000 - 10250 39.00 To 1 4425.1 5 7217.02 10500 - 77.61 10990 0.00 11480 3756.12 11970 - 15.90 0.00 12960 12960 13450 13450 "----" 13940 13940 - 7237.02 77.61 0.00 3760.41 0.00 0.00 7553.78 7677.39 90.00 93.53 2.65 359.19 3794.55 3790.74 4.00 4.00 12.17 -44.37 16:15, June 29 2017 7921.70 8014.73 93.53 90.00 359.19 0.36 3775.69 3772.82 0.00 4.00 0.00 161.60 1H-102D 01.T1 020617 RP CASING DETAILS 8025.38 8794.34 89.79 89.79 0.36 6.36 3772.84 3775.70 2.00 0.00 .179.97 0.00 TVD MD Name 8805.02 90.00 0.38 3775.72 2.00 3.92 1H-102D 02.1`2 020217 RP 3753.15 7204.23 7.5/8" z 9-7/8" 3800.66 14425.15 4-1/2' x 6-3/4" 8871.34 90.17 1.69 3775.62 2.00 82.66 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 03.1`3 020217 RP 9678.20 10104.46 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-102D 04.T5 020217 RP T. a1..rrPlM10422.64 ,« ww ,xnw.w 1n..: ,x.uei 10652.64 87.34 348.00 3797.50 0.00 0.00 x.uWv 1n�: vx-u:� m-r-ux. 10992.06 90.00 0.00 3805.47 3.62 77.68 wvv vim: a ui r�w.ixaw. i....ws iri,.:.x um� m 11174.20 90.00 3.67 3805.41 2.01 89.96 .zx u.zs.0 ,x.uu..u> in.,: ,x.vv"i mam-u� 11184, 54 90.00 3.67 3805.41 0.00 0.60 1H-1020 07.1`8 020217 RP 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-162D 08.T9 020217 RP 11498.90 91.14 1.22 3794.01 3.60 126.15 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 12239.99 89.94 359.05 3787.32 0.00 0.00 -@ -901270 -11 12332.69 87.88 358.00 3789.09 2.50 -153.05 1H -102D 10.1`11 020217 RP 7204 - 7390 7390 - 7570 7570 - 7760 7760 - 7940 7940 - 8130 8130 - 8310 8310 - 8500 8500 - 8750 8750 9000 9000 - 9250 9250 - 9500 9500 - 9750 9750 - 10000 10000 - 10250 10250 -"" 10500 10500 - 10990 10990 11480 11480 11970 11970 - 12460 12460 12960 12960 13450 13450 "----" 13940 13940 - 14425 Np20 1 H-102L4wp23 39.00 To 14425.15 16:16, June 29 2017 CASING DETAILS TO MD Name 3753.15 7204.23 7-518" x 9-718' 3800.66 14425.15 4-112" x 6-314- .�linnr Rielt -90/ MD Inc Azi TVD Dl eg TFace Ta C 7204.22 75.57 0.00 3753.15 0.00 0.00 7217.02 77.61 0.00 3756.12 15.90 0.00 7237.02 77.61 0.00 3760.41 0.60 0.00 7553.78 90.00 2.65 3794.55 4.00 12.17 7677.39 93.53 359.19 3790.74 4.00 -44.37 7921.70 93.53 359.19 3775.69 0.00 0.00 8014.73 90.00 0.36 3772.82 4.00 161.60 1H -102D 01.T1 020617 RP 8025.38 89.79 0.36 3772.84 2.00 -179.97 8794.34 89.79 0.36 3775.70 0.00 0.00 8805.02 90.00 0.38 3775.72 2.00 3.92 1H -102D 02.T2 020217 RP 8871.34 90.17 1.69 3775.62 2.00 82.66 9268.93 90.17 1.69 3774.45 0.00 0.00 9581.82 90.06 355.44 3773.98 2.00 -91.54 1H -102D 03.T3 020217 RP 9678.20 89.51 357.30 3774.40 2.00 104.80 10104.46 89.51 357.30 3778.06 0.00 0.00 10422.64 87.34 348.00 3786.83 3.00 -103.22 1H-1020 04.T5 020217 RP 10652.64 87.34 348.00 3797.50 0.00 0.00 10992.06 90.00 0.00 3805.41 3.62 77.68 11174.28 90.00 3.67 3805.41 2.01 89.96 11184.54 90.00 3.67 3805.41 0.00 0.00 1H -102D 07.T8 020217 RP 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 11498.90 91.14 1.22 3794.01 3.00 126.15 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 12239.99 8994 359.05 3787.32 0.00 0.00 12332.69 87..88 358.00 3789.09 2.50 -153.05 1H-1020 10.711 020217 RP 7204 7390 7390 - 7570 7570 - 7760 7760 7940 7940 - 8130 8130 - 8310 8310 - 8500 8500 - 8750 8750 9000 9000 - 9250 9250 - 9500 9500 - 9750 9750 - 10000 10000 - 10250 10250 -"" 10500 10500 - 10990 10990 11480 11480 11970 11970 - 12460 12460 - 12960 12960 13450 13450 - 13940 13940 - 14425 1-125wp20 m June 29 Kuparuk 1H Pad Easting (2500 usftlin) Easting (2500 usft/in) Iwp20 1H-120wp21 AC Flipbook ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-102 (formerly 31) 50103xxxxx00 Plan: 11-1-1021-4 Plan: 1 H-102L4wp23 Error Ellipse Survey Report 29 June, 2017 Company: Con000Phillips (Alaska) Inc. -Kupt Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-102(formerly 31) Wellbore: Plan: 11H-1021-4 Design: 1H-102L4wp23 SLB Error Ellipse Report Local Coordinate 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) Tme Minimum Curvature 1.00 sigma EDM Production Survey Tool Program Date 6/29/2017 From To (usR) (usft) Survey(Wellbora) Tool Name Description 39.00 700.00 1 H-102wp23 (Plan: 1H-102) GYD-GC-SS Gyrodata gyro single shots 700.00 1,794.10 1H-102wp23(Plan: 111-102) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1,794.10 7,204.22 1 H-1 02wp23 (Plan: i 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 1 H-1 02L4wp23 (Plan: 1 H-10214) MWD MWD -Standard 7,554.22 14,425.15 1 H-1 02L4wp23 (Plan: i H-1021-4) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC Position uncertainty and blas at survey station Measured Imlima tim Azimuth Vuh., Kighal4e raaral Vertical Magnitude Semimajor Semiminor cmuh Depth Error Blas Emr Bias Emor Bias mBW Error Emir "amilt Tool (usn) M (1) umll) Want (ttsn) Until lasft) lusat laanl (.e) (van) (eant) V) 7,204.22 75.57 0.00 3,753.15 10.47 -1.44 9.44 244 8.41 1.50 2.66 24.48 7.61 103.89 MADHFR-AK-CAZSC 11, 3) 1-204.23 75.57 0.00 3,753.15 10.47 -144 944 244 841 150 288 24.48 7.61 10389 MW INC _ONLY (1, 4) 7,212.00 7893 000 3,75549 1003 446 944 244 8.39 t50 2.05 24.58 7,70 10354 MW INL_ONLY(1, 4) 7,217.02. 77.61 cm 3,756.12 10.03 -146 944 244 839 1.50 2.86 2458 770 103.54 MW61NC_ONLY (1, 4) 7.237.02 77.61 0.00 3.760.41 1003 -146 945 244 839 1.50 2.86 24.50 7.70 103.54 MWOINC ONLY (1,4) 7,521.05 8872 2.38 3.794.18 848 -1.52 10.18 243 848 1.52 2.89 24.96 17.09 112.39 MNIPINC_ONLY(1, 4) 7,553.78 90.00 2.65 3.794.55 8.40 -1.52 18.16 2.43 848 1.52 289 24.96 1709 112.39 Mw INC _ONLY (1, 4) 7.67068 9334 35938 3.791.14 8.49 -1.54 20.27 228 8.50 1.52 275 24.90 1907 114.59 mm (1, 5) 7,877.39 93.53 359.19 3,790.74 8.49 -1.54 20.27 228 0.50 1.52 2.75 24.90 19.07 114.59 mm (1, 5) 7,893.65 93.53 359.19 3,77741 B.56 -1.54 20.53 1.87 8.58 1.52 244 24.39 19.99 10815 MM(1, 5) 7,921.70 93.53 359.19 3,77589 0.58 -154 20.59 163 8.59 1.52 241 24.35 20.10 100.10 mm (1, 5) 8,002.07 90.48 0.20 3,772.07 8.65 -1.51 20.74 166 8.65 1.51 229 2419 20.50 107.55 MWD(1, 5) 8,01273 90.08 cm 3,772.02 8.65 451 M.74 1.66 865 151 229 24.19 Mac 104.55 MM (1. 5) 801473 MOD 0.36 3,772.82 865 -151 M.74 1.88 865 I51 229 24.19 20.50 104.55 MMM. 5) 0,02598 89.79 cm 3,772.84 8.66 -1S1 20.76 1.64 9.65 1.51 228 24.17 20.54 10408 MMIC. 5) 0701.68 8979 0.36 3.775.65 960 -1.51 2585 0.33 960 1.52 1.77 26.93 n.78 3203 MMIC. 5) 0,792.36 89.79 0.35 3,775.69 9.60 -1.51 25.95 D.33 9.60 152 1.77 26.93 2278 3203 mm (1. 5) 8.794.34 99.79 ow 3]75]0 9.60 -1.51 2585 0.33 9.80 132 1 ]7 26.93 2218 32c3 MAD (1, 5) 8,805.02 90.00 0.38 3,77572 981 -1.52 2595 0.31 9.61 1.52 1A 27.03 2278 31.62 mvmc, n, 5) 8,850.60 90.14 t." 3,775.65 972 -1.52 2661 0.18 9.73 1.52 1.77 27.61 2273 29.82 mm (1, 5) 8,871.34 90.17 1.69 3,775.62 9,72 -1.52 2881 0.18 9.73 1.52 1P 2781 2273 29.82 MM (1. 5) 9,256.27 90.17 189 3,71448 9.01 -1.52 21.67 2.42 9.02 1.51 3.08 24.20 21.54 104.32 MAD+IFR-AK-CAZ-SC(2, 5) 9,268.93 90.17 1.69 3,77445 9.01 -1.52 2167 2.42 9.02 1.51 3.08 2420 2154 104.32 MAD+IFR-AK-CAZ-SC(2, 5) 9.569.16 90.01 355.69 3.77398 9.22 -1.51 22.13 254 922 151 3.13 24.08 22.02 98.38 MWD+IFR-AK-CAZ-SC(2, 5) 9,581.82 90.00 35544 3,773.90 922 -1.51 22.13 254 9.22 1.51 3.13 24.08 22.02 98.38 MWD+IFR-AK-CAZ-SC(2, 5) 9,665.54 09.57 357.06 3,774.29 9.31 AM 22.16 2.50 9.29 1.51 3.15 2405 22.12 9581 MWD+IFR-AK-CAZ-SC(2,5) 987820 89.51 357,30 3,77440 9.31 -1.50 22.16 250 929 151 3.15 24.05 22.12 95.81 MWD+IFR-AKAAZ-SC(2. 5) 10,091.80 89.51 357,30 3,777.95 eat AM 2322 2.50 9.63 1.52 3.24 2406 23.18 74.13 MWOHFR-AKAAZ�SC(2, 5) 10,10446 09.51 35730 3,77006 9.64 -150 MM 2.50 9.63 1.52 3.24 2406 23.18 7413 MM+IFR-AK-CAZSC(2,5) 1040998 07.43 348.37 3,786.25 10.01 -147 2356 271 991 1.52 3.31 24.37 23.31 49.02 MAD+IFR-AK-CAZ-SC(2.5) 1042264 BTU 348.00 3,785.83 10.01 -1.47 23.56 Z71 991 152 3.31 24.37 23.31 49.02 MAD+IFR-AK-CAZSC(2,5) 10,63990 0734 34800 3,796.92 1023 -147 24.13 231 IT13 153 3.35 24.86 23.38 33.07 MAD+1FR.AK-CAZ-SC(2, 5) 10,65264 87.34 340.00 3,797.50 10.23 -147 24.13 2,71 10.13 1.53 3.36 24.86 23.35 3307 MWD+IFR-AK-CAZ SC (2, 5) 10,600.95 8762 34929 3.799.10 1026 -147 2427 267 10.17 1.53 337 24.96 23.37 31.32 MM+IFR-AR-CAZSO(2.5) 10,97940 8990 359.55 3.805.40 1047 -153 25.10 2.37 1047 1.53 345 25.58 23.25 27.53 MW0+IFR-AK-CAZSO(2.5) 10.992.06 90.00 0.00 3,80541 1047 -1.53 25.10 2.37 1047 1,56 345 25.56 2325 27.53 MAD+IFR-AR-CAZ-SC(2, 5) 11,16162 9000 3.42 380541 low -1.53 25.55 2.23 1088 1.53 3.50 25.97 23.18 27.09 MAU+IFR-M-CAZSO(2. 5) 11,171.80 9000 3.82 3,905.41 10fi6 -1.53 25.55 2.23 10.66 1.53 3.50 25.97 23.18 27.09 MWWIFR-AK-CAZ-SC(2, 5) 11,17428 90.00 3.67 3.805.41 10.66 -1.53 25.55 223 10.66 1.53 360 25.97 23.18 27.09 MAD+IFR-AK-CAZ-SC(2. 5) 11,184.54 90,00 3.67 380541 10.87 -1.53 25.50 2.23 1067 1.53 3.51 26.00 23.18 27.00 MWD+1FR.AKAAZSC(2, 5) 1134174 9331 358.31 3,800.95 10.05 -1.66 25.82 2.45 10.85 1.53 355 28.50 23.15 25.33 MWD+IFR-AR-CAZ-SC(2, 5) 6/292017 4.:07.47PM Page.2 COMPASS 5000.1 Build 74 Company: ConowPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-102 (formerly 31) Wellbore: Plan: 1H -102L4 Design: 1H-102L4wp23 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: 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 Measured Incllna9on Az uth Vertical Highside lateral Vertical Magnitude Semima)or SeMlminor Depth Depth Enor Blas Emf Bias Emf Bias NBias Error Emr Azimuth Tod (use) (°i (°) (-,ft) (u.h) (usft) (usft) Iuaa) (,aft) (use) Naa) (usn) (unit) (7 11,34841 9345 358.08 3,80646 1085 -186 25.02 2.45 1086 163 355 2650 23.15 2533 MWD+IFR-AK-CM-SC(2, 5) 11,35439 9358 357.88 180609 1085 -1.66 25.02 245 10,86 153 355 26.50 23.15 25.33 MAD+IFR-AK-CM-80(2,5) 11,38107 9158 357.88 3799.68 10.85 -1.66 25.64 2.45 10.87 153 355 26.52 23.15 2525 MWD+1FR-AK-CM-SC(2, 5) 11,406.25 9136 0.91 3]9428 11.00 -1.57 26.18 2.32 11.02 153 3.59 28.76 2308 2540 MWD+IFR-AK-CM-SC(2.5) 11,490.90 91.14 1.22 3]9401 1100 -157 26.18 2.32 11.02 1.53 3.59 26]6 23.08 2540 MWD+IFR-AK-CM-SC(2,5) 11775.69 91.14 1.22 3,780.52 11.34 -1.57 27,25 2.32 11.36 1.52 168 2.03 23.07 22.41 MM+IFR-AK-GMSC (2,5) 11780.35 81.14 1M 3.788.27 11.34 -157 2725 232 1136 1.52 368 27.63 23.07 2241 MWTAIFR-AK-CMSC(2.5) 11903.33 90.11 359.18 3,787.02 11.52 -1.52 2)31 242 11.52 1.52 372 28.03 23.01 2257 MWD+IFR.AK4MS0(2, 5) 11,915.93 90.00 358.93 3707.00 11.52 -1.52 27.31 242 1152 1.52 In 2806 23.01 22.57 MWD+IFR-AK-CA -SC (2, 5) 11,916.53 90.00 358.94 3787.00 11.52 -1.52 27.31 242 1152 152 372 207,6 23.01 22.57 MWD+IFR-AWCM-SC(2,5) 11,92918 8994 359.05 3,78701 fl53 -1.52 27.34 241 11.53 1.52 372 28.09 23.00 22.58 MWD+IFR-AK-CM-SC(2,5) 12,22]34 8994 359.05 3,787.31 11.92 -1.52 28.46 241 11.91 152 382 29.21 2298 20.40 MWD+1FR-AK-CM-SC(2,5) 12,239.99 89.94 359.05 3,78132 11.92 -1.52 28.46 241 11.91 152 382 29.21 2298 20.40 MWD+1FR-M-CM-SC(2, 5) 12.320.03 88.10 358.14 378865 12.11 -1.43 28.55 2.46 12.03 1.52 3.86 29.40 22.94 2642 MWD+1FR-AK-CM-W(2,5) 12,33269 87.00 35000 3,789.09 12.11 -143 28.55 246 12.03 1.52 3.06 2940 22.94 2942 MWD+tFR-AK-CM-SC(2, 5) 13,277.02 89.00 319.25 3.81590 13.29 -152 2600 369 13.30 1.54 4.10 31.77 22.63 1369 1AWD+1FR-AK-CM-SC(2,5) 13.29648 8902 31673 3.816.12 1329 -1,52 2000 389 1330 1.54 4.10 31.77 22.63 13.69 MWDHFRAK-CM-SC(2. 5) 13,339.45 09.02 31673 3.816.96 13.39 -1.52 26.17 3.69 13.39 1.54 4.11 31.92 22.62 1393 MWD+IFR-AK-CM-SC(2, 5) 13.352.11 09.02 31873 3.817.18 13.38 -1.52 26.17 369 1339 1.54 4.11 3192 22.62 12.93 MWD+IFR-AK-CM-SC(2,5) 13,395.20 90.65 31905 3,817.31 1349 -1.56 26.19 171 1346 1.54 4.12 32.M 2281 1225 VM+1FR-AK-CM-SC(2, 5) 13,407.96 91.12 317.85 3,817.11 1349 -1.56 26.19 371 13.46 154 412 3205 22.61 1225 MWD+IFR-AK-CM-SC(2,5) 13922.92 91.12 317.85 3,80701 14.24 456 27.05 371 14.21 154 4.19 33.50 22.51 649 MWD+IFWAK-CM-SC(2, 5) 13.935.58 91.12 31785 3,80678 1424 -1.56 27.05 3.71 14.21 154 4.19 33.50 2251 649 MWD+IFR-AWCM-SC(2, 5) 14,14744 90.62 324.18 3,803.53 14.54 -1.55 29.69 3.54 14.53 1.53 4.21 14.04 2241 5.09 MWD+1FR-AK-CM-SC(2, 5) 14,180.10 9059 324.56 3,80340 14.54 -1.55 29.69 3.54 14.53 153 4.21 3404 2241 5.09 MWD+1FR-M-CM-80(2,5) 14.41249 90.59 324.55 3,00079 14.93 -1.55 30.70 3.54 14.92 1.53 4.26 34.96 22.37 3.04 MWD+1FR-AK-CM-SC(2, 5) 14.425.15 90.59 324.56 3.800.66 14.93 -155 30.70 3.M 14.92 153 428 34.96 22.37 3.04 MM+IFR-AK-CM-SC(2, 5) 6/292017 4:07:47PM Page 3 COMPASS 5000.1 Build 74 Pool Report 1 H-102L4wp23 Surface Location 13 CPAI Coordinate Converter o 0' (-From:-- -----_,, To: Datum: NAD83 Region: lalaska I Datum: NAD27 f Region: alaska i Latitude/Longitude DecimalDegrees—� i LatitudelLongitude Decimal Degrees {" UTM Zone: (— South (" UTM Zone: True r South !� State Plane Zone: 4 - Univ-: us-ft i- State Plane Zone: q : Units: us-ft Legal Description (NAD27 only) f— Legal Description (NAD27 only) Starting Coordinates: — ----- X: 11689609.08 Ending Coordinates: X: 1549577.455558541 Y: 15980414.37 Y: 5980662.56352101 L� .............. ... Transform Quit Help 1H-102L4w 23 Surface Location L41 CPAI Coordinate Converter From: - To: Datum: INAD83 Region: alaska --- Darum: NAD27 . Region: alaska r Latitude/Longitude Decimal Degrees C Latitude/Longitude Decimal Degrees r UTM Zone: r South C UTM Zone: True South r State Plane Zone: q Units: us-ft r State Plane Zone: q � Units: us -ft il i` 1:- Legal Description (NAD27 only) Starting Coordinates:---------- --- Legal Description—-------—� X: 1689609.08 Township: -012 -i Range: )N010 Y: 15980414.37 Meridian: Section: 33 FNL 40.519229 FEL 764.65061 Transform Quit Help 1H-102L4wp23 Surface Casing E3 CPA[Coordinate Converter 0 - r--From: .. To:.. - -------- ---- - - Datum: NAD83 Rcgion: alaska ., Datum: NADp7 Rcgion: alaska �.. * Latitude/Longitude Decimal Degrees LatitudelLongitude Decimal Degrees-� C' UTM Zone: F— r South C UTM Zone: True South G State Plane Zone: ',r� Units: us-ft fi State Plane Zone: q �.. Units: us-ft r Legal Description (NAD27 only) r Legal Description (NAD27 only) Starting Coordinates: X: 11689909.67 Ending Coordinates: - - - X: 549878.038975245 Y: 5980107.45 i Y: 5980355.6450701 Tran<form j Quit Help 1 H-102L4wp23 Surface Casing n CPA[ Coordinate Converter -From:- To. - - - Datum:NAD83 Region: lalaska Datum: NAD27 Regionlalaska i Latitude/Longitude Gerimal Degreesr Latitude/Longitude Decimal Degrees C UTM Zone: South r UTM Zone: True I- South %' State Plane Zone: q Units: us-ft C" State Plane Zone: I. Units: us-ft I C Legal Descriphnn ('IAD27 nnly) L C Legal Description (NAD27 only) - Starting Coordinates: ---- 1669909.67 Legal Description Township: 012 N Range: 010 E Y 5980107.45 Meridian: U Section:33 --- --- - FNL f349.44826 IFEL 1466.76527 ........................................................... .Transform. Quit Help 11H-102L4wp23 Kick-off Point M CPAI Coordinate Converter— __From --- Datum: Rogion: a—lask—a-- PziT7D_ F r Latitude/Longitude Decimal Degrees UTM Zone: F_ F South G State Plane Zone: 4 Units: fus-ft_.I (- Legal Description (NAD27 only) Starting Coordinates: - X 11693980.98 Y: 15979931.10 11H-102L4wp23 Kick-off Point [ ft CPAICoordinate Converter To Datum;Rogion: FZF Flaska I Latitude/Longitude ]Decimal Degrees UTM Zone: FT—,u, T- South State Plane Zone: 1'4- 1 Units: FU7T__1 Legal Description (NAD27 only) Ending Coordinates: X 553949.285837716 Y: 5%0179,22228383 L.Transform 1) [Alt Help .......... ...........'.1 ]l From: Datum: INAD83 .j Region: fa_jaska____,] r Latitude/Longitude jDecimal Degrees * UTM Zone: I— f - South * State Plane Zone: F---:-] Units: us -ft -3 r Legal Description (NAD27 only) Starting Coordinates: X 11693980.98 Y: 15979931.10 To: Datum: ft1A_D27 � Region: alaska • Latitude/Longitude DecimalDegrees • UTM Zone:Truer South r State Plane Zone: FJ Units: us -ft r- Legal Description (NAD27 only) Legal Description - Township: 0_12FN:-�] Range: 10-10- F—:-:] Meridian: Section: I J4- - J FFNL-,IF55-410063 .FEL -1 11676.8335 1 — I — Tran dorm Quit Help 11H-102L4wp23 Top of Production CPAI Coordinate Converter From: ------------------ Datum: NAD83 3. Rogion: alaska t' Latitude/Longitude Decimal Degrees —� r UTM Zone: r South G State Plane Zone:q Units: us -ft C Legal Description (NAD27 only) Starting Coordinates: -- X 11693981.00 Y: 15979927.80 QIP To- ---. -- - --------_--_- - _. Datum: fNAD27 � Rogion: JaIISK, * Latitude/Longitude IDecimaiDegrees r UTM Zone: True F South f• State Plane Zone: F Units:Fu —s C Legal Description (NAD27 only) EndingCoordinates: ----- X:553949.305813978 Y: 5980175.92236175 Transform Quit Help 11H-102L4wp23 Top of Production N- CPA Coordinate Converter a 1 O From: Datum: INAD83 Region: jalaska r Latitude/Longitude IDecimalDegrees, r UTM Zone: F— r South fes' State Plane Zone: [4----,l Units: jui r Legal Description (NAD27 only) -Starting Coordinates: X: 1693981.00 Y: 15979927.BO To: Datum: INAD27 Region alaska * Latitude/Longitude IDecimal Degrees * UTM Zone: True r— South f StatePlane Zone: q Units: us -ft C Legal Description (NAD27 only) Legal Description - Township: 012 I">J Range: 010 Meridian: [U-----7, Section:34 FNL I 557.39336 FEL -111676.8389 Quit Help 11H-102L4wp23 TD CPAI Coordinate Converter From: -- - - - - -_..-- ----- - - ---- I Datum: NAD83 Region: alaska r Latitude/Longitude Decimal Degrees f UTM Zone: F— F" South (: State Plane Zone:q Units: us -ft C' Legal Description (NAD27 only) Starting Coordinates: X: 11692735.54 Y: 15986776.45 To Datum: NAD27 � Rogion: (alaska • Latitude/Longitude Decimal Degrees • UTM Zone: True i South C•` State Plane Zone: �� Units: us -ft C Legal Description [NAD27 only) Ending Coordinates: — — X: 552703.912252242 Y: 5967024.43441855 ,........................................................... Transform Quit Help 1 H-102L4wp23 TD M CPAI Coordinate Converter oil From: Datum: NAD63 Region:alaska r Latitude/Longitude IDecimal Degrees .I C UTM Zone: F_ r_ South r State Plane Zone: f"� Units: us ft C Legal Desoription (NAD27 only) Starting Coordinates: X: 11692735.54 Y: 15986776.45 To Datum: 1NAD27 Region: alaska t Latitude/Longitude IDecimal Degrees i UTM Zone: True F South C` State Plane Zone: 4 Units: usft t' Legal Description (NAD27 only) Legal Description— — Township: 012 1", Range: 010 Meridian: Section: 22 FNL 4259.5209 IFEL I2861.7877 Transform Ouit Help 16:13, June 292017 1 H-102L4wp23 WELLBORE Nama ,H:02 OIn OZOsn Rv TARGET DETAILS 3nz az 377 (MAP CO-ORDINATES) Shape axle (Roams: 100,00) 1H-102D 03 T2020217 RE 377572 Circle (Raaiui!cc oo) Quarter Mile View ,H-,02D 6J T30202,]RP ,H-102D 0d Ts 020217 RE 3773.95 370383 Circle IRaaiu5: , 0000) Circle (Raaiuz:,0000) 1H-102007.Te 020217 RP 3805 41 arch (Raame. m0.00) 11�ID2D OB 7902021] RP 3]99.68 Clrare (cad us 10000) 1H-102D 09 TID 0202P RP 3]0]00 Ciu e(Raaius 100.00) 1H-10201D T 1102028 RP 378909 Grde (RaaWz: 100.00) ,H-102D 13.T14020717 RP 3017.11 Clrcle(Radius: 100.00) IH-102D 14.T15 020717 RP 3806.]6 circle (RaaWz: 10000) 1M -102D 15 TIE 020]t]RP 380066 Circle (Radius: 10000) 1FI-102 Nerh Fsul1 380066 Polygon 1H-102 Polygon 020717 OR 380066 Polygon !O IH- 02 Soutn Fre' 3900.66 Polygon N a' 1H-1 2° OI T, 0203,] RP circle iH-tO D05.TG 0202P RP 371282 380009 CVcle (Ratliuz' 1320.00) Tied, (Radius10000) n (y iH-t02 0677020217 RP 380301 1FL102D TT 2" Ie 3800.66 Circle(Radius: 1 oo 00) Circle (Radius 1320 00, g0J n O 8000 ry°v , b Q rye+ 1H-20 &000 n ^p 1R-29L1- 3 ��Q. og1 'iii �H, O tb 1gP�1PA O O 19 9 1 N.59P m 1H-1 A b� +4000 000 1H-19A 2 Q 1 -17 7r O Q jos Z Z: 2000 r oAP83 � 3 - 0 1H- s N 0 P O U 2 H,40 N 7 eb y 2 —2000 , . n —2000 0 2000 4000 6000 8000 10000 12000 14000 16:32, June 29 2017 1 H -102 L4wp23 WELLBORE TARGET Name 1H-ID2D 01 T1 020617 RP DETalLS (MAP COORDINATES) WD Shape 3772.82 Crela (Radius: 100.00) tH-1 oto 02T202021] RP 377572 Circle(RaI us: 100.00) wt02003T 02029 RP 0 Crile (RaCiu510000) Quarter Mile View 1H-1ozD 04.rs Ozo2 7 RP 3]Bs 83 orale (Radius'. 10a.00) 1H-102D 0778020217 RP 380541 Did, (Reel 100.001 1H- 102D 08 TO 020217 RP 3799.68 Circle (Red.., 10000) 1H-102D 09_T10020217 RP 3707.00 Circle(Relus 100.00) 1 H� 102D 10 T 1102029 RP 379909 Circle(ardh,, 100.00) 1H- 102013.T140207T7 RP 3817.11 ortle(Radius: 10000) 1H- 102014.T150117 RP 3906.76 Cnis (RaI s: 10000) 1H-ID2D 15 T1802079RP 3800.66 Cie, (Radius'. 100.00) 1H-102 NUM Fault 3000.66 Polygon 1H-102 P01y9on 020]1]BP 380066 Poly90e 1H-102 SCu1M1 Fault 390066 Polygon 1H-102D 01 Tl 02"17 RP Circle 377282 Circle Realms 1320.00) 1 H-102D 0556 020217 RP 3000.89 Crcla (Radw5: 100.00) td-1020 86.1020217 RP 3808.01 Crcle (Ratlius 100.00) 1H- 102015 T16020]9 RP Circle 3B0066 Circle (Radius 132000) 8000 A Q P1 C X6000 - - N 7 O O N +4000 L O COs Z :S2000- 000 0 O x N 0 M 1 h -2000 -2000 0 2000 4000 6000 1 8000 10000 12000 14000 16:34, June 29 2017 m 1 H-102L4wp23 Quarter Mile View -2000 0 2000 4000 (I&" WCLLBORE TARGET DETNLS (MPP CO-ORDINATES) Neme TVD 3oape ;IH -102D OLT1020617 RP 3]]282 Clyds(Radius: 100.00) l+ 02D 02T202o21] RP 3]75.]2 Circle(ReEius: 100.00) 11102003.T302021]RP 37]3.90 Circle (Radius: 100.00) 11102D 04.T5 U0217 RP 3786.83 Circle(Radius: 100.W) IH -102D 07,T 020217 RP 3805.41 Circle (Radius: 100.00) 11-10213 OB.T9020217 RP 379980 C'ircle(Rediva: 100.00) 11102D 09.T10000217 RP 3707.00 Circle (Radius IOD.Oo) 11+102D 10 T1102021] RP 3]89.09 CNcle(Radius: 1W.00) 11102D 13.T14 020717 RP 3017.11 "Ile (Radius: 100.00) t 1102014.T1502W1]RP 3006.76 Circle(Radlus: 100.W) 11102015.T1602D717 RP 38100.66 Circle(Radws: 100.00) 114(02 North FauX 3000.66 Polygon 11102 Polygon 020717 BP 380068 Polygon -- —+102SoWR Fault 3800 fib- ---Polygon - 111020 01.T1 =617 RP Circle 3772,82 COcle (Radius: 1320.00) 111020 05 T6 000217 RP 3800.09 Circle (Radius: 100.00) 11020 W.T] 000217 RP 3808.01 Circle (Radius: 100.00) 111020 15.T16 020717 RP Circle 3800.66 Circle (Radius 1320.00) 6000 8000 10000 12000 14000 (2000 usft/inl 1 H-102L4wp23 Section View 3650- 6503700Q3750 3700- Q3750 L - O - o -----_. ._WS-_-C- ---------------B_C - m 7-5/8" x 9-7/8'' 0 rn� oo o WS E? 4t. o U 1� W O OOo O — — i — O W � 3800 0 - -' �WSA4 M r. o WS A4 Objective o 01 - o 3850 -- ----- - -- WS -A3 3900 -- --------- -- �y -21 -900 0 �00 1800 2700 3600 4500 5400 6300 Vertical Section at 0.000 Tollerable Collision Risk Worksheet conocc)phillips Alaska ATolerable Collision Risk Worksheet based on Rev. t - 29 Jul 99 Use this sheet to describe a well Interference scemmr where ORA may be applicable. Check first that Ne scenario realty is different from those described on existing worksheets. Prepared by: Kelsey Hailford . i Authorized by: can Bearden j _.—�"-- Conocolahillips Alaska, Inc Drilling Anti -Collision Management Generic name of scenario: Collision with other lalemis In mull14ateral well (A3 with A2. A4 with A3 and A2, B with A4, A3, and A2, D with B, A4, A3 and Are Description: (Be specific. Include all factors which affect either the cost of collision or the cost of reducing the risk Well 1H -m2 A3, A4, B and D laterals fall anti collision with one another in the horizontal legs of the well base on WP21. The four upper laterals will be geosleared using periscope so risk of leaving the zone is minimal. There is no immediate danger to lire or impact on the environment if well 1H- 102 intersects itself. If 1H-002 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 drilled Is above the previous placed lalemis (upper laterals have the same or slightly higher PP) and is teing drilled from the main bore with kill weight mud in the hole. The laterals fall with the mother bore at the kick off point, but we are intentionally side tracking. We will be kicking off with motors to keep us in the target sands. Do the consequences Are the of collision include a aes risk to personnel or the consequences environment? of collision List all the consequences of I Ickes / collision and the necessary remedial action: No HSE risks exist with 1 H-1 02 intersecting itself while drilling. An economic concern exists and it would be the cost of damage to the completion equipment that has already been placed in the lower laterals prior to drilling the upper laterals and the impact it may have on future production from the well If necessary the lateral that tied been dulled Into can be isolated and production shut off (loss of lateral) which is worst case scenario. The biggest chance of getting"bsr Is when crossing faults, there are three fault crossings in 1H-102, but since the lower lalemis will have already drilled across the fault the exact throw of the fault will be known so the fault crossing can be planned for, If we do gel act of zone we can determine what mne we are In based on real time logs and cuttings and then steer back into the correct zone. How could the probability of collision or the severity of the consequences be reduced? How might this impact the drilling operation? cost: reducing V = $0 the risk Given the uncertainty in the above estimates, by how many fines must the savings made from not reducing the risk outweigh he risk itself? (Guideline = 20) M = 20 F=1/M= 0.05 C = $10,000,000 Is there a practical way pre: to substantially reduce hiff, Estimate the NPV of either the probability of the Planned well collision or the severity V= $42,650,000 of the consequences? 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 < i then Tolerable Collision Risk = 1 in C I V F Tolerable Collision Risk = 1 in 23 Minor Risk 1/50 applied to all laterals reducing V = $0 the risk Given the uncertainty in the above estimates, by how many fines must the savings made from not reducing the risk outweigh he risk itself? (Guideline = 20) M = 20 F=1/M= 0.05 C = $10,000,000 Is there a practical way pre: to substantially reduce hiff, Estimate the NPV of either the probability of the Planned well collision or the severity V= $42,650,000 of the consequences? 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 < i then Tolerable Collision Risk = 1 in C I V F Tolerable Collision Risk = 1 in 23 Minor Risk 1/50 applied to all laterals As -built 1 12/05/01 MRT I CC I IRev. Per K05014ACS 12 02/01/11 JAH I LGM I Rev. Per K170005ACS N •12 25 30 29 26 27 2` •10 *17 G •16 _ •15 •13 36 31 KCS 3233 7� 18 ) 34 35 36 i •3 T1 NP10F •8 •4 T11NPTOE a 6 4 3 2 1 0120 IA ASP GRID NORTH ®1192 CPFI 10 �°.tiF 1 0118 a 9 2 ®117 � 0116 0115 18 17 16 15 14 1< 0114 Is LEGEND 0113In 0112 2 24 194, 20 21 2 23 0 AS—BUILT CONDUCTOR 0`111 0110 VICINITY MAP • EXISTING CONDUCTOR 0109 SCALE: 1' = 2 MILES 0104 0108 0103 28 27 33 34 0102 0106 0101 DS1 H •UGNU 01 SEE SHEET 2 & 3 FOR COORDINATE TABLE NOTES: 1. BASIS OF LOCATION AND ELEV. IS DS1H MONUMENTATION PER LOUNSBURY & ASSO 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. 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS 26 AND 33, TOWNSHIP 12 NORTH, RANGE 10 EAST, UMIAT MERIDIAN, ALASKA. 5. DATES OF SURVEY: 12-26-16 THRU 1-31-17 FIELD BOOKS L16-35, L16-40, L17-02 & L17-03. 6. ALL DISTANCES SHOWN ARE GROUND. GRAPHIC SCALE 0 00 200 400 1 inch = 200 ft. LOUNSBURY & ASSOCIATES, INC. MYOR3 ENGINEERS V1 NEM AREA: IH MODULE: XXXX UNIT: D1 ConocoPhilli„S DS1H M WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD nLE NO. DRAWING NO. PART: REV: LK6108d31 2/05/05 CEA—DIHX-6108D31 1 of 3 2 *14 •5 •20 •12 •19 •11 *22 •10 *17 •6 •16 •21 •15 •13 •1 •9 •2 07 •3 •18 •8 •4 SEE SHEET 2 & 3 FOR COORDINATE TABLE NOTES: 1. BASIS OF LOCATION AND ELEV. IS DS1H MONUMENTATION PER LOUNSBURY & ASSO 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. 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS 26 AND 33, TOWNSHIP 12 NORTH, RANGE 10 EAST, UMIAT MERIDIAN, ALASKA. 5. DATES OF SURVEY: 12-26-16 THRU 1-31-17 FIELD BOOKS L16-35, L16-40, L17-02 & L17-03. 6. ALL DISTANCES SHOWN ARE GROUND. GRAPHIC SCALE 0 00 200 400 1 inch = 200 ft. LOUNSBURY & ASSOCIATES, INC. MYOR3 ENGINEERS V1 NEM AREA: IH MODULE: XXXX UNIT: D1 ConocoPhilli„S DS1H M WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD nLE NO. DRAWING NO. PART: REV: LK6108d31 2/05/05 CEA—DIHX-6108D31 1 of 3 2 1 1 102/01/171 JAH I LGM I ICreate Per K170005ACS I I I I I I CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 28, T. 12 N.. R. 10 E.. UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geo ra hic Coordinates Section Offset. Elev. Y I X 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' 46.0' 54.1' *104 5,980,782.43' 549,568.74' N 70' 21' 29.809" W 149' 35' 50.655" 79' 772' 48.0' 54.1' *108 5,980,752.52' 549,570.98' N 70' 21' 29.515" W 149' 35' 50.595" 49' 770' 48.0' 54.0' *109 5,980,812.20' 549,566.50' N 70' 21' 30.102" W 149' 35' 50.714" 109' 774' 48.0' 54.0' *110 5,980,842.21' 549,564.40' N 70' 21' 30.398" W 149' 35' 50.770" 139' 776' 48.0' 54.0' *111 5,980,872.05' 549,562.21' N 70' 21' 30.691" W 149' 35' 50.828" 169' 778' 48.0' 54.1' *112 5,980,902.08' 549,559.94' N 70' 21' 30.987" W 149' 35' 50.889" 199' 780' 48.0' 54.0' *113 5,980,932.00' 549,557.76' N 70' 21' 31.281" W 149' 35' 50.947" 229' 782' 48.0' 54.0' *114 5,980,961.86' 549,555.50' N 70' 21' 31.575" W 149' 35' 51.006" 259' 784' 48.0' 54.1' *115 5,980,991.68' 549,553.43' N 70' 21' 31.868" W 149' 35' 51.062" 289' 786' 48.0' 54.1' *116 5,981,021.61' 549,551.58' N 70' 21' 32.163" W 149' 35' 51.110" 319' 787' 48.0' 54.1' *117 5,981,051.73' 549,548.80' N 70' 21' 32.459" W 149' 35' 51.185" 349' 790' 48.0' 54.0' *118 5,981,081.22' 549,546.95' N 70' 21' 32.750" W 149' 35' 51.234" 378' 791' 48.0' 54.0' *119 5,981,111.42' 549,544.52' N 70' 21' 33.047" W 149' 35' 51.299" 408' 794' 48.0' 54.2' *120 5,981,141.33' 549,542.48' N 70' 21' 33.341" W 149' 35' 51.353" 438' 795' 48.0' 54.1' * CONDUCTOR ASBUILT THIS SURVEY �;.• 49th '. T c I JEREMIAH •F••CORNELLp7 LS -12663 •; •,��AV SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT 1 AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION ARE CORRECT AS OF JANUARY 31, 2017 LOUNSBURY & es30CUTES, INC. IVRTORS ENGINEERS P A MS AREA: IH MODULE: XXXX UNIT: D1 ConocoPhillips WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD 1nQA., , '� a DRAWING N0. OF-A-mwv-F1/l Rrl71 PART: z z I REV: Haagen Dazs Necessary Plan Request (NPR) Appendix ■ Tier 1: Standard Section ■ Intervals without issues noted for Tier 2 or 3 ■ Tier 2: Challenging Orientation ■ DriIIingwithin 30' of horizontal inclination AND driIIingwithin 300 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 ■ 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: ■ Consider all Tier 2 & 3 mitigations 7 z=iig ConocoPhillips 1H-102 Drilling Hazards Summary 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Mitigation Strategy 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 accuracy. 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Gravels Low Maintain planned mud parameters, increase mud weight, use weighted sweeps. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight. Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, LCM. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out. 6-3/4" Open Hole / 4-1/2" Liner Intervals Hazard Risk Level Mitigation Strategy 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. IH -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 wear model. Getting Liner to Bottom Moderate Properly clean hole on the trip out with the BHA, perform clean out run if necessary, utilize super sliders for weight transfer, monitor torque and 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 111-102 Cement Calculations 13.5 39 1794 10.75 9.95 45.5 T875 5900 8325 7.625 6.875 29.7 Surface Cement: Surface to 1,794' MD Capacities: Capacities Slurry: Lead 1.91 ft3/ sx of 11.0 ppg DeepCRETE 9-7/8" x 7-5/8" OH 0.177045 Tail 2.28 ft3/ sx of 12.0 DeepCRETE Permafrost (PF) depth 1620 It 13-1/2"x 30-3/4" 0.064783 XS% Lead 250 % 20"x 10-3/4" 0.220213 XS% Tail 50% 10-3/4" 0.096175 Tail Cement 1.4 0.27 bbls Shoe Track 80 x Length 500 It 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 It 1294 x 0.06478288 x 3.5 293.4 bbl Conductor Length 80 It 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 Capacities: Slurry: 9-7/8" x 7-5/8" 0.03825 15.8ppg Class 0 yielding 1.16ft^3/sk XS%for open hole and annulus: 40% 9-7/8" OH 0.094731 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 Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, July 13, 2017 1:34 PM To: Kelsey.Hallford@conocophillips.com Subject: KRU 1 H -102L3 (PTD 217-103): Permit to Drill Application Good afternoon Kelsey, The proposed wellbore survey (Standard Proposal Report), Clearance Summary Anticollision Report, and Error Ellipse Report included in the permit to drill application for KRU 1H -102L3 was for KRU 1H -302L4. Please submit as soon as possible the correct surveys and reports for KRU 11-1-1021-3. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at (907) 793-1238 or patricia.bettisCaalaska.eov. TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: ✓ Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: 4 L14jr POOL: N�1.44( K�1�U �1�� Di-/ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit / LATERAL No. �, API No. 50--n-�0 -QQ-M. (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50— from from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Com an Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Nam el in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL-490150 PTD#: 2171030 Company CONOCOPHILLIPS ALASKA INC. _ _ Initial ClasslType Well Name: KUPARUK RI_V UNIT 11-1-_1021-3. Program DEV _ _ Well bore seg❑ _ DEV/PEND GeoArea 890 Unit 11160 _ On/Off Shore On_ Annular Disposal ❑ Administration 17 Nonconven, gas conforms to AS31,05.0300. 1..A),Q.2.A-D) NA ors -7I zt i 1 Permit fee attached NA _ 2 Lease number appropriate.. Yes ADL0025639, Surf Loc & Top Prod; AOL0025636, TD.. _ 3 Unique well. name and number _ Yes KRU 1H-102L3 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 tome _ _ _ _ _ _ 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. IO# 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 1H-102 _ Engineering 19 Surface casing protects all. known USDWs NA Surface casing set in KRU 1H-102 20 CMT vol adequate to circulate. on conductor & surf. csg NA Surface casing will be set and fully cemented in KRU 1H-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; no major risk failures 27 If.diverter required, does it meet regulations NA Appr Date 28 Drilling fluid. program schematic & equip list adequate Yes Max formation pressure is 1696 psig(8.5 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; test to (put psig in comments) Yes MPSP is 1314 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 112S 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 112S measures required.. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is 8.47 ppg EMW; production lateral. 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 used. Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date ors -7I zt i �7 _21-//,7