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217-101
DATA SUBMITTAL COMPLIANCE REPORT 1122/2018 Permit to Drill 2171010 Well Name/No. KUPARUK RIV UNIT 1H -102L2 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23580-61-00 MD 13435 TVD 3924 Completion Date 10/20/2017 Completion Status 1 -OIL REQUIRED INFORMATION Mud Log No I/ Samples No ./ DATA INFORMATION List of Logs Obtained: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data Current Status 1-0I1 UIC No Directional Survey Yes v/ (from Master Well Data/Logs) Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 1698 14740 10/26/2017 Electronic Data Set, Filename: CPAI 1 H-10212 . Scope Resistivity_RM_LWD002.las 7878 13434 10/26/2017 Electronic Data Set, Filename: CPAI 1H-10212 Scope Resistivity_RM_LWD014.las 32 1776 10/26/2017 Electronic Data Set, Filename: CPAI 1H-10212 VISION Resistivity_RM_LWD001.1as 32 13434 10/26/2017 Electronic Data Set, Filename: CPAI 11H-1021-2 Scope Resistivity RM.las 32 13434 10/26/2017 Electronic Data Set, Filename: CPAI 11-1-10212 Scope Resistivity Customer Channel LAS.Ias 10/26/2017 Electronic File: CPAI 11-1-10212 Scope Resistivity. RM LW D002 DLIS.dlis 10/26/2017 Electronic File: CPAI 11-1-10212 Scope Resistivity, RM LWD002 DLIS.html 10/26/2017 Electronic File: CPAI 1H-10212 Scope Resistivity. RM LWD014 DLIS.dlis 10/26/2017 Electronic File: CPAI 11-1-10212 Scope Resistivity RM LWD014 DLIS.html 10/26/2017 Electronic File: CPAI 1H-10212 Scope Resistivity* RM LWD001 DLIS.dlis 10/26/2017 Electronic File: CPAI 1 H-10212 Scope Resistivity RM LWD001 DLIS.html 10/26/2017 Electronic File: CPAI 11-1-1021-2 Scope Resistivity RM DLIS.dlis 10/26/2017 Electronic File: CPAI 1 H-10212 Scope Resistivity RM DLIS.html- A06CC Page 1 01 3 Monday, lunuary 22. 2019 DATA SUBMITTAL COMPLIANCE REPORT 1/22/2018 Permit to Drill 2171010 Well Name/No. KUPARUK RIV UNIT 1H -102L2 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23580-61-00 MD 13435 TVD 3924 Completion Date 10/20/2017 Completion Status 1 -OIL ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data ED C 28750 Digital Data Log C 28750 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED 0 0 Current Status 1 -OIL UIC No 10/26/2017 Electronic File: CPAI_1H- .P 1021-2_ Scope_Resistivity_2in_MD.pdf 10/26/2017 Electronic File: CPAI_1H- F 1021-2_Scope_Resistivity_2in_TVD.pdf - Compass Survey.pdf Electronic File: CPAI_1H- n10/26/2017 Y 102L2_Scope_Resistivity_5in_MD.pdf _ 10/26/2017 Electronic File: CPAI_11-1- F 1021-2 Scope Resistivity Sin TVD pdf Sample Interval Set Start Stop Sent Received Number Comments AOGCC Page 2 of 3 Monday, January 22, 2018 10/26/2017 Electronic File: 1H -102L2 NAD27 EOW Compass Survey.pdf 10/26/2017 Electronic File: 1H-1021-2 NAD83 EOW Compass Survey.pdf 10/26/2017 Electronic File: 1 H-1021-2 [Canvas] NAD27.txt 10/26/2017 Electronic File: 1H-1021-2 [Canvas] NAD83.txt 10/26/2017 Electronic File: 1 H-1021-2 [Macro] NAD27,txt 10/26/2017 Electronic File: 1 H-1021-2 [Macro] NAD83.txt - 10/26/2017 Electronic File: 11-1-1021-2 [Petrel] NAD27.txt • 10/26/2017 Electronic File: 1 H-1021-2 [Petrel] NAD83.txt - 10/26/2017 Electronic File: 11-1-10212 [Surveys] NAD27.txt - 10/26/2017 Electronic File: 1H-1021-2 [Surveys] NAD83.txt 10/26/2017 Electronic File: CPAI 1 H-1021-2 Survey List.csv 2171010 KUPARUK RIV UNIT 11-1-1021-2 LOG HEADERS Sample Interval Set Start Stop Sent Received Number Comments AOGCC Page 2 of 3 Monday, January 22, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/22/2018 Permit to Drill 2171010 well Name/No. KUPARUK RIV UNIT 1H-1021-2 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23580-61-00 MD 13435 TVD 3924 Completion Date 10/20/2017 Completion Status 1 -OIL Current Status 1 -OIL UIC No Completion Report 0 Directional / Inclination Data 9 Mud Logs, Image Files, Digital Data Y / I® Core Chips Y /OJm J Production Test Informatioe NA Mechanical Integrity Test Information Yom/ NA Composite Logs, Image, Data FilesYY Core Photographs Y 6 Geologic Markers/Tops Daily Operations Summary �r / Cuttings Samples Y,& Laboratory Analyses Yf& COMPLIANCE HISTORY Completion Date: 10/20/2017 Release Date: 7/7/2017 Description Date Comments Comments: Compliance Rview y 'C/ v Date: AUGCC Page 3 of 3 Monday, January 22, 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REL;1=1Vtu P,Ouv 2 0 2017 A f -%,r rr WELL .COMPLETION OR RECOMPLETION REPORT ANMUM 1a. Well Status: Oil ❑� • Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20MC 25.110 GINJ❑ WIND❑ WAGE] WDSPL❑ No. of Completions: 1b. Well Class: Development Q - 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: 217-101 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 9/21/2017 15. API Number: 50-029-23580-61-00 4a. Location of Well (Governments] Section): Surface: 40.52' FNL, 764.65' FEL, Sec 33, T12N, R1 OE, UM Top of Productive Interval: 183' FNL, 1659' FEL, Sec 34, T12N, R10E, UM Total Depth: 5182' FNL, 1777' FEL, Sec 22, T12N, R1 OE, UM 8. Date TD Reached: 9/24/2017 16. Well Name and Number: KRU i H-1021-2 - 9. Ref Elevations: KB:92.62 GL: 54 . BF: 17. Field / Pool(s): Kuparuk River Field/West Sak Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25639 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 549577.46 y- 5980662.56 Zone- 4 TPI: x- 553964 y- 5980550 Zone- 4 Total Depth: x- 553797 y- 5986110 Zone- 4 11. Total Depth MD/TVD: 13435/3924 19. DNR Approval Number: LO/NS 80-261 12. SSSV Depth MD1TVD: N/A 20. Thickness of Permafrost MDffVD: 1699/1630 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 1 WA (ft MSL) 1 21. Re-drill/Lateral Top Window MD/TVD: 7845/3863 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 20 78.67 B 40 119 40 119 42 Existing Cement to Surface 10 314 45.5 L-80 40 1771 40 1691 13.5 876 sx 11.0 ppg Lead Cement 211 sx 12.0 opq Tail Cement 76/8 29.7 L-80 37 8593 37 3991 9.875 1155 sx 15.8 ppg, Class G 41/2 11.6 L-80 7840 13204 3862 3933 6.75 Uncemented Slotted Liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Slotted Liner @: 8301 - 13204 MD and 3878 - 3933 TVD -;OMPLE L I !ON nA'T _ folZo /-i'. 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 ❑ No ❑r Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 11/4/2017 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 11115/2017 Hours Tested: 13 hrs, 7 min Production for Test Period Oil -Bbl: 3058 bbls Gas -MCF: 1154 MSCF Water -Bbl: 1 bbl Choke Size: 62%, Gas -Oil Ratio: 416 SCF/STB Flow Tubinq Press. 334 PSI Casinq Press: PSI Calculated 24 -Hour Rate Oil -Bbl: 5469STB/d Gas -MCF: 2273 MSCTId Water -Bbl: Oil Gravity -API (torr): 2 .7 API Form 10307�tevjsa /2f 1J V7 L t�Z�! g� �/C{aNTINUED ON PAGE 2 RBCi"� L" NOVP L 20�� Submit ORIGINIAL gRly_ 28. CORE DATA Conventional Core(s): Yes ❑ No Sidewall Cores: Yes ❑ No Q 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, H needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1699 1630 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7845 3863 information, including reports, per 20 AAC 25.071. Formation @ TPI -West Sak A4 TD 13435 3924 Formation at total depth: West Sak A4 , 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, paleontolooical report. production or well test results, per 20 AAC 7 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G. L. Alvord Contact Name: Kelsey Hallford Authorized Title: Alaska Drilling Mana ery ul�l7� Contact Email: kelsev.hallford(alco.com Authorized (T>2 (� L • Contact Phone: 265-1577 Signature: Date: 1 ZU 'ZP 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 S1m O Q`® - \ Wdmead/Tubing Hnd ITree, aWCoodnaor r13-141" +V°.5,WOkI 1H-102 Producer Schematic Tobing String: 4-12",126#, 480 M Final -As Run K55x34",0.312" l calar Sed Arwmbly@7259.98'MD +1-80'MD Bonamo[Mula Slice ®]289.D8'MD Gas Lift Mandrel, 4.1/2" x 1" w/dummy Vdve26R.5e MDI nM' WD Gas Lift Mamirel, 4-12" x I- w/dummy valve 5515.1' MD /3199' WD 10-W4 45.M, GasMRMmdral, 4-1/8.V" /SOV7057.49'MD/3647'TVD LBO, HyclM3 4-W'SSD wi0s 3.812' DB Nipple Mille 7126.66' MD 1771MD/ 1691' WD Pmmmmnt Down Hole Ciao, 7193 23' MD Tubing Sed Aexmbly IA MP Packer @725223' MD S - 3,75" DP Nipple Profle@730825'MD---3A'W Sand Willow@ 7377' MD/ BOW: 739069 MD 6-3/4"D amd lmeral _ - ,•• Swell Parkers 4-12", IL& IBTM L60, Sloped Liner, 4-S" Blank 1269 L-80 TXP 146J0'hEl/ 37897VD Liner TD®14652.5 NID i z s pipe ..................................................... ... F --------------------------------------____________________- '•___ ' E 'y ____________________________________________________________________________________________% C43/4"Bsem llaser d 9: 45bcked Baker Hook Hanger L3"B"S®d Window®Jfi4TIG) IBOW: 7660.T •••.•• 14686'MD/38"''WD c� Level 3 Junction Synenes Uncr TD @ 14668'tW) r, •. .__ _lX Sbt(ed Cher,l 1.64 IBTM L80;4h"Blmik eiif 269_ xOTXP ------------------------ ±, ••-........................................................................... ZXP Pecker Dd.: W-A4"Seal Window@ 7845'M1 BOW: 7859' MD ...............................•. 6.3K"A4smdlelcral L3@74WAV MD•` 75.27°a. ••`•. 13435' MD 139N' WD L2@7718.396Il1 4-12_Sloned Liar, 116q IBTM L80,4 -k" Blank pipe 12.41-80 T%P Lbmr TD a 13204_MD� ••, L1 "A3" Saud Window @ ]979' W W W 7993MD 6WM nM laced a-lXSk tcd Liner,11.0IBTM 140;,W'Blande pipe 12.64 1.80 TXP MD/ 3988'WD \,••••yam• ............................................ Laced Eery Module �•13129 mTD@1309T `. } ? ---------------------------------------------- .• Tubing Sed AssemHY •____ _______________________________________________________________________________• 3.562" DPNipple Prone @ 8244.36' hD 6-314"A2sand Inad 12969 MD/4022'M3 4-M" Sla°ed Liner, and Blevk PeI ip, L6RIBTM LBD LO ZXP paker@6249.5'b� .........__ Liner TD@12790'MD� = 7-518", 29.74, LW, HY063, Osg ___ _____________a...==____ ••`v °i 8591'MD/3991'TVD .... ............ ..............................................................' uperations Summary (with Timelog L epths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth StartTime End Time Dur(hd Phase Op Code Activity Code Time P -T -X Opeahon (ftKB) End Depth (WS) 8/22/2017 8/23/2017 6.00 MIRU MOVE MOB P Move rig f/ 1H-118 to 1H-102 ('417). 18:00 00:00 Al 2300 spot over conductor. 823/2017 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 ann / 12:00 18:00 Divert. & GE starting head. build spud mud, C/O saver sub. Install bushings / and elevators to dg floor. Swap to high line power at 1730 HRS. 823/2017 823/2017 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. 8/232017 8/23/2017 2.25 MIRU MOVE RURD P Send BHA componels to rig floor while 18:45 21:00 working smart tools in the pipe shed. Work and inspect 5" DP on sills outside. load 5" DP in shed. 8/23/2017 8/23/2017 2.00 MIRU MOVE BHAH P MU surface BHA. RIH with same to 105.0 21:00 23:00 tag at 105' 8/23/2017 8/24/2017 1.00 MIRU MOVE SEQP P Make up top drive and surface test to 105.0 105.0 23:00 00:00 3,500 PSI for 15 min. Shallow hole test GPM 450 GPM @ 424 PSI, F/O = 32%. 8124/2017 8/242017 6.00 SURFAC DRILL DDRL P Drill 13 1/2" surface hole from 105'- 105.0 491.0 00:00 06:00 491' MD 491' TVD. 500 GPM, 800 PSI DPP. 44% F/O 40 RPM, 3K TO with 20K WOB. UP WT = 74K. DWN WT = 79K. 5K TO, off BTM pressure - = 730 PSI. Maz gas units = 35. AST .66 , ART = 2. ADT = 2.66// Total bit hours = 13.3. Total jar hrs = 92.98 Page 1179 Report Printed: 1013012017 operations Summary (with Tiri uepths) 11H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stant Depth Stan Time End Time Dur(hr) Phase Op Code Activity Code Time P -T -X Opa. ion (MKB) End Depth(ttKB) 8/24/2017 8/24/2017 6.00 SURFAC DRILL DDRL P Drill 13112" surface hole from 491- 491.0 1,008.0 06:00 12:00 1,008' MD 1,006TVD. 500 GPM, 1,090 PSI DPP. 44% F/O 60 RPM, 5K TO with 27K WOB. UP WT = 93K. DWN WT = 94K. 1 K TO, off BTM pressure = 875 PSI. Max gas units = 160. AST 1.43 , ART = 3.21. ADT = 4.64/1 Total bit hours = 17.94. Total jar hrs =97.62 8/24/2017 8/24/2017 6.00 SURFAC DRILL DDRL P Drill 13 112" surface hole from1,008' 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. DWN WT=99K. 1K TO, off BTM pressure = 943 PSI. Max gas units = 8658. AST 2.21 , ART = 2.11. ADT = 4.32// Total bit hours = 22.26. Total jar hrs = 101.94 8/24/2017 8/24/2017 3.25 SURFAC DRILL DDRL P Drill 13 1/2" 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/0 60 RPM, 4K TO with 15K WOB. UP WT = 105K. DWN WT = 100K. 2K TO, off BTM pressure = 950 PSI. Max gas units= 827. AST 1.59 , ART= .44. ADT = 2.031/ Total bit hours = 24.29. Total jar hrs = 103.97 8/24/2017 8/2412017 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% F10. 60 RPM, 2K Q UP WT=105K. DWN WT=100K. ROT = 103K 2K TQ total stks pumped 2,872. 812412017 8/24/2017 0.50 SURFAC CASING OWFF P OWFF. Hydrates noted breaking out. 1,777.0 . 1,777.0 22:00 22:30 slowed down significantly. Continue to POOH as planned. 8/24/2017 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 Q 1,128 PSI DPP. RPM =- 60. 2K TQ. UP WT=95K. DWN WT = 92K. ROT= 95K. 8/25/2017 0/25/2017 2.25 SURFAC CASING BKRM P Continue to BKRM OOH from 1,292'- 1,292.0 398.0 00:00 02:15 398' MD. 500 GPM @ 730 PSI DPP. 33% F/O. 60 RPM, 2K TQ. 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, 1K TO, total strokes pumped = 2,200. BD top drive. monitor well for 10 min. static with slight gas breakout. UP WT=68K. DWN WT=71K. 8/25/2017 8125/2017 2.00 SURFAC CASING SHAH P RB stand 1 and break / LD 305.0 0.0 03:00 05:00 Schlumberger directional tools as per DD. 8125/2017 8/25/2017 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 8/25/2017 2.00 SURFAC CASING RURD P RU all 10 3/4" handding equipment for 0.0 0.0 05:45 07:45 10 3/4" casing. slips / Volant / elevators and empty pipeshed of BHA, and load shoe track. 8/25/2017 8/25/2017 0.25 SURFAC CASING SFTY P Pre -job safety meet for running 10 3/4" 0.0 0.0 07:45 08:00 HYD 563. Page 2179 Report Printed: 1 013 012 01 7 Operations Summary (with Timelog L/epths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Star) Time End Time Dur (tv) Phase Op Code Activity Cede Time P -T -X Operation Shirt Depth (flKB) End Depth (fiKB) 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. 4 BPM = 17% F/O. 2 BPM = 11% F/O. 8/25/2017 8/25/2017 5.25 SURFAC CASING PUTB P RIH from 105'- 1,725' MD. monitor 105.0 1,725.0 09:00 14:15 disp via pits 3-6. Fill on the fly every 5 joints. TQ 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 hngrwith 103K UP WT - 114K. Jt # 41 last joint with a centralizer, 43 centralizers and 4 stop rings were run. 8/25/2017 8125/2017 0.50 SURFAC CEMENT SFTY P PJSM with all crews on cement 1,771.0 1,771.0 14:45 15:15 program. RU on cement hose B/D top drive. 8/25/2017 8/25/2017 7.00 SURFAC CEMENT CMNT P Stage pumps up to 8 BPM 290 PSI 1,771.0 1,771.0 15:15 22:15 DPP with 268 PSI FDPP. 23% F/O. While recip from 1,740-1770' MD. Pump maker sweep and observe back at 3,650 STKS. 12,000 Total stks pumped @ 8 BPM. UP WT = 117K DWN WT= 109K. Lineup SLB pump 5 BBLS CWto PT lines & chart 3,500 PSI test. Pump remainder CW for total BBLS of 40 @ 3.1 BPM 75 PSI DPP. 15% F/O. Batch up and pump 77.4 BBLS 10.5 PPG Mud Push. @ 3.5 BPM 115 PSI DPP. 19% F/O. ' Drop BTM plug. Batch and pump 298 BBLS of 11# cement @ 5.6 BPM 180 PSI DPP, 21% F/O. Batch and pump 61.9 BBLS 12# tail cement and pump at 4 BPM 164 PSI DPP with 19% F/O. Drop top ;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% FIO. from 1356 STKS reduce rate to 3 BPM 300 PSI FCP 56% F/O. Bump plug at 1,502 STKS at 2207. increase pressure to 1,082 PSI and hold for 5 min. Bleed off pressure and check floats. GOOD. Cement in place at 2207 hrs. Recip until last 30 bbls pumped. Circulated contaminated cement to surface 67.7 bbls prior to bumping the plug, circulated 9 bbls of good 11. ppg cement to surface. CIP 2207 hrs 8/25/2017. 8125/2017 8/26/2017 1.75 SURFAC CEMENT RURD P RD cement equipment B/D cement 1,771.0 0.0 22:15 00:00 lines. B/O landing joint and lay down. Clean pits and flow box. Drain stack , PU 5" test joint to wash stack. Page 3179 Report Printed: 1 0/3 012 01 7 Operations Summary (with Timelog uepths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth SlanTime End Time our (hr) Phase Op Code Activitycode Time P -T -X Operation (ftKB) End Depm (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 00:00 01:30 Flush stack and set black water pill in place. Rinse out same. Suck out cellar and UD test jt. 8/26/2017. 8/26/2017 4.00 SURFAC CEMENT NUND P ND surface annular, Tee 1 starting 0.0 0.0 01:30 05:30 head. Remove riser and flange. PUII back diverter line. Measured cement in conductor, 2' below starting head at the 4" drain outlets. 8/26/2017 8/26/2017 1.75 SURFAC WHDBOP NUND P Clean hanger neck, install Vetco grey 0.0 0.0 05:30 07:15 MB222 wellhead. Test seal sub to 2000 psi f/ 10 min (good). Test witnessed by Granville Rizek. 8/26/2017 8/26/2017 4.75 SURFAC WHDBOP NUND P NU hi pressure riser and BOPE stack. 0.0 0.0 07:15 12:00 Install choke and kill lines. Install riser / flange install 1502 unionson tbg. IA/OA valves. Install test plug and MU dart I TIW valves, RU test pump. 8/26/2017 8/26/2017 1.25 SURFAC WHDBOP NUND P DNL valve IA & OA, Plug seocndary 0.0 0.0 12:00 13:15 IA, insstall safety slings on choke & kill, air up boots. 8/26/2017 8/26/2017 8.75 SURFAC WHDBOP BOPE P Flush and fill stack and choke. TEst 0.0 0.0 13:15 22:00 BOPE all test to 250 low 13,500 PSI high for 5 min each with exception of man operated and super chokes to 25/2000 \PSI for 5 min. Tested with 4 1/2" - 5 "- 7 5/8" . Tested LPR's, H2S, 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 block height. 8/27/2017 8/27/2017 1.00 SURFAC CEMENT SVRG P Service topdrive. 0.0 01:00 02:00 827/2017 8/27/2017 2.50 SURFAC CEMENT BHAH P MU BHA #2. as per DD. RIH to 829' 0.0 829.0 02:00 04:30 1 MD. Monitor displacement via pit1. 8/27/2017 8/27/2017 0.75 SURFAC CEMENT PULD P RIH to 1,583' MD. Monitor DISP via 829.0 1,583.0 04:30 05:15 p8 1. Change out joint number 20 and . kick out as it is bent. 8/27/2017 8/27/2017 0.50 SURFAC CEMENT DHEQ P Circulate at 500 GPM / 915 PSI DPP. 1,583.0 1,583.0 05:15 05:45 32% F10. Shallow hole test MWD (GOOD) total stks pumped = 1,400. MW-in=9.5, MW -out =9.6.. UP WT =104K DWN WT=99K. ROT - 101 k. 8/27/2017 8127/2017 1.25 SURFAC CEMENT PRTS P RU lest OA valve and casing to 3,000 1,583.0 1,583.0 05:45 07:00 PSI charted (GOOD) RD test equip. 26 stks t / pressure up. 2.7 BBLS . bleed back. Page 4179 Report Printed: 1 013 0/2 01 7 AL Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stad Time End Time D (hr) Phase Op Code Activity Code Time P-T-X Operation (M13) End Depth (flKa) 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 F/C@ 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 8/27/2017 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 TO.. Total STKS pumped = 5,824. 9.6 MW IN/OUT. 10 min gel = 14. 8/27/2017 8/27/2017 1.00 SURFAC CEMENT FIT P R/U flood lines for FIT/LOT to 12.5 1,797.0 1,797.0 11:00 12:00 PPG. 40 STKS pumped. 0 BBLS bleed back. STBY for orders. 8/27/2017 8/2712017 1.00 SURFAC CEMENT WAIT T Wait on orders from town for plan 1,797.0 1,797.6- 12:00 13:00 forward. 8/27/2017 8/27/2017 1.00 SURFAC CEMENT FIT T RU for FIT. Obtained LOT 12.6 1,797.0 1,797.0 13:00 14:00 PPGEMW w/ 9.6 ppg mud weight, 262 psi and 1691.1 TVD. 24 STKS were pumped (2.4 bbls) 0 BBLS returned. RD. 8/27/2017 8/27/2017 3.75 SURFAC CEMENT COND T Begin making up LCM pill as per 1,797.0 1,779.0 14:00 17:45 program. Mix up number2 FINE 10 PBL, #2 MED 20# 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 rale displacing with 34 bbis 9# LSND. 8/27/2017 8/27/2017 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 8/28/2017 4.75 SURFAC CEMENT SQEZ T Circulate 8 BBLS at 2 BPM to ensure 1,397.0 1,397.0 19:15 00:00 no LCM left in DP. RU circ equipment with ANN closed to SQZ LCM @.6 BPM. 264 PSI, Shut in and monitor/bleed off. Repeal 1O 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 6179 ReportPrinted: 10/3012017 Operations Summary (with Tlmelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Suit Depth Start Time Foul Time Our (hr) Phase Op cede Activity Cade Time P -T -X Operation (MB) EM Depth (ftKB) 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 8/2812017 0.50 SURFAC CEMENT SVRG P Service rig. 1,397.0 1,397.0 00:30 01:00 8/28/2017 8/28/2017 1.00 SURFAC CEMENT WASH T Wash down to 1,770' MD. @ 5 BPM 1,397.0 1,770.0 01:00 02:00 140 PSI, 18% F/O UP WT = 110K, DWN WT = 102K. 8/28/2017 8/28/2017 0.50 SURFAC CEMENT CIRC T Circulate bottoms up while rotating / 1,770.0 . 1,770.0 02:00 02:30 circulating from 1,276'- 1,680' MD. With 500 GPM, 545 PSI, 31 % F/O. 60 RPM, 3K TQ. 9.0 MW in/out. total STKS pumped = 2,260. UP WT = 110K. 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 pie. Discussed pressures, LCM squeezed away and timing. 8/28/2017 8/28/2017 2.50 INTRM1 DRILL DDRL P Make connection and downlink to 1,770.0 1,961.0 03:30 06:00 EXCEED. DBI/ 9 718" 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 = 11 OK 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 INTRM1 DRILL DDRL P Dtill97/8"hole from 1,961"MD- 1,961.0 2,594.0 06:00 12:00 2,594' MD 2,253' TVD. 550 GPM @ 735 PSI DPP. 34% F/O, 120 RPM 4K TO, 4.5K WOB. ECD's 9.86 PPG. Off bottom 730 PSI DPP. UP WT = 119K DWN WT= 105K. ROT= 112K. 3.5K TO. ADT- 4.6, Bit hrs 6.27, Jar hrs 56.82. MAx gas 220 units. SPR's 2,245' MD 2,050 TVD MW = 9.1 PPG @ 0900 hrs - MP1) 30 SPM 120 PSI 40 SPM 140 PSI MP2) 30 SPM 120 PSI 40 SPM 140 PSI 8/28/2017 8/28/2017 6.00 INTRMl 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% F/O, 100 RPM 6- 9K TO, 1 OK WOB. ECD's 9.86 PPG. - Off bottom 885 PSI DPP. UP WT = 131K DWN WT=91 K. ROT =11 OK. 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 -6/79 Report Printed: 10130/2017 Operations Summary (with Timeiog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sled Time End Time Dur (hr) Phase Op Code Activity Code Tune P-T-X operation 9tarl Depth (tlKB) End Depth (fiKB) 8/28/2017 8/29/2017 6.00 INTRMI DRILL DDRL P Dtill 9 7/8" 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 OWN WT=96K. ROT =IIOK. 6K TO. Max gas 96 units. ADT 8.92, Bit hrs 15. 19, Jar hrs 65.74 SPR's 3,571' MD 2,620' TVD MW = 9.0 PPG @ 2200 hrs MP1) 30 SPM 160 PSI 40 SPM 180 PSI MP2) 30 SPM 150 PSI 40 SPM 180 PSI 8/29/2017 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' ND. 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 hrs, Bit 20.12 hrs, Jars 70.67 hrs. Pump hi- vis sweep with 4 ppb Nut Plug Medium every 4 x stands. • SPRs @ 4045' MD 2757' TVD, MW=9.0 ppg, 02:30 hours MP#1: 30 spm=160 psi, 40 spm=200 psi. MP #2: 30 spm=160 psi, 40 spm=200 psi. 829/2017 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- blm, 1405 psi off-btm, 35% F/O, ECD 10.22 ppg. Rotate at 150 rpm with 101k 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-Torg, total concentration in mud at 1.5% Lo-Torq. Pump hi-vis sweep with 4 ppb Nut Plug Medium every 4-5 stands. SPRs Q 4610' MD 2921' TVD, MW=9.05 ppg, 07:58 hours MP#1: 30 spm=180 psi, 40 spm=220 psi. MP #2: 30 spm=180 psi, 40 spm=220 psi. Page 7179 Report Printed: 10130/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log scan Depth clan Time End roe Dur (hr) Phese Op cede A yity code Time P -T -x Ope2fon (flKe) End Depth mKa) 8/29/2017 8/29/2017 6.00 INTRM1 DRILL DDRL P Directionally drill 9-7/8" intermediate 5,010.0 5,384.0 12:00 18:00 hole from 5010' to 5384' MD, 3160' TVD. Pump at 603 gpm, 1200 psi on-btm, 1200 psi off-btm, 34% F/O, ECD 10.07 ppg. Rotate at 100 rpm with 9- 11 k Tq on-btm, 7.5k Tq off-btm. 6k WOB. PUW 139k, SOW 99k, ROT 117k. Max gas of 132 units. ADT 4.5 hrs, Bit 28.93 hrs, Jars 79.48 hrs. Pump hi -vis sweep with 4 ppb Nut Plug Medium every 5 x stands. SPRs @ 5084' MD 3065' TVD, MW=9.05 ppg, 12:40 hours MP#1: 30 spm=190 psi, 40 spm=230 psi. MP #2: 30 spm=190 psi, 40 spm=230 psi. 8/29/2017 8/30/2017 6.00 INTRM1 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 it. 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 INTRM1 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: 10/30/2017 Operations Summary (with Timelog Depths) „ IH -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 Operation (ftKB) End Depth (fd(B) 8/30/2017 8/30/2017 6.00 INTRMI 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, 101k 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 -Torg to try and help with continued high stick -slip. Drill hard spot @ 6483'. Pump hi -vis sweep at 6600' and observe -10% increase in cuttings, it came back -800 strokes early. 8/30/2017 8/30/2017 6.00 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 6,837.0 7,176.0 12:00 18:00 hole from 6837' to 7176' MD, 3682' TVD. Pump at 510 gpm, 1055 psi on- btm, 1055 psi off-btm, 31 % NO, ECD 10.09 ppg. Rotate at 100 rpm with 10- 15k Tq on-btm, 9.5k Tq off-btm. 18k - WOB. PUW 164k, SOW 99k, ROT 126k. Max gas of 737 units. ADT 3.73 ITS, 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 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 7,176.0 7,421.0 18:00 00:00 hole from 7176'to 7421' MD, 3750' TVD. Pump at 697 gpm, 1800 psi on- btm, 1800 psi off-btm, 35% F/O, ECD 10.19 ppg. Rotate at 120 rpm with 13k Tq on-btm, 9.5k Tq off-btm. 1 O WOB. PUW 164k, SOW 99k, ROT 126k. Max gas of 161 units. ADT 5.26 hrs, Bit 52.08 hrs, Jars 102.63 ITS. 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 Wis. Page 9179 Report Printed: 1 013 012 01 7 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our ft) Phase Op Code Activity Code Time P -T -X Opemimn (ftKB) End Depth(hKB) 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. t Ok WOB. PUW 164k, SOW 97k, ROT 128k. Max gas of 480 units. ADT 3.97 hrs. Bit 56.05 hrs. Jars 106.6 hrs. Drill through concretions at 7427'- 74361, 74671- 7469', 75571- 75611, 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 - trim, 1985 psi off-btm, 35% F/O, ECD 10.62 ppg. Rotate at 150 rpm with 14k Tq on-btm, 11 k Tq off-btm. 7k WOB. PUW 171 k, SOW 99k, ROT 129k. Max gas of 620 units. ADT 4.84 hrs, Bit 60.89 hrs, Jars 111.44 his. Drill through concretions at 7673'- 7677', 7771'- 7773', 7809'- 7813', and 7963'- 7967', 8/31/2017 8/31/2017 6.75 INTRM1 DRILL DDRL P Directionally drill 9-7/8" intermediate 8,142.0 8,598.0 12:00 18:45 hole from 8142' to TD of 8598' MD, 3991' TVD. Pump at 697 gpm, 2015 psi on-btm, 2010 psi off-btm, 36% F/O, ECD 10.65 ppg. Rotate at 130 rpm with 12-16k Tq on-blm, 12.4k Tq off-btm. 1 O WOB. PUW 173k, SOW 92k, ROT 131k. 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) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time End Tmre our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (eKB) 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 Xceed to neutral. PUW 173k, SOW 92k, ROT 131k w/ 12.4k Tq. Backream out stand to 8500' MD with 697 gpm, 2030 psi, , 35% F/O, 120 rpm, 11-16k Tq, ECD 10.62 ppg SPRs @ 8598' MO 3991' TVD, MW=9.25 ppg, 19:05 hours MP#1: 30 spm=310 psi, 40 spm=360 psi. MP #2: 30 spm=310 psi, 40 spm=360 psi. 8/31/2017 8/31/2017 0.50 INTRMI CASING OWFF P Monitor well for flow for 30 minutes- 8,500.0 8,500.0 19:45 20:15 observe fluid level drop -1 fl in riser over 30 minutes, calculated to -0.5 bbllhr 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/O, ECD 10.45 ppg. Rotate at 120 rpm with 11-16k Tq, ROT 123k. Monitor displacement via pits #1-5. Lay down 5" DP via mousehole. Calculated displacement = 8.4 bbls. Actual displacement = 23 bbls. 9/1/2017 9/1/2017 6.00 INTRMI CASING BKRM P Backream OOH from 7362'-4849' 7,362.0 4,849.0 00:00 06:00 MD with 700 gpm, ICP 1910 psi, FCP 1660 psi, 36% F/O, Initial ECD 10.45 ppg, Final ECD 10.48 ppg. Rotate at 120 rpm with 7k Tq. PUW 135k, SOW 92k. Monitor displacement via pits #1- 5. Increase pulling speed up to 1000 ft/hr. MW 9.3 ppg. SIMOPS: Floorhands lay out 5" DP stands using mousehole while backreaming out. At 1000 fl/hr pulling speed, floorhands finish laying out stand by the time driller reaches top of next stand. 9/1/2017 9/1/2017 6.00 INTRM1 CASING BKRM P Backream OOH from 4849'- 3010' 4,849.0 3,010.0 06:00 12:00 MD with 698 gpm, ICP 1660 psi, FCP 1470 psi, 35% F/O, Initial ECD 10.48 ppg, Final ECD 10.30 ppg. Rotate at 120 rpm with 5k Tq. Pull at -700 ft/hr from 4849'to 3120'then drop pulling speed to 200 ft/hr as ECD increased, up to a 10.70 ppg highest seen -3240' MD. MW 9.3 ppg. SIMOPS: Floorhands lay out 5" DP stands using mousehole while backreaming out. Page 11179 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Slab Time ad Time Dur (hr) Phase Op Cade Activity Code Time P-T-X Operation (nKa) End Depth (rtKa) 9/1/2017 9/1/2017 5.50 INTRMI CASING BKRM P Backream OOHfrom3010'-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 a1-2350' 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 9/1/2017 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 INTRM1 CASING BKRM P Backream OOH from 1771'- 1397' 1,771.0 1,397.0 17:45 19:00 MD with 697 gpm, 1215 psi, 34% FIC, 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 9/1/2017 1.00 INTRM1 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 INTRM1 CASING OWFF P Monitor welt for flow at top of BHA- 829.0 829.0 20:00 20:15 well static. 9/1/2017 9/1/2017 2.50 INTRM1 CASING BHAH P Pull OOH on elevators from 829'to 829.0 0.0 20:15 22:45 surface, laying out BHA #2 per DD. Observe large amount of wear on upper NM integral blade stabilizer with unusual wear pattern, significant wear on 8-3/8" sleeve stabilizer with only -2" of blades remaining and stabilizer loose from original position, and minimal wear on the two NM stabs on the Xceed. The bit had multiple broken teeth and chipped teeth but was in- gauge. 9-7/8" Smith MSi516 PDC Bit grade: 2 -3-BT-A-X-0-CT-TD Upper 9-3/4" NM Integral Blade Stabilizer: 1-5/16" undergauge 8-3/8" NM Straight-blade sleeve stabilizer: minimal amount of stabilizer remaining Upper Xceed 9-3/4" NM Integral Blade Stabilizer: In-gauge Lower Xceed 9-3/4" NM Integeral Blade Stabilizer: 1/16" undergauge Calculated displacement for trip = 90.9 bbls Actual displacement for trip = 126.0 bbls 9/1/2017 9/1/2017 0.50 INTRM1 CASING BHAH P Clean and clear floor of BHA 0.0 0.0 22:45 23:15 equipment. Page 12179 Report Printed: 10/3012017 Operations Summary (with Timelog Depths) %1 - IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth start Time End Time our (no Phase Op Cade Activity Code Time P -T -X Operation (RKB) End Depth(ftK6) 9/1/2017 9/1/2017 0.50 INTRMI CASING W W WH P Make up 2 x 5" DP singles, X0, and 0.0 0.0 23:15 23:45 stack washer. Jet stack and wellhead with 819 gpm. 9/1/2017 9/2/2017 0.25 INTRMI CASING RURD P Lay out stack washer and make up 0.0 0.0 23:45 00:00 wearbushing retrieval tool. 9/2/2017 9/2/2017 0.50 INTRMI CASING RURD P Pull Velco 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 jts). 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 10' f/ each end). Jt # 2 centralzied the same as above, and it 3 with the Davis Lynch double valve float collar (no centralizers on jt #3). MU joint #4 (pin end of #4 and all below are baker locked).Check floats, OK. Continue to run 7-5/8" 29.7# L-80 Hydril 563 dopeless casing per tally to jt # 41. PU wt 86k, SO wt 88k. Fill pipe on the fly and top off every 10 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 INTRM1 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 INTRM1 CASING PUTB P Contiinue to run in w17-5/8" 29.7 ppf L 1,771.0 3,780.0 07:00 10:45 -80 Hyd 563 dopeless casing f/ 1771' to 3780' installing 7-5/8" x 9-3/8" . Volant centralizers floating on its up to it 105. 90 joints in the hole at this depth. Average MU torque 14k ft be. Fill pipe on the fly and top off every 10 jts. 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'. 91212017 9/2/2017 0.50 INTRM1 CASING PUTB P Contiinue to run in w/ 7-5/8" 29.7 ppf L 3,780.0 4,024.0 11:30 12:00 -80 Hyd 563 dopeless casing f/ 3780' to 4024' installing 7-5/8" x 9-3/8" Volant centralizers floating on jts up to jt 105. 96 joints in the hole at this depth. Average MU torque 14k ft lbs. PU wt 120k, SO wt 96k. Fill pipe on the fly and top off every 10 jts. Install centralizers per tally.. Calculated mud losses -17-19 bbls. Page 13/79 Report Printed: 1013012017 Mitt 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 (flKB) End Depth(MKB) 9/2/2017 9/2/2017 2.75 INTRMI CASING PUTB P Conliinue to run in w/ 7-518" 29.7 ppf L 4,024.0 5,429.0 12:00 14:45 -80 Hyd 563 dopeless casing V 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 ft Ibs. Fill pipe on the fly and top off every 10 jts. Install centralizers per tally.. 9/2/2017 9/2/2017 1.25 INTRM1 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 wl 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 9/212017 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 INTRMI CASING CIRC P Circulate/ reciprocate from 6873'to 6,873.0 6,908.0 19:00 20:15 5908', 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 PUTB P RIH w/ 7-5/8" 29.7# L-80 Hyd 563 6,908.0 8,550.0 20:15 23:45 dopepless casing per tally from 6908' to 8550' MD. MUT 14k Calculated displacement = 90.72 bbls Actual displacement = 63.50 Wis . 9/2/2017 9/3/2017 0.25 INTRMI CASING HOSO P _ Make up Vetco 7-5/8" casing hanger 8,550.0 8,550.0 23:45 00:00 using single -stack tongs. Pick up and make up landing joint to hanger. 9/3/2017 9/3/2017 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 1 8,591.0 8,591.0 00:30 01:30 condition mud with reciprocation, 470 psi, 24% F/O, PUW 184k, SOW 82k. MW in 9.3ppg Vis 50, MW out 9.35ppg Vis 63. 9/3/2017 9/3/2017 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: 1 013 012 01 7 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten Time Eras Time Dur thr) Phase Op Cade Activity Code Time P -T -x Operation start Depth (ftKB) End Depth mKB) 9/3/2017 9/3/2017 2.00 INTRM1 CEMENT CMNT P Pump cement job as follows: SLB 8,591.0 8,591.0 03:00 05:00 pump 5 bbls freshwater and pressure test lines to 400 / 3500 psi - good test. Pump 50 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 hrs. SLB pump total of 239.3 bbis 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 slop 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 951k. 9/3/2017 9/3/2017 1.25 INTRMI CEMENT CMNT P Swap to dg mud pump #1 and 8,591.0 8,591.0 05:00 06:15 displace cement with 9.3ppg LSND at 8 bpm for 3250 strokes, ICP 242 psi, FCP 1587 psi. Drop rate to 3 bpm and continue displacing cement, ICP 1120 psi. Bump plug at 3797 strokes, FCP 1423 psi. Pressure up to 2000 psi and hold for 5 minutes. Bleed off and .. check floats - floats holding. Cement in place @ 06:10 hrs. Calculated TOC @ 4250' MD. Note: Total downhole losses throughout cement job = 11 bbis 9/312017 913/2017 0.75 INTRMI CEMENT PRTS P Pressure up to 3500 psi and hold for 8,591.0 0.0 06:15 07:00 30 minutes to test 7-5/8" casing - good test. Pump 5.6 bbis, returned 5.6 bbis. 9/3/2017 9/3/2017 1.50 INTRMI CEMENT RURD P Rig down and blow down cement line 0.0 0.0 07:00 08:30 and test equipment. Lay down Volant tool and casing handling equipment. 9/3/2017 9/3/2017 1.50 INTRMI CEMENT W WSP P Make up packoff running tool and 0.0 0.0 08:30 10:00 install packoff. Run in lock down screws and lay down running assembly. Inject packoff with packing and pressure test to 5000 psi / 10 min, witnessed by CPAI - good test. SIMOPS: Start rigging in E -line. 9/32017 9/3/2017 2.00 INTRMI EVALWB ELOG P Rig up SLB E -line. Pick up Welltec 0.0 0.0 10:00 12:00 tractor and LIST logging tools and Function test at surface. 9/3/2017 9/3/2017 2.50 INTRMI EVALWB RIH on E -line from surface to 3000' 0.0 0.0 12:00 14:30 MD and then utilize tractor to run in JELOG IP from 3000'to 7500', average of 57 fUmin with tractor. Page 15179 ReportPrinted: 10/3012017 „- Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth start Time I End Time Our (hr) Phase Op Code Activity C.de Time P -T -X Operation (BKB) End Depth (MB) 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 INTRMI EVALWB ELOG P Rig down E -line equipment. 0.0 0.0 22:30 23:15 9/3/2017 9/4/2017 0.75 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 ROPE. 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 16/79 Report Printed: 1 013 012 01 7 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) .Phase Op Code Activity Code Time P-TA Operation Star) Depth (ftKB) End Depth(Po®) 9/4/2017 9/4/2017 5.50 INTRM1 WHDBOP BOPE P Test BOPE with 4" and 4-1/2" test joint 0.0 0.0 02:30 08:00 to 250/3500 psi 5/6 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 anine Kill 9) Lower 3-1/2" x 6" pipe rams Install 4" test joint 10) Annular, Manual choke, Manual Kill, and HCR 11) Lower 3-1/2" x 6" pipe rams Pull test joint 12) Blinds, Manual Kill, Choke valves #6 and 7 13) Choke valves #3 and 4. Perform koomey drawdown test: System Pressure = 3,000 psi PSI after closure = 1,900 psi 200 psi Attained with 2 x electric pumps = 8 seconds Full Pressure attained with 2 x electric and 2 x air pumps = 47 seconds N2 = 6 each @ 2,033 psi Tested all gas and H2S sensors, PVT and flow alarms both audio and visual, and functioned primary and remote BOP controls - all good. Upper 7-5/8" casing rams not tested. Note: 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 INTRM1 WHDBOP RURD P Blow down and dg down lest 0.0 0.0 08:00 09:00 1 I equipment. Pull test plug and install Vetco short wearbushing with 9" ID. Page 17179 Report Printed: 10/3012017 t: , Operations Summary (with Timeiog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Time End Time our (hr) phase Op Code Activity Code Tune P -T -x Operseon stun Depth (H(B) End Depth (ftKB) 9/4!2017 9/412017 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 INTRM1 CEMENT BHAH P Make up 6-314" production "A2" drilling 0.0 118.0 10:15 11:30 BHA to 11 8'MD per DD, monitoring displacement via trip tank. SIMOPS: Pressure up on OA with mud pump #1 to 700 psi at 7 spm - observe erratic pressure buildup. Swap to mud pump #2 and continue pressuring up to 960 psi at 7 spm with no indication of leak off. Kill pump and shut in. Observe pressure fall to 300 psi after 40 minutes. Discuss path forward with town. 9/4/2017 9/4/2017 1.00 INTRMI CEMENT LOT P Pressure up on OA with mud pump #2 118.0 118.0 11:30 12:30 to 1460 psi at 7 spm and observe pressure break over and drop to -800 psi. Bullhead total of 80 bbls freshwater, increasing rate to 3 bpm and observe injection pressure stabilize - 470 psi. 9/4/2017 9/4/2017 1.50 INTRMI CEMENT FRZP P Rig up Little Red and pressure test 118.0 118.0 12:30 14:00 lines to 2000 psi. Little Red freeze protect OA with 82 bbls IsoTherm at -1.5 bpm, ICP 335 psi, FCP 1050 psi. Rig down Little Red. After shut in for 10 minutes, OA pressure = 550 psi. SIMOPS: Service topdrive and blocks. 9/4/2017 9/4/2017 0.75 INTRMI CEMENT BHAH P Continue making up 6-3/4" drilling 118.0 302.0 14:00 14:45 BHA from 118' to 302' MD per DD, monitoring displacement via trip tank. . 9/4/2017 9/4/2017 2.50 INTRMI CEMENT PULD P Single in hole on 4" DP singles from 302.0 2,196.0 14:45 17:15 302'- 2196' MD, monitoring displacement via trip tank. 9/4/2017 9/4/2017 0.50 INTRMI CEMENT DHEQ P Fill pipe and shallow hole test MWD 2,196.0 2,196.0 17:15 17:45 tools at 240 gpm, 1100 psi, 19% F/O - good test. 9/4/2017 9/4/2017 3.50 IR-TR—Ml CEMENT PULD P Single in hole on 4" DP singles from 2,196.0 5,797.0 17:45 21:15 2196'- 5797' MD, monitoring displacement via trip tank and filling pipe every 20 x stands. Page 18179 ReportPrinted: 1 013 012 01 7 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time Dur (hr) Phase Op Cade Activity Code Time P -T -X Operation Stan Depth (ftKB) End Depth (MB) 9/4/2017 9/5/2017 2.75 INTRM1 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' MO, 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 INTRM1 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, 1-4k WOB. 9/5/2017 9/5/2017 2.75 INTRMI CEMENT DRLG P Drill out plugs, float collar, shoetrack 8,501.0 8,598.0 01:45 04:30 cement, shoe, and rathole from 8501'- 8598! MD with 222 gpm, 1760 psi, 24% F/O, 40-60 rpm, 8-10k Tq, 2-14k WOB. 9/5/2017 9/5/2017 0.25 INTRMI CEMENT DDRL P Drill 20' of new formation from 8598' to 8,598.0 8,618.0 04:30 04:45 8618' MD with 270 gpm, 2280 psi, 26% F/O, 60 rpm with 9k Tq on btm, 6k Tq off btm. 2k WOB. PUW 145k, SOW 62k, ROT 94k. MW 9.3ppg. ADT 0.33 hrs, Bit 0.33 hrs, Jar 0.33 hrs: 9/5/2017 9/512017 0.75 INTRMI CEMENT CIRC P Pull up inside shoe to 8588' MD and 8,618.0 8,586.0 04:45 05:30 circulate I condition mud with 240 gpm, 1916 psi, 22% F/O, 60 rpm, 8.5k Tq until even inlout 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: 10130120171 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Start Tme End Time our (hr) Phase Op COGe Activity Cede Time P -TX Operation (ftKB) Ertl Depth (MxB) 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 6-3/4" production 8,636.0 9,011.0 07:45 12:00 "A2" lateral from 8636' to 9011' MD, 3990' TVD. Pump at 271 gpm, 1906 psi, 23% F/0, ECD 10.95 ppg, MW 9.2 ppg. Rotate at 140 rpm with 8k Tq on-btm, 6k Tq off-btm. 3k WOB. PUW 140k, SOW 70k, ROT 96k. ADT 3.61 hrs, Bit 4.14 hrs. 4.14 hrs. Observe shakers start blinding off throughout section. Quadco troubleshoot gaswatch system. 9/5/2017 9/5/2017 6.00 PRODt DRILL DDRL P Directionally drill 6-3/4" production 9,011.0 9,554.0 12:00 18:00 'A2" lateral from 9011' to 9554' MD, 3986' TVD. Pump at 280 gpm, 1950 psi, 23% 1`10, ECD 11.18 ppg, MW 9.2 ppg. Rotate at 150 rpm with 8k Tq ori 8k Tq off-btm. 5k WOB. PUW 1431k, SOW 65k, ROT 95k. Max gas of 277 units. ADT 4.56 bra, Bit 8.7 hrs, Jar 8.7 hrs. Continue controlling ROP at -100 f thr 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: 1 013 012 01 7 Operations Summary (with Timelog Depths) 111-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Start Time EM Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) 9/5/2017 9/6/2017 6.00 PRODt DRILL DDRL P Directionally drill 6-3/4" production 9,554.0 .9,960.0 18:00 00:00 "A2" lateral from 9,554' to 9960' MD, 3999' TVD. Pump at 275 gpm, 2000 psi on-btm, 1990 psi off-btm, 22% F/O, ECD 11.43 ppg. MW 9.2 ppg. Rotate at 170 rpm with 8.5k Tq on- btm, 8k Tq off-btm. 5k WOB. PUW 148k. SOW - Lose ability to obtain slackoff weight at 9945' MD. ROT 92k. Max gas of 177 units. ADT 4.34 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-Torq. OA pressure at midnight = 460 psi Downhole losses over past 24 hours = 31 bbls. 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-btm, 8k Tq off-btm. 3-6k WOB. PUW 170k, unable to slack off, ROT 99k. Max gas of 577 units. ADT 4.5 hrs, Bit 22.22 hrs, Jar 22.22 hrs. Control drilled as needed for directional control. No further "greasing" observed at shakers. Changed 4 x 170 mesh screens over past 12 hours due to wear. Faulted out of zone at 11,047' and observed 27' DTN throw. Total of 221' out of zone. Page 21/79 Report Printed: 1 013 012 01 7 I Operations Summary (with Timelog Depths) ;a 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log SW Depth stad Tame End Time Der(hr) Phase Op Code Activity Code Time P -T -X Operation (tlKa) End Depth(VKe) 9/6/2017 9/612017 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' MO 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, 9k Tgon- btm, 9k Tq off-blm. 3k WOB. PUW 186k, unable to slack off, ROT 11 Ok. Max gas of 226 units. ADT 4.01 hrs, Bit 30.18 hrs, Jars 30.18 his. Perform 290 bbl dump/dilute at 12,170' MD. OA pressure at midnight = 400 psi Downhole losses for past 24 hours = 8 bbls 9/7/2017 9!7/2017 6.00 PROD1 DRILL DDRL P Directionally drill 6-3/4" production 12,260.0 12,814.0 00:00 06:00 "A2" lateral from 12260' to 12814' MD, 4020' TVD. Pump at 275 gpm, 2646 psi, 22% f/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 11 Ok. 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 PRODt DRILL DDRL P Directionally drill 6-3/4" production 12,814.0 12,960.0 06:00 07:00 "A2" lateral from 12814'to TD 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-blm, 9k Tq off-btm. 31k WOB. PUW 190k, Unable to slackoff, ROT 110k. ADT 0.88 hrs, Bit 35.55 hrs, Jars 35.55 hrs. Did not see at 12,845' MD. Page 22179 Report Printed: 10/3012017 Operations Summary (with Timelog Depths) A9!7� 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depm Start Tari! End come Dur (hr) Phase Op Cade AcAwty Code Time P-T-x Operation (flKB) End Depth (flKB) 917/2017 9/7/2017 1.75 PROD1 CASING CIRC P Circulate bottoms up at TD with 275 12,960.0 12,960.0 07:00 08:45 gpm, 2686 psi, 170 rpm, 9k Tq. Obtain final surveys, parameters, and SPR's. PUW 190k, Unable to slack off, ROT 110k. SPRs @ 12960' MD 4022' TVD, MW=9.20 ppg, 07:00 hours MP#1: 20 spm=810 psi, 30 spm=1020 psi. MP #2: 20 spm=810 psi, 30 spm=980 psi. 9/7/2017 9/7/2017 0.50 PROD1 CASING OWFF P Monitor well for flow -well static. 12,960.0 12,960.0 08:45 09:15 Service top drive and traveling equipment. 9/7/2017 9/7/2017 2.75 PROD1 CASING BKRM P Backream out of hole from 12960'to 12,960.0 11,987.0 09:15 12:00 11987' MD with 275 gpm, ICP 2700 psi, FCP 2500 psi, ECD 11.63 ppg, 170 rpm, 6k Tq, monitoring displacement via pits 1-5. Note: Regained slackoff weight @ 11,986' MD, PUW 170k, SOW 82k 9/7/2017 9/7/2017 6.00 PROD1 CASING BKRM P Backream out of hole from 11987'to 11,987.0 10,055.0 12:00 18:00 10055' MD with 277 gpm, 1995 psi, 20% F/O, ECD 10.98 ppg, 170 rpm, 4- 5k Tq, PUW 145k, SOW 83k, ROT 100k, monitoring displacement via pits 1-5. Ream stand #109 twice through 5.64' DLS at 10543' MD and re- survey. 9/7/2017 9/7/2017 4.00 PROD1 CASING BKRM P Backream out of hole from 10055'to 10,055.0 8,546.0 18:00 22:00 8546' MD with 277 gpm, 1845 psi, 21% F/O, ECD 10.8 ppg, 170 rpm, 4- 51 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!712017 0.25 PROD1 CASING OWFF P Monitor well for flow -well static. 8,546.0 8,546.0 23:00 23:15 917/2017 97712017 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 PROW CASING RURD P Blow down lopddve 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 PRODt CASING TRIP P POOH on elevators f/ 8540' MD to 8,546.0 123.0 00:00 04:00 123' MD standing back 4" DP and 4" HWDP in derrick. Actual displacement= 60.4 bbls, Calculated displacement= 55.2 bbls. 5.2 bbls lost to formation. Page 23179 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start DWh Starr Time End Time Our(ho Phase Op Cotla Activity CmEe Time P -T -x Operation (fKB) I End Oeplh(aKB) 9/8/2017 9/8/2017 1.50 PROD! CASING BHAH P UD 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 ATB CSING PU 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 x joints 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- 112" by 6-1/8" Tesco hydroform centralizers, and 1 x 4-1/2" by 6-1/2" Volant hydroform centralizer. No remakes. Rejected 1 xjoint (#58 = 41.77') prior to torquing up as centralizer would not easily go onto pipe - replaced with #101 = 42.15'. 9/8/2017 9/8/2017 1.00 COMPZ1 CASING OTHR P Make up Flex -Lock Liner hanger and 4,483.0 4,553.0 12:30 13:30 HRD-E liner top packer w/ pusher tool per Baker to 4553' MD. Fill tieback sleeve with Xan-Plex D. PUW 79k, SOW 72k. 9/8/2017 9/8/2017 0.50 COMPZ1 CASING CIRC P RIH with 1 x stand 4" DP to 4647' MD. 4,553.0 4,647.0 13:30 14:00 Circulate -12 bbls through liner assembly and confirm no obstructions. Blow down lop 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 demck to 12790' MD, . monitoring displacement via trip tank. PUW 174k, SOW 97k. Calculated displacement = 82.3 bbls Actual displacement = 87.8 bbls (pipe self -filling, not full) Note: 12 x stands 4" DP slick, 43 x stands 4" DP with super sliders, 30 x stands 4" HWDP with super sliders, and 3 x stands 4" HWDP slick. 9/8/2017 9/8/2017 0.50 COMPZ1 CASING CIRC P Circulate 1 x drill pipe volume per 12,790.0 12,790.0 19:15 19:45 Baker, staging up to 3 bpm, 544 psi, 13% F/O. Page 24/79 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 77 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stars Time End Time DW (hr) Phase Op Code Activity Cade Time P-T-X Opam ion Start Depth (MKB) End Depth (MKS) 9/8/2017 9/8/2017 0.75 COMPZ1 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/0 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 COMPZ11 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 COMPZ1 WELLPR CIRC P Pick up and expose dogs. PUW 153k, 8,249.5 8,249.5 21:30 22:15 SOW 116k. Slack off to block weight, observing dog sub shear at 50k hookload. Pressure up to 200 psi and pull out of RS 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 COMPZ1 WELLPR TRIP P Pull OOH with running tools to 8246' 8,249.5 8,246.0 22:15 22:30 and rack back stand #88. Blow down kill line. 9/8/2017 9/812017 0.50 COMPZ1 WELLPR OWFF P Monitor well for flow -well static. 8,246.0 8,246.0 22:30 23:00 9/8/2017 919/2017 1.00 COMPZ1 WELLPR TRIP P Pull OOH on elevators from 8246' to 8,246.0 6,775.0 23:00 00:00 6775' MD, racking back 4" HWDP in derrick, monitoring displacement via trip tank. PUW 126k, SOW 102k. OA pressure at midnight = 280 psi 9/9/2017 9/9/2017 3.00 COMPZ1 WELLPR TRIP P POOH w/ Baker liner running tools f/ 6,775.0 0.0 00:00 03:00 6775' MD to surface. Inspect running tools, oberserved dog sub sheared. Calculated displacement = 62.1 bbls Actual displacement = 71.91 bbis 9/9/2017 9/9/2017 0.75 COMPZ1 WELLPR BHAH P Service break Baker liner running 0.0 0.0 03:00 03:45 tools and UD tools via beaver slide. 9/9/2017 9/9/2017 1.00 COMPZ1 WELLPR SLPC P Cut and slip 73' of drilling line. 0.0 0.0 03:45 04:45 9/9/2017 9/9/2017 1.00 PROD2 WHPST BHAH P Mobilize Baker BHA components to rig 0.0 0.0 04:45 05:45 floor: string mills, magnets, whip stock and misc BHA tools. Page 25179 Report Printed: 10130/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stall Time End rime Mr (hr) Phase Op Code ActlWty Code Time P -T -X Operation Sled Depth (IIKa) End Depth (ftKa) 9/9/2017 9/9/2017 4.25 PROD2 WHPST SHAH P Make up milling BHA. MIU 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. MIU and RIH w/ seals, unloader, 7 joints of 4" DP, string magnet and Anchor assembly. Whipstock assembly weight = 5k. MIU milling BHA stand to whip stock using 35K brass shear screw and RIH w/ 4 string magnets on top. 9/9/2017 9/9/2017 1.00 PROD2 WHPST TRIP P Run in hole on 4" DP stands from 404.0 1,533.0 10:00 11:00 derrick from 404' to 1533' MD, monitoring displacement via trip tank. 9/9/2017 9/9/2017 0.25 PROD2 WHPST DHEQ P Shallow hole test MWD at 1533' MD 1,533.0 1,533.0 11:00 11:15 with 235 gpm, 590 psi. 9/9/2017 9/9/2017 4.75 PROD2 WHPST TRIP P Trip in hole on 4" DP /4" HWDP string 1,533.0 8,189.0 11:15 16:00 with super sliders installed to 8189' MD, running speed 60 ft/min, filling pipe every 20 stands, monitoring displacement via trip tank. 919/2017 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. 9/9/2017 919/2017 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 -65k weight on it and pulling 20k weight max overpull with no indication of shear. Kill pump and continue working with no success. Note: Anchor pinned to shear at 60k overpull 9/9/2017 9/9/2017 2.50 PROD2 WHPST WPST T Work down torque in 500 ft -Ib 8,249.5 8,249.5 17:45 20:15 increments up to max of 8000 ft -lbs (3- 1/2" REG make-up torque at 8000 ft - lbs, anchor slips good to 15000 ft -lbs) and continue working pipe up/down, setting down -65k weight on it and pulling 20k max overpull with no indication of shear. Establish circulation at 234 gpm, 1285 psi, 20% F/O and confirm orientation hasn't changed once trapped torque let out. Discuss path forward with town. Page 26179 ReportPrinted: 1 013 0/2 01 7 Summary (with Timelog Depths) 1 H-102 lipOperations Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Tune End Time Dur(hr) Phsse Op Code Activity Code Time P -T-% Operation (HKB) EW Depth(AKB) 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 V 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 9110/2017 1.00 PROD2 WHPST BHAH 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 wl whipstock retrival BHAf190' 90.0 7,970.0 03:00 07:00 MD to 7970' MD. Obtain parameters, P/U= 136K, S/0= 107K, Pump @ 237 gpm= 1130 psi. 9/10/2017 9110/2017 3.25 PROD2 WHPST FISH T Orient retrieval hook to 20 deg L and 7,970.0 7,986.0 07:00 10:15 hook up into retrieval slot. Set down 10K @ 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 9110/2017 0.25 PROD2 WHPST OWFF T OWFF, static. 7,986.0 7,970.0 10:15 10:30 9/10/2017 9/10/2017 0.50 PROD2 WHPST TRIP T POOH 5 stands f/ 7970' MD to 7602' 7,970.0 7,602.0 10:30 11:00 - MD, P/U= 147K, 11K drag. 9/10/2017 9/10/2017 0.50 PROD2 WHPST SFTY T Perform postjarring derrick inspection 7,602.0 7,602.0 11:00 11:30 as per DDI, all good. 9/10/2017 9/10/2017 4.75 PROD2 WHPST TRIP T Pull OOH on elevators from 7602'to 7,602.0 268.0 11:30 16:15 268' to bring whipstock to surface, monitoring displacement via trip tank. Page 27179 Report Printed: 1 013 012 01 7 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log stat Time End Tama Dur (hr) Phase Op Code AcWM1y Code Time P -T -X Operation Start Depth QIKB) End Depth(flKS) 9/10/2017 9110/2017 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 Gear rig floor and mobilize 0.0 0.0 18:00 19:30 new whipstock components to dg floor. 9/10/2017 9/10/2017 2.50 PROD2 WHPST SHAH T Make up milling BHA. WU 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 f/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 28179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Tme End Time our (hr) Phase op Code Activity Code Time P -T -X opeishon start Depth (ftKB) End Deplh(fIKB) 9/11/2017 9/11/2017 3.25 PROD2 WHPST TRIP T Trip in hole on 4" DP / 4" HWDP with 3,144.0 8,219.0 00:00 03:15 super sliders from 3144'to 821 9'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 (11k overpull) and confirm anchor set. 9/11/2017 9/11/2017 1.00 PROD2 WHPST WPST T Slack off to block weight (-65k on it) to 8,249.5 8,249.5 03:45 04:45 shear 35k shear bolt - no sign of shear. Start working pipe up/down to fatigue bolt, 238 gpm, 1240 psi, 20% F/O, pulling up to 15k overpull (152k HL) and slacking off down to 75k on it (31k HL) - no sign of shear. 9/11/2017 9/11/2017 0.25 PROD2 WHPST WPST T Slack off to block weight, kill pumps, 8,249.5 8,249.5 04:45 05:00 and start using rig's rocker system with 3-5k torque limit. Observe hookload increase from 45k to 52k. 9/11/2017 9/11/2017 0.25 PROD2 WHPST WPST T With rocker system engaged and 3k 8,249.5 7,979.1 05:00 05:15 torque limit, start working pipe up/down to fatigue bolt, no pumps. Work up to 20k overpull (157k HL) and down to 68k weight slacked off (38k HL). Observe good indication of bolt shear on downstroke and HL increase from 38k to 52k. Top of window @ 7979.13' MD Btm of window @ 7992.80' MD 9/11/2017 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 L1 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 6-3/4" hole to 7997' MD, rathole to 8014.3' MD Page 29179 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log wart cepm Siad Tune End Time our (hr) Phase Op Code Acfivily Code Time P -T -X Operafion (ftKB) End Depth (W13) 9/11/2017 9/11/2017 1.00 PROD2 WHPST REAM P Pump super sweep at TO with 238 8,014.3 7,975.0 17:00 18:00 gpm, 1464 psi, 20% VO, 80 rpm, 5-91k - Tq and ream through window twice and wash down through window once. With pump on, PUW 133k, SOW 100k, ROT 122k. Once sweep turned corner, 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. 9/11/2017 9111/2017 0.75 PROD2 WHPST FIT P Blow down top 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 test equipment and blow down lines. 9/11/2017 9/11/2017 4.00 PROD2 WHPST TRIP P Pull OOH on elevators from 7975'to 7,975.0 133.0 19:00 23:00 133' MD racking back 4" DP / HWDP stands, monitoring displacement via trip tank. Note: Laid down the 31.63' DP single we installed between stand #83 & 84 that allowed us to mill window on full stand 9/11/2017 9112/2017 1.00 PROD2 WHPST BHAH P Lay down milling assembly per Baker. 133.0 0.0 23:00 . 00:00 Observe pockets full of metal shavings on all 4 X magnets. Clean off magnets and lay down MWD tool and mills. - 6-3/4" 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 midnght = 465 psi No downhole losses observed over past 24 hours 9/12/2017 9/12/2017 1.00 PROD2 WHPST W W WH P WU stack washing tool on stand of 0.0 0.0 00:00 01:00 HWDP, wash and flush stack/ wellhead of swarf from milling operations. 9/12/2017 9/12/2017 1.50 PROD2 WHPST BHAH P Make up clean out BHA, Mud motor, 0.0 639.0 01:00 02:30 impulse w/ 4 Baker string magnets to 639' MD as per SLB. Page 30179 Report Printed: 1 0130/20 7 7 Operations Summary (with Timelog Depths) 1H-102 16 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth start Tme End Time our (hr) Phase Op Code Ac ivity Code Time P -T -X Operation (flKB) End Depth (MB) 9/12/2017 9/12/2017 4.00 PROD2 WHPST TRIP P RIH w/ clean out BHA f/ 639' MD to 639.0 7,645.0 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/0= 99K, ROT= 106K. 9.2 ppg MW. AST= 2.0, ART= 1.47. ADT= 3.47, Bit hours= 3.47, Total jar hours= 39.02. At 8299' MD 33' of separation from 1 H -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 wl 9.2 ppg mud MP #1: 20 spm= 480 psi, 30 spm= 660 psi MP#2: 20 spm- 480 psi, 30 spm= 660 psi 9112/2017 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. DWN 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. 9112/2017 9/12/2017 1.00 PROD2 DRILL BHAH P LD BHA. Monitor disp via TT. 101.0 0.0 17:30 18:30 9/12/2017 9/12/2017 1.50 PROD2 WHDBOP RURD P Olean rig floor and wash out stack. 0.0 0.0 18:30 j 20:00 Set isplug and pull wear bushing. Page 31/79 ReportPrinted: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Sted Time End Time Dur(hr) Phase Op Code Activity Code Time P -T -X Operation (W13) End Depth (fIXa) 9/12/2017 9/13/2017 4.00 PROD2 WHDBOP BOPE P Test BOPE with 4" and 4-1/2" testjoint 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 3-1/2n 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 @j 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 lest plug seal and retest _ GOOD_ 9/13/2017 9/13/2017 0.50 PROD2 WHDBOP BOPE P Cont to test BOPE w/ 4-1/2" TJ to 0.0 0.0 00:00 00:30 250/3500 psi. Test pit level sensors and flow out alarm. Test 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. R/D floor valves from testing equipment. Install wear bushing. 9/13/2017 1.00 PROD2 DRILL BHAH P M/U BHA as per SLB, X516 PDC bit, 0.0 302.0 01:30 02:30 PowerDrIve, Periscope, ImPulse, 19/13/2017 NMFC, Jars and 4" HWDP to 302' MD. Page 32179 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Srah Time End Time Dur (hr) Phase Op Code Achvity Code Tune P -T -X Operation Start Depth (ftKB) End Depth (MKB) 9/13/2017 9/13/2017 4.25 PROD2 DRILL TRIP P RIH w/ drilling BHA f/ 302' MO to TOW 302.0 8,093.0 02:30 06:45 Q 7979' MD. Shallow hole test tools 1500, tools in neutral. Slowly trip down thought window @ 7979' MD to 7993' MD. Cont RIH U 8093' MD. P/U= 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' MID -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. 2-51K WOB along with ECD's of 10.64 EMW. Off BTM 1,830 PSI DPP, UP WT = 114K, OWN WT = 79K. ROT = 94K. 4K TO. MW = 9.2 PPG. Max gas = 50 units. ADT -3 Bit hrs - 3 Jar hrs - 42.02 SPR 7,870' MD 2,930' TVD Q 0600 hrs MP 1) 20 SPM - 440 PSI 30 SPM - 620 PSI MP 2) 20 SPM - 420 PSI 30 SPM - 600 PSI 9/13/2017 9/13/2017 6.00 PROD2 DRILL DDRL P DDRL from 8,636'MD 3,929'TVD- 8,636.0 9,430.0 12:00 18:00 9,430' MD 3,948' TVD. 271 GPM 1,947 PSI DPP. 23% F/O. 120 RPM with 6K TO. 4-5K WOB along with ECD's of 10.82 EMW. Off BTM 1,931 PSI DPP, UP WT= 121K, OWN WT = 70K. ROT = 94K. 6K TO. MW = 9.2 PPG. Max gas = 171 units. ADT -4.25 Bit hrs - 7.24 Jar hrs - 45.79 SPR 8,825' MD 3,941' TVD @ 1330 hrs MP 1) 20 SPM - 420 PSI 30 SPM - 600 PSI MP 2) 20 SPM - 420 PSI 30 SPM - 620 PSI 9/13/2017 9/14/2017 6.00 PROD2 DRILL DDRL P DDRL from 9,430' MD 3,948' TVD - 9,430.0 10,215.0 18:00 00:00 10,215' MD 3,957' TVD. 271 GPM 2,090 PSI DPP. 22% F/O. 120 RPM with 6K 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. 61K 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 OPP. 22% F/O. 120 - 135 RPM with 8K TQ. 2-51K WOB along with ECD's of 11.5 EMW. Off BTM 2,264 PSI DPP, UP WT= 136K, OWN WT=73K. ROT =101K. 61K 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 Timelog Depths) 1H-102 DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Ti. our (hr) Phase Op Code AGNiry Code Time P -T -X Dperabon (MB) End Depth (WB) 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 0600 12:00 11,716' MD 3,986' TVD. 271 GPM 2,595 PSI DPP. 22% F/O. 120 - 135 RPM with 8K TO. 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 TO. MW = 9.2 PPG. Max gas = 65 units. ADT -4.16 Bit hrs - 20.3 Jar hrs - 58.85 SPR 10,333" MD 3,955' TVD @ 00:30 hrs MP 1) 20 SPM -550 PSI 30 SPM - 760 PSI MP 2) 20 SPM - 540 PSI 30 SPM - 740 PSI 9/14/2017 9/14/2017 6.00 PROD2 DRILL DDRL P DDRL from 11,716' MD 3,986' TVD - 11,716.0 12,362.0 12:00 18:00 12,362' MD 3,974' 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 TO. MW = 9.2 PPG. Max gas = 150 units. ADT -4.6 Bit hrs - 24.63 Jar hrs - 63.18 SPR 11,803" MD 3,985' TVD @ 13:33 his 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 TO. 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 PROW DRILL DDRL P DDRL from 12,719 MD 3,970' TVD - 12,719.0 13,126.0 00:00 03:15 13,126' MD 3,988' TVD. 271 GPM 2,653 PSI DPP. 22% F/O. 110-135 RPM with 9K TO. 2-5K 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 his - 69.63 Page 34/79 Report Printed: 10130/2017 Operations Summary (with Timelog Depths) �s 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log stall Depth stsd Time End Time our (hr) Phase Op Code Activity code Time P -T -X Operation (ftKa) EM Depth (40) 9/15/2017 9/15/2017 1.75 PROD2 CASING CIRC P TD called by Anch Geo / Rack bak 13,125.0 13,126.0 03:15 05:00 stand and pump BU. rotate 140 RPM, 8K TO. 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. OWN WT=69K. ROT =101K. 9/15/2017 9/15/2017 0.50 PROD2 CASING TRIP P POOH on elevators from 8,356'- 8,356.0 7,882.0 18:45 19:15 7,882' MD with Baker rep on site through window. - 1 O bobble. UP WT=128K. OWN 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 TO. 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 P POOH on elevators from 7,882'-1,155' 7,882.0 1,155.0 21:15 - 00:00 MD. Monitor disp via TT. UP WT = 118K. DWNWT=80K. 9/16/2017 9/16/2017 0.75 PROD2 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 OWFF - P OWFF. PJSM for laying downBHA. 302.0 302.0 00:45 01:00 dNGTRIP 9/16/2017 - 9/16/2017 1.25 PROD2 BHAH P Lay down BHA #9 as per DD from 302.0 0.0 01:00 02:15 302'MDto surface. Monitordispvia TT. 9/16/2017 9/16/2017 0.25 PROD2 BHAH P Clean dg floor. 0.0 0.0 02:15 02:309/16/2017 9/16/2017 1.25 PROD2 SLPC P SLPC 73' drill line. 0.0 0.0 02:30 03:45 9/16/2017 9/162017 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 9/162017 1.25 COMPZ2 FISH TRIP P RIH from 230'- 2,209' MD monitoring 230.0 2,209.0 06:00 07:15 Disp via TT. UP WT= 70K DWN WT= 70K 9/16/2017 9/162017 0.25 COMPZ2 FISH DHEQ P Shallow test MWD (PASSED). 2,209.0 2,209.0 07:15 07:30 9/16/2017 9/162017 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 studs. Page 35179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log s an oapN $IaM1 Time End Tim Ow(hr) Phew Op Code AcOvity Code- Time P -T -X Operation (Po(B) End Depth (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 @ 5.5 BPM 1,650 PSI DPP. 20% FIG. Up WT=120K, OWN WT=77K. Orient 22 DEG. Latch into whipstock and work up to 100K overpull with no success with straight overpull. Jar 3X at 40K / 4X at 60K, Whipstock free after 2 80K hits with straight pulls to 100K. 127K UP WT with 10K drag. 9/16/2017 9/16/2017 1.50 COMPZ2 FISH CIRC P Circulate bottoms up X2 @ 268 GPM, 7,991.0 7,960.0 12:00 13:30 1,284 PSI DPP. 21% F/O. 4,862 STKS pumped. 9/16/2017 9/16/2017 0.50 COMPZ2 FISH OWFF P OWFF. (STATIC). PUH to 7,904' MD. 7,960.0 7,904.0 13:30 14:00 UP WT = 125K. Blow down top drive. 9/16/2017 9/16/2017 5.00 COMPZ2 FISH TRIP P POOH with Whipstock assym on 7,904.0 230.0 14:00 19:00 elevators. from 7,960'-230'MD. UP WT = 125K. Monitor disp via TT. Drop 2.115 OD rabbit. 9/16/2017 9/16/2017 2.00 COMPZ2 FISH BHAH. P Lay down BHA #10 and whipstock as 230.0 0.0 19:00 21:00 per Baker rep. Monitor disp via TT. 9/16/2017 9116/2017 1.00 COMPZ2 FISH BHAH P Clean rig floor and LD running tools. 0.0 0.0 21:00 22:00 9/16/2017 9/16/2017 1.50 COMPZ2 CASING RURD P Rig up to run liner., Bring GBR 0.0 0.0 22:00 23:30 equipment to rig floor, centrilizers, etc. 9/16/2017 9/17/2017 0.50 COMPZ2 CASING PUTB P PJSM / pick up 4 1/2" 11.6# IBTM 0.0 290.0 23:30 00:00 slotted liner as per tally to 290' MD. UP WT = 47K, OWN WT = 47K. 9/17/2017 9/17/2017 7.25 COMPZ2 CASING PUTS P RIH with 41/2" 11.6# L-801BTM 290.0 5,097.0 00:00 07:15 slotted liner as per tally from 290' - 5,097' MD. Monitor disp via TT. Install centralizer on every joint. TO connections to 5K FT/LB. 9/17/2017 9117/2017 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. OWN WT= 69K. 9/17/2017 9117/2017 0.50 COMPZ2 CASING RUNL P RIH with DP fro 5,130'- 5,687' MD. 5,130.0 5,687.0 08:15 08:45 Monitor Disp via TT. 9/17/2017 9/1712017 0.25 COMPZ2 CASING DHEQ P Shallow hole test MWD with 100 GPM 5,687.0 5,687.0 08:45 09:00 320 PSI DPP, 10% F/O (PASSED) Blow down top drive. 9/17/2017 9/17/2017 4.50 COMPZ2 CASING RUNL P RIH with 4" DP from 5,687'- 10,431' 5,687.0 13,040.0 09:00 13:30 MD then HWDP to 13,040' MD UP WT 168K, OWN WT 91 K. 9/1712017 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 3 112 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 PIU 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 uepths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Siad Time End Time Dur (hr) Phase Dp Code Activity Code Time P -T -X Operation (flKa) Ed Depth (MKa) 9/17/2017 9/17/2017 0.75 COMPZ2 CASING CIRC P Drop 29/32" ball and pump down Q 4 13,110.0 13,110.0 14:45 15:30 BPM 170 GPM, 1,350 PSI DPP. 14% F/O. Decrease rate to 42 GPM - 350 PSI DPP. 5% F/O. Ball on seat at 667 STKS. Pressure up to 3,300 PSI. Pick up to confirm release observe 145K UP WT. Pressure up to 4,362 PSI to shear out ball seat. 9/17/2017 9/17/2017 0.50 COMPZ2 WELLPR OWFF P OWFF (Static) 13,110.0 13,110.0 15:30 16:00 9/17/2017 9/17/2017 3.50 COMPZ2 WELLPR TRIP P POOH on elevators from 7,952 to 75' 7,952.0 75.0 16:00 19:30 MD. 9/17/2017 9/17/2017 0.50 COMPZ2 WELLPR SHAH 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 9/17/2017 9/17/2017 1.00 COMPZ2 WELLPR SHAH P Clean rig floor and remove BHA from 0.0 0.0 21:00 22:00 1 1 floor. Service TD. 9/17/2017 9/18/2017 2.00 COMPZ2 WELLPR RGRP T Begin traction motor replacement on 0.0 0.0 22:00 00:00 top drive. 9/18/2017 9/18/2017 15.00 COMPZ2 WELLPR RGRP T Continue to change out top drive 0.0 0.0 00:00 15:00 motors 9/18/2017 9/18/2017 0.50 COMPZ2 WELLPR SFTY T Perform DROPS inspection. 0.0 0.0 15:00 15:30 9/18/2017 9/18/2017 1.00 COMPZ2 RWRID RURD P Bring tools to dg floor to run LEM / 0.0 0.0 15:30 16:30 ZXP. GBR set to Torque turn TXP treads. 9/18/2017 9/18/2017 2.50 COMPZ2 RWRID PUTB P MU and RIH with LEM /ZXP assym to 0.0 399.0 16:30 19:00 399'MD. Up WT=47K OWN WT= 53K. Monitor disp via TT. Utilizing GBR to make up torque on TXP threads. 9/18/2017 9/19/2017 5.00 COMP72 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 OWN 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 OWN and confirm latched with 5K overpull. Work pipe to turn to 28 DEG left and drop 13/4" ball. Bring pumps on line at 80 GPM with ball going on seat at 558 STKS. Pressure up to 2,800 PSlfor 5 min. Increase pressure to 3,700 PSI to set isolation tool and PKR. Bleed off pressure. Pressure test PKR for 10 min at 3,500 PSI. (PASSED). UP WT= 145K. OWN WT = 106K 9/19/2017 9/19/2017 1.00 COMPZ2 RWRID CIRC P PUH to 7,907' MD and circulate in 28 8,299.0 7,907.0 03:45 04:45 BBLS of 9.3 PPG Cl pill with 140 GPM at 440 PSI DPP. 12% F/O. UP WT = 147K. 9/19/2017 9/19/2017 0.75 COMPZ2 RWRID OWFF P PUH to 7,849'MD OWFF. Blow down 7,907.0 7,849.0 04:45 05:30 top drive. Fluid level dropped 2" Page 37179 Report Printed: 1 013 0/2 01 7 r; " operations Summary (with Timelog uepths) - 114-102 Rig: DOYON 142 Job: DRILLING ORIGINAL 71me Log Start Depth Slap Mme End Time our (hr) Phase Op COEe Activity Code Tim P-T-X Operation (MB)End Depth(fIKB) 9/19/2017 9/19/2017 4.50 COMPZ2 RWRID TRIP P POOH from 7,849' -74' MD 7,849.0 74.0 05:30 10:00 monitoring disp via TT. Up WT = 145K 9/19/2017 9/19/2017 0.75 COMPZ2 RWRID SHAH P LD LEM assym BHA 74.0 0.0 10:00 10:45 9/19/2017 9/19/2017 0.50 COMPZ2 RWRID BHAH P Clean dg floor and perp for next run. 0.0 0.0 10:45 11:15 9/192017 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. Own 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 PROD3 WHPST WPST P Kelly up and fill pipe @ 7,811' MD. 7,511.0 - 7,915.0 19:15 20:30 Wash DWN and orient 125 DEG Left high side @ 220 GPM, 1,177 PSI DPP. 16% FlO. 7,915' MD UP WT = 137K. 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 10K over to check set. Shear off and slide with 40K DWN WT. 91192017 9/20/2017 2.75 PROD3 WHPST MILL P Mill window as per BOT 7,831.8 7,848.0 21:15 00:00 recomendations with 300 GPM, 1,906 PSI DPP with 20% F/O. 80 RPM with 4K TO. UP WT=137K. DW WT= 105K. ROT= 120K. to 7,848' MD. 9/20/2017 9/20/2017 6.00 PROD3 WHPST MILL P Mill Window and new hole as per 7,848.0 7,865.9 00:00 06:00 Baker rep. From 7,848' MD - 7,865.87' MD. At 296 GPM, 2,050 PSI DPP, F/0 = 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 9120/2017 3.50 PROD3 WHPST MILL P Continue to mill from 7,865'- 7,865.9 7,880.0 06:00 09:30 7,880'10D. 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, DWN WT = 106K. 9/2012017 9/20/2017 0.25 PRODS WHPST CIRC P Circulate BU at 200 GPM. 7,880.0 7,880.0 09:30 09:45 9/20/2017 9/202017 1.25 PRODS WHPST FIT P Perform FIT Tto 12.9 EMW. 8 STKS 7,880.0 7,880.0 09:45 11:00 to pressure up to 720 PSI. -8 BBLS bled back. RD and BD test equip. 9/20/2017 9/20/2017 0.25 PROD3 WHPST OWFF P OWFF (GOOD). 7,880.0 7,880.0 11:00 11:15 9/202017 9120/2017 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 9/202017 1.25 PROD3 WHPST BHAH P LD Milling BHA as per Baker Rep from 231.0 0.0 16:00 17:15 231' to Surface. Upper mill was full guage. Page 38179 ReportPrinted: 10/30/2017 Operations Summary (with Timelog IJepths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log seen Depth Sten Time End Time Our (n0 Phase Op Code Activity Code Time PJA Operation tftKB) End Depth (flKB) 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 912012017 1.00 PROD3 WHPST RGRP T Change out lights of derrick. 0.0 0.0 19:00 20:00 9/20/2017 9/2012017 0.50 PRODS WHPST EQRP P Change out SLB stand pipe 0.0 0.0 20:00 20:30 1 transducer. 9/20/2017 9/20/2017 1.75 PROD3 WHPST SHAH P PU/MU clean out BHA as per SLB DD. 0.0 887.0 20:30 22:15 to 887'MD/IUP WT=53K, DWN WT = 58K. Monitor disp via TT. 9/20/2017 9/20/2017 1.00 PRODS WHPST TRIP P Trip in hole with 4" DP form 887'- 887.0 1,558.0 22:15 23:15 1,558'MD. UP WT 67K, DWN WT= 71K. Perform shallow test @ 250 GPM 1,048 PSI DPP 20% F/O. (FAILED) 9/20/2017 1912112017 0.75 PRODS 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 PRODS 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 TQ, 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 PROD3 DRILL DDRL P DDRL 6 314" hole fro,m 8,283'- 6,331' 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 his. 4.89. SPR's @ 8,373' MD 3,873 TVD - MW 9.2 PPG Time 13:00 MP 1) 20 SPM = 450 PSI 30 SPM = 620 PSI MP 2) 20 SPM = 450 PSI 30 SPM = 620 PSI Page 39179 Report Printed: 1 013 0/2 01 7 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Dept Stan Tme EM Time Cur (hr) Phase Op Code Activity Code Time P -T -X Operation (11Ka) End Depth (MKa) 9121/2017 9/21/2017 0.75 PROD3 DRILL CIRC P Rotate and reciprocate from 8,331'- 8,331.0 8,331.0 13:00 13:45 8,285' MD at 230 GPM, 1,310 PSI, 18% F/O. 40 RPM, with 6K DWN WT --UP WT=72K. ROT WT=94K, 2,580 STKS pumped. 9/21/2017 9/21/2017 0.50 PROD3 DRILL OWFF P OWFF (Static) 8,331.0 8,331.0 13:45 14:15 9/21/2017 9/21/2017 0.50 PROD3 DRILL TRIP P POOH on elevators from 8,331'- 8,331.0 7,905.0 14:15 14:45 7,905' MD. Monitor disp via TT. UP WT = 135K, DWN WT = 74K. 9/21/2017 9/21/2017 0.75 PROD3 DRILL TRIP P Kelly up and orient to 25 DEG 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. 9/2112017 9/21/2017 1.50 PROD3 DRILL SHAH 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 test plug 0.0 0.0 21:00 21:30 9/21/2017 9/22/2017 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 #1-4 JNT, ANN, CV1,12,13,14,4" Kill line on mud manifold, 4:" Dart valve. Test #2 CV 9,11 Mez Kill ine 4" FOSV. 9/22/2017 922/2017 3.00 PROD3 WHDBOP BOPE P Continue to lest BOPE. All test to 0.0 0.0 00:00 03:00 250/ 3,500 PSI 5 min charted. Except super chokes to 1,500 PSI. Test choke valves 1-14 UPR & -WR SOP, 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 btt[ 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 ]BOP. 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 9/22/2017 9/22/2017 1.50 PROD3 DRILL SHAH P PU/MU BHA # 14 as per DD / MWD. 0.0 306.0 04:15 05:45 Monitor disp via TT 9/22/2017 9/222017 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 Report Printed: 101=2017 Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log StartDepth Stad Tune End Time Our(hr) Phase Op Code Adivily Code Time P -T -X Operation (ftKa) End Depth(ftKe) 9/22/2017 9/22/2017 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 9/2212017 3.75 PROD3 DRILL TRIP P Continue to RIH from 2,105'- 7,945' 2,105.0 7,945.0 06:45 10:30 MD. Monitor disp via TT. UP WT = 132K. DWN WT=79K. Fill pipe - every 20 stands. 9-/22/2017 9/22/2017 1.50 PROD3 DRILL DLOG P Perform MAD PASS from 7,945'- 7,945.0 8,290.0 10:30 12:00 8,290' MD w@ 390 FPM. 250 GPM Q 1,545 PSI DPP. F/O = 19%. UP WT=130K, DWN WT 72K. ROT= 92K 6K TO. 9/22/2017 9122/2017 0.50 PROD3 DRILL DLOG P Continue MAD pass form 8,290'- 8,290.0 8,377.0 12:00 12:30 8,377' MD. with 250 GPM, 1,600 PSI, 20% FIO, 80 RPM, 5.51K TO. 9/22/2017 9/22/2017 5.50 PRODS 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 1,680 PSI DPP. 22% F/O 150 RPM, 71K TO, with 3-31K 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 9/2212017 9/23/2017 6.00 PRODS 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' TVD, 272 GPM at 2,005 PSI DPP. 22% F/O 150 RPM, 81K TO, with 4-5K WOB. ECD's 10.98 PPG EMW, Off BTM 2,000 PSI DPP, UP WT = 137K DWN WT = 63K. ROT = 98K. 7.81K TO. Max gas = 223 units. ADT - 4.31, Bit HRS = 8.51 Jars = 13.4 9/23/2017 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' TVD, 272 GPM at 2,185 PSI DPP. 21 % F/O 150 RPM, 8K TO. with 31K WOB, ECD's 11.52 PPG EMW, Off BTM 2,180 PSI DPP, UP WT=125K DWN WT= 60K. ROT =99K. 7.5K TO. Max gas = 580 units. ADT - 4.15, Bit HRS = 12.66 Jars = 17.55 SPR's Q 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 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, 81K TO, with 5K WOB. ECD's 11.8 PPG EMW, Off BTM 2,355 PSI DPP, UP WT= 143K DWN WT=61 K. 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: 10/3012017 ` Operations Summary (with Timelog (Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Time Dir(hr) Phase Op Code A vity Code Time P -T -X Operation (Win End Depih(ttKB) 9/23/2017 9/23/2017 6.00 PROD3 DRILL DDRL P Drill 6 3/4" hole from 11,188' MD 11,188.0 11,758.0 12:00 18:00 3,922' TVD- 11,758' MD 3,922' TVD, 271 GPM at 2,425 PSI DPP. 21% F/O 150 RPM, 9K TQ, with 5K WOB. ECD's 11.48 PPG EMW, Off BTM 2,420 PSI DPP, UP WT= 148K DWN WT=67K. ROT =101 K. 8.3K TO. Max gas = 7,736 units. ADT - 4.41, Bit HRS = 21.07 Jars = 25.96 SPR's @ 11,266" MD 3,930' TVD - MW 9.2 PPG Time 12:30 MP 1) 20 SPM = 650 PSI 30 SPM = 860 PSI MP 2) 20 SPM = 640 PSI 30 SPM = 820 PSI 9/23/2017 9/24/2017 6.00 PROD3 DRILL DDRL 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, 9K TO, with 5K WOB, ECD's 11.30 PPG EMW, Off BTM 2,420 PSI DPP, UP WT = 154K DWN WT=63K. ROT=101K. 8.5KTQ. Max gas = 3,458 units. ADT - 4.95, Bit HRS = 26.02 Jars = 30.91 9/24/2017 9/24/2017 6.00 PRODS DRILL DDRL P Drill 6 3/4" hole from 12,003' MD 12,003.0 12,517.0 00:00 06:00 3,909' TVD - 12,517' MD 3,903' TVD, 270 GPM at 2,500 PSI DPP. 21 % F/O 140 RPM, 8K TO, with 2.5K WOB. - ECD's 11.43 PPG EMW, Off BTM 2,495 PSI DPP, UP WT= 160K DWN WT = 74K. ROT = 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 PRODS DRIUL DDRL P Dri116 3/4" hole froml2,517' MD 3,903' 12,517.0 13,177.0 06:00 12:00 TVD - 13,177' MD 3,934' TVD, 270 GPM at 2,705 PSI DPP. 21% F/O 120 RPM, 8.5K TO, with 5K WOB. ECD's 10.71 PPG EMW, Off BTM 2,700 PSI DPP, UP WT = 175K DWN WT = 68K. ROT= 120K. 8.2K TO. Max gas = 65 units. ADT - 3.78 Bit HRS = 33.82 Jars = 38.71 Page 42179 Report Printed: 1013012017 Operations Summary (with Timelog Llepths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log San Depth Slav Time EM TMe Dur(m) Phase Op Code Activity Code Time P -T -X Opeabon (ftKB) End Deplh ftKa) 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 PSIDPP. 21 % F/O 140 RPM, 8.5K TO, with 5K WOB. ECD's 11.81 PPG EMW, Off BTM 2,810 PSI DPP, UP WT = 177K DWN WT = 67K. ROT= 117K. 8.41K 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% FIO, 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 TO. 11.41 ECD EMW. UP WT= 137K, DWN WT = 756K Monitor disp via TT. 9/25/2017 9/25/2017 7.50 PROD3 CASING BKRM P Continue to BKRM OOH from 10,900' 10,900.0 8,169.0 00:00 07:30 MD - 8,169' MD. 270 GPM @ 1,880 PSI DPP. 150 RPM with 5K TO. ECD =10.57, UP WT=130, DWN WT= 75K. 9125/2017 9/25/2017 0.50 PROD3 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 9/2512017 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 PRODS 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 PROD3 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. 7,768.0 7,788.0 11:00 11:15 Page 43179 Report Printed: 10130/2017 = 9 1 ! Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time sad Tune Dur(ht) Phase Op Code Ad%*Code Time P -T -X Operation (flKB) End Depth(fiKB) 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 DWN 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 9/252017 0.50 PRODS CASING BHAH P Clean rig 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. 925/2017 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. 9/252017 9/252017 0.50 COMPZ3 FISH DHEQ P Shallow pulse test SLB BHA for 1,638.0 1,636.0 20:00 20:30 communications. 250 GPM Q 1,060 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. 9/252017 926/2017 0.50 COMPZ3 FISH FISH P Mousehole botm single stand 82. 7,828.0 7,848.0 23:30 00:00 obtain toolfaoe 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 9/262017 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. 9/262017 9262017 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 ft 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. 9/26/2017 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 9262017 0.75 COMPZ3 FISH BHAH P Clean and clear rig floor of whipstock 0.0 0.0 09:45 10:30 equipment. 9/262017 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: 1 013 012 01 7 operations Summary (with Timelog uepths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log SW Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation start Depth (flKe) I End Depth (ftKB) 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 9126/2017 8.75 COMPZ3 CASING PUTB P Pick up bent shoe and run in hole with 0.0 5,338.0 12:45 21:30 4-1/2" 11.6# L-80 IBTm slotted liner with 4-1/2" 12.6# L-80 blank joints and 6" OD swell packers to 5338' MD per tally. Run total of 1 x bent shoe joint, 109 x 4-1/2" 11.6# L-80 IBTm slotted liner, 14 x 4-1/2" 12.6# L-80 TXPm blank liner, and 3 x 6" OD Baker swell packers with -2.7' long elements. Run total of 130 x 6-1/8" thick-walled Volant hydroform centralizers. Install 1 x free-floating on every joint and install above and below each swell packer element. MUT for 4-1/2" IBTm of -4500 fl -lbs. MUT for 4-1/2" TXPm of -7000 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, rig 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° toolface offset measured MWD highside to 180" off from hook. 9/26/2017 9/2612017 0.25 COMPZ3 CASING CIRC P Make up stand of 4" DP and break 5,368.0 5,368.0 2230 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 9126/2017 9126/2017 0.50 COMPZ3 CASING DHEQ P Shallow hole test SLB Slimpulse at 90 5,835.0 5,835.0 23:00 23:30 gpm, 290 psi, 9% F/O - good test. Blow dow topddve. 9/26/2017 9/2712017 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 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, - 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% FlO, 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 46179 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Deplh sold Time End Time our (hr) Phase Op Code Activity Code Time P -T-% operation (Vir) End Depth (W13) 9127/2017 9/27/2017 1.00 COMPZ3 CASING RUNL P Kelly up and pump at 90 gpm, 590 psi, 13,153.0 13,204.2 04:00 05:00 9% F/O. Orient to 154° right and run in hole 60' on stand #84 to 13213' MD, putting hook 10' past window- no issues. Pick up and orient to 20° left. Run in hole and engage hook hanger 50.5' in on stand #84. Set down 20k weight and confirm orientation 20° left. Pick up 15', run back in, see slight bobble of weight 50.5' in on stand #84 then engage hook at 52' in on stand #84. Set down 20k and confirm orientation 20° left. Total of 717 strokes pumped. 9/27/2017 9/27/2017 1.25 COMPZ3 CASING CIRC P Drop 29/32" phenolic ball and pump 13,204.2 7,835.0 05:00 06:15 down, 139 gpm, 990 psi, 12 % F/O for 350 strokes, then 85 gpm, 540 psi, 9% F/O for 150 strokes, then 66 gpm, 429 psi, 7% F/O for 100 strokes, then 44 gpm, 328 psi, 4% F/O to seat ball. Ball on seat at 645 strokes. Pressure up to 3300 psi and hold to release liner running tool. Continue pressuring up to 4450 psi with mud pump to shear ball seal - no shear observed. Bleed off pressure, line up test pump, pressure up with mud pump to 4100 psi, and continue pressuring up with test pump to shear ball seat. Observe shear at 4850 psi (pinned for 4000 psi shear). Pick up above hook hanger to 7835' MD, PUW 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. 9127/2017 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 BHAH 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 SHAH P Clean and clear rig floor of running 0.0 0.0 11:00 11:15 - tools. 9/27/2017 9/27/2017 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 turn and hold PJSM. Page 46179 ReportPrinted: 1013012017 Operations Summary (With Timelog LDepths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Tim End Time Dor (hr) Prow Op Code Advily Code Time P4A Operation start Depth (flKe) Eno DepN (flKa) 9/27/2017 9/27/2017 2.75 COMPZ3 RWRID PUTB P Makeup LEM/ZXP assemblyfor 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 z stand 4" DP to 337' 242.0 337.0 14:30 15:15 MD and break circulation at 2 bpm, 310 psi, 9% F/O, no issues observed. Blow down topdrive. 9/27/2017 9/27/2017 1.50 COMPZ3 RWRID RCST P Run in hole with L2 LEM / ZXP 337.0 2,137.0 15:15 16:45 assembly on 4" DP from 337' to 2137' MD, monitoring displacement via trip tank. 9/27/2017 9/27/2017 0.25 COMPZ3 RWRID DHEQ P Shallow hole test MWD SlimPulse with 2,137.0 2,137.5- 16:45 17:00 92 gpm, 320 psi, 10% F/0. 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 hale 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 Ll LTP. Run in and bury stand #82 to 7930.48' MD. Make up 4" DP single and continue washing in hole. Locate LEM in hook hanger 17.5' in on single. Slack off to 90k HL (19k set down) and observe toolface roll to 26° left. Confirm orientation at 26° left, Pick up to 155k (12k overpull) and confirm latched. 9127/2017 9/27/2017 1.25 COMPZ3 RWRID PACK P Drop 1.625" frac ball and pump down 7,948.0 7,948.0 21:15 22:30 at 3 bpm, 780 psi, 13% F/O for 350 strokes, then 2 bpm, 490 psi, 10% F/0 for 150 strokes, then 1.5 bpm, 385 psi, 8% F/0. 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: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log SWInime End Time Dia(hr) Phase Op Code Activity Code rime P4 -X Operation Start Depth (MB) End Deplh(tlKB) 9/2712017 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 top packer. Pressure up to 3500 psi and hold for 10 minutes, charted - good test. Pumped 3.6 bbls, returned 3.6 Wis. 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 9127/2017 0.50 COMPZ3 RWRID CIRC P Lay down single and continue pulling 7,948.0 7,718.0 23:00 23:30 up to place ports at top of liner tieback sleeve for high circulation rate. Pump 26 bbis 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 I 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 dear rig floor of running 0.0 0.0 06:45 07:15 tools. 9/28/2017 9/28/2017 1.25 PROD4 WHPST BHAH P Mobilize whipstock BHA to rig floor, 0.0 0.0 07:15 08:30 confine spaceout, and mobilize spaceout pups to rig floor. Hold PJSM. 9/28/2017 9/28/2017 3.00 PROD4 WHPST BHAH P Make up 6-3/4" milling assembly with 0.0 307.0 08:30 11:30 Slimpulse MWD and scribe, 242.11° _ TFO. Rack back milling assembly. Make up 7-5/8" Gen II whipstock assembly and bolt up milling assembly with 25k shear bolt. RIH to 307' MD. SOW 57.5k 9/28/2017 9/28/2017 1.50 PROD4 WHPST TRIP P Trip in hole with whipstock assembly 307.0 2,197.0 11:30 13:00 on 4" DP from 307' to 2197' MD, monitoring displacement via trip tank. 9/28/2017 9/28/2017 0.50 PROD4 WHPST DHEQ P Shallow hole test MWD with 213 gpm, 2,197.0 2,197.0 13:00 13:30 605 psi, 16% F/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: 10/30/2017 Operations Summary (with Timelog Uepths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Start Time End Tim our (hr) Phase Do Cade Activity Code Time PJA Operation We) End Depth(M(B) 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 9/26/2017 9/28/2017 0.50 PROD4 WHPST WPST P Wash in hole from 7625', SOW 110k. 7,625.0 7,647.0 18:15 18:45 Observe —1k drag as seals entered top of liner. 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 Blm of window @ 7660.7' MD 9/28/2017 9/28/2017 0.25 PROD4 WHPST WPST P Establish parameters with 200 gpm, 7,647.0 7,647.0 18:45 19:00 1000 psi, 16% F/0, 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/0, 100 rpm, 3-7k Tq, 5-12k WOB. Pump super sweeps per Baker rep. Mill out on pit #1 only, keeping other FloPro isolated. Note: —7 ft of gauge 6-3/4" hole to 7666' MD, rathole to 7685' MD TOW @ 7647.0' MD BOW @ 7660.7' MD 9/29/2017 9/29/2017 0.50 PROD4 WHPST REAM P Pump super sweep at TD with 300 7,685.0 7,637.0 07:45 08:15 gpm, 1850 psi, 21% VO, 100 rpm, 3- 4k Tq and ream through window - no issues. Kill rotary, drop flow to 86 gpm, 618 psi, 11 % F/O and wash up and down through window - no issues. Pumps on PUW 140k, SOW 104k. Rack back stand to 7637' MD. Page 49179 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth StenTime End Time Dm(hr) Phase Op Code Activity Coda Time P-T-X Operation (RKB) End Deplh(ftKB) 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. 9/2912017 9/29/2017 1.00 PROD4 WHPST FIT P Rig up and perform FIT for L3 window 7,637.0 7,637.0 0845 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 and blow down lopdrive. 9129/2017 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 9/29/2017 2.00 PRO04 WHPST BHAH P Make up 6-314" motor BHA with 1.5" 0.0 896.0 17:00 19:00 motor and run in hole to 896' MD. Monitor displacement via trip tank. Note: Re-run 6-3/4" milltooth bit and 1.5° motor as they are both in good shape and low hours. 9/29/2017 9/29/2017 1.00 PROD4 WHPST TRIP P Trip in hole on 4" DP from 89610 896.0 2,087.0 19:00 20:00 1 1 2087' MD, monitoring displacement via trip tank. Page 50179 Report Printed: 10J3012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time - End rine our" Phase Op Code Activity Code Time P -T -X Operation Start Depth (HKB) End Depth (fIKB) 9/29/2017 9/2912017 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 It 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' MO 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 losses for past 24 hours = 20 bbls 9/30/2017 9/30/2017 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 TD 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 110k, ROT 114k. ADT 1.43 hrs, AST 0.67 hrs, Bit 9.79 hrs, Jar 41.98 hrs. Displace wellbore to new/used 9.2ppg Flo -Pro on the fly on first full stand and put on full active system, dumping all milling fluid. Note: Observed flow -out reading drop & gas unit reading rise once started dumping milling fluid returns to rockwasher. Actual flow out did not change, nor did gas units increase. Rig is investigating the issue with the sensors when we dump fluid to rockwasher. SPRs @ 7822' MD 3851' TVD, MW=9.20 ppg, 01:40 hours MP#1: 20 spm=440 psi, 30 spm=620 psi. MP #2: 20 spm=430 psi, 30 spm=610 psi. Page 51179 Report Printed: 10/30/2017 f e Operations Summary (with `�imeiog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Toe End Time our (hr) Phase Op Cade AcNity Code Time P -T -x Operation (ItKB) End Depth (flKB) 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 Blow down topdrive and monitor well 7,824.0 7,824.0 03:30 04:00 for flow - observe fluid level drop -6 inches over 30 minutes 9/30/2017 1913012017 0.50 PROD4 DRILL TRIP P Trip out of hole from 782,V 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 9/3012017 0.25 PROD4 DRILL OWFF P Monitor well for flow at top of BHA - 895.0 895.0 08:00 08:15 well static. 9/3012017 9/30/2017 2.25 PROD4 DRILL BHAH P Pull out of hole from 895'to surface. 895.0 0.0 08:15 10:30 Cleani off magnets and lay down. Rack back jar stand and lay BHA per SLB. Bit was in good shape, graded 0- O -NO -A -E -0 -NO -BHA. 9/30/2017 9/30/2017 0.50 PROD4 DRILL BHAH 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/O, 10 rpm. 9/30/2017 9/30/2017 0.75 PROD4 DRILL RURD P Pull wearbushing, clean off, and re- 0.0 0.0 11:45 12:30 install same. 9/30/2017 9/30/2017 1.00 PROD4 DRILL BHAH P PJSM. Make up RSS BHA to 306' with 0.0 306.0 12:30 13:30 6-3/4" Smith AxeBlade PDC bit, X6 Powerdrive, 4-3/4" PeriScope, 4-314" 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 lest MWD 2,195.0 2,195.0 14:30 14:45 with 200 gpm, 760 psi, 16% F/O - good test. Blow down top drive. 9/30/2017 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 9/3012017 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 9/3012017 0.50 PROD4 DRILL TRIP P, Trip in hole from 6370'to 7124' MD on 6,370.0 7,124.0 17:30 18:00 4" DP stands slick, monitoring displacement via pit #5, filling pipe every 20 x stands. Page 52179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) -77 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth I Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation (") End Depth (flKS) 9/30/2017 9/30/2017 1.50 PROD4 DRILL SVRG P Service topdrive. Inspect saver sub 7,124.0 7,124.0 18:00 19:30 and decision made to change out due to wear. 9/30/2017 9/30/2017 0.75 PROD4 DRILL TRIP P Trip in hole from 7124' to 7601' MD on 7,124.0 7,601.0 19:30 20:15 4" OP stands slick, monitoring displacement via pit #5. Fill pipe. 9/30/2017 9/30/2017 0.25 PROD4 DRILL TRIP P Run in hole from 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 rale 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 DLOG P Observe bit tagging up at 7677' on 7,677.0 7,918.0 20:45 22:30 concretion. Attempt to wash past several times, setting down 15k weight, no success. With bit and stabilizer in open hole (below window), engage rotary at 15 rpm, 34k 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 Q 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: 11 013 012 01 7 I AM-,Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Our or) Phase Op Code Activity Code Time P -T -x Operation Shut Depth (ftKB) End Depth tftKB) 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% NO, ECD 10.36 ppg, MW 9.25 ppg. Rotate at 130 rpm with 4.5k Tq on-blm, 4k Tq off-btm. Max gas 115 units. 1k WOB. PUW 107k, SOW 84k, ROT 95k. ADT 1.24 hrs, Bit 1.24 hrs, Jars 43.22 hrs. OA pressure at midnight = 220 psi. Downhole losses for past 24 hours = 10 bbls. 10/1/2017 1011/2017 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, 3818' TVD. Pump at 269 gpm, 1729 psi, 21% F/O, ECD 10.34 ppg, MW 9.25 ppg. Rotate at 130 rpm with 5.5k Tq on-btm, 4k Tq off-btm. 2- 3k WOB. PUW 111 k, SOW 80k, ROT 92k. Max gas 229 units. ADT 5.03 hrs, Bit 6.3 his, 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 L3 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 54179 Report Printed: 10130/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time EM Tme Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (aKS) End Depth (MKS) 10/1/2017 10/1/2017 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 8,871.0 9,700.0 12:00 18:00 lateral in WestSak B sand from 8871' to 9700' MD, 3836' TVD. Pump at 280 gpm, 2130 psi, 23% F/0, 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-blm, 7k Tq off- blm. 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 10/22017 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% FIO, 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', 10667'- 10571', 10667'- 10674', 10680'- 10687',10712'- 10716', and 10723'- 10727'. Page 55179 Report Printed: 1 0/3 012 01 7 r Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time our (hr) Phase Op Cod. Activity Code Time PJA Operation Start Depth (ftKB) End Depth(RKB) 10/212017 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/0, ECD 11.37 ppg, MW 9.2ppg. Rotate at 180 rp with 9k on-btm Tq, 7k off-blm Tq. 34k 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', 121641- 12173', 12260'- 12281', and 12284'- 12287'. Page 56179 Report Printed: 1013012017 • Operations Summary (with Timelog Depths) I 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time Tim our tv) Phase Op Code Activity Code Time P -T -X Operation (AKS) End Depth(ftKB) 10/212017 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/O, 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-btm. 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 10/312017 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 % FIO, ECD 11.97 ppg, MW 9.2 ppg. Rotate at 160 rpm with 9k Tq on-btm, 8k Tq off-btm. 3k WOB. PUW 168k, unable to slackoff, ROT 106k. Max gas 279 units. ADT 3.87 hrs, Bit 44.17 hrs, Jar 86.15 hrs. Concretions drilled at 13548' - 13553', 13686'- 13692', 13731'- 13739', 13750'- 13762', and 13771'- 13774'. Page 57179 Report Printed: 10130/2017 Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log shad DepN Slart Time Ertl 7me Dur (hr) Phase Op Cote Arlivity Code Time P -T -X Opwa6on (fiK8) End Depth (MKB) 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 TD of 14686' MD, 3844' TVD. Pump at 272 gpm, 2770 psi, 21 % F/O, ECD 11.86 ppg, MW 9.2 ppg. Rotate at 180 rpm with 9.5k Tq on-btm, 8k Tq off- btm. 3k 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',14115'- 14123', 14126' -14129', 14170' - 14177', 14201' - 14207',14217- - 14222', 14335'- 14349',14449- - 14450', 14466'- 14474', 14540'- 14562', and 14663'- 14668' 10/3/2017 10/3/2017 1.50 PROD4 CASING CIRC P Obtain final parameters, downlink 14,686.0 14,615.0 18:30 20:00 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' ND, 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. 10/312017 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' MO 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 I I Operations Summary (with Timelog Depths) IH-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log SW Depth Start Time End Time D.(hr) Phase Op Code Amotycode Time P-T-X Operation (W) End Depth(fd(B) 10/4/2017 10/4/2017 0.75 PROD4 CASING TRIP P Trip out of hole on elevators from 7,980.0 7,593.0 11:30 12:15 7980' to 7593', observing no issues or drag pulling BHA through window. PUW 118k, SOW 85k 10/4/2017 10/4/2017 1.25 PROD4 CASING CIRC P Circulate bottoms up while 7,593.0 7,593.0 12:15 13:30 reciprocating from 7593'to 7503' with 270 gpm, 1815 psi, 20% F/O, 120 rpm, 3.3k Tq, ECD 10.25 ppg, MW in/out 9.2ppg. Total of 3905 strokes pumped. PUW 112k, SOW 86k. 10/4/2017 10/4/2017 0.50 PROD4 CASING OWFF P 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 Slip/cut drilling line. Calibrate blocks 7,593.0 7,593.0 14:00 15:30 and service rig. 10/4/2017 10/412017 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 10/412017 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.Stabilizers 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 10/4/2017 0.50 PROD4 CASING BHAH P Clean and clear floor of BHA 0.0 0.0 19:00 19:30 equipment. 10/4/2017 10/4/2017 1.00 COMPZ4 FISH BHAH P PJSM. Make up L-3 whipstock 0.0 229.0 19:30 20:30 retrieval BHA, scribe MWD, and RIH to 229' 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. 10/4/2017 10/4/2017 0.25 COMPZ4 FISH DHEO P Fill pipe and shallow hole test MWD 2,120.0 2,120.0 21:30 21:45 with 250 gpm, 940 psi, 19% F/O - good test. 10/4/2017 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 6050' MD, monitoring displacement via trip tank. OA pressure at midnight = 0 psi. Downhole losses for past 24 hours = 95 bbls. Page 59179 ReportPrinted: 10/3012017 Operations Summary (with Timelog Depths) 1H-102: *g: DOYON 142 Job: DRILLING ORIGINAL Time Log star Depth sled Tsne End Time Dur(hr) Phase Op Code ActivityCode Time F0-T-X Operefion (flKB) End Depth(IRKS) 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 00:45 079, fill pipe, and obtain parameters. PUW 143k, SOW 109k with pumps off, PUW 1381k and SOW 107k with pumps on at 251 gpm. Pump at 251 gpm, 1358 psi, 17% F/O and orient to 155° right. RIH and jet retrieval slot (retrieval slot 5.23' down from top of whipstock). Pick up above top of whipstock and orient to 22" left. RIH and set down 8k on bottom of retreival slot with hook right on depth. Pick up and confirm latched. Kill pump and 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 COMPZ4 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 BHAH P Lay down L3 whipstock BHA per 76.0 0.0 07:30 10:30 Baker. Observe mill pattern extend past bottom of slide to bottom of whipstock (-tft). Clean and clear rig floor of whipstock BHA. 10/5/2017 10/5/2017 1.00 COMPZ4 WHDBOP RURD P Flush and drain stack, pull 0.0 0.0 10:30 11:30 wearbushing, and install test plug. Rig up 4-1/2" test joint and test assembly. Purge air out of lines with freshwater. Page 60179 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1H-102 W Rig: DOYON 142 Job: DRILLING ORIGINAL Tine Log sten Depth StaM1Tme End Time Dur" Phase Op Code Activity Code Time P-T-X Opemocn (PI03) End Depth (MB) 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" lest 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 H2S sensors, PVT and flow alarms both audio and visual, and functioned primary and remote BOP controls - all good. Upper 7-5/8" rasing rams not tested. 10/5/2017 10/W017 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: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time ciir (hr) Phase op cod. Activity code Time P -T -x Operation start ceph (ftKB) End Depth dtKB) 10/6/2017 10/6/2017 1.50 COMPZ4 CASING PUTS P Run in hole with 4-1/2' 11.6# L-80 6,168.0 6,996.0 00:00 01:30 IBTm slotted liner / 4-1/2" 12.6# L-80 TXPm blank liner per tally from 6168' to 6996' MD, monitoring displacement via trip tank. MUT of IBTm = 4500 ft - lbs. MUT of the blank 12.6# L-80 TXPm joints = 7000 ft -lbs. Install 1 x 6- 1/8" Voiant thick-walled centralizer free-floating on each joint. Pick up 1 x Baker 6" OD swell packer (2.67' element) with centralizer above and below. PUW 95k, SOW 72k. 10/6/2017 10/6/2017 1.00 COMPZ4 CASING OTHR P Pick up MWD collar and install 6,996.0 .7,030.0 01:30 02:30 Slimpulse tool. Pick up Baker B-3 Flanged Hook hanger and M/U per Baker. Scribe MWD to 180" off from hook, toolface offset = 303.55°. Run in hole to from 6996' tp 7030' MD. 10/6/2017 10/6/2017 0.25 COMPZ4 CASING RUNL P Run 1-3 lower completion in hole on 4" 7,030.0 7,600.0 02:30 02:45 DP stands from derrick from 7030'to 7600' MD, monitoring displacement via trip tank. 10/6/2017 10/6/2017 0.25 COMPZ4 CASING DHEQ P Circulate through running tools and 7,600.0 7,600.0 02:45 03:00 shallow hole test MWD tool with 90 gpm, 260 psi, 11% F/O - good test. 10/6/2017 10/6/2017 4.00 COMPZ4 CASING RUNL P Run L3 lower completion in hole on 4" 7,600.0 14,622.0 03:00 07:00 DP l4" 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 it, run in and re-engage hook on window at same depth, set down 20k. Confirm orientation at 8° left. 10/6/2017 10/6/2017 0.75 COMPZ4 CASING CIRC P Drop 29/32" phenolic ball and pump 14,668.0 7,644.0 08:00 08:45 down at 127 gpm, 825 psi, 12% F/O for 300 strokes, then 86 gpm, 500 psi, 9% F/O for 200 strokes, then 64 gpm, 375 psi, 8% F/O for 100 strokes, then 43 gpm, 276 psi, 4% F/O to seat ball - seat at 635 strokes. Pressure up to 3500 psi to release from hook hanger and hold for 1 minute. Continue pressuring up to shear out ball seat, observe shear at 4270 psi (pinned for 4000 psi). Pick up and confirm released from hook hanger with PUW 143k. Confirm circulation with 85 gpm, 300 psi, 8% F/0. Top of hook hanger at 7644.62' MD. Page 62179 ReportPrinted: 1013012017 f Operations Summary (with Timeiog Depths) ANft� 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stan-Time I End Tone We (hr) Phase Op Cade Activity Code Time PJA Operation (fIKB) End DepN(fIKB) 10/6/2017 10/6/2017 0.25 COMPZ4 WELLPR OWFF P Monitor well for flow and confirm 7,644.0 7,644.0 08:45 09:00 static. 10/6/2017 10/6/2017 2.50 COMPZ4 WELLPR TRIP P Trip OOH on elevators from 7644'to 7,644.0 0.0 09:00 11:30 surface, racking back 4" HWDP and 4" DP, monitoring displacement via trip tank. 10/6/2017 10/6/2017 0.50 COMPZ4 WELLPR BHAH P Lay down SLB Slimpulse MWD and 0.0 0.0 11:30 12:00 Baker running tools. 10/6/2017 10/6/2017 0.50 COMPZ4 WELLPR BHAH P Clean and clear rig floor of running 0.0 0.0 12:00 12:30 tools. 10/6/2017 10/6/2017 1.50 COMPZ4 RWRID RURD P Rig up GBR torque turn and casing 0.0 0.0 12:30 14:00 equipment for running LEM. 10/6/2017 10/6/2017 2.50 COMPZ4 RWRID PUTB P PJSM. Make up LEM / 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 it -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 topdrive. 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 DHEO 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 . tum on. Confirm setting for gravity toolface - all good. 10/612017 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 Wit, 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/0. Increase rate to 120 gpm, 974 psi, 12% F/0 with no sign of signal to MWD - cycle pumps and increase rate to 132 gpm, 1024 psi, 12% F/0 and observe pressure drop to 800 psi and tool start transmitting signal. Page 63179 Report Printed: 1013 012017 Operations Summary (with Timelog Depths) Awlh: 11-1-1102 W Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time CMTime DW(hr) Phase Dip Code Actimy Code Time P-T-X Dperalion (Win End Depth MMB) 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 bbls 10/7/2017 10/7/2017 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 -6k seal drag through SBE. Latch LEM into hook hanger on depth @ 7644.62' MD, set down 15K, observed tool face roll from 80 Deg L to 28 Deg L. Pick up 1 OK over. Set down 20K then pulled 15K over to confirm LEM latched into hook hanger, good. Tool face still @ 28 deg L. 10/7/2017 10/7/2017 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 1017/2017 0.50 COMPZ4 RWRID PRTS P P/U 3'@ 143K P/U, Gose annular 7,753.1 7,751.0 01:00 01:30 preventer and pressure test ZXP liner top packer to 3500 psi f/ 10 min on chart, good. 10/7/2017 1017/2017 0.75 COMPZ4 RWRID CRIH P Spot corrosion inhibited brine f/ 7751' 7,751.0 7,639.0 01:30 02:15 MD to 7639' MD(calc TOW @ 7376' MD) Pumped 25 bbls of C1 brine followed by 73 bbls of drilling mud, pumped @ 255 gpm=870 psi. 10/7/2017 10/7/2017 0.50 COMPZ4 RWRID OWFF P OWFF 1130 min, static to 2" below 7,639.0 7,639.6- 02:15 02:45 flowline. 101712017 10/7/2017 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 bbls. (4.7 bbl loss) 1017/2017 j 10/7/2017 1.00 COMPZ4 RWRID BHAH P LID Baker running tools and SLB 0.0 0.0 05:15 06:15 i i MWD. 10/7/2017 10/712017 1.50 PROD5 WHPST BHAH P Mobilize L4 whipstock BHA to rig floor. 0.0 0.0 06:15 07:45 I Page 64179 Report Printed: 1013012017 Operations Summary (with Timelog Depths) AR0 1 I 1H-102 qW Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Star[Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth m(S) 10/7/2017 10/7/2017 3.00 PROD5 WHPST BHAH P PJSM. M/U Milling BHA as per Baker. 0.0 319.0 0745 10:45 M/U window mill, lower and upper mills, 1 HWDP, XO, float sub and SLB slimpulse. Scribe MWD to window mill, 187 Deg tool face offset. Stand milling easy back in derrick. P/U Baker Whipstock and built anchor assy below as per BHA order. M/U milling easy to whipstock assy 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 1017/2017 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 test MWD tool with 205 1,350.0 1,350.0 11:30 11:45 gpm, 490 psi, 15% Flo - good test. Blow down top drive. 10/7/2017 10/7/2017 4.25 PROD5 WHPST TRIP P Trip in hole on 4" DP l4" HWDP 1,350.0 7,360.0 11:45 16:00 stands from 1350'to 7360' MD, running speed of 60 ftfmin, monitoring displacement via trip tank. Calculated displacement = 49.6 bits, Actual displacement= 45.5 bbls (4.1 bbl loss) 10/7/2017 1017/2017 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 1O 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 Bim of window @ 7390.60' MD Page 66/79 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sled Depth SM Time End Tune Dor(hr) Phase Op Code ActivityCode Time P-T-X Opemhon IKe) End Depth(aKa) 10/7/2017 101812017 6.25 PROD5 WHPST MILL P Establish parameters with 282 gpm, 7,377.0 7,394.0 17:45 - 00:00 1509 psi, 19% FfO, 80 rpm, 3.5k Tq. Mill window per Baker from 7377'to 7394' MD with 282 gpm, 1560 psi, 20% FIO, 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 1-4 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 131 k, 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% F/O, 100 rpm, 3k Tq. Observed moderate increase in metal cuttings at surface as sweep came around. Kill rotary and drop rate to 1 bpm, 430 psi, 3% F/O. Trip through window with no issues, observed 0-1k drag. PUW 135k, SOW 109k. Pull up above window to 7348' MD. 10/8/2017 10/8/2017 0.50 PROD5 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' TVD) using 9.2ppg FloPro. Close annular, pump doom drill pipe and IA with mud pump #1. Pressure up to 739 psi and shut in, observe pressure drop to 590 psi after 10 minutes. Pumped 1.4 bbls, returned 1.0 bbls. Blowdown lines. 10/8/2017 0.50 PRODS WHPST OWFF P Monitor well for flow -well static. 7,348.0 7,348.0 06:45 10/8/2017 0.25 PRODS WHPST TRIP P Trip OOH from 7348' to 6810' MD, 7,348.0 6,810.0 r06:45 07:00 monitoring displacement via trip tank.10/812017 0.25 PROD5 WHPST CIRC P Pump dry job. 6,810.0 6,810.0 07:15 10/8/2017 2.25 PROD5 WHPST TRIP P Trip OOH from 6810'to 232'MD, 6,8100 232.0 09:30 racking back 4" HWDP and 4" DP, monitoring displacement via trip lank. Page 66179 Report Printed: 10/30/2017 e Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EM Imre Dm(hd Phase Op Code Acdvlty Code lime P -T -X Operation Start Depth (IME) End Depth(Po(B) 10/8/2017 10/8/2017 1.50 PRODS WHPST SHAH 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 6-518" Mill - 1/4" undergauge Window 63/4" Mill - 3/8" undergauge 10/8/2017 10/8/2017 0.50 PRODS WHPST WWWH P Make up stackwasher and jet stack. 0.0 0.0 11:00 11:30 SIMOPS - Clean and clear dg floor of BHA components. 10/8/2017 10/8/2017 0.50 PRODS 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 PRODS WHPST BHAH 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 10/812017 0.25 PRODS WHPST TRIP P Trip in hole from 897'to 1840' MD, 897.0 1,840.0 15:00 15:15 monitoring displacement via trip tank. 10/8/2017 10/8/2017 0.75 PRODS WHPST DHEQ P Shallow hole test MWD with 209 gpm, 1,840.0 1,840.0 15:15 16:00 782 psi, 18% F/O - good test. Blowdown 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 x stands. PUW 116k, SOW 86k. 10/8/2017 10/8/2017 0.50 PRODS 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 PRODS 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 1 Ok weight. Page 67/79 Report Printed: 10130/20171 1 - Operations Summary (with Timelog Depths) t , 1 H-102 qW Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Ti= End Tim Write) Phase Op Code AcfiWty Code Time P -T -X Operation (like) End Depth(ftl(B) 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-blm, 3k Tq off- btm. 3-18k WOB. PUW 116k, SOW 82k, ROT 92k. AST 2.29 hrs, ADT 2.8 hrs, Bit 12.59 hrs, Jars 94.05 hrs. Displace milling fluid out of well with new/used 9.2 ppg FloPro at 7477' MD. Concretions drilled from 7412'- 7419', 7428' - 7432', 7434' - 7440', and 7450' to 7453'. Utilize rig's twister system to help transfer weight down to bit when sliding through concretions. SPRs @ 7430' MD 3750' TVD, MW=9.25 ppg, 21:30 hours MP#1: 20 spm=550 psi, 30 spm=720 psi. MP #2:20 spm=550 psi, 30 spm=720 psi. OA pressure at midnight = 0 psi Downhole losses for past 24 hours = 2 bbls 1019/2017 10/9/2017 2.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 7,524.0 7,650.0 00:00 02:00 from 7524' MD to TO of 7650' MD, 3815' TVD. Pump at 231 gpm, 1352 psi on-btm, 1270 psi off-btm, 17% F/O. Rotate at 40 rpm with 3-4k Tq on- btm, 3k Tq off-btm. 3-18k WOB. PUW 116k, SOW 82k, ROT 93k. AST .86 hrs, ADT 1.09 hrs, Total Bit 13.68 his, 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 0.50 PROD5 DRILL BKRM P Backream OOH f/ 7650' MD to 7525' 7,650.0 7,525.0 02:00 02:30 MD, Rotate @ 40 rpm's w/ 3 K Tq, 110/9/2017 pump @ 230 gpm= 1270 psi, ROT= 96K. 10/9/2017 10/9/2017 0.25 PROD5 DRILL CIRC P Orient motor to 20 deg L @ 7525' MD, 7,525.0 7,525.0 02:30 02:45 before BHA enters the slide. 10/9/2017 10/9/2017 0.25 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: 1 013 012 01 7 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan DepN Start Time EM Time Dur(h) Phase Op Code Activity Code Tune P -T -X Operation (IKB) End Depth(HKS) 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 08:00 697', 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 bbis, Actual displacement = 44.5 bbis. 10/9/2017 10/9/2017 1.50 PROD5 DRILL BHAH 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. 10/912017 10/9/2017 1.00 PROD5 DRILL BHAH P PJSM. Make up 14 RSS drilling BHA 0.0 307.0 10:00 11:00 per SLB to 307' MD, monitoring displacement via trip tank. 10/9/2017 1019/2017 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. 10/912017 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/0 - 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 110k, 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 025 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 drag observed tripping bit across window. PUW 114k, SOW 83k. Calculated displacement = 53 bbis, Actual displacement = 53.6 bbis. 10/9/2017 10/912017 0.25 PROD5 DRILL CIRC P Fill pipe and obtain slow pump rales. 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 fUhr with 200 gpm, 1000 psi, 14% F/O. Stop and shoot surveys per DD. Observe 1-6 k drag while washing down. Page 69179 Report Printed: 10/301'20117 Operations Summary (with Timelog Depths) IH -102 ... Rig: DOYON 142 Job: DRILLING ORIGINAL Trine Log SW Depdt Start Time End Time Dur(hr) .Phase Op Cade Activity Code Time P -T -X Operation (MKB) End Depth (MB) 10/9/2017 10/10/2017 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-blm, 2k Tq off-btm. 3k WOB. PUW 109k, SOW 81k, 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 PROD5 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-blm. 3k WOB. PUW 11 Ok, SOW 76k, ROT 92k. Max gas 105 units. ADT 4.98 hrs, Bit 8.78 hrs, Jars 103.94 hrs. SPRs @ 7976' MD 3744' TVD, MW=9.2 ppg, 00:30 hours MP#1: 20 spm=370 psi, 30 spm=550 psi. MP #2: 20 spm=380 psi, 30 spm=510 psi. 10/10/2017 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/O, 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 10110/2017 6.00 PROD5 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 71 k, ROT 93K. Max gas 425 units. ADT 5.9 hrs, Bit 18.13 hrs, Jars 113.29 hrs. SPRs @ 7,728' MD 3,753' TVD, MW=9.3 ppg, 13:30 hours MP#1: 20 spm=460 psi, 30spm=650 psi. MP #2: 20 spm=460 psi, 30 spm=640 psi. Page 70179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) =I; 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slat Time End Time Our(hr) Phase op Code Activity Code Time P-T-x Operation SWDep"' W113) Entl 0epm (flKB) 10/10/2017 10/11/2017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 9,265.0 9,653.0 18:00 00:00 from 6,265' MD 3,763' TVD - 9,653' MD 3,774' TVD. Pump at 275 gpm, 1,896 psi, 21% F/O, ECD 10.61 ppg, MW 9.3 ppg. Rotate at 150 rpm with 6k TQ on-btm, 5k TQ off-btm. 1-5K 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. 10/112017 10/11/2017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 9,653.0 9,850.0 00:00 06:00 from 9,653' MD 3,774' TVD - 9,850' MD 3,777' TVD . Pump at 275 gpm, 1,896 psi, 21 % F/O, ECD 10.61 ppg, MW 9.3 ppg. Rotate at 150 rpm with 6k TQ on-btm, 5k TQ off-blm. 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. 10/112017 10/11/2017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 9,850.0 10,065.0 06:00 12:00 from 9,850' MD 3,777' TVD - 10,065' MD 3,777' TVD . Pump at 277 gpm, 1,948 psi, 21 % F/O, ECD 10.52 ppg, MW 9.2+ ppg. Rotate at 120 rpm with 6k TQ on-btm, 5k TO off-btm. 1-5K WOB. UP WT = 119K, DWN WT = 70K, ROT 92K. Max gas 44 units. ADT 4.19 hrs, Bit 26.75 hrs, Jars 126.91 hrs. 10/11/2017 10/112017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 10,065.0 10,537.0 12:00 18:00 from 9,850' MD 10,065' MD 3,777' TVD - 10,537' MD 3,760' TVD . Pump at 272 gpm, 1,990 psi, 21% F10, ECD 10.52 ppg, MW 9.2+ ppg. Rotate at 120 rpm with 7K TO on-blm, 6K TQ off -btm. 2K WOB. UP WT = 122K, DWN WT = 68K, ROT 93K. Max gas 259 units. ADT 4.48 hrs, Bit 36.23 hrs, Jars 131.39 hrs. SPRs @ 10,156"' MD 3,771' TVD, MW=9.2+ ppg, 13:15 hours MP#1: 20 spm=460 psi, 30 spm=660 psi. MP #2: 20 spm=440 psi, 30 spm=590 psi Page 71179 Report Printed: 10130/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log stall Tuns End Tima �f (hf) Phase Op Catle Activity Code Tune P -T -X Operation start Depth (MB) End Depth (MKB) 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-blm, 6K TO off-btm. 2-5K WOB. UP WT = 123K, OWN WT = 67K, ROT 94K. Max gas 185 units. ADT 5.21 hrs, 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 froml0,792' 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, 61K TO 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 PRODS DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 10,980.0 11,535.0 06:00 12:00 from10,980' MD 3,791' TVD - 11,535' MD 3,802' TVD. Pump at 272 gpm, 2.200 psi, 21 % F/O, ECD 11.7 ppg, MVV 92+ 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 146.56 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, 71K 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 Report Printed: 1 013 012 01 7 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slat Depth Start Tune Ed Tune Wr(hr) Phase Op Code Activity Code Time P -T -X Operation MKI31 End Deplh(WS) 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% NO, ECD 11.41 ppg, MW 9.2+ ppg. Rotate at 120 rpm with 9K TQ on-btm, 8K TO off-btm. 2,380 PSI off BTM 2-5K WOB. UP WT = 139K, DWN WT = 52K, ROT 94K. Max gas 261 units. ADT 4.91 hrs, Bit 60.94 hrs, Jars 156.1 hrs. 10/13/2017 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 9K TQ on-btm, 7K TO off-blm. 2,380 PSI off BTM 2-5K WOB. UP WT = 154K, DWN WT = 56K, ROT 106K. Max gas 93 units. ADT 4.57 hrs, Bit 65.51 hrs, Jars 160.67 hrs. 10/13/2017 10/13/2017 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 12,921.0 13,217.0 06:00 12:00 from12,921' MD 3,808' TVD - 13,217' MD 3,813' TVD . Pump at 279 gpm, 2.550 psi, 23% F/O, ECD 11.48 ppg, MW 9.2+ ppg. Rotate at 100 rpm with 9K TQ on-blm, 7.5K TQ off-btm. 2,500 PSI off BTM 1-6K WOB. UP WT = 154K, DWN WT = 56K, ROT 106K. Max gas 178 units. ADT 4.89 hrs, Bit 70.40 hrs, Jars 165.56 hrs. SPRs @ 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 fmml3,217' MD 3,813' TVD - 13,476' MD 3,796' TVD . Pump at 277 gpm, 2.597 psi, 23% F/O, ECD 11.62 ppg, MW 9.2+ ppg, Rotate at 120 RPM with 9K TQ on-btm, 8K TO off-blm. 2,572 PSI off BTM 1-61K 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: 1013012017 Operations Summary (with Timelog Depths) 111-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start TBne End Time our (hr) Phase Op Code Adiv4 Cade Time P -T -X Operation (ILM) End Depth(flKa) 10/13/2017 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/O, ECD 11.62 ppg, MW 9.2+ ppg, Rotate at 120 RPM with 9K TQ 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 10/14/2017 6.75 PROD5 DRILL DDRL P Directionally drill 6-3/4" 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/0, 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, DWN WT= K, ROT 119K. Max gas 150 units. ADT 5.07 hrs, Bit 84.97 his, 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 10114/2017 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, 81K TQ with 11.45 ECD. STKS PUMPED=4,618. MWI/0=9.3 PPG. UP WT = 178K DNW = K, ROT 119K. 7.8K TQ. SPRs @ 14,670" MD 3,780' TVD, MW=9.3 ppg, 08:00 hours MP#1: 20 spm=660 psi, 30 spm=920 psi. MP #2: 20 spm=670 psi, 30 spm=920 psi 10/14/2017 10/14/2017 0.50 PROD5 CASING OWFF P OWFF dropped 18". 14,670.0 14,670.0 08:00 08:30 10/14/2017 10/14/2017 3.50 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/0 @120 RPM, 7.3K TQ. 11.18 EC, UP WT=150K DWN WT=61 K. DWN WT @ 14,250'= 50K 13,793' MD = 64K. 10114/2017 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/O @120 RPM, 6K TQ. 10.8 ECD, UP WT = 92K @ full pump rale 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 ReportPrinted: 1 0/3 012 01 7 Operations Summary (with Timelog Depths) 77 IH-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Tme End Tmie Dur (hr) Phase Op Coda Activity Code Time P4A Operation (ftKB) End Depth Qtl(B) 10/15/2017 10/15/2017 1.75 PROD5 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 10K DWN WT. Bring on pumps to circulate possible fill/junk. PU to 130K UP WT for check. 3X jar licks down to free up. RIH Ito, 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 PROD5 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 PROD5 CASING OWFF P OWFF. 7,223.0 7,223.0 03:00 03:15 10/15/2017 10/15/2017 0.25 PROD5 CASING SVRG P Service crown/top drive. 7,223.0 7,223.0 03:15 03:30 10/15/2017 10/15/2017 0.50 PROD5 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 PROD5 CASING SHAH 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 PROD5 CASING BHAH P Clear rig floor of SLB tools BHA #26 0.0 0.0 12:00 12:45 and clean same. 10/15/2017 10/152017 1.50 COMPZ5 FISH BHAH P MU hook BHA #27 as per Baker Rep. 0.0 225.0 12:45 14:15 UP WT =47K DWN WT 52K. Monitor - disp via TT. 10/15/2017 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 how, test MWD at 1,650' with 252 GPM PSI 1,681. 28% F/O. (PASSED). 10/1512017 10/152017 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. Attempt to straight pull with 80K over.. NOPE. Jar 1X 20K, 40K, 60K over before release. UP WT= 138K. 10/15/2017 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 10/152017 10/152017 0.50 COMPZ5 FISH OWFF P OWFF. static 7,350.0 7,350.0 20:00 20:30 10/15/2017 10/16/2017 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 FISH TRIP P Continue to POOH with Whipstock2,220.0 319.0 00:00 01:30 fishing assym from 2,200' MD to 319' MD. Monitor disp via TT. - Page 75/79 Report Printed: 10/3012017 !> Operations Summary (with Tirnelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Tim Dur(hs) Phase Op Code Activity Code Time P -T -X Operation (NCB) End Depth (W) 10/16/2017 10/16/2017 2.25 COMPZ5 FISH BHAH 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 10116/2017 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 dg 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 lest handeling equipment. Make up same. 10/16/2017 10116/2017 0.75 COMPZ5 CASING PUTB P RIH with 41/2" 11.6# L-801BTM/TXP - 0.0 254.0 05:30 06:15 slotted / Blank lower liner asym as per detail to 254' MD. Installing cent on all joints as per program. TQ /BTM to 4.5K FT/LB 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 1/2" 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 10/16/2017 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 Conflnue to RIH with liner as per tally. 7,285.0 8,795.0 16:00 - 18:00 Monitor disp via TT. 10/1612017 10116/2017 0.50 COMPZ5 CASING DHEQ P Shallow hole lest MWD. 100 GPM @ 8,795.0 8,795.0 18:00 18:30 353 PSI DPP. 10% 17/0 (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% FIO. 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/O. slow rale to 62 GPM, 375 PSI with 7 1/2 FO/ at 400 SKS. 10/17/2017 10/17/2017 0.50 COMPZ5 CASING CIRC P Continue to pump 29132" 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. 10/1712017 10/17/2017 0.25 COMPZ5 WELLPR OWFF P OWFF 10 min. Dropped 1'. 7,351.0 7,351.0 00:30 00:45 10/17/2017 10/17/2017 0.75 COMPZ5 WELLPR CIRC P PUH to 7,190' MD and pump dry job. 7,351.0 7,190.0 00:45 01:30 1 Install strippin 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: 10/30/2017 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Shad Tim End Time ow(hr) Phase Op Code Activity Code Time P -T -X Operation WS) End Depth(WEI) 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. 10/1712017 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 10/1712017 2.25 COMPZ5 RWRID PUTS P MU L-4 LEMIZXP and scribe as per 0.0 255.0 07:15 09:30 1 BKR and SLB Rep. Monitor DISP via TT. 10/17/2017 1011712017 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 lest MWD at 103 GPM 1,667.0 1,667.0 10:30 11:00 350 PSI w/10% F/O. (PASSED) BD - TD 10/17/2017 10/17/2017 3.25 COMPZ5 RWRID RCST P Continue to RIH from 1,667' MD - 1,667.0 7,459.0 11:00 14:15 7,459' MD. UP WT = 137K DWN WT = 107K Monitor disp via TT. 10/1712017 10/17/2017 1.75 COMPZ5 RWRID PACK P Kelly up and orient to 30 DEG left 7,459.0 7,495.0 14:15 16:00 High side @ 127 GPM 785 PSI, 13% F/O. Wash down and set LEM as per BOT REP. Drop 1.625" ball to set ZXP PKR and release running tool. Pump down at 150 GPM 954 PSI with 13% F/O Ball on seat at 520 STKS. Pressure up to 2,600 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 lop 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/0. Chase with 9.4 PPG brine with 150 GPM. ICP = 650 PSI DPP FCP = 376 DPP. 11% F/O total stks 3,748. Continue to pump and spot 25 BBL hich vis pill at liner top packer with 150 GPM 443 PSI DPP 10% F/O total stks pumped= 939 BD TD with simops of UD 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. DWN WT = 80K. 10/18/2017 10/18/2017 5.50 COMPZ5 RWRID PULD P Continue pulling out of hole F13,952' 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 dawn ZXP running tool. Clear and 40.0 0.0 05:30 06:15 clean rig floor. Page 77179 ReportPrinted: 1 013 0/2 01 7 -; Operations Summary (with Timelog Depths) I H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth I Start Time End Time Dw(hr) Phase Op Corte Activity COCe Time P-T-X Operation W13) End Depth(fll(B) 10/18/2017 10/18/2017 2.50 COMPZ5 EVALWB ELOG P PJSM / Rig up SLB E-Line toolsat 0.0 O.0 06:15 08:45 surface. Test tools prior to running in hole. Monitor well via trip tank. 10/18/2017 10/1812017 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 Sialic fluid loss 54 bbls. 10/18/2017 10/18/2017 7.75 COMPZ5 EVALWB ELOG P POOH logging with Usit and CBL from 6,950.0 0.0 12:00 19:45 6,950' MD. Monitoring Displacement via TT. 10/18/2017 10/18/2017 1.25 COMPZ5 EVALWB ELOG P RD SLB wieline and Wellteh 0.0 0.0 19:45 21:00 1 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 10118/2017 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 1830 hrs.)). 10/1912017 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 PUTS 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 mode to 7K ft/LB. UP WT=98K DWN WT= 76K. Witnessed drag as stinging into seal asym and tagged up at 7,292' with I OK OWN. 10/19/2017 10/1912017 1.25 COMPZ5 RPCOMP PRTS P Close Ann and lest sealbore seals 7,292.0 7,292.0 20:00 21:15 down IA t/500 PSI. (GOOD) 10/19/2017 10/19/2017 0.75 COMPZ5 RPCOMP THGR P Terminate tech wire for SLB pressure 7,260.0 7,260.6- 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 I 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. 10/20/2017 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 78/79 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Start Time End Time Dur (ht) Phase Op Code Activity Code Time P-T-% Operation {We) End NPM(ftKB) 10/20/2017 10120/2017 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 10120/2017 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 WHDBOP NUND P Clean out hanger void. Nipple up 0.0 0.0 07:30 09:15 production tree. 10/20/2017 10/2012017 0.75 COMPZ5 WHDBOP PRTS P Test hanger void to 5,000 psi for 15 0.0 0.0 09:15 10:00 1 1 min. Good test. 10/20/2017 10/2012017 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 12:00 250/5,000 for 10 min each. Tests good and tests charted. Rig down from test. 10/20/2017 10/20/2017 0.50 COMPZ5 WHDBOP MPSP P Pull BPV and prep for FP 0.0 0.0 12:00 12:30 10/20/2017 10/20/2017 1.50 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 rig down. 10120/2017 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 I 10/20/2017 10/21/2017 8.00 COMPZ5 MOVE MOB P MovetolH-111 0.0 0.0 16:00 00:00 Page 79179 ReportPrinted: 1013012017 NADConversion Kuparuk River Unit Kuparuk 1H Pad 1H -102L2 IH -102L2 ConocoPhillips Definitive Survey Report 03 October, 2017 ConocoPhillips Conocolohillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 1 H-102 Project: Kupamk River Unit TVD Reference: iH-102 actual @ 92.62usft (Doyon 142) Site: Kupamk 1 H Pad MD Reference: iH-102 actual @ 92.62usft (Doyon 142) Well: Rig: 1H-102 North Reference: True Wellbore: 11-1-10212 Survey Calculation Method Minimum Curvature Design: 11-1-1021-2 Database: OAKEOMP2 'roject Kuparuk River Unit, North Slope Alaska, United States lap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level leo 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: From To Well Position +N/ -S 0.00 usft Northing: 5,980,662.56 usft Latitude: 70° 21'28.630 N +N/ -S +E/ -W 0.00 usft Easting: 549,577.46 usft Longitude: 149" 35'50.423 W Position Uncertainty 0.00 0.00 usft Wellhead Elevation: usft Ground Level: 54.00 usft fellbore IH -10212 tagnescs Nodal Name Sample Date Declination Dip Angle Field Strength 11 (1 (nT) BGGM2017 9/21/2017 1748 80.95 57,490 Design 1H-10212 Data Audit Notes: From To Map Version: 1.0 Phase: ACTUAL Tie On Depth: 7.768.14 Vertical Section: Depth From (ND) +N/ -S +E/ -W Direction 1,009.26 1H-102 Srvy 1 - SLB GWD70 (1 H-102) (usR) (usft) (usft) (') 1,050.36 38.62 0.00 0.00 0.00 Survey Program Data From To Map Map (usft) (usft) Survey (Wellbore) Tool Nana Description Survey Date 67.62 1,009.26 1H-102 Srvy 1 - SLB GWD70 (1 H-102) GYD-GCSS Gymdata gyro single shots 8/24/2017 10:04 1,050.36 1,678.041H-102 Srq 2- SLB _MWD+GMAG If H- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 8/24/201710:12 1,777.33 7,768.141H-102 Srvy 3 -SLB MWD+GMAG(1 H- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 8/271201712:16 7,845.00 7,954.97 1H-10212 Srvy 1 - SLB _MWD -INC Filler MWO4NC ONLY MWD -INC -ONLY -FILLER 9/21/2017 2:59:, 8,014.35 13,373.641H-1021-2 Srvy 2-SLB_MWD+GMAC It MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 9/22/2017 3:02: 10737201711:29:45AM Page 2 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (°) 11 (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 38.62 0.00 0.00 3862 -54.00 0.00 0.00 5,980,662.56 549,577.46 0.00 0.00 UNDEFINED 67.62 0.19 41.29 67.62 -25.00 0.04 083 5,980,66260 549,577.49 0.66 0.04 GYD-GCSS(1) 165.90 045 132.01 165.90 7328 -0.10 043 5,980,662.46 549,577.89 0.50 -0.10 GYD-GCSS(1) 258.98 1.01 128.15 258.97 165.35 -0.85 1.34 5,980,661,72 549,578.81 0.60 -0.85 GYD-GCSS(1) 354.48 3.34 138.19 354.40 26178 -3.44 3.86 5,98(1,659.14 549,581.34 2.46 -3.44 GYD-GC-SS(1) 447.17 4.61 135.26 446.86 354.24 -8.10 8.28 5,980,654.51 549,585.79 1.39 -8.10 GYD-GC-SS(1) 539.82 5.77 132.42 539.13 446.51 -1389 14.34 5,980,648.77 549,591.89 1.28 -13.89 GYD-GC-SS(1) 632.64 7.61 134.49 631.51 538.89 -21.36 22.19 5,980,641.35 549,599.79 1.99 -21.36 GYD-GC-SS(1) 725.82 8.77 137.82 723.54 630.92 -30.93 31.34 5,980,631.84 549,609.00 1.35 -30.93 GYD-GC-SS(1) 821.24 10.73 141.32 817.58 724.96 43.25 41.78 5,980,61959 549,619.52 2.15 43.25 GYD-GC-SS(1) 10737201711:29:45AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConvereon Local Co-ordinate Reference: Well Rig: 1H-102 Project: Kupamk 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: 11-1-102 North Reference: True Wellbore: 11-1-1021.2 Survey Calculation Method: Minimum Curvature Design: 11-1-1021-2 Database: OAKEDMP2 Survey 1OW01711:29:45AM Page 3 COMPASS 5000.14 Build 86 Map Map Vertical MD Inc Azi TVD TVDSS -NIS +E/ -W Northing Easting DLS Section (usft) (1) 0 (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 914.20 12.89 139.61 908.57 815.95 -57.91 53.90 5,980,60501 549,63174 2.35 -57.91 GYD-GC-SS(1) 1,009.26 14.89 136.85 1,000.84 908.22 -74.90 69.13 5,986,588.13 549,647.08 2.22 -74.90 GYD-GCSS(1) 1,050.36 15.72 135.96 1,040.49 947.87 -82.75 76.61 5,980,580.32 549,654.61 2.10 -82.75 MWD+IFR-AKCAZSC(2) 1,144.89 17.17 134.37 1,131.15 1,038.53 -101.72 95.49 5,983,56149 549,673.61 1.61 -101,72 MWD+IFR-AKCAZ-SC(2) 1,239.16 20.84 134.25 1,220.26 1,127.64 -123.16 117.46 5,980,540.20 549,695.72 3.89 -123.16 MWD+IFR-AKCAZ-SC(2) 1,334.20 24.71 136.54 1,307.88 1,21526 -149.38 143.24 5,980,514.14 549,721.67 4.18 -149.38 MWD+IFR-AK-CAZ-SC(2) 1,428.98 27.54 137.49 1,392.97 1,300.35 -179.92 171.68 5,980,483.80 549,750.31 3.02 -17992 MWD+IFR-AK-CAZ-SC(2) 1,523.25 28.14 137.93 1,476.33 1,38311 -212.49 201.30 5,980,451.43 549,780.14 067 -212.49 MWD+IFR.AKCAZSC(2) 1,618.09 28.94 137.33 1,55964 1,467.02 -245.96 231.84 5,986,418.16 549,810.90 0.90 -24&% MWD+IFR-AKCAZ-SC(2) 1,678.04 29.99 135.80 1,611.84 1,519.22 -267.37 252.11 5,980,396.89 549,831.31 2.15 -267.37 MWD+IFR-AKCAZ-SC(2) 1,771.00 33.38 135.72 1,690.93 1,598.31 -302.34 286.17 5,980,362.15 549,865,60 3.65 -302.34 NOT an Actual Survey 10 314" z 13-112" 1,777.33 33.61 135.72 1,696.21 1,603.59 -304.85 288.61 5,980,359.66 549,858.06 3.65 40485 MWD+IFR-AK-CAZ-SC(3) 1,801.61 34.53 134.79 1,71632 1,62310 -314.50 298.19 5,980,350.07 549,877.69 4.35 -314.50 MWD+1FR-AK-CAZSC(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-GAZSC(3) 1,991.93 40.86 131.83 1,866.72 1,774.10 -394.45 382.87 5,986,270.70 549,962.89 3.39 -394.45 MWD+IFR-AK-W-SC(3) 2,088.48 43.97 130.99 1,936.52 1,843.90 -436.61 430.70 5,98,228.85 55,011.00 3.34 -436.61 MWD+IFR-AK-CAZ-SC(3) 2,184.36 47.16 129.49 2,005.04 1,912.42 -081.73 484.06 5,980,184.09 550,06465 3.44 481.73 MWD+IFR-AK-CAZ-SC(3) 2,276.23 50.08 128.77 2,065.76 1,973,14 52522 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 -571.22 MWD+IFR-AK-CAZ-SC(3) 2,464.98 55.35 124.47 2,179.57 2,086.95 -615.68 657.76 5,98,05130 550,239.21 3.45 .61568 MWD+IFR-AK-CAZSC(3) 2,55960 56.73 122.73 2,232.43 2,139.81 559.10 723.12 5,980,008.32 550,304.86 2.11 559.10 MWD+IFR-AK-W-SC(3) 2,653.87 58.79 122.43 2?82.72 2,190.10 -702.03 790.31 5,979,965.84 550,372.32 2.20 -702.03 MWD+IFR-AKCAZ-SC(3) 2,748.30 59.37 121.74 2,331.24 2,238.62 -745,W 858.95 5,979,923.27 55,441.23 0.88 -745.06 MWD+IFR-AK-CAZ-SC (3) 2,843.07 6140 121.48 2,378.07 2,285.45 -788.24 929.11 5,979,886.56 550,511,67 2.16 -788.24 MWD+IFR-AK-CAZ-SC(3) 2,937.25 65.11 121.93 2,420.45 2,327.83 -832.44 1,000.65 5,979,83684 550,583.50 3,% -832.44 MWD+IFR-AK-CAZSC(3) 3,032.88 69.13 121.16 245]62 2,365.00 -878.52 1,075.72 5,979,79127 550,658.87 4.27 -878.52 MWD+IFR-AKCAZSC(3) 3,126.86 71.43 121.37 2,489.33 2,396.71 -924.43 1,151.34 5,979,745.86 550,73418 2.46 -924.43 MWD+IFR-AKCAZ-SC(3) 3,221.95 72.62 121.37 2,518.67 2,42605 -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.% -1,018.73 1,305.53 5,979,652.59 550,889.57 0.54 -1,018.73 MWD+IFR-AK-CAZ-SG(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) 3,5W.07 73,21 122.55 2,60129 2,508.67 -1,116.05 1,458.78 5,979,555.30 551,043.45 0.21 -1,116.05 MWD+IFR-AK-CAZSC(3) 3,601.42 73.21 122.70 2,628.83 2,586.21 -1,165.27 1,535.66 5,979,50]59 551,120.65 0.15 -1,16527 MWD+IFR-AKCAZSC(3) 3,696.85 7321 122.29 2,656.40 2,55318 -1,214.35 1,612.72 5,979,459.03 551,1%.03 0.41 -1,214.35 MWD+IFR-AKCAZ-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-AKCAZ-SC(3) 3,886.74 73.14 118.95 2,711.17 2,618.55 -1,30]43 1,768.88 5,979,366.99 551,354.78 2.05 -1,307.43 MWD+IFR-AKCAZ-SC(3) 3,981.94 73.09 119.64 2,738.82 2,64620 -1,352.00 1,848.32 5,979,322.95 551,434.51 0.70 -1,352.00 MWD+IFR-AK-CAZ-SC(3) 4,076.41 73.30 119.87 2,786.13 2,673.51 -1.396.88 1,92664 5,979,278.59 551,513.31 0.32 -1.395.88 MWD+IFR-AK-CAZ-SC(3) 4,17102 73.17 118.99 2,793.42 2,700.80 4,441.40 2,00573 5,979,234.61 551,592.49 0.% -1,441.40 MWD+IFR-AK-CAZ-SC(3) 4,266.02 73.06 119.53 2,82102 2,728.40 -1,485.83 2,085.04 5,979,190.71 551,672.08 0.56 -1,485.83 MWD+IFR-AK-CAZ-SC(3) 4,360.46 73.01 11904 2,84857 2755.95 -1,530.01 2,16383 5,979,14705 551,751.15 0.50 -1,530.01 MWD+IFR-AK-CAZ-SC(3) 1OW01711:29:45AM Page 3 COMPASS 5000.14 Build 86 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 1 H-102 Project: Kuparuk River Unit TVD Reference: iH-102 actual @ 92.62usft (Doyon 142) 81te: Kuparuk 1H Pad MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Wen: Rig: iH-102 North Reference: True Weabaa: 11-1-1021-2 Survey Calculation Method Minimum Curvature Design: 11-1-1021-2 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (salt) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) ("/100') (ft) Survey Tool Name 4,455.58 72.90 119.77 2,876.45 2,783.83 -1,57466 2,243.05 5,979,102.93 551830.66 074 -1,57466 MWD+IFR-AK-CAZ-SC(3) 4,549.81 7287 120.06 2,904.19 2,811.57 -1,619.57 2,321.11 5,979,058.54 551,909.01 0.30 -1,619.57 MWD+IFR-AK-CAZ-SC(3) 4,644.52 7320 118.40 2,931.82 2,839.20 -1,663.81 2,400.16 5,979,014.84 551,988.35 171 -1,663.81 MWD+IFR-AK-CAZSC(3) 4,739.99 72.42 114.51 2,960.05 2,857.43 -1.704,44 2,481.79 5,978,974.75 552,070.24 3.98 -1,704.44 MWD+IFR-AK-CAZ-SC (3) 4,786.24 72.31 110.47 2,974.06 2,88144 -1,721.29 2,522.51 5,978,958.17 552,111.06 8.33 -1,721.29 MWD+IFR-AK-CAZ-SC (3) 4,833.76 7248 108.23 2,988.44 2,895.82 -1,736.30 2,56.5.24 5,978,993.45 552,153.89 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 10058 3,046.89 2,954.27 -1,780.14 2,739.52 5,978,900.76 552,328.44 331 -1,780.14 MWD+IFR-AK-CAZSC(3) 5,070.23 71.27 98.69 3,062.16 2,969.54 -1,787.68 2,783.71 5,978,89352 552,372.67 3.99 -1,787.68 MM+IFR-AK-CAZSC(3) 5,116.77 71.68 96.97 3,076.95 2,984.33 -1,79369 2,827.43 5,978,88779 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 5,978,87999 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 5,978,878.73 552,595.65 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 5,978,885.29 552,684.94 4.85 -1,797.98 MWD+IFR-AK-CAZSC(3) 5,495.26 72.32 81.29 3,194.69 3,102.02 -1,786.21 3,18570 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 5,978,915.95 552,862.91 5.27 -1,768.49 MM+IFR-AK-CAZ-SC (3) 5,685.45 7261 70.23 3,252.48 3,159.86 -1,742.11 3,361.14 5,97$94290 552,94973 5.83 -1,742.11 MWD+IFR-AK-CAZ-SC(3) 5.779.73 7302 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 3,307.23 3,214.61 -1,667.90 3,525.49 5,979,018.19 553,113.57 1,34 -1,667.90 MWD+IFR-AK-CAZSC (3) 5,968.69 74.38 63.99 3,333.12 3,240.50 -1,627.64 3,607.17 5,979,05898 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-CA2-SC(3) 6,156.96 74.68 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 MWD+IFR-AK-CAZSC (3) 6,252.33 7403 54.53 3,408.96 3,316.34 -1,493.22 3,844.61 5,979,194.96 553,431.50 3.87 -1,493.22 MWD+IFR-AK-CAZ-SC(3) 6,346.97 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 -1,43841 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-AKCAZ-SC (3) 6,537.27 73.10 45.02 3,493.23 3,400.61 -1,317.09 4,05112 5,979,372.44 553,637.42 3.18 -1,31709 MWD+IFR-AK-CAZSC(3) 6,585.21 73.18 41.30 3,507,14 3,414.52 -1,28363 4,083.10 5,979,406.11 553,668.57 7.43 -1283.63 MWD+IFR-AK-CAZSC(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+IFR-AK-CAZ-SC(3) 6,727.59 71.99 32.96 3,549.95 3,457.33 -1,175.60 4,165.17 5,979,51467 553,749.91 5.79 -1,175.60 MWD+IFR-AK-CAZ-SC(3) 6,522.80 72.62 27.41 3,578.91 3,406.29 -1,067.23 4210.74 5,979,593.33 553,794.96 5.59 -1,09723 MWD+IFR-AKCAZ-SC(3) 6,915.59 72.83 23.59 3,606.48 3,513.66 -1,017.27 4,248.88 5,979,673.53 553,832.57 3.94 -1,017.27 MWD+IFR-AK-CAZSC(3) 7,011.34 72.49 1SW 3,635.02 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) 7,10401 7390 18.26 3,661.82 3,569.20 598.34 4,311.14 5,979,842.85 553,893.70 1.99 548.34 MWD+IFR-AK-CAZ-SC(3) 7,198.95 7327 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 3,622.64 571.64 4,352.87 5,906,019.81 506,934.25 515 67164 MWDHFR-AKCAZ-SC(3) 7,387.86 74.53 4.10 3,740.79 3,648.17 581.33 4,362.35 5,980,11017 553,943.13 3.90 -581.33 MWD+IFR-AKCAZSC(3) 7,48161 74.18 4.40 3,766.13 3,673.51 491.11 4,369.05 5,906,200.43 553,949.24 0.48 -491.11 MWD+IFR-AK-CAZSC (3) 7,576.96 74.34 2.50 3,791.94 3,699.32 599.70 4,374.56 5,906,291.86 553,954.15 1.93 -399.70 MWD+IFR-AK-CAZSC(3) 7,673.24 74.65 2.06 3,817.68 3,725.06 -307.01 4,378.66 5,980,384.56 553,957.63 0.33 -307.01 MWD+IFR-AK-CAZ-SC(3) 7,768.14 74.30 2.49 3,84308 3,750.46 -215.66 4,38268 5,980,475.93 553,961.05 0.38 -215.66 MWD+IFR-AK-W-SG(3) 7,845.00 74.55 2.07 3,863.72 3,771.10 -141.68 4,385.63 5,980,549.92 553,963.51 0.62 -141.68 NOT an Aclual Survey 10/32017 11:29:45AM Page 4 COMPASS 5000.14 Build 65 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 11-1-102 Project: Kuparuk River Unit TVD Reference: iH-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-102 actual @ 92.62usR (Doyon 142) Well: Rig: 1H-102 North Reference: True Wellbore: 1 H-1021-2 Survey Calculation Method: Minimum Curvature Design: 11,1-1021-2 Database: CAKEDMP2 Survey 10/WO1711:29:45AM Page 5 COMPASS 5000.14 BUM 85 Map Map Vertical MD Inc An TVD TVDSS +N/ -S +EI -W Northing Eaegng DLS Section (usft) V) V) (usR) Well (usR) (usR) (tt) (ft) (°11001 (it) Survey Tool Name x 9-718 7,858.00 7640 1.38 3666.98 3,774.36 -129.11 4,386.01 5,980,56250 553,963,80 15.13 -129.11 MM -INC _ONLY (4) 7,954.97 82.56 2.57 3,88467 3,792.05 33.87 4,38980 5,980,65774 553,966.46 6.47 -33.87 MWD-INC-ONLY(4) 8,014.35 86.19 3.33 3,890.49 3,797.87 25.14 4,392.34 5,980,716.76 553,969.11 6.24 25.14 MWD+IFR-AK-CAZ-SC(5) 8,108.31 92.48 262 3,891.58 3,79896 118.91 4,397.22 5,980,810.56 553,973.37 6.74 118.91 MWD+IFR-AK-CAZ-SC(5) 8,154.40 94.63 2.27 3,81 3,796.10 164.87 4,399.18 5,980,856.53 553,975.03 4.73 164.87 MWD+IFR-AK-CAZSC(5) 8,202.23 95.05 1.98 3,884.69 3,792.07 212.50 4,400.95 5,980,904.16 553,976.48 1.07 212.50 MWDNFR-AK-CAZSC(5) 8,295.94 93.11 0.24 3,878.02 3,785.40 30.5.94 4,402.76 5,980,997.61 553,977.67 278 305.94 MWD+IFR-AK-CAZSC(5) 8,390.27 9061 0.28 3,874.96 3,782.34 400.22 4,403.18 5,981,091.87 553,977.47 2.65 40022 MWD+IFR-AK-CAZSC(5) 8,485.72 9001 359.99 3,87444 3,781.82 495.66 4,403.41 5,981,187.31 553,977.06 0.70 49566 MWD+IFR-AK-CAZ-SC(5) 8,580,64 90.46 359.14 3,874.05 3,781.43 590.58 4,402.69 5,981,28221 553,975.72 1.01 590.58 MWD+IFR-AK-CAZ-SC(5) 8,676.10 90.02 357.24 3,873.65 3,781.03 685.99 4,39967 5,981,377.58 553,97207 2.04 685.99 MWD+IFR-AK-CAZ-SC(5) 8,770.73 89.13 358.90 3,874.36 3,781.74 7K% 4,396.49 5,981,472.12 553,968.26 1.99 780.% MND+IFR-AK-CAZSC (5) 8,665.84 89.03 3%.77 3,875.88 3,783.26 875.58 4,392.89 5,981,567.11 553,964.04 2.24 875.58 MWD+IFR-AK-CAZSC(5) 8,960.93 8976 356.60 3,876.89 3,784.27 970.51 4,387,40 5,981,66199 553,957.91 079 970.51 MWD+IFR-AK-CAZ-SC(5) 9,055.53 89.51 357.28 3,877.49 3,784.87 1,054.97 4,382.35 5,981,756.40 553,952.24 0.77 1,064.97 MWD+IFR-AK-CAZ-SC(5) 9,150.62 89.34 358.32 3,878.44 3,785.82 1,159.98 4,378.70 5,981,851.38 553,94796 1.11 1,159.98 MWD+IFR-AK-CAZ-SC(5) 9,245.49 8862 0.07 3,863.13 3,787.51 1,254.82 4,377.36 5,981,946.20 553,946.00 1.99 1,254.82 MWD+IFR-AK-CAZSC(5) 9,340.32 88.55 1.63 3,882.48 3,789.85 1,349.61 4,378.77 5,982,040.99 553,946.78 1-65 1,349.61 MWD+IFR-AK-CAZ-SC (5) 9,435.28 88.58 0.86 3,884.85 3,792.23 1,444.52 4,3%.83 5,982,135.90 553,948.21 0.81 1,444.52 MWD+IFR-AK-CA7-SC(5) 9,530.04 88.56 0.47 3,887.22 3,794.60 1,539.24 4,381.93 5,982,230.62 553,948.68 0.41 1,539.24 MWD+IFR-AK-CAZ-SC(5) 9,625.21 90.42 3.01 3,888.07 3,79545 1,634.35 4,384.82 5,982,325.74 553,950.94 3.31 1,634.35 MND+IFR-AK-CAZSC(5) 9,719.84 90.23 0.26 3887.53 3,794.91 1,728.93 4,387.52 5,982,420.32 553,953.02 291 1,728.93 MND+IFR-AK-CAZSC(5) 9,768.33 907/ 359.97 3,887.11 3,794.49 1,777.42 4,387.62 5,982,468.81 553,952.79 126 1,777.42 MWD+IFR-AK-CAZSC(5) 9,815.02 90.57 356.95 3,8%.% 3,793.94 1,824.09 4,386.36 5,982,515.46 553,951.23 6.48 1,824.09 MWD+IFR-AK-CAZ-SC(5) 9,862.70 91.37 356.35 3,885.75 3,793.13 1,871.68 4,383.58 5,982,563.03 553,948.13 2.10 1,877 68 MWD+IFR-AK-CAZ-SC (5) 908.77 90.64 354.00 3,884.86 3,79224 1,917.57 4,379.70 5,982,608.89 553943.95 5.23 1,917.57 MWD+IFR-AK-CAZ-SC(5) 10,004.12 90.36 350.52 3,833.86 3,791.24 2,01203 4,3%.87 5,982,703.25 553,930.49 3.68 2,012.03 MWD+IFR-AK-CAZSC(5) 10,051.35 88.03 349.69 3,884.53 3,791.91 2,058.55 4,358.75 5,982,749.71 553,922.07 5.24 2,058.55 MWD+IFR-AK-CAZSC(5) 10,098.47 88.92 350.07 3,885.78 3,793.16 2,104.92 4,350.47 5,982,796.02 553,91548 2.05 2,104.92 MNDHFR-AK-CAZSC(5) 10,19200 8875 347.45 3,887.68 3,795.06 2,196.63 4,332.25 5,982,887.60 553,89465 281 2,196.63 MWD+IFR-AK-CAZSC(5) 10,286.93 8873 346.74 3,889.77 3,797.15 2,289.14 4,311.05 5,982,979.% 553,872.85 0.75 2,289.14 MWD+IFR-AK-CAZ-SC(5) 10,378.41 88.11 34971 3,892.29 3,799.67 2,378.65 4,292.39 5,983,06934 553,853.60 3.32 2,378.65 MWD+IFR-AK-CAZ-SC(5) 10,470.89 89.67 351.84 3,894.09 3,801.47 2,469.91 4,277.57 5,983,160.49 553,838.18 2.85 2,469.91 MWD+IFR-AK-CAZ-SC(5) 10,561.32 89.68 352.26 3,894.60 3,801.98 2,559.47 4,26507 5,983,249.95 653,82508 0.46 2,559.47 MWD+IFR-AK-CAZSC(5) 10,653.72 89.23 353.68 3,895.48 3,802.86 2,651.17 4,253.76 5,983,341.% 553,813.16 1.61 2,651.17 MND+IFR-AK-CAZSC(5) 10,745.08 88.65 354.12 3,897.17 3,804.55 2,741,99 4,244.05 5,983,43232 553,802.86 0.80 2,741.99 MWD+IFR-AK-CAZSC(5) 10,836.30 88.70 356.03 3,89928 3,806.66 2,832.85 4,236.22 5,983,523.11 553,794.43 2.09 2,83265 MWD+IFR-AK-CAZ-SC (5) 10,928.53 88.00 357.36 3,901.93 3,809.31 2,924.88 4,230.91 5,983,615.10 553788.51 1.63 2,924.88 MWD+IFR-AK-CAZ-SC(5) 11,02178 84.87 358.87 3,907.73 3,815.11 3,017.89 4,227.84 5,983,708.07 553,784.83 3.73 3,017.89 MND+IFR-AK-CAZ-SC (5) 10/WO1711:29:45AM Page 5 COMPASS 5000.14 BUM 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1 H-102 Project: Kuparuk River Unit TVD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: iH-102 actual @ 92.62usft (Doyon 142) Well: Rig: iH-102 North Reference: True Wellbore: 11-1-1021-2 Survey Calculation Method: Minimum Curvature Design: 11-1-1021-2 Database: 0AKEDMP2 Survey 10/12017 11:29:46AM Page 6 COMPASS 5000. 14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/ -W Northing Easting DLS Section (usft) V) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Too[ Name 11,112.96 8465 0.87 3,916.06 3,82344 3,108.68 4,22264 5,983,79885 553,78402 2.20 3,108.68 MWD+IFR-AK-CAZ-SC(5) 11,206.05 86.64 358.26 3,923.13 3,830.51 3,201.49 4,226.93 5,983,891.64 553,782.70 3.52 3,20149 MWD+FR-AK-CAZSC(5) 11,297.04 88.69 359.44 3,926.84 3,834.22 3292.38 4,225.11 5,983,982.51 553,780.27 2.60 3,292.38 MWD+IFR-AKCAZ-SC(5) 11,389.05 89.10 359.93 3,928.61 3,835.99 3,384.37 4,224.60 5,984,07449 553,779.16 0.69 3,384.37 MWD+IFR-AK-CAZ-SC(5) 11,481.47 90.23 1.67 3,929.15 3,836.53 3,476.77 4,225.89 5,984,166.89 553,779.84 2.24 3,476.77 MWD+IFR-AK-CAZ-SC(5) 11,574.22 92.28 2.57 3,927.12 3,834.50 3,569.43 4,229.32 5,984,259.56 553,782.65 2.41 3,569.43 MWD+IFR-AK-CAZ-SC (5) 11,66514 91.25 356.70 3,92430 3,83168 3,660.87 4,22874 5,984,350.98 553,78146 6.51 3,660.87 MWD+IFR-AKCAZ-SC(5) 11,713.08 92.60 352.92 3,922.71 3,830.09 3,707.98 4,224.46 5,984,398.05 553,776.87 8.47 3,707.98 MWD+IFR-AKCAZSC(5) 11758.30 92.71 353.25 3,920.61 3,827.99 3,752.82 4,219.02 5,984,442.85 553,771.14 0.77 3,752.82 MWD+IFR-AKCAZ-SC(5) 11,850.43 92.53 355.58 3,916.40 3,823.78 3,844.41 4,210.06 5,984,53437 553,761.58 2.53 3,844.41 MWD+IFR-AK-CAZ-SC(5) 11,892.46 9281 358.03 3,91444 3,821.82 3,886.32 4,20772 5,984,576.27 553,758.96 5.86 3,886.32 MWD+IFR-AK-CAZ-SC(5) 11,942.85 91.11 35729 3,912.72 3,820.10 3,936.64 4,205.67 5,984,626.57 553,756.57 3.68 3,936.64 MWD+IFR-AKCAZ-SC(5) 12,033.69 91.55 356.24 3,910.61 3,817.99 4,02731 4,200.54 5,984,717.19 553,750.85 1.25 4,02231 MWD+IFR-AKCAZSC(5) 12,126.50 91.72 0.15 3,90796 3,815.34 4,120.02 4,197,62 5,984,809.87 553,74231 4.22 4,120.02 MWD+IFR-AK-CAZ-SC(5) 12,159.89 90.57 2.48 3,907.29 3,814.67 4,153.39 4,198.39 5,984,843.24 553,747.86 7.78 4,153.39 MWD+IFR-AK-CA7-SC(5) 12,219.66 90.91 4.85 3,906.52 3,813.90 4,213.03 4,202.21 5,984,902.90 553,751.28 4.01 4,213,03 MWD+IFR-AKCAZ-SC(5) 12,311.08 91,04 10.11 3,904.97 3,812.35 4,30363 4,214.10 5,984,993.56 553,762.58 5.75 4,303.63 MWD+IFR-AK-CAZSC(5) 12,403.93 WZ8 1193 3,903.82 3,811.20 4,394.75 4,231.85 5,985,089.80 553,779.72 2.08 4,394.75 MWD+IFR-AK-CAZ-SC(5) 12,45165 8979 11.16 3,903.74 3,811.12 4,441.51 4,241.40 5,985,131.61 553,78896 2.03 4,441.51 MWD+IFR-AK-CAZ-SC(5) 12,495.64 90.15 9.92 3,903.77 3,811.15 4,484.75 4,249.45 5,985,174.90 553,796.72 2.94 4,484.75 MWD+IFR-AK-CAZ-SC(5) 12,540.81 89.75 8.69 3,903.81 3,811.19 4,529.33 4,256.75 5,985,219.52 553,803.73 2.86 4,529.33 MWD+IFR-AKCAZ-SC(5) 12,588.37 89.44 7.93 3,904.14 3,811.52 4,576.39 4,263.62 5,985,266.62 553,810.29 1.73 4,576.39 MWD+IFR-AKCAZSC(5) 12,632.96 89.35 6.58 3,904.61 3,811.99 4,620.62 4,259.25 5,985,310.88 553,81562 3.03 4,620.62 MWD+IFR-AK-CAZ-SC(5) 12,678.21 88.92 5.67 3,905.30 3,812.68 4,665.59 4,274.16 5,985,355.89 553,820.23 1,83 4,665.59 MWD+IFR-AK-CAZ-SC (5) 12,724.85 88.45 484 3,906.37 3,813.75 4,712.02 4,278.51 5,985,402.33 553,824.28 2.43 4,712.02 MWD+IFR-AKCAZ-SC(5) 12,770.99 88.10 4.16 3,907.76 3,815.14 4,75799 4,282.13 5,965,448.33 553,827.59 1.66 4,757.99 MWD+IFR-AKCAZ-SC(6) 12,817.28 8245 3.37 3,909.55 3,816.93 4,804.15 4,285.17 5,985,494.50 553,830.32 2.21 4,804.15 MWD+IFR-AKCAZ-6C(5) 12,86179 87.00 222 3,91171 3,819.09 4,848.55 4,287.33 5,985,538.91 553,832.20 277 4,848.55 MWD+IFR-AK-CAZSC(5) 12,954.91 85.97 358.29 3,91742 3,824.80 4,941.48 4,287.75 5,985,631.83 553,832.00 4.36 4,941.48 MWD+IFR-AK-CAZ-SC(5) 13,046.64 85.72 357.36 3,924.07 3,831.45 5,032.90 4,284.28 5,985,723.21 553,827.92 1.05 5,032.90 MWD+IFR-AK-CAZ-SC(5) 13,139.28 86.65 355.94 3,930.23 3,837.61 5,12517 4,278.88 5,985,815.44 553,821.91 1.83 5,125.17 MWD+1FR-AK-CAZ-SC(5) 13,204.00 88.30 355.77 3,933.08 3,840.46 5,189.66 4,274.20 5,985,87989 553,816.81 2.57 5,189.66 NOT an Actual Survey 4.112" x 8.914" 13,2310 89.01 355.70 3,933.73 3,841.11 5,217.19 4,272.15 5,985,90741 553,814.57 2.57 5217.19 MWD+IFR-AK-CAZ-SC (5) 13,323.97 93.61 354.95 3,931.62 3,839.00 5,309.19 4,264.63 5,985,999.34 553,806.44 5.05 5,309.19 MWD+IFR-AK-CAZ-SC(5) 13,37364 93.95 355.41 3,928.34 3,835.72 5,358.57 4,260.46 5,986,048.69 553,801.95 1.15 5,358.57 MWD+IFR-AKCAZSC(5) 13,435.00 93.95 355.41 3,924.11 3,831.49 5,419.59 4,255.57 5,986,109.67 553,79G65 0.00 5,419.59 PROJECTED to TD 10/12017 11:29:46AM Page 6 COMPASS 5000. 14 Build 85 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. Q Yes ❑ No I have checked to the best of my ability that the following data is correct: 771 Surface Coordinates [71 Declination & Convergence 0 GRS Survey Corrections E,] Survey Tool Coders randon Temple SLB DE: Brandon IernpleDite,201ally i.10031gned by B34:30-8'00' Date; 2017.1003 11:34:30 -08'00' IXy BlyRgc3MKdxtl Xdlfatl Client RepresentativeKelsey Hallford : Date10/03/17 r --.- Cement Detail Report IH-102 String: Conductor Cement Job: DRILLING ORIGINAL, 8/22/2017 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 1/11/2016 18:15 1/11/2016 22:15 1 H-102 Comment Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Realm? Vol Cement... Top Plug? Bum Plug? Conductor Cement cement 20" x 34" 43.1 118.6 No No No Insulated conductor in 142" hole Q Pump Ina (bbllm..Q Pump Final (bbl1... Q Pump Avg (bbf/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rofatad? Pipe RPM (rpm) No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill out Diameter (in) 105.0 Drill Bit 118.6 131/2 Comment Cement Fluids 8 Additives Fluid Fluid TypeFluid Description Estimated Top INKS) Est Bum (ftKB) Amount (sacks) Class Volume Pumped (bbl) 3500 mix 43.1 118.6 Yield (ft'/sack) Mix H2O Ratio (gallant... Free Water (%) Density (iblgal) Plastic Viscosity (Pa,$) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 11/1412017 Cement Detail Report 11-1-102 String: Surface Casing Cement Job: DRILLING ORIGINAL, 8/22/201718:00 Cement Details Description Cementing Sfart Date Cementing Entl Date Wellbore Name Surface Casing Cement 8125/2017 18:15 8I25I2017 22:07 IH -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 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/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. Balch and pump 298 BBLS of 11# cement ( yield 1.91 cuft/sx, mix water 6.828 gattsx, 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 gal/sx, thickening time 4 hr 1 min) and pump at 4 BPM 164 PSI DPP with 19% F/O. Drop top plug and pump with 10 BBLS H2O, UP WT = 111K-DWN WT = 95K. Chase cement with rig pumps utilizing 9.6# mud @ 5 BPM 330 PSI 31-55% F/O. from 1356 STKS reducerate 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 bbis prior to bumping the plug, circulated 9 bbis of good 11. ppg cement to surface. CIP 2207 hrs 8/25/2017. Cement Stages Stage # 1 Description jObjective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? I Vol Cement... Top Plug? Bon Plug? Surface Casing Cement Cement 10 3/4" 1 42.0 1,777.0 Yes 9.0 Yes Yes O Pump /nit (bbl/m... O Pump Final (669... O Pump Avg (bb9... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 3 5 286.0 1,082.0 Yes 30.00 No Tagged Depth (ftKB) Tag McNod Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Bit 1,777.0 97/8 Comment Stage pumps up to 8 BPM 290 PSI DPP with 268 PSI FDPP. 23% F/O. While recip from 1,740-1770' MD. Pump maker sweep and observe back at 3,650 STKS. 12,000 Total siks 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. Balch 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 cuff/sx, mix water 6.828 gal/sx, thickening time 6hr 22 min) @ 5.6 BPM 180 PSI DPP, 21% F/O. Batch and pump 61.9 BBLS 12# tail cement (yield 1.65 cuft/sx, mix water 5.733 gai/sx, thickening time 4 hr 1 min) and pump at 4 BPM 164 PSI DPP with 19% F/O. Drop top plug and pump with 10 BBLS H2O, UP WT = 111 K-DWN WT = 95K. Chase cement with rig pumps utilizing 9.6# mud @ 5 BPM 330 PSI 31-55% F/O. from 1356 STKS reduce rate to 3 BPM 300 PSI FCP 56% F/O. Bump plug at 1,502 STKS at 2207. increase pressure to 1,082 PSI and hold for 5 min. Bleed off pressure and check floats. GOOD. Cement in place at 2207 his. Recip until last 30 bbis pumped. Circulated contaminated cement to surface 67.7 bbis prior to bumping the plug, circulated 9 bbls 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 Bon (ftKB) Amount (sacks) Class - Volume 1 1 Pumped (bbl) MudPush II 1 1 77.4 Yield (ft%sack) Mix H2O Ratio (gal/so,... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pais) Thickening Time (hr) CmprStr 1 (psi) 10.80 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB)Est Btm (ftKB) Amount (sacks) Class Volume Pum petl (bbl) Lead Cement 42.0 1,250.2 876 - 298.0 Yield (ft%sack) Mix H2O Ratio (gal/sa... Free Water (%) Density po/gal) Plastic Viscosity (Pa -s) Thickening Time (hr)CmprStr 1 (psi) 7.91 6.83 11.00 1 6.37 Additives Additive Type Concentration one Unit label 0046 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 gallsx Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 1,250.2 1,777.0 211 61.9 Yield (ft/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (lblgal)Plastic Viscosity (Pa,$) Thickening Time (hr) CmprStr 1 (psi) 1.65 5.73 12.02 4.00 Additives Additive Type Concentration Cone Unit label DG46 Antifoam 0.2 %BWOC Additive Type Concentration Cone Unit label D185 Dispersant 0.1 %BWOC Additive Type concentration Cone Unit label D177 Retarder 0.005 gal/sx Page 112 ReportPrinted: 11/14/2017 Cement Detail Report IH -102 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 8/22/201718:00 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 Comment Pump cement job as follows: SLB pump 5 bbls freshwater and pressure test lines to 400 13500 psi - good test. Pump 50 bbls 12.5ppg Mudpush at 3 bpm, ICP 450 psi, FCP 210 psi. Drop Davis Lynch anti -rotational bottom plug. Batch mix cement, cement wet at 03:46 hrs. SLB pump total of 239.3 bbls 15.8ppg Class G cement. Pumped 170 bbls at 6 bpm, ICP 459 psi, FCP 315 psi. Then observe "H" pump fail so swap to "G' pump which has slightly lower rate capacity. Did.not have to stop pumping but rate briefly dropped to -3 bpm. Continue pumping additional cement at -4.5 bpm, ICP 230 psi, FCP 190 psi. Drop Davis Lynch anti - rotational top plug. SLB pump 10 bbls freshwater at 4 bpm, 120 psi. Reciprocate pipe -15 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 Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) IS Return? Vol Cement... lop Plug? Bim Plug? Intermediate Casing Cement Intermediate 4,250.0 8,591.0 No Yes Yes Cement casing O Pump Init (bbl/m... IQ Pump Final (bbll...O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 3 6 1,423.0 2,085.01 Yes 15.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 6 314 Comment Pump cement job as follows: SLB pump 5 bbls freshwater and pressure test lines to 400 13500 psi - good test. Pump 50 bbls 12.5ppg Mudpush at 3 bpm, ICP 450 psi, FCP 210 psi. Drop Davis Lynch anti -rotational bottom plug. Batch mix cement, cement wet at 03:46 hrs. SLB pump total of 239.3 bbls 15.8ppg Class G cement. Pumped 170 bbls at 6 bpm, ICP 459 psi, FCP 315 psi. Then observe "H" pump fail so swap to "G" pump which has slightly lower rate capacity. Did not have to stop pumping but rate briefly dropped to -3 bpm. Continue pumping additional cement at -4.5 bpm, ICP 230 psi, FCP 190 psi. Drop Davis Lynch anti - rotational lop 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 Bbn (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push 3,317.0 4,250.0 50.0 Yield (tPisack) Mix H2O Ratio (gallsa... Free Water (%) Density, (Iblgal) Plastic Viscosity (Pa*s) Thickening Time (hr) CmprStr t (psi) 12.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount(sacks) Class Volume Pumped (bbl) Cement 4,250.0 8,591.0 1,159 G 239.3 Yield (IP/sack) Mix H2O Ratio (ga9sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.12 15.80 4.30 Additives Additive Type Concentration Conc Unit label D255 aFluid Loss 0.5 %BWOC Additive Type Concentration Conc Unit label D047 Antifoam 0.05 gal/sx Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Page 1/1 ReportPrinted: 11114/2017 21 7101 28 750 chlumberg Drilling & Measur`em encs 20V Product Delivery AOGCC Customer: ConocoPhillips Alaska Dispatched To: Well Name: 1H -102L2 Date Dispatched: Service Order #: 17AKA0021 Dispatched By: Transmittal #: 260CT17-SP03 DATA LOGGED %\ i \ /2011 M. K.BENDER AOGCC: Makana Bender 26 -Oct -17 Stephanie Pacillo Product Description Hardcopy Digital Copy Logging Date Color Log Prints: 4 Contents on CD 25 -Sep -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.Oslerkamp(a)conocophillips.com Alaska PTSPrinlCenterpslb.com Attn: Tom Osterkamp Attn: Stephanie Pacillo Received By:u+l✓ RECEIVED OCT 2 6 2017 FINAL AOGCC NADConversion Kuparuk River Unit Kuparuk 1H Pad 1H -102L2 IH -102L2 ConocoPhillips Definitive Survey Report 03 October, 2017 21 7101 28 7 5 D ConocoPhillips ConocclPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 1 H-102 Project: Kuparuk River Unit TVD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Well: Rig: 1H-102 North Reference: True Wellbore: 1H-1021-2 Survey Calculation Method- Minimum Curvature Design: 1 H-1021.2 Database: OAKEDMP2 roject Kuparuk River Unit, North Slope Alaska, United States lap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level leo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point lap Zone: Alaska Zone 04 Using geodetic scale factor Yell Rig: 1H-102 Audit Notes: To Well Position +N/ -S 0.00 usft Northing: 5,980,662.56 usft Latitude: 70' 21'28.630 1 7,768.14 +E/ -W 0.00 usft Easting: 549,577.46 usft Longitude: 149° 35' 50.423 V 'osition Uncertainty (usft) 0.00 usft Wellhead Elevation: usft Ground Level: 54.00 usf Vellbore 11-1-1021-2 nagrtetics Model Name Sample Date Declination Dip Angle Field Strength (1) V) (nT) BGGM2017 9/21/2017 17.48 80.95 57,490 Design 11-1-10212 Date Audit Notes: To Version: 1.0 Phase: ACTUAL Tie On Depth: 7,768.14 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 1,050.36 (usft) (usft) (usft) 0 1,777.33 38.62 0.00 0.00 0.00 Survey Program Date From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 67.62 1,009.26 1H-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 7,768.141H-102 Srvy 3- SLB _MWD+GMAG(1 H- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/27/201712:16 7,845.00 7,954.97 11-1-110212 Srvy 1-SLB_MWD-INC_Filler MWD -INC -ONLY MWD -INC_ ONLY FILLER 9/21/2017 2:59: 8,014.35 13,373.641H-1021-2 Srvy 2- SLB _MWD+GMAG It MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 9/22/2017 3:02: Survey Map Map vertical MD Inc AZI TVD TVDSS +N/5 +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 3862 0.00 0.00 3882 -54.00 0.00 000 5,980,662.56 549,577.46 0.00 0.00 UNDEFINED 6762 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) 165.90 045 132.01 165.90 73.28 -0.10 0.43 5,980,662 46 549,577.89 0.50 -0.10 GYD-GC-SS(1) 25898 1.01 128.15 258.97 166.35 -0.85 1.34 5,960,66172 549,578.81 0.60 -0.85 GYD-GC-SS(1) 354,48 3.34 138.19 354.40 261.78 -344 3.86 5,98D,659.14 549,581.34 2.46 -3.44 GYD-GC-S$(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-GC-SS(1) 539.82 5.77 132.42 539.13 44651 -13.89 14.34 5,980,64877 549,591.69 1.28 -13.89 GYD-GC-S$(1) 632.84 761 134.49 631.51 538.89 -21.36 22.19 5,980,641.35 549,599.79 1.99 -21.36 GYD-GC-SS(1) 725.82 8.77 137.82 723.54 630.92 -30.93 31.34 5,980,631.84 549,609.00 1.35 -30.93 GYD-GC-SS(1) 82124 10.73 141.32 817.58 724.96 -43.25 4178 5,980,619.59 549,619.52 2.15 -43.25 GYD-GC-SS(1) 10/3/2017 11:29.45AM Page 2 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 1 H Pad MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Well: Rig: 1H-102 North Reference: True Wellbore: 1 H-10212 Survey Calculation Method: Minimum Curvature Design: 1 H-10212 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1 -S +El -W Northing Easting DLS Section (usft) (") (') (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 914.20 12.89 139.61 908.57 815.95 -5791 53.90 5,980,605.01 549,631.74 2.35 -57.91 GYD-GC-55(1) 1,009.26 14.89 136.85 1,000.84 908.22 -74.90 69.13 5,980,588.13 549,647.08 222 -74.90 GYD-GC-SS (1) 1,050.36 15.72 135.96 1,04049 947.87 -82.75 76.61 5,980,580.32 549,654.61 2.10 -82.75 MWD+IFR-AK-CAZ-SC(2) 1,144.89 17.17 134.37 1,131.15 1,038.53 -101.72 9549 5,980,56149 549,673.61 161 -101.72 MW0+IFR-AK-CAZ-SC (2) 1,239.16 20.84 134.25 1,220.26 1,127.64 -123.16 11746 5,980,540.20 549,695.72 3.89 -123.16 MWD+IFR-AK-CAZ-SC(2) 1,334.20 24.71 136.54 1.307.88 1,21526 -149.38 143.24 5,980,51414 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 5,980,48380 549,750.31 3.02 -179.92 MWD+IFR-AK-CAZ-SC(2) 1.52325 28.14 137.93 1476.33 1,363.71 -212.49 201.30 5,980,451.43 549,780.14 0.67 -212.49 MWD+IFR-AK-CAZ-SC(2) 1,618.09 2894 137.33 1,55964 1,467.02 -245.96 231.84 5,980,418.16 549,810.90 0.90 -24596 MWD+IFR-AK-CAZ-SC(2) 1,678.04 2999 135.80 161184 1,519.22 -267.37 252.11 6,980.396.89 549,831.31 2.15 -267.37 MM+IFR-AK-CAZ-SC(2) 1,771.00 33.38 135.72 1,690.93 1,598.31 -30234 286.17 5,980,362.15 549,86560 3.65 -30234 �TOq ACIipI SINy�y 10 314" x 13-112" 1,777.33 33.61 135.72 1,69621 1,603.59 -304.85 288.61 5,9W,359 66 549,868.06 365 -304.85 MWD+IFR-AK-CAZ-SC(3) 1801.61 34.53 13479 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) 1,89666 37.81 133.50 1,793.04 1,700.42 -353.55 338.45 5,980.311.29 549,918.21 354 -353.55 MWD+IFR-AK-CAZ-SC(3) 1,991.93 40.86 13183 1,866.72 1,774.10 -39445 382.87 5,980,27070 549,962.89 3.39 -39445 MWD+IFR-AK-CAZ-SC(3) 2,086.48 43.97 130.99 1,936.52 1,843.90 -436.61 430]0 5,980,22885 550,011.00 334 -436.61 MWD+IFR-AK-CAZ-SC(3) 2,184.36 47.16 129.49 2,005.04 1,912.42 -481.73 484.06 5,980,184.09 550,064.65 3.44 -48173 MWD+IFR-AK-CAZ-SC(3) 2,276.23 50.08 12877 2,065]6 1,973.14 -525.22 537.53 5,980,14096 55,118.40 3.23 -525.22 MWD+IFR-AK-CAZ-SC(3) 2,37148 53.12 127.35 2,124.92 2,032.30 -571.22 596.31 5,980,095.36 550.177,48 340 -571.22 MWD+IFR-AK-CAZ-SC(3) 2464.98 55.35 124.47 2,179.57 2,086.95 -615.68 657.76 5,980,05130 550,23921 345 -615.68 MWD+IFR-AK-CAZ-SC(3) 2,55960 56.73 122.73 2,23243 2,139.81 -659.10 723.12 5,980,008.32 550,304.86 2.11 -659.10 MWD+IFR-AK-CAZ-SC(3) 2,85387 56.79 12243 2,282.72 2,190.10 -702.03 790.31 5,979,965.84 550,372.32 2.20 -70203 MWD+IFR-AK-CAZ-SC(3) 2,748.30 59.37 12174 2,33124 2,238.62 -745.87 85895 5,979,92327 550,441.23 0.88 -745.06 MWD+IFR-AK-CAZ-SC(3) 2.843.07 61.40 121.48 2,378.07 2,285.45 -78824 929.11 5,979,880.56 550,51167 2.16 -788.24 MWD+IFR-AK-CAZ-SC(3) 2,937.25 65.11 121.93 2,420.45 2,327.83 -832.44 1.000.65 5,979,836.84 550,583.50 3.96 -832.44 MWD+IFR-AK-CAZ-SC(3) 3,03288 69.13 121.16 2,457.62 2,365.00 -878.52 1,075.72 5,979,791.27 550,658.87 4.27 -878.52 MWD+IFR-AK-CAZ-SC(3) 3,126.85 71.43 121.37 2,489.33 2,396.71 -924.43 1,151.34 5,979,745.86 550,734.78 246 -92443 MWD+IFR-AK-CAZ-SC (3) 3,221.95 72.62 121.37 2,518.67 2426.05 -971.51 1,228.56 5,979,699.29 550,812.31 125 -971.51 MWD+IFR-AK-CAZ-SC (3) 3,316.46 7303 121.69 2,546.58 2,45396 -1,018.73 1,305.53 5,979,65259 650,889.57 0.54 -1,018.73 MWD+IFR-AK-CAZ-SC(3) 3,410.86 73.34 12271 2,57389 2,481.27 -1,066.89 1,381.99 5,979,604.95 55,966.35 1.09 -1,066.89 MWD+IFR-AK-CAZ-SC(3) 3,506.07 73.21 122.55 2,601.29 2.508,67 .1,116.05 1,458.78 5,979.556.30 551,04345 0.21 4,116.05 MWD+IFR-AK-CAZ-SC(3) 3,601.42 73.21 122.70 2,628.83 2,536.21 -1,165.27 1.53586 5,979,507.59 551,120.65 0.15 -1,165.27 MWD+IFR-AWCAZ-SC(3) 3,696.85 7321 122.29 2,656.40 2,563.78 -1,214.35 1,612.72 5,979,45903 551,198.03 0.41 -1.214.35 MWD+IFR-AK-CAZ-SC(3) 3,791.46 73.30 120.98 2,683.66 2,591.04 -1,261.87 1689.85 5.979.412.03 551,275.46 1.33 -1,261.87 MWD+IFR-AK-CAZ-SC(3) 3,886.74 73.14 118.95 2,711.17 2.61855 -1,30743 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 2,73B.82 2,646.20 -1,352.00 1,848.32 5,979,322.95 551.434.51 030 -1,352.00 MWD+IFR-AK-CAZ-SC(3) 4,076.41 73.30 119.87 2,766.13 2,673.51 -1,398.88 1,926.84 5,979,27B.59 551,513.31 0.32 -1,39688 MWD+IFR-AK-CAZ-8C(3) 4,171.02 73.17 118.99 2,793.42 2,700.80 -1,441.40 2,005.73 5,979,23461 551,59249 0.90 -1,44140 MWD+IFR-AK-CAZ-SC(3) 4,28682 73.06 119.53 2.821.02 2,728.40 -1,485.83 2,085.04 5,979,190.71 551,672.08 0.56 -1,485,83 MWD+IFR-AK-CAZ-SC(3) 4,36046 73.01 11904 2.848.57 2.755.95 -1,530.01 2,163.63 5,979,147.05 551,751.15 0.50 -1,530.01 MWD+1FR-AK-CAZ-SC(3) 101312017 11 29 45AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 1H-102 Project: Kuparuk River Unit TVD Reference: 1H-102 actual @ 92.62usn (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Well: Rig: 11-4-102 North Reference: True Wellbore: 1H-1021-2 Survey Calculation Method: Minimum Curvature Design: 1 H-1021-2 Database: OAKEDMP2 Survey Map Map Vertical MD Inc An TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) V) (usft) (usft) (uaft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4455.58 72.90 119.77 2,87645 2,763.83 -157466 2.243.05 5,979,10293 551,63066 0.74 -1,574.66 MWD+IFR-AK-CAZ-SC(3) 4,549.81 72.87 120.06 2,904.19 2.811.57 -1,619.57 2,321.11 5,979,058.54 551,909.01 0.30 -1,61957 MWD+IFR-AK-CAZ-SC(3) 4,644.52 73.20 118.40 2.931.82 2,839.20 -1863.81 2,400.16 5,979,014.84 551,988.35 171 -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]9 5,978,97475 552,07024 3.98 -1,704.44 MWD+IFR-AK-CAZ-SC(3) 4,786.24 72.31 110.47 2,974.06 2,881.44 -7721.29 2,522.51 5,978,958.17 552,111.06 833 -1,721.29 MWD+IFR-AK-CAZ-SC 13) 4,833.76 7248 108.23 2,988.44 2,895.82 -1,735.30 2,565.24 5,978,943.45 55215389 4.51 -1,736.30 MWD+IFR-AK-CAZ-SC 13) 4,92809 72.21 103.78 3,01706 2,924.44 -1761.08 2,651.62 5,978,919.24 552240.42 4.50 -1,761.08 MWD+IFR-AK-CAZ-SC (3) 5,022.87 71.11 100.68 3,046.89 2,95427 -1,760.14 2,739.52 5,978,900.76 552,328.44 3.31 -1,780.14 MWD+IFR-AK-CAZ-SC(3) 5,070.23 71.27 98.69 3,062.16 2,969.54 -1787.68 2,783.71 5,978,893.52 552,372.67 399 -1,787.68 MWD+IFR-AK-CAZ-SC(3) 5,116.77 71.68 9697 3,076.95 2,984.33 -1,793.69 2,82743 5,978,887.79 552,416.42 3.61 -179369 MWD+IFR-AK-CAZ-SC(3) 5.211.19 72.12 93.77 3.105.29 3,01367 -1,802.09 2,916.77 5,978,879.99 552,505.81 3.25 -1,802.09 MWD+IFR-AK-CAZ-SC(3) 5,3D5.75 71.74 8859 3,135.64 3,043.02 -1,803.94 3,006.61 5,978,878.73 552.59565 5.22 -1,803.94 MWD+IFR-AK-CAZ-SC(3) 5,400.08 71.70 83.77 3,165.24 3,072.62 -1,797.98 3,095.95 5.978,885.29 552,684.94 4.85 -1,797.98 MWD+IFR-AK-CAZ-SC(3) 5495.26 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 -1786.21 MWD+IFR-AK-CAZ-SC(3) 5,59001 72.15 7605 3,223.57 3,130.95 -1,76849 3,274.13 5,978,915.95 552,862.91 5.27 -1,766.49 MWD+IFR-AK-CAZ-SC(3) 5,685.45 7261 7023 3,252.48 3,159.86 -1,742.11 3,361.14 5,978,94290 552,94933 5.83 -1,742.11 10WD+1FR-AK-CAZ-SC(3) 5.779.73 73.02 64.52 3280.36 3,187.74 -1,707.48 3,444.24 5,978,97808 553,032.59 5.80 4]0].48 MWD+IFR-AK-CAZ-SC(3) 5,874.02 73.87 63.54 3,307.23 3,214.61 -1,667.90 3,525.49 5,979,018.19 553,113.57 1.34 -1,66790 MWD+IFR-AK-CAZ-SC 13) 5,96869 74.38 63,99 3,333.12 3,240.50 -1,627.64 3,607.17 5,979,058.98 553,194.97 071 -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 -1,58]68 MWD+1FR-AK-CAZ-SC 13) 6,158.96 74.68 58.30 3,383.23 3,290.61 -1,544.01 3,768.12 5,979,143.67 553,355.35 579 -1,544.01 MWD+IFR-AK-CAZ-SC(3) 6,252.33 74.03 54.53 3.408.96 3,316.34 -1.493.22 3,844.61 5,979,19496 553,431.50 3.87 -1,493.22 MWD+IFR-AK-CAZ-SC(3) 6,346.97 72.68 5105 3,436.08 3,34346 -1,438.41 3,916.82 5,979,250.25 553,503.33 3.80 -1,43841 MWD+IFR-AK-CAZ-SC(3) 6,441.76 72.16 48.05 3.464.71 3,372.09 -1,37979 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 -1,31709 4,051.72 5,979,372.44 553,63].42 3.18 -1.317.09 MWD+IFR-AK-CAZ-SC(3) 6,585.21 73.18 41.30 3,507.14 3,414.52 -1,28363 4,083.10 5.979,406.11 553,668.57 743 -1,283.63 MWD+IFR-AK-CAZ-SC(3) 6,632,17 7264 38.72 3,520.94 3,428.32 -1,249.25 4,11196 5,979,44067 553,697.19 5.38 -1,249.25 MWD+IFR-AK-CAZ-SC(3) 6,727.59 7199 32.96 3,549.95 3,457.33 -1,17560 4,165.17 5.979,51467 553,749.91 579 -1,175.60 MWD+IFR-AK-CAZ-SC(3) 6,822.80 72.62 27.41 3,578.91 3,486.29 -1,097.23 4,21074 5,979,59333 553,794.96 5.59 -1,097.23 MWD+IFR-AK-CAZ-SC(3) 6,915.59 72.83 23.59 3,608.48 3,513.86 -1,017.27 4,24888 5,979,673.53 553,83257 3.94 -101727 MWD+IFR-AK-CAZ-SC(3) 7,011.34 72.49 19.05 3,635.02 3,542.40 -932.28 4,282.44 5,979,758.73 553,855.56 4.09 -93228 MWD+IFR-AK-CAZ-SC 13) 7,104.01 73.90 18.26 3,661.82 3,569.20 -848.34 4,311.14 5,9]9,842.85 553,893.70 1.99 -848.34 MWD+IFR-AK-CAZ-SC (3) 7,198.95 73.27 13.49 3.688.66 3,596.04 -760.78 4,336.05 5,979,930.57 553,918.03 4,86 -760.78 MWD+IFR-AK-CAZ-SC (3) 7,293.52 74.08 7.89 3,715.26 3,622.64 .671.64 4,352.87 5,980,019.81 553.934.25 5.75 -671.64 MWD+IFR-AK-CAZ-SC (3) 7,387.86 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) 7,48181 74.18 4.40 3,766.13 3,673.51 -091.11 4,369.05 5,980,200.43 553,949.24 0.48 491.11 MWD+IFR-AK-CAZ-SC (3) 7,57696 74.34 2.50 3,791.94 3,699.32 -399.70 4,374.56 5,980,291.86 553.954.15 1.93 -399.70 MWD+IFR-AK-CAZ-SC(3) 7,67324 74.65 2.56 3,817.68 3,725.06 -307.01 4,37866 5.980,384.56 553,957.63 0.33 J07.01 MWD+IFR-AK-CAZ-SC(3) ],]68,14 74.30 2.49 3,843.08 3,75046 -215.66 4,382.68 5.980.475 93 553,961.05 0.38 -21566 MWD+1FR-AK-CAZ-SC(3) 7,845.00 74.55 2.07 3,86372 3,771.10 -141.68 4,38563 5,980,549.92 553,963.51 0.62 -141.68 NOT an Actual Sunray 10/3/2017 11:29.45AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 111-102 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-1021.2 Survey Calculation Method Minimum Curvature Design: 1H-1021-2 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azl TVD TVDSS +N/ -S +El -W Northing Easting OLS Section (usft) V) 0 (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7-6/8" x 8-7/8 7,85800 76.40 1.38 3,866.98 3,774.36 -129.11 4,386.01 5,980,562.50 553,963.80 15.13 -129.11 MWO-INC_ONLV(4) 7.954.97 82.56 2.57 3,884.67 3,792.05 -33.87 4,389.30 5,980,65774 553,966.46 6.47 .33.87 MWD -INC _ONLY (4) 8,014.35 86.19 3.33 3,890.49 3,797.87 25.14 4,392.34 5,98,71676 553,969.11 6.24 25.14 MWD+IFR-AK-CAZ-SC(5) 8,108.31 92. t8 2.62 3,891.58 3,798.96 118.91 4,397.22 5,980,810.56 553,973.37 6.74 118.91 MWD+IFR-AK-CAZ-SC(5) 8,154.40 99.63 2.27 3,888.72 3,796.10 164.87 4,399.18 5,9W,856 53 553,975.03 4.73 184.87 MWD+IFR-AK-CAZ-SC(5) 8,202.23 9505 1.98 3,884.69 3,792.07 212.50 4,40095 5,980,904.16 553,97648 1.07 212.50 MWD+IFR-AK-CAZ-SC(5) 8,295.94 93.11 0.24 3,878.02 3,785.40 305.94 4,402]6 5,99,99761 553,977.67 2.78 305.94 MWD+IFR-AK-CAZ-SC(5) 8,390.27 90.61 0.28 3,874.96 3,782.34 400.22 4,403.18 5,981,091.87 553,97747 2.65 400.22 MWD+IFR-AK-CAZ-SC (5) 8,485.72 90.01 359.99 3,874.44 3,781.82 495.66 4,40341 5,981,187.31 553,977.06 0.70 495.66 MWD+IFR-AK-CAZ-SC (5) 6,580.64 90.46 359.14 3,874.05 3,78143 590.58 4,40269 5,981,282.21 553,97572 1.01 590.58 MWD+IFR-AK-CAZ-SC(5) 8676.10 90.02 357.24 3,873.65 3,781.03 685.99 4,39967 5,981,377.58 553,972.07 2.04 68599 MWD+IFR-AK-CAZ-SC (5) 8,77073 89.13 358.90 3,674.36 3,781.74 780.56 4,396.49 5,981,472.12 553,968.26 1.99 780.56 MWD+IFR-AK-CAZ-SC(5) 8,865.84 89.03 35677 3.875.88 3,783.26 875.58 4392.89 5,981,567.11 553,964.04 2.24 875.58 MWD+IFR-AK-CAZ-SC(5) 8,96093 89.76 356.60 3,876.89 3,784.27 970.51 4,38740 5,981,661.99 553,957.91 0.79 970.51 MWD+IFR-AK-CAZ-SC(5) 9,055.53 89.51 357.28 3,877.49 3,784.87 1,064.97 4,382.35 5,981,75640 553,952.24 0.77 1,064.97 MWD+IFR-AK-CAZ.SC(5) 9,150.62 89.34 358.32 3,878.44 3,785.82 1,159.98 4,37870 5,981,851.38 553,94796 1.11 1.159.98 MWD+IFR-AK-CAZ-SC(5) 9,245.49 8862 0.07 3,880.13 3,787.51 1,254.82 4,377.36 5,961,946.20 553,946.00 1.99 1,254.82 MWD+IFR-AK-CAZ-SC(5) 9,340.32 88.55 163 3,882.48 3,789.86 1,349.61 4,37877 5,982,040.99 553,94678 1.65 1,34961 MWD+IFR-AK-CAZ-SC(5) 9,435.28 8858 0.86 3,864.85 3,792,23 1,444.52 4,380.83 5,982,135.90 553,948.21 081 1444.52 MWD+IFR-AK-CAZ-SC(5) 9,530.04 88.56 0.47 3,887.22 3,79460 1,539.24 4.381.93 5,982,23062 553,948.68 0.41 1,539.24 MWD+IFR-AK-CAZ-SC(5) 9,62521 90.42 3.01 3,888.07 3,795.45 1,634.35 4,389.82 5,982,32574 553,950.94 3.31 1,634.35 MWD+1FR-AK-CAZ-SC (5) 9,71984 90.23 0.26 3,887.53 3,794.91 1,728.93 4,387.52 5,982,420.32 553,953.02 2.91 1,728.93 MWD+IFR-AK-CAZ-$C(5) 9,768.33 9077 359.97 3,887.11 3,794.49 1,77742 4,387.62 5,982,468.81 553,952.79 126 1,777.42 MWD+IFR-AK-CAZ-SC(5) 9,815.02 90.57 356.95 3,886.56 3,793.94 1,824.09 4,386.36 5,982,51546 553,951.23 648 1,824.09 MWD+IFR-AK-CAZ-SC(5) 9,862.70 91.37 356.35 3,885.75 3,793.13 1,87168 4,383.58 5,982,563.03 553,948.13 2.10 1,871.68 MWD+IFR-AK-CAZ-SC(5) 9,908.77 90.84 354.00 3,884.86 3,792.24 1,917.57 4,379.70 5,982,60869 553,943.95 5.23 1,917.57 MWD+IFR-AK-CAZ-SC(5) 10,004.12 90.36 350.52 3,883.86 3.791.24 2,012.03 4,366.87 5,982,703.25 553,93049 3.68 2,012.03 MWD+IFR-AK-CAZ-SC(5) 10,051.35 8803 34969 3,SIM 53 3,791.91 2,058.55 4,358.75 5,982,74971 553,922.07 5.24 2,058.55 MWD+IFR-AK-CAZ-SC(5) 10,098.47 88.92 350.07 3,885.78 3,793.16 2,104.92 4,350.47 5,982,796.02 553.913.48 2.05 2,104.92 MWD+IFR-AK-CAZ-SC(5) 10,19200 88.75 347.45 3,887.68 3,795.06 2196.63 4,33225 5,982887.60 553,89465 2.81 2,196.63 MWD+1FR-AK-CAZ-SC(5) 10,286.93 88,73 346.74 3,889.77 3,797.15 2,289.14 4,311.05 5,982,979.96 553,872.85 0.75 2289.14 MWD+IFR-AK-CAZ-SC(5) 10,378.41 88.11 349.71 3,892.29 3,799.67 2,378.65 4,292.39 5,983,069.34 553,85360 3.32 2,378.65 MWD+IFR-AK-CAZ-SC(5) 10,47089 89.67 351.84 3,894.09 3,801.47 2,469.91 4,27757 5,983,160.49 553,838.18 2.85 2,469.91 MWD+IFR-AK-CAZ-SC(5) 10,551.32 89.68 35226 3,894.60 3,801.98 2,55947 4,265.07 5,983,249.95 553,825.08 0.46 2,559.47 MWD+IFR-AK-CAZ-SC(5) 10,653.72 8923 35368 3,895.48 3,802.86 2,651.17 4,253.76 5,983,341.56 553,813.16 1.61 2,651.17 MWD+IFR-AK-CAZ-SC(5) 10,745.08 8865 354.12 3,897.17 3,804.55 2,741.99 4,244.05 5,983,432.32 553,80286 0.80 2,741.99 MWD+IFR-AK-CAZ-SC(5) 10,836.30 88.70 356.03 3,899.28 3,8W.66 2,632.85 4,236.22 5,983,523.11 553,794.43 2.09 2832.85 MWD+IFR-AK-CAZ-SC(5) 10,928.53 88.00 35736 3,901.93 3,809.31 2,924.88 4,230.91 5,983,615.10 553,788.51 1.63 2,924.68 MWD+IFR-AK-CAZ-SC(5) 11,021.78 8487 358.87 3,907.73 3,815.11 3,017.89 4,227.84 5.983,70807 553,784.83 3.73 3,017.89 MWD+IFR-AK-CAZ-SC(5) 10/32017 11:29:45AM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 1H-102 Project: Kuparuk River Unit TVD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Well: Rig: 1H-102 North Reference: True Wellbore: 1 H-10212 Survey Calculation Method: Minimum Curvature Design: 1 H-1021-2 Database: OAKEDMP2 Survey Map MD Inc, AZI TVD TVDSS +N/ -S +E/ -W Northing (usft) (") V) (usft) (usft) (usft) (usft) (ft) 11,112.96 8465 087 3,916.06 3,823.44 3,108.68 4,227.64 5,983,798.85 11,20605 88.64 358.26 3,923.13 3,830.51 3,201.49 4,226.93 5,983,891.64 11,297.04 88.69 359.44 3,926.84 3,834.22 3,292.38 4,225.11 5,983,982.51 11,389.05 89.10 359.93 3,928.61 3,635.99 3,384.37 4,224.60 5,984074.49 11481.47 9023 1.67 3,929.15 3,836.53 3,476.77 4,225.89 5,984,186.89 11,574.22 92.28 2.57 3,927.12 3,834.50 3,56943 4,229.32 5,984,259.56 11,665.74 91.25 358.70 3,924.30 3,831.68 3,660.87 4,228.74 5,984,35098 11,713.08 9260 352.92 3,92271 3,830.09 3,707.98 4,224.46 5.984,39805 11]58.30 92.71 353.25 3,920.61 3,82799 3,752.82 4,219.02 5,984,44285 11,850.43 92.53 355.58 3,91640 3,82378 3,844.41 4,210.06 5,984,534.37 11,892.46 92.81 358.03 3,914.44 3,821.82 3,686.32 4,207 72 5,984,576.27 1194285 91.11 357.29 3,912.72 3,820.10 3,936.64 4,205.67 5,984,626.57 12,03369 91.55 358.24 3,910.61 3,817.99 4,027.31 4,200.54 5,984,717.19 12,126.50 9172 0.15 3,907.96 3,815.34 4,120.02 4,197.62 5,984,809.87 12,159.89 90.57 248 3,907.29 3,81467 4,153.39 4,198.39 5.984,843.24 12,219.66 9091 4.85 3,906.52 3,813.90 4,213.03 4,202.21 5.984,902.90 12,311.08 91.04 10.11 3,904.97 3,812.35 4,303.63 4,214.10 5,984,993.56 12,403.93 90.38 11.93 3,903.82 3,811.20 4,394.75 4,231.85 5,985,084.80 12,451.65 89.79 11.16 3,903.74 3.811.12 4,441.51 4,241.40 5,985,131.61 12,495.64 90.15 9.92 3,903.77 3.811.15 4,48475 4,24945 5,985,174.90 12,540.81 8975 869 3,903.81 3,811.19 4,529.33 4,256.75 5,985,219.52 12,588.37 89.44 7.93 3,904.14 3,811.52 4,576.39 4,263.62 5,985,26662 12,632.96 8935 6.58 3,904.61 3,811.99 4,62062 4,269.25 5,985,310.88 12,678.21 88.92 5.87 3,905.30 3,812.68 4,665.59 4,274.16 5,985.355.89 12,724.85 8845 4.84 3,906.37 3,81335 4,71202 4,278.51 5,985,402.33 12,770.99 88.10 4.16 3,907.76 3,815.14 4,757.99 4,282.13 5,985,44833 12,817.28 87.45 3.37 3,909.55 3.816.93 4,804.15 4,285.17 5,965,494.50 12.86179 87.00 2.22 3,911.71 3,819.09 4,848.55 4,287.33 5,985,538.91 12,954.91 85.97 358.29 3,917.42 3,824.80 4,941.48 4,28775 5,985,631.83 13,046.64 8572 357.36 3,92407 3,831,45 5,032.90 4,284.28 5,985,723.21 13,139.28 85.65 355.94 3,930.23 3,837.61 5,125.17 4,278.88 5,985,81544 13,204.00 8830 355.77 3,933.08 3,840.46 5,189.68 4,274.20 5,985,879.89 4-1/2" z 6,314" 13,231.62 89.01 355.70 3,933.73 3,841.11 5,217.19 4,272.15 5,985,907.41 13,323.97 9361 354.95 3,931.62 3,83900 5,309.19 4,264.63 5,985,999.34 13,373.64 93.95 35541 3,928.34 3,835.72 5,358.57 4,260.46 5,986,048.69 13,435.00 9395 355.41 3,924.11 3,831.49 5,419.59 4,255.57 5,986,10967 Map Vertical Easting DLS Section (ft) (°/100') (ft) Survey Tool Name 553.78402 2.20 3,108.68 MWD+IFR-AK-CAZ-SC(5) 553,78230 3.52 3,201.49 MWD+IFR-AK-CAZ-SC(5) 553,78027 2.60 3,292.38 MWD+IFR-AK-CAZ-SC(5) 553,779.16 069 3,384.37 MWD+IFR-AK-CAZ-SC(5) 553,77984 2.24 3,476.77 MWD+IFR-AK-CAZ-SC (5) 553,782.65 241 3,569.43 MWD+IFR-AK-CAZ.SC(5) 553,78146 6.51 3,660.87 MWD+IFR-AK-CAZ-SC(5) 553,776.87 847 3,707.98 MWD+IFR-AK-CAZ-SC(5) 553,771,14 0.77 3,75262 MWD+IFR-AK-CAZ-SC(5) 553,761.58 253 3,84441 MWD+IFR-AK-CAZ-SC(5) 553,75896 5.86 3,886.32 MWD+IFR-AK-CAZ-SC(5) 553,756.57 3.68 3,936.64 MWD+IFR-AK-CAZ-SC(5) 553.75085 1.25 4,027.31 MVV)+IFR-AK-CAZ-SC(5) 553,747.31 4.22 4,120.02 MWD+IFR-AK-CAZ-SC(5) 553.74766 778 4,153.39 MWD+IFR-AK-CAZ-SC(5) 553,751.28 4.01 4,213.03 MWD+IFR-AK-CAZ-SC(5) 553,762.58 5.75 4,303.63 MWD+IFR-AK-CAZ-SC(5) 553,779.72 2.08 4.394.75 MWD+IFR-AK-CAZ.SC(5) 553,788.96 2.03 4,441.51 MWD+IFR-AK-CAZ-SC (5) 553,796.72 2.94 4,484 75 MWD+IFR-AK-CAZ-SC (5) 553,803.73 2.88 4,529.33 MWD+IFR-AK-CAZ-SC(5) 553,81029 1.73 4,57639 MWD+IFR-AK-CAZ-SC(5) 553,815.62 3.03 4,620.62 MWD+IFR-AK-CAZ-SC(5) 553,820.23 1.83 4,665.59 MWD+IFR-AK-CAZ-SC(5) 553,824.28 2.43 4,712.02 MWD+IFR-AK-CAZ-SC (5) 553,827.59 1.65 4,757.99 MWO+IFR-AK-CAZ-SC (5) 553,830.32 221 4,804.15 MWD+IFR-AK-CAZ-SC(5) 553,832.20 2.77 4,848.55 MWD+IFR-AK-CAZ-SC(5) 553,832.00 4.36 4,94148 MWD+IFR-AK-CAZ-SC (5) 553,827.92 105 5,032.90 MWD+IFR-AK-CAZ-SC(5) 553,821.91 1.83 5,125.17 MWD+IFR-AK-CAZ-SC (5) 553,816.81 2.57 5,18966 NOTanAehiY.S6rv6y 553,814.57 2.57 5,217,19 MWD+IFR-AK-CAZ-SC 15) 553,806.44 5.05 5,309.19 MWD+IFR-AK-CAZ-SC(5) 553,801.95 1.15 5,358.57 MWD+IFR-AK-CAZ-SC(5) 553,796.65 0.00 5,419.59 PROJECTED to TD 101312017 11:29:45AM Page 6 COMPASS 5000.14 Build 85 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. 0 Yes ❑ No 1 have chocked to the best of my ability that the following data is correct E Surface Coordinates U Declination & Convergence GRS Survey Corrections Survey Tool Codes Temple SLB DE: Brandon 1 ernple Dite:20ally si 10.031ned by Brandon34:30-11:34:30-08-00- Client 2 017.10.03 11:34:30 -08'00' Client Representative: ..y..o.y—.yam.._..__ Kelsey Hallford MU2OV.0 lwo G� wuzoo.n Din iosooem Date: 10103(17 RECEIVED OCT 2 6 2017 FINAL AOGCC ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad 1 H-1021-2 1H -102L2 ConocoPhillips Definitive Survey Report 03 October, 2017 21 7101 28 7-5 0 i ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Rig: 1H-102 Wellbore: 11-1-10212 Design: iH-102L2 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Rig: IH -102 1 HA 02 actual @ 92.62usft (Doyon 142) 1 H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 'roject Kuparuk River Unit, North Slope Alaska, United States lap System: US Stale Plane 1983 System Datum: Mean Sea Level ieo Datum: North American Datum 1983 Using Well Reference Point lap Zone: Alaska Zone 4 Using geodetic scale factor Well Rig: iH-102 Audit Notes: To Map Well Position +N/ -S 0.00 usft Northing: 5,980,414.37 usft Latitude: 70" 21'27.583 N Depth From (TVD) +E/ -W 0.00 usft Easting: 1,689,609.08 usft Longitude: 149° 36' 1.638 W Position Uncertainty 1,777.33 0.00 usft Wellhead Elevation: usft Ground Level: 54.00 usft Wellbore 1H-1021-2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength P) l9 (nT) BGGM2017 9/21/2017 17.48 80.95 57,489 Design 11-1-10212 Date 10/3/2017 Audit Notes: To Map Map Version: 1.0 Phase: ACTUAL Tie On Depth: 7,768.14 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 1,050.36 (usft) (usft) (usft) V) 1,777.33 38.62 OAO 0.00 0.00 Survey Program Date 10/3/2017 From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 67.62 1,009.26 1 H-102 Srvy 1 - SLB GW070 (11-1-102) GYD-GC-SS Gyrodata gyro single shots 8/24/2017 10:04 1,050.36 1,678.041H-102 Srvy 2- SUB _MWD+GMAG(1 H- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 8/24/201710:12 1,777.33 7,768.141H-102 Srvy 3 -SLB MWD+GMAG(1 H- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 8/27/2017 12:16 7,845.00 7.954+971H-1021-2 Srvy 1- SLB _MWD -INC Filler MWD-INC_ONLY MWD -INC ONLY -FILLER 9/21/2017 2:59: 8,014.35 13,373.641H-1021-2 Srvy 2-SLB_MWD+GMAC It MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 9/22/2017 3:02: Survey 10/3/2017 8:41:58AM Page 2 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I V) (usft) (usft) (usft) (usft) (ft) (ft) (0/1001 (ft) Survey Tool Name 38.62 0.00 0.00 38.62 -54.00 O.OD 0.00 5,980,414.37 1689,609.08 OAD 0.00 UNDEFINED 6762 0.19 41.29 67.62 -25.00 0.04 0.03 5.980.414.40 1,689,609 12 0.66 004 GYD-GC-SS(1) 165.90 0.45 132.01 165.90 7328 -0.10 043 5,980,41427 1,689,609.51 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) 35448 3.34 138.19 354.40 26178 -3.44 3.86 5,980,410.95 1,68061297 246 -3.44 GYD-GC-SS(1) 447.17 4.61 135.26 446.86 35424 -8.10 8.28 5,980,406.32 1,689,617.42 1.39 -8.10 GYD-GC-SS(1) 539.82 5.77 132.42 539.13 446.51 -13.89 14.34 51980400.57 1,689,623.51 1.28 -1389 GYD-GC-SS(1) 63284 7.61 13449 631.51 53889 -21.36 22.19 5.980,393.15 1,689,631.41 1.99 -21.36 GYD-GC-SS(1) 725.82 877 137.82 723.54 630.92 -30.93 31.34 5,980.38365 1,689,640.62 1.35 -30.93 GYD-GC-SS(1) 821.24 10.73 141.32 817.58 724.96 -43.25 41.78 5,980,371.39 1,689,651.14 2.15 -43.25 GYD-GC-SS(1) 10/3/2017 8:41:58AM Page 2 COMPASS 5000.14 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-1021-2 1H-1021-2 MD Inc Azi (usft) (I V) 91420 12.89 13961 1009.26 14.89 136.85 1,050.38 15.72 135.96 1,144.89 17.17 134.37 1.239.16 20.84 134.25 1.334.20 24.71 138.54 1,428.98 27.54 137.49 1523.25 28.14 137.93 1,61809 28.94 137.33 1,678.04 29.99 135.80 1771.00 33.38 135.72 10 3/4" 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 40.86 131.83 2,086.48 43.97 130.99 2,184.36 47.16 12949 2,276.23 50.09 128.77 2,371.48 53.12 127.35 2 464 98 55.35 124.47 2,55960 56.73 12273 2,653.87 58.79 122.43 2,748.30 59.37 121.74 2,843.07 6140 121.48 2,937.25 65.11 12193 3,032.88 69.13 121.16 3,12686 71.43 121.37 3,221.95 72.62 121.37 3,316.46 7303 121.69 3,41086 73.34 122.71 3,506.07 73.21 122.55 3,601.42 73.21 122.70 3,696.85 73.21 122.29 3,79146 73.30 12098 3,88634 73.14 118.95 3,98194 73.09 119.64 4,076.41 73.30 119.87 4,171.02 73.17 118.99 4,266.02 73.06 119.53 4.36046 73.01 119.04 ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Rig: 11-1-102 1 H-102 actual @ 92.62usft (Doyon 142) 1 HA02 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 1,696.21 1,603.59 -304.85 28861 Map Map TVD TVDSS +N/S +E/ -W Northing Easting D (usft) (usft) (usft) (usft) (ft) (it) (°/1 908.57 81595 -57.91 53.90 5,980,356.82 1,689,663.36 1.000.84 908.22 -74.90 69.13 5,980,339.93 1,689,678.70 1,040.49 947.87 -82.75 7661 5,980,332.13 1,689,686.23 1,131.15 1,038.53 -10132 95.49 5,980,313.29 1,689,70523 1,220.26 1,12764 -123.16 11746 5,980,29200 1889,727.33 1,307.88 1,215.26 -149.38 143.24 5,980,26594 1,689,75329 1,392.97 1,300.35 -179.92 171.68 5,980,235.60 1,689,781.92 1,476.33 1,383.71 -212.49 201.30 5,980,203.23 1,68881175 1,55964 1467.02 -245% 231.84 5,980,169.96 1,689,842.51 1,611.84 1,519.22 -26737 252.11 5,980,14869 1,689,862.92 1,690.93 1598.31 -302.34 286.17 5,980,113.94 1,689,897.21 1,696.21 1,603.59 -304.85 28861 5,980,11145 1,689,89966 1,716.32 1,623.70 -314.50 298.19 5,980,101.86 1,689,909.30 1793.04 1,700.42 -353.55 338.45 5,980,063.08 1,689,949.82 1866.72 1,774.10 -39445 382.87 5,980,022.48 1,689.994.50 1,936.52 1,843.90 -436.61 43030 5,979,980.63 1,690,04260 2,005.04 1,91242 -481.73 484.06 5,979,93587 1,690,096.25 2,065,76 1,973.14 -525.22 537.53 5,979,892.74 1,690,15000 2,124.92 2,032.30 -571.22 596.31 5,979,847.13 1,690,209.07 2,179.57 2,086.95 -615.68 657.76 5,979,803.07 1,690,270.80 2,232.43 2,139.81 -659.10 723.12 5,979,760.09 1,690,336.45 2.282.72 2,190.10 -702.03 790.31 5,979,717.61 1,690.403.91 2,331.24 2,23882 -745.06 858.95 5,979,67503 1,690,47282 2,378.07 2,28545 -788.24 929.11 5,979,632.32 1,690,54326 2,420.45 2,327.83 -83244 1.00065 5,979,588.60 1,690,615.08 2,457.62 2,36500 -878.52 1,075.72 5,979,543.02 1,690,690.45 2,489.33 2,396.71 -924.43 1,151.34 5,979,49761 1,690,766.35 2,518.67 2,426.05 -971.51 1,228.56 5,979,451.04 1,690,843.88 2,546.58 2,453.% -1018.73 1,305.53 5,979,404.33 1,690,921A5 2,573.89 2,48127 -1.066.89 1,38199 5,979,35668 1,690,997.92 2,601.29 2,508.67 -1,116.05 1,458.78 5,979,30803 1,691,075.02 2,628.83 2,536.21 -1,165.27 1,535.66 5,979,259.32 1,691,152.22 2,656.40 2,563.78 -1,214.35 1,612.72 5,979,210.75 1,691,229.59 2,683.66 2,591.04 -1,261.87 1869.85 5,979,163.75 11691,307.03 2,711.17 2,618.55 -1,307.43 1,768.88 5,979,118.71 1,691,38634 2,738.82 2,646.20 -1352.00 1,848.32 5,979.074.66 1,69146607 2,766.13 2,673.51 -1,396.88 1,926.84 5,979,030.30 1891,544.87 2.79342 2,700.80 .1,441,40 2,005.73 5,978,966.31 1,691,624.05 2,821.02 2,728.40 -148513 2,085.04 5,978,942.41 1,691,703.63 2,848.57 2,755.95 -1,530.012,16383 5.978,898.75 1,691,782.70 LS Vertical Section 00') (ft) Survey Tool Name 2.35 -57.91 GVD-GC-SS it) 2.22 -74.90 GVD-GC-SS(1) 2.10 -82.75 MWD+IFR-AK-CAZ-SC(2) 1.61 -10172 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 -179.92 MWD+IFR-AK-CAZ-SC(2) 0.67 -21249 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) 365 -302.342 NI bi1H8y 3.65 -30485 MWD+IFR-AK-CAZ-SC(3) 4.35 -314.50 MWD+IFR-AK-CAZ-SC (3) 3.54 -353.55 MWD+IFR-AK-CAZ.SC(3) 3.39 -394.45 MWD+IFR-AK-CAZ-SC(3) 3.34 436.61 MWD+IFR-AK-CAZ-SC(3) 344 -481.73 MM+IFR-AK-CAZ-SC (3) 3.23 -525.22 MWD+IFR-AK-CAZ-SC (3) 340 -571.22 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 -83244 MWD+IFR-AK-CAZ-SC(3) 4.27 -878.52 MWD+IFR-AK-CAZ-SC(3) 2.46 -92443 MWD+IFR-AKCAZ-SC(3) 1.25 -971.51 MWD+IFR-AK-CAZ-SC(3) 0.54 -1,01873 MWD+IFR-AK-CAZ-SC(3) 1.09 -1,06689 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 -1307.43 MWD+IFR-AK-CAZ-SC(3) 0.70 -1,352.00 MWD+lFR-AK-CAZ-SC (3) 0.32 -1,39688 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 MWD+tFR-AK-CAZ-SC(3) 1013/2017 8:41 58AM Page 3 COMPASS 500014 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 Pad Well: Rig: 1H-102 Wellbore: 111-10212 Design: 111-10212 Survey 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 @ 92.62usft (Doyon 142) 1 H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 Map Map MD Inc Am TVD TVDSS +N/ -S +El -W Northing Easting (usft) (I V) (usft) lush) lush) lush) (ft) (ft) 4,455.58 72.90 119.77 2,876.45 2763.83 -1,57466 2.243.05 5,978,8U 62 1,691,862.21 4,54961 7287 120.06 2,904.19 2,811.57 -1,619.57 2,321.11 5,978,810.23 1,691,940.55 4,644.52 73.20 118.40 2,931.82 2,839.20 -1,663.81 2,400.16 5,978,768.52 1,692,019.89 4,73999 72.42 114.51 2,960.05 2,867.43 -1,704.44 2,481.79 5,978,726.43 1,692,101.78 4,78624 72.31 110.47 2,974.06 2.88144 -1,721.29 2,522.51 5.978T709 84 1,692,142.60 4,83376 7248 108.23 2,988.44 2,895.82 -1,736.30 2,565.24 5,978,695.12 1,692,18542 4,928.09 72.21 103.78 3,017.06 2,92444 -1,761.08 2,651.62 5,978,67091 1,692,271.95 5,022.87 71.11 100.68 3,046.89 2,95427 -1,780.14 2,73952 5,978,652.43 1,692,359.97 5,070.23 71.27 9869 3,062.16 2,969.54 -1,787.68 2,78371 5,978,645.18 1,692,404.21 5,11677 71.68 96.97 3,07895 2.984.33 -1,793.69 2,82743 5,978,639.46 1,692,447.96 5,211.19 72.12 9377 3,19729 3,013.67 -1,802.09 2,916.77 5,97863165 1,692,537.34 5,305.75 71.74 88.59 3,13564 3,043.02 -1,803.94 3,00661 5,978,630.38 1,692,627.18 5,400.08 7170 83.77 3,16524 3,072.62 -1,79798 3,09595 5,978,83693 1,692,716.47 5,495.26 72.32 81.29 3,19464 3,102.02 -1,786.21 3,185.70 5,978,649.29 1,692,80813 5,590.01 72.15 76.05 3,223.57 3,130.95 -1,768.49 3,274.13 5,978,667.59 1,692,894.44 5,68545 72.61 70.23 3,25248 3,159.85 -1.742.11 3,381.14 5,978,694.53 1,692,98127 5,779,73 7302 64.52 3,280.36 3.187.74 -1,707.48 3,444.24 5,978,72971 1,693,064.13 5,874.02 73.87 63.54 3,307.23 3,214.61 -1,667.90 3,525.49 5,978.769.82 1,693,145.11 5,96869 74.38 63.99 3,333.12 3,240.50 .1,627.64 3,607.17 5,978,810.60 1,693,226.51 6,063.17 74.61 63.93 3,358.38 3,265.76 -1.587.68 3,688.97 5,976,851.10 1,693,30804 6,156.96 7468 58.30 3,383.23 3,29061 .1,544.01 3,768.12 5,978,895.29 1,693,38690 6,252.33 74.03 54.53 3,408% 3,316.34 -1493.22 3,844.61 5,978,946.57 1693,463.05 6,346.97 72.68 51.05 3.436.08 3,343.46 -1.438.41 3.916.82 5,979,001,85 1,693,53489 6,441.76 72.16 48.05 3,464.71 3,372.09 -1,379.79 3,985.58 5,979,06091 1,693,60325 6,53727 73.10 45.02 3.493.23 3,400.61 -1,317.09 4,051.72 5,979,124.04 1,693,66897 6,585.21 73.18 4130 3,507.14 3,414.52 -128363 4,083.10 5.979,157 70 1,693,700.13 6,632.17 72.64 38.72 3,520.94 3,428.32 -1,249.25 4,111.% 5,979,192.26 1,693,72876 6,727.59 71.99 32.96 3,549.95 3,457.33 -1,175.60 4,165.17 5,979,268.26 1,693,781.48 6,82280 72.62 27.41 3,578.91 3,486.29 -1,097.23 4,210.74 5,979,34492 1,693,826.53 6,915.59 7283 23.59 3,608.48 3,513.86 -1,017.27 4,24888 5,979,425.12 1,693,864.14 7,011.34 72.49 1950. 3,635.02 3,542.40 -932.28 4,282.44 5,979,510.32 1,893,897.14 7,104.01 73.90 18.26 3,66182 3,569.20 -848.34 4,311.14 5,979,59444 1,693,925.28 7.198.95 73.27 13.49 3,688.66 3.596.04 -760.78 4,336.05 5,979.682.15 1,693,949.61 7,293.52 74.08 7.89 3,715.26 3,622.64 -67164 4,352.87 5,979,77140 1,693,965.84 7,387.86 74.53 4.10 3,740.79 3,648.17 -581.33 4,362.35 5979,861.76 1.693,974.73 7,481.81 74.18 4.40 3,766.13 3,673.51 491.11 4,369.05 5,979,952.01 1,693,980.84 7,576.96 7434 2.50 3,791.94 3,69932 39970 4,374.56 5,980,043.45 1,693,985.75 7,673.24 74.65 2.56 3,817.68 3,725.06 -30]01 4,378.66 5,980,136.15 1,693,989.24 7,768.14 7430 249 3,843.08 3,75646 -21566 4,382.68 5,980,227.51 1,693,992.66 7,845.00 74.55 2.07 3,863.72 3,771.10 -141.68 4,385.63 5,980,301.50 1,693,995.12 Vertical DLS Section (°7100') (ft) Survey Tool Name 0.74 -1,57466 MWD+IFR-AK-CAZ-SC(3) 0.30 -1,619.57 MWD+IFR-AK-CAZ-SC(3) 1.71 -1663.81 MWD+IFR-AK-CAZ-SC(3) 3.98 -1,704.44 MWD+IFR-AK-CAZ-SC(3) 8.33 -1,721.29 MWD+IFR-AK-CAZ-SC(3) 4.51 -1,736.30 MWD+IFR-AK-CAZ-SC(3) 4.50 -1,76108 MWD+IFR-AK-CAZ-SC(3) 331 -1,780.14 MWD+IFR-AK-CAZ-SC(3) 3.99 -1,78768 MWD+IFR-AK-CAZ-6C(3) 361 -1,79369 MWD+IFR-AK-CAZ-SC 13) 3.25 -1,802.09 MWD+IFR-AK-CAZ-SC(3) 5.22 -1,803.94 MWD+IFR-AK-CAZ-SC(3) 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(3) 5.80 -1,707.48 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 -1,587.68 MWD+IFR-AK-CAZ-SC(3) 579 -1,544.01 MWD+IFR-AK-CAZ-SC(3) 3.87 -1,493.22 MWD+IFR-AK-CAZ-SC(3) 3.80 -1,438.41 MWD+IFR-AK-CAZ-SC(3) 3.07 -1,37979 MWD+IFR-AK-CAZ-SC(3) 3.18 -1,317.09 MWD+IFR-AK-CAZ-SC(3) 7.43 -1,283.63 MWD+IFR-AK-CAZ-SC(3) 5.38 -1,249.25 MWD+IFR-AK-CAZ-SC(3) 5.79 -1,175.60 MM+IFR-AK-CAZ-SC (3) 5.59 -1,097.23 MWD+IFR-AK-CAZ-SC(3) 3.94 -1,017.27 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) 575 -67164 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 -39970 MWD+IFR-AK-CAZ-SC (3) 0.33 -30701 MWD+IFR-AK-CAZ-SC(3) 0.38 -215.66 MWD+IFR-AK-CAZ-SC(3) 062 -141 68 101312017 8:41:58AM Page 4 COMPASS 500014 Build 85 ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Cc -ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1 H Pad MD Reference: Well: Rig: 1H-102 North Reference: Wellbore: 1 H-10212 Survey Calculation Method: Design: 1H-1021-2 Database: Survey Well Rig: 111-102 1 H-102 actual @ 92.62usft (Doyon 142) 1H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 10/3/2017 8: 41:58AM Page 5 COMPASS 5000.14 Build 85 Map Map vertical MD Inc Azi TVD TVDSS -NI-S +El -W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (1/100') (ft) Survey Tool Name 7.618" x 9-718 7,858.00 7640 1.38 3,866.98 3,774.36 -129.11 4,386.01 5,980,31408 1,693,995.42 15.13 -129.11 MWD-INC_ONLV(4) 7954.97 82.% 2.57 3,88467 3,792.05 -33.87 4,389.30 5,980.409.33 1,693,998.09 6.47 -33.87 MWD-INC_ONLV(4) 8,01435 86.19 3.33 3,890.49 3,797.87 25.14 4,392.34 5,980,468.34 1,694,000.74 6.24 25.14 MWD+IFR-AK-CAZ-SC(5) 8,108.31 9248 2.62 3,891.58 3,798.96 118.91 4,397.22 5,980,562.14 1,694,005.00 634 118.91 MWD+IFR-AK-CAZ-SC(5) 8,154.40 9463 2.27 3,88872 3,796.10 164.87 4,399.18 5980,608.11 1,694,00866 4.73 164.87 MWD+IFR-AK-CAZ-SC(5) 8,202.23 95.05 1.98 3,884.69 3.792.07 212.50 4,400.95 5,980,65534 1,694,008.11 107 212.50 MWD+IFR-AK-CAZ-SC(5) 8,29594 93.11 0.24 3,87802 3,785.40 305.94 4,402.76 5,980,749.19 1,694,009.31 2.78 30594 MWD+IFR-AK-CAZ-SC(5) 8,390.27 90.61 0.28 3,874.96 3,782.34 400.22 4,403.18 5,980,843.45 1,694,009.12 2.65 400.22 MWD+IFR-AK-CAZ-SC(5) 8,48572 90.01 359.99 3,874.44 3,781.82 49566 4,403.41 5,980,938.89 1,694,00872 0.70 495.66 MWD+IFR-AK-CAZ-SC(5) 8,580.64 90.46 359.14 3,874.05 3,781.43 590.58 4,402.69 5,981,033.79 1,694,00737 1.01 590.58 MWD+IFR-AK-CAZ-SC(5) 8,676.10 9002 35724 3,87365 3,781.03 685.99 4,399.67 5,981,129.16 1,694.00333 2.04 685.99 MWD+IFR-AK-CAZ-SC(5) 8,770.73 89.13 358.90 3,874.36 3,781.74 780.56 4,396.49 5,981,22370 1,693,999.92 199 780.56 MWD+IFR-AK-CAZ-SC(5) 8,865.84 89.03 356.77 3,875.88 3,783.26 875.58 4,392.89 5,981,318.69 1,693.99571 2.24 87558 MWD+IFR-AK-CAZ-SC(5) 8,960.93 8976 356.60 3,876.89 3,784.27 970.51 4,38740 5,981413.57 1,693.989.59 039 970.51 MWD+IFR-AK-CAZ-SC(5) 9,055.53 89.51 357.28 3,877.49 3,784.87 1,064.97 4,382.35 5,981,507.99 1,693,98392 0.77 1,064.7 MWD+IFR-AK-CAZ-SC(5) 9,150.62 89.34 358.32 3,87844 3,785.82 1,15898 4,378.70 5.981,602.97 1,693,979.64 1.11 1,159.98 MWD+IFR-AK-CAZ-SC(5) 9,245.49 88.62 0.07 3,880.13 3,787.51 1,254.82 4,37736 5,981,697.79 1,693,9]].69 1.99 1254.82 MWD+1FR-AK-CAZ-SC(5) 9,340.32 68.55 1.63 3,882.48 3,789.86 1,34961 4,378.77 5,981,792.57 1,693,9]8.47 1.65 1,349.61 MWD+IFR-AK-CAZ-SC(5) 943528 88.58 0.86 3,884.65 3.792.23 1,444.52 4.380.83 5,981,88748 1693,9]9.91 0.81 1,444.52 MWD+IFR-AK-CAZ-SC(5) 9,530.04 88.56 0.47 3,8722 3,794.60 1,53924 4,381.93 5,981,982.20 1,693,980.39 0.41 1,539.24 MWD+IFR-AK-CAZ-SC(5) 9,625.21 90.42 3.01 3,888.07 3,795.45 1,634.35 4,384.82 5,982,077.32 1,693,98265 3.31 1634.35 MWD+IFR-AK-CAZ-SC(5) 9,719.84 90.23 0.26 3,887.53 3,794.91 1,728.93 4,387.52 5,982,171.91 1,693,98433 2.91 1,728.93 MWD+IFR-AK-CAZ-SC(5) 9,768.33 90.77 359.97 3,887.11 3,794.49 1,777.42 4,M7 62 5,982,220.39 1,693,984.51 1.26 1,777.42 MWD+IFR-AK-CAZ-SC(5) 9,815.02 90.57 356.95 3,886.56 3,793.94 1,824.09 4,386.36 5,982,267.04 1,693.98295 6.48 1824.09 MWD+IFR-AK-CAZ-SC(5) 9,86230 91.37 $56.35 3,885.75 3,793.13 1,871.68 4,383.58 5,982,314.61 1.693,979.85 2.10 1,871.68 MWD+IFR-AK-CAZ-SC(5) 9,908.77 9064 354.00 3,864.85 3,792.24 1,917.57 4,37970 5,982,360.47 1,693,97568 5.23 1,91].57 MWD+IFR-AK-CAZ-SC(5) 10,004.12 90.36 350.52 3,88386 3,791.24 2,012.03 4,366.87 6,982 454,84 1,693,962.22 368 2,012.03 MWD+IFR-AK-CAZ-SC(5) 10,05135 88.03 349.69 3,884.53 3,791.91 2,058.55 4,35835 5,982,501.30 1,693,953.80 5.24 2,058.55 MWD+IFR-AK-CAZ-SC(5) 10,098.47 88.92 350.07 3,885.78 3,793.16 2,104.92 4,350.47 5,982,547.61 1,693,94522 2.05 2,104.92 MWD+IFR-AK-CAZ-SC(5) 10,19200 88.75 34745 3,887.68 3,795.06 2,196.63 4,332.25 5,982,639.19 1,693,926.39 2.61 2,196.63 MWD+IFR-AK-CAZ-SC(5) 10,286.93 8873 346.74 3,889.77 3,]9].15 2,289.14 4,311.05 5,982.731 55 1,693,904.59 0.75 2,289.14 MWD+IFR-AK-CAZ-SC(5) 10,378.41 88.11 349.71 3,892.29 3,799.67 2,378.65 4,29239 5,982,82092 1,693,885.35 3.32 2,37865 MWD+IFR-AK-CAZ-SC(5) 10,470.89 8967 351.84 3,894.09 3,801.47 2,469.91 4,277.57 5,982,912.07 1,693,869.93 2.85 2,469.91 MWD+IFR-AK-CAZ-SC(5) 10,561.32 8868 35226 3,894.60 3,801.98 2.55947 4,265.07 5,983,001.54 1,693,856.83 0.46 2,55847 MWD+IFR-AK-CAZ-SC(5) 10,653.72 8923 35368 3,895.48 3,802.86 2,651.17 4,253.76 5,983,093.15 1,693,844.93 161 2,651.17 MWD+IFR-AK-CAZ-SC(5) 10,745.08 88.65 354.12 3,897.17 3,804.55 2,74199 4,244.05 5.983,183.91 1,693,834,62 0.80 2,741.99 MWD+IFR-AK-CAZ-SC(5) 10,836.30 8830 356.03 3,899.28 3,806.66 2,832.85 4,236.22 5,983,274.70 1.693,826.20 2.09 2,832.85 MWD+IFR-AK-CAZ-SC(5) 10,928.53 88.00 357.36 3,901.93 3,809.31 2,924.88 4.230.91 5,983,366.69 1,693,820.28 1.63 2,924.88 MWD+IFR-AK-CAZ-SC(5) 11,02138 84.87 358.87 3,907.73 3,815.11 3,017.89 4,22].84 5,983,459.86 1,693,816.61 3.73 3,017.89 MWD+IFR-AK-CAZ-SC(5) 10/3/2017 8: 41:58AM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupi Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1 H Pad MD Reference: Well: Rig. 1H-102 North Reference: Wellbore: 111-10212 Survey Calculation Method: Design: 111-10212 Database: Well Rig: 1 H-102 111-102 actual Q 92.62usft (Doyon 142) 1 H-102 actual Qa 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +Ei-W Northing Easting DLS Section (usft) (1 0 (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 11.112.96 8465 0.87 3,916.% 3,823.44 3,108.68 4,227.64 5,983,550.44 1,693,815.80 220 3,108.68 MWD+IFR-AK-CAZ-SC(5) 11,206.05 86.84 358.26 3,923.13 3,830.51 3,201.49 4,226.93 5,983,643.23 1,693,814.49 3.52 3,201.49 MWD+IFR-AK-CAZ-SC(5) 11,297.04 88.69 359.44 3,926.84 3.834.22 3,29238 4,225.11 5,983,734.10 1,693812.07 2.60 3,292.38 MWD+IFR-AK-CAZ-SC(5) 11,38805 89.10 359.93 3,926.61 3,835.99 3,384.37 4,224.60 5,983,82608 1693,810.96 0.69 3,384.37 MW0+1FR-AK-CAZ-SC(5) 11481.47 9023 1.67 3,929.15 3,836.53 3,476,77 4,22589 5,983,918.48 1,693,81164 2.24 3,476.77 MWD+IFR-AK-CAZ-SC(5) 11,574.22 92.28 2.57 3,927.12 3,834.50 3,569.43 4,229.32 5,984,011.15 1693,814.46 241 3,56943 MWD+IFR-AK-CAZ-SC(5) 11865]4 91.25 356.70 3,924.30 3,831.68 3,66087 4,228.74 5,984,102.57 1,693,813.28 6.51 3,660.87 MWD+IFR-AK-CAZ-SC(5) 11,713.08 9260 35292 3,922.71 3,830.09 3,707.98 4,224.46 5984,149.64 1,693,808.69 8.47 3,70798 MWD+IFR-AK-CAZ-SC(5) 11]58.30 92.71 353.25 3,920.61 3,827.99 3,752.82 4,21902 5,984,194.45 1,693,802.96 0.77 3,752.82 MWD+IFR-AK-CAZ-6C(5) 11,850.43 92.53 355.58 3,916.40 3,823.78 3,844.41 4,210.06 5,984,285.97 1693,79340 2.53 3.84441 MWD+IFR-AK-CAZ-SC(5) 1189246 92.81 358.03 3,91444 3821.82 3,886.32 4,20712 5,984.327.86 1,693.790]9 5.86 3,886.32 MWD+IFR-AK-CAZ-SC(5) 11,942.85 91.11 357.29 3,912.72 3,82010 3,93664 4,205.67 5,984,378.16 1,693,788.40 368 3,936.64 MWD+IFR-AK-CAZ-SG(5) 12,03369 91.55 356.24 3,910.61 3.817.99 4827.31 4,200.54 5,984,468.78 1,693,782.68 1.25 4,027.31 MWD+IFR-AK-CAZ-SC(5) 12,126.50 91.72 0.15 3,907.96 3,815.34 4,120.02 4,19762 5,984,551.46 1,693,779.15 4.22 4,12002 MWD+IFR-AK-CAZ-SC(5) 12.159.89 9057 248 3,90729 3,814.67 4,153.39 4,198.39 5,984,594.83 1,693,779.70 7.78 4,153.39 MWD+IFR-AK-CAZ-SC(5) 12,219.66 90.91 4.85 3,906.52 3,813.90 4,213.03 4,202.21 5,984,654.49 1,693,783.13 4.01 4,213.03 MWD+IFR-AK-CAZ-SC (5) 12,311.08 91.D4 10.11 3,904.97 3,812.35 4,30363 4,214.10 5,984,745.15 1,693,794.42 575 4,303.63 MWD+IFR-AK-CAZ-SC(5) 12,403.93 90.38 1193 3,903.82 3,811.20 4,394.75 4,231.85 5,984,836.39 1,693,811.57 2.08 4,39435 MWD+IFR-AK-CAZ-SC(5) 12.451.65 89.79 11.16 3,903.74 3,811.12 4,441.51 4,24140 5,984,883.20 1693,820.81 203 4,441,51 MWD+IFR-AK-CAZ-SC(5) 12,49564 90.15 9.92 3,90337 3,811.15 4,484.75 4,249.45 5,984,926.49 1,693,828.57 2.94 4,484.75 MWD+IFR-AK-CAZ-SC(5) 12,540.81 8975 869 3,903.81 3,811.19 4,529.33 4,256.75 5,984,971.11 1,693,835.58 2.86 4,529.33 MWD+IFR-AK-CAZ-SC(5) 12,588.37 89.44 7.93 3,904.14 3,81152 4,576.39 4,263.62 5,885,018.21 1,693,842.15 1.73 4,576.39 MWDHFR-AK-CAZ-SC(5) 12,632.96 8935 6.58 3,900.61 3,811.99 4,620.62 4,269.25 5,98566247 1,693,847.49 3.03 4,62062 MWD+IFR-AK-CAZ-SC(5) 12,678.21 88.92 5.87 3,90530 3,812.68 4.66559 4,274.16 5.985,107 47 1,693,85210 1.83 4,665.59 MWD+IFR-AK-CAZ-SC(5) 12,724.65 88.45 4.84 3,906.37 3,813.75 4,712.02 4,278.51 5,985,153.92 1,693,856.14 2.43 4.712.02 MWD+IFR-AK-CAZ-SC (5) 12,77099 88.10 4.16 3,90776 3,815.14 4,75799 4,282.13 5,985,199.92 1,693,85946 1.66 4,757.99 MWD+IFR-AK-CAZ-SC(5) 12,817.28 87.45 3.37 3,909.55 3,816.93 4,804.15 4,285.17 5,985,24808 1,693,852.19 2.21 4,804.15 MWD+IFR-AK-CAZ-SC(5) 12,861]9 87.00 2.22 3,911]1 3,81909 4,84855 4,287.33 5,985,29050 1,693,86407 277 4,848.55 MWD+IFR-AK-CAZ-8C(5) 12,954.91 85.97 358.29 3,91742 3,824.80 4,941.48 4,28775 5,985,38341 1,693,86387 4.36 4,941.48 MWD+IFR-AK-CAZ-SC(5) 13,046.64 8532 357.36 3,924.07 3,831.45 5,032.90 4,284.28 5,985,474.80 1,693,859.80 1.05 5,03290 MWD+IFR-AK-CAZ-SC(5) 13,139.28 86.65 355.94 3,930.23 3.837.61 5,125.17 4,278.88 5,985.567.03 1,693,85380 1.83 5,125.17 MWD+IFR-AK-CAZ-SC(5) 13,204.00 88.30 355.77 3,933.08 3,84046 5,189.66 4,27420 5,985,63148 1693,848.70 2.57 5,189.66 �TigIN .g41y4J1 4.112' x 6.014" 13,231.62 8901 355.70 3,93313 3,841.11 5,217.19 4,272.15 5,985,659.00 1,693,84647 2.57 5217.19 MWD+IFR-AK-CAZ-SC(5) 13,323.97 93.61 354.95 3,931.62 3,839.00 5,309.19 4,264.63 5,985,750.93 1,693,838.34 5.05 5,309.19 MWD+IFR-AK-CAZ-SC (5) 13,373.64 93.95 355.41 3,928.34 3,83572 5,358.57 4,260.46 5,885,800.28 1,693,833.85 1.15 5,358.57 MWD+IFR-AK-CAZ-SC(5) 13,435.00 93.95 355.41 3,924.11 3,831.49 5,419.59 4,255.57 5,985,66126 1,693,828.55 0.00 5,419.59 PROJECTEDIOTD 10/3/2017 8:41:58AM Page 6 COMPASS 5000.14 Build 85 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. F,1 Yes ❑ No 1 have checked to the best of my ability that the following data is correct: D Surface Coordinates [j Declination & Convergence GRS Survey Corrections Survey Tool Codes Brandon Tem le Digitally signed by Brandon Temple SLB DE: Date: 2017.10.03 11:34:30 -08'0(Y Client Representative: Kelsey Ha Ilford pY309.IIR1S1p5080J Date: 1010N17 THE STATE OfALASKA 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.olaska.gov Re: Kuparuk River Field, West Sak Oil Pool, KRU 1H -102L2 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-101 (Revised) Surface Location: 40.52' FNL, 764.65' FEL, SEC. 33, T12N, RIDE, UM Bottomhole Location: 5175.82' FNL, 1775.32' 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, Hollis S. French { Chair DATED thisic) day of September, 2017. RECEIVE® <- STATE OF ALASKA SEP 1,' OIL AND GAS CONSERVATION COMI, ,ON ACIGCC PERMIT TO DRILL 20 AAC 25.005 _�EVi5ob 1 a. Type of Work: 11b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG LJ Service - Disp ❑ 1c. Speafy if well is proposed for: Drill ❑ Lateral. Stratigraphic Test ❑ Development - Oil Service - Winj ❑ Single Zone ❑� ' Coalbed Gas ❑ Gas Hydrates ❑ Reddll ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑' Single Well ❑ 11. Well Name and Number: ConocoPhillips Bond No. 59-52-180 KRU 1 H-10212 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 13435 TVD: 3959 Kuparuk River Field West Sak Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 40.52' FNL, 764.65' FEL, Sec 33, T 12N, R010E, UM ADL025639, 25636. 8. DNR Approval Number: 13. Approximate Spud Date: Top of Productive Horizon: 4413.77' FNL, 1663.97' FEL, Sec 27, T 12N, R010E, UM LO/NS 80-261 8/1/2017 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 5175.82' FNL, 1775.32' FEL, Sec 22, T 12N, R010E, UM 5120 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: 1015 16. Deviated wells: Kickoff depth: 7841 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 92.22 degrees Downhole: 1714 psi . Surface: 1327 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 7841 Surface Surface 7841 3863 644 sx 15.8 Class G 6.75" 4.5" 11.6# L-80 IBTM 5594 7841 3863 13435 3959 N/A: Un -cemented slotted liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Reddll and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (fl): 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 Q 20. Attachments: Property Plat ❑ BOP raTimDivelterysis v. Depth eFluid Shallow Hazard lentsB✓ Sketchetch e SeabDrillmged RProeport B Drilling Program a 20 AAC 25.050 requiremot 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be Kelsey Hallford deviated from without prior written approval. Contact Name: Vd Authorized Name: G. Alvord Contact Email: kelsey.haillorMconoco lips.com Authorized Title: Alaska Drilling Contact Phone: 1-907-265-1577 /Manager Authorized Signature:- (�(, Date: 19 -Sep -17 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other �1 Number: 2,I7- l O �Yr 50-02-�-C. ��0 - 4 I - G G Date: '7 _'-'(_ T Zv , 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: 16 Other: nD P fr y .�- 7'� -3 500 P 5- t 9 u Samples req'd: Yes Nov Mud log req'd: Yes No Lb ��,Y2 V� R ✓ Vt 4 �, HzS measures: Yes No❑-/ Directional svy req'tl: YesR Nom❑] Yes[] No [K o 2 70 r�� c, Spacing exception req'd: Yes ❑ No(t Inclination -only svy req'd: f o z 5� 5 (/ ❑ F / t $ / Post initial injection MIT req'd: Yes No APPROVED BY Z�II Approved by: COMMISSIONER THE COMMISSION Date: C (�iL 7 ZS / suomn rorm ano %Form 1co-4ptti R� �s5i2o1 /4Mrttliwfo� 24 mon from thp�ate of approval per 20 AAC 25.005(8) attachments in Duplicate 7IuW1 { I a I H L 2�o�i Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone(907)265-1577 Email: kelsev.hallfordCo?conocoghillips. com September 19, 2017 Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue, Suite 100 Anchorage, Alaska 99501 Application for Permit to Drill, Well 1H -102L2 Saved: 19 -Sep -17 ConocoPhillips Re: Application for a Revision of PTD# 217-101: 1H-1021-2, West Sak Producer Dear Commissioner: RECEIVED SEP 19 2011 AOGCC ConocoPhillips Alaska, Inc. hereby applies for a revised permit to drill the A4 lateral (L2) of a penta-lateral West Sak producer. A revision to approved PTD# 217-101 is requested to drill additional footage in the A4 pay. J The surface, intermediate, and first lateral have been drilled and completed under PTD 217-097. Analysis of the drilling data obtained in the first lateral (1 H-102: A2 sand) identified additional pay footage. We would like to pursue drilling the additional footage, bringing the total depth to 13,435' MD. J Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Kelsey Hallford at 265-1577 (kelsev.hallford(i�conocophillii)s.com) or Chip Alvord at 265-6120. K srly, Kelsey Hallfo d Drilling Engineer Application for Permit to Drill Document Kuparuk Well 1 H-1021-2 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 1H -102L2 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must he accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the propertv's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the swface, referenced to the state plane coordinate sysieni for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 40.52' FNL, 764.65' FEL Sec 33, T 12N, ROI OE UM NGS Coordinates Northings: 5980662.56' Eastings: 549577.46' i RKBElevation 93' AMSL Pad Elevation 54' AMSL Location at Surface Casing 349.45 FNL, 466.77 FEL, Sec 33, T12N, ROI OE, UM NGS Coordinates Northings: 5980355.65' Eastings: 549878.04' Measured De th, RKB: 1794' Total Vertical De th, RKB: 1700' Total Vertical Depth, SS: 1607' Location at Intermediate Casing NGS Coordinates Northings: 5986115.98' Eastings: 553798.35' 4413.77' FNL, 1663.97' FEL, Sec 27, TI 2N, ROI OE, UM NGS Coordinates Northings: 5981599.45' Eastings: 553949.6' Measured Depth, RKB: 7841' Total Vertical De th, RKB: 3863' Total Vertical Depth, SS: 3770' Location at Total Depth 5175.8' FNL, 1775.3' FEL, Sec 22, T12N, R010E, UM NGS Coordinates Northings: 5986115.98' Eastings: 553798.35' I Measured De th, RKB71 13435' Total Vertical De th, RKB. 3959' Total Vertical Depth, SS: 1 3867' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) Ifo well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, shoving the path of the proposed wellbore, including all adjacent wellbores within 100 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records. and shoe that each named operator has been firnished a copy of the application by certified mail: or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drift must be accompanied by each of the follmving items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowma prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 15.036. or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142. Due to lower reservoir pressure in the West Sak a fixed stack ram placement will be utilized to fulfill all barrier requirements during well construction operations, graphic attached. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the follmving items, except for an item already on file witlr the commission and identified in the application: (4) information on drilling hacards, including (A) the maximum doumhole pressure that may be encountered. criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) wile drilling 1H -102L2 is calculated using an estimated maximum reservoir pressure of 1714 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 A4 sand window at 3871' TVD: / A4 Sand Estimated. BHP = 1,714 psi A4 Sand estimated depth = 3,871' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (e)(4)(A) Hydrostatic of full gas column = 387 psi (3,871' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 1,327 psi (1,714 psi — 387 psi) (B) data on potential gas cones; The wellbore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata. lost circulation cones, and =ones that have a propensityfor differential slicking: See attached 1H -102L2 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the faflmving items, excepi far an item already on file with the commission and identified in the application: (5) a description of the procedure for conductingformation integrity tests, as required under 20 AAC 25.03009; A procedure is on file with the commission for performing FIT/LOT'S. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must he accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cmmenting program as required by 10 AAC 15.030, and a description of mry slotted liner, pre -perforated liner, or screen to be installed Casing and Cement Program 18. Casing Program Specifications Top - Setting Depth - Bottom I Cement Quantity, c.f. or sacks Flole Casing Weight Grade Coupling Length ND ND NID ND I (including stage data) 42" 20" 94# PAOWelded 80 Surface Surface 80 80 Ecisting, cement to surface 13.5" 10.75" 45.5# L-80 H563 1794 Surtace Surface 1794 1700 914 sx 11.0 Lead, 145 sx 12.0 Tail 9.875" 7.625" 29.7# L-80 H563 7841 Surface Surface 7841 1 3863 1544 sx 15.8 Class G 6.75" 4.5" 11.6# L-80 I IBTNi r 5594 7341 3863 1 13435 1 3959 NA: Un -cemented slotted liner Diverter System Information Reauirements of 20 AAC 25.005(c)(7) An application fora Permit to Drill must be accompanied by each of the following items. except for an item alreadv on file with the commission and identified in the application.' (7) a diagram and description of the divettersystem as required by 20 AAC25. 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 for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application.' (B) a drilling fluid program, including a diagram and description of the dd0ing fluid system, as required by 20 AAC 15 033; 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 Reauirements 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 FlowPro 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 Reauirements 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 Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program follows. Please refer to attachment for proposed well schematic. Note: Previous operations are covered under the 1H-102 and 1H-IO2L1 Application for Permit to Drill. 1. With 6-3/4" bit, motor, GR/Res, and magnets, and drill —200' of new hole in the A4 sand. POOH. 2. Pick up 6-3/4" RSS lateral drilling assembly with GR, Res, periscope and RIH. 3. Drill lateral to A4 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 window just below the top of the B 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 IH -102L2 PTD & begin 1H -102L3 PTD. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied by each of the following items, except for an item already on file with the commission and identified in the application.' (1 J) a general description of how the operator plans to dispose of drilling mud and tunings and a statement of whether the operator intends to request authorisation under 20 AAC 25.080 for an annular disposal operation in the well.: Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class 11 disposal well at the IB Facility. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. / Attachments: Attachment I BOP Ram Placement Attachment 2 Well Schematic Attachment 3 Diverter Layout Diagram Attachment 4 Directional Plan Attachment 5 Drilling Hazards Summary Attachment 6 Cement Summaries Fixed BOP configuration for West Sak Operations Class 2 BORGptlonfl Ann Fixed n{ I0-3/4".45.5#. L-80, Hyd563 �► 1794' MD / 1700' TVD Wellhead / Tubing Head / Tree - 13 -3/8" x 4-Y•", 5.000 ksi / Tubing String: 4-I/2". 12.6 #. L-80 TXP - Gas UP Mandrel, 4-1/2" x I" w/ dummy valve — Gas Lift Mandrel, 4-1/2" x I" w/ SOV — 4-'/:" SSD with 3.812" DB Nipple profile Permanent Down Hole Gauge .� Tubing Seal Assembly 1H-102 Producer Schematic wellolan25 ZXP Packer � L4 "D" Sand Window n 7377' MD / 3740' T VD 3.75" DP Nipple Profile75.57° inc ____ 4-1/2", 11.6# IBin TM L80, Slotted Ler 6-3/4" D sand lateral 14699' MD/ 3801' TVD • .• • • ••....... Jf L3' B" Sand Window @ 7646' MD / 3815' T VD Swell Packers J 6-3/4" B sand lateral -......75.57-inc .__ 14718'MD/ 3859'TVD3 4 Stacked Baker honk hanger .• 4-I/2" Slotted Liner, 11.6# IBTM L80 Level Junction Svstems.............................................................................. ....................••• •..............................................................................'.... .....................- L2 "A4" Sand Window n 7841' MD / 3868' TVD 6-3/4" A4 sand lateral ZXP Packer •....75 57- inc 4-1/2" 13435' MD / 3959' TVD -- . Slotted Liner, .. ........ ................... . .... . LI "A3" Sand Window n 7983' MD / 3900' TVD, 75.57 ° inc 6-3/4" A3 sand lateral Lateral Entry Module •••••`•.-4-1/2"Slotted Lineal 1.61 IBTM L80 13434'MD/4016'TVD--_� •• Tubing Seal Assembly ♦ •....................oft.in ................................................................... 1562" DP Nipple Profile 6-3/4" A2 sand lateral ZXP packer1290 .• 4-1/2" Slotted Liner, 11.6# IBTM L80 'MD/4023'TVD —% .. ................................... 7 -5/8'129.7#.L -8Q Hyd563. Csg------------------- - •••�.................... W..All .......................................... 8600'MD/4004'TVD..................: Insulated Conductor Casing, 20".94#. OK55 x 34", 0.312" WT ub n Q +/-80'MD S 1A y 1A I0-3/4".45.5#. L-80, Hyd563 �► 1794' MD / 1700' TVD Wellhead / Tubing Head / Tree - 13 -3/8" x 4-Y•", 5.000 ksi / Tubing String: 4-I/2". 12.6 #. L-80 TXP - Gas UP Mandrel, 4-1/2" x I" w/ dummy valve — Gas Lift Mandrel, 4-1/2" x I" w/ SOV — 4-'/:" SSD with 3.812" DB Nipple profile Permanent Down Hole Gauge .� Tubing Seal Assembly 1H-102 Producer Schematic wellolan25 ZXP Packer � L4 "D" Sand Window n 7377' MD / 3740' T VD 3.75" DP Nipple Profile75.57° inc ____ 4-1/2", 11.6# IBin TM L80, Slotted Ler 6-3/4" D sand lateral 14699' MD/ 3801' TVD • .• • • ••....... Jf L3' B" Sand Window @ 7646' MD / 3815' T VD Swell Packers J 6-3/4" B sand lateral -......75.57-inc .__ 14718'MD/ 3859'TVD3 4 Stacked Baker honk hanger .• 4-I/2" Slotted Liner, 11.6# IBTM L80 Level Junction Svstems.............................................................................. ....................••• •..............................................................................'.... .....................- L2 "A4" Sand Window n 7841' MD / 3868' TVD 6-3/4" A4 sand lateral ZXP Packer •....75 57- inc 4-1/2" 13435' MD / 3959' TVD -- . Slotted Liner, .. ........ ................... . .... . LI "A3" Sand Window n 7983' MD / 3900' TVD, 75.57 ° inc 6-3/4" A3 sand lateral Lateral Entry Module •••••`•.-4-1/2"Slotted Lineal 1.61 IBTM L80 13434'MD/4016'TVD--_� •• Tubing Seal Assembly ♦ •....................oft.in ................................................................... 1562" DP Nipple Profile 6-3/4" A2 sand lateral ZXP packer1290 .• 4-1/2" Slotted Liner, 11.6# IBTM L80 'MD/4023'TVD —% .. ................................... 7 -5/8'129.7#.L -8Q Hyd563. Csg------------------- - •••�.................... W..All .......................................... 8600'MD/4004'TVD..................: Wellhead /Tubing Head /Tree, 13-3/8" x 4-'/?, 5,000 ksi _� Tubing String: 4-1/2", 12.6 #, L-80 TXP - Gas Lift Mandrel, 4-M" x I" w/ dummy valve — Gas Lift Mandrel, 4-1/2" x I" w/ SOV — 4-'/z" SSD with 3.812" DB Nipple profile Permanent Down Hole Gauge � Tubing Seal Assembly 1H-102 Producer Schematic wellolan25 L4 "D" Sand Window @ 7377' MD / 3740' TVD 75.570 inc 4-1/2". 11.6# IBTM L80. Slotted Liner �__ _ _ L3 "B" Sand Window Q 7646' MD / 3815' TVD 75.570 inc 'ger 4-1/2" Skilled Liner, 11.69 IBTM L80 s................................. L2 "A4" Sand Window @ 7841' MD / 3868' TVD ZXP Packer 75.570 inc •.•yam 4-I/2" SlottedLiner,L80 -aleral Entry Module � 'ubing Sea] Assembly — 3.562" DP Nipple Profile - ZXP packer 7-5/8",29.7#, L-80, Hy 8600' MD / 4 Ll "A3" Sand Window @ 7983' MD / 39 ' TVD, 75.57 0 inc 4-1/2"Slotted Liner, 11.6 BTM L80 zl. 4-1/2" cited Liner, 11.6# IBTM L80 I Swell Packers 6-3/4" D sand lateral 14699 MD / 3801' TVD 6-3/4" B sand lateral 14718' MD / 3859' TVD 6-3/4" A4 sand lateral _ ...................•13435'MD/3959'TVD 6-3/4" A3 sand lateral 13434' MD / 4016' TVD � � 6-3/4" A2 sand lateral 12801' MD / 4023' TVD ConocoPhillips TITLE: DS1H LAYOUT DRAW Alaakajnc. \_ DRAWN BY: ALKET MICI DATE: M-01-2017 REV: 1 Drill Smite i N uu va a.iaair a wmx Co pC_ September 18 0 1H-101Ltwp28 1H-101wp28.1 1H-101L2wp28 1H-101 L3wp28 1H-14 1H-101L4wp28---.--�_::� . Kuparuk 1H Pad 1 1 Easting (2500 usft/in) 1H-125wp20 /- 1H-124wp20 1H-123wp20 1H-122wp20 1H -121 1H-1 /- 1H-120wp21 1H-104wp21 H-21 Easting (2500 usff/in) 1H-11?v�p23 1H H-104L1 — wp22 1H- _ - 1 03L3w 1 Z 03 wp211 1H-104L4wp22 3L1wp211H-103wp231H-103L2wp211H-115wp211H-113wp21 1H-106 1H-09 p 1H-11 f5/H 1H-104wp21 H-21 Easting (2500 usff/in) 1H-11?v�p23 1H H-104L1 — wp22 1H- _ - 1 --:-- 1H-104L2wp22 1H -104L 3wp22 1H-104L4wp22 L 1H-106 1H-09 p 1H-11 O 8 rn ? D rn D � x m = i ? ? pa A 0 _ 2 a � S m _ ?_ '� � o m d N d � N � � � � t!• O � ? j O A IT � O S _ V n r d 2 nd v N 2 W N 2 w 4_0_ f tyy� 2 ? rop 2 IT ? O N ? N � W � O N n N N p A o N v � a o � O N W a All �cn a (ui/ysn 004Z) 6UMPON 1 H-102L2wp24 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 1H-102L2wp24 -- 13435 130(0 H-102L1 4-1/2" x 6-3/4" 4500- 1 H-102 12000 3000 1000 L O z 10000 tl 500- �i I W i _9000 0 ODO � �oo0 7-5/8" x 9-7/8" P8 100 o 3/4" x 13-1/2" moo o r10 b�O o o -0p0 N -1500 4) \. i5o 0 -3000 -1500 0 1500 3000 4500 6000 7500 West(-)/East(+) Z L2wp24 luction section, within 100 feet QP o° o° 3/4" x 13-1/2" lbo of 1H-102L2wp24------- 4-1/2" x 6-3/4" unless notified 3435 3000 H -102L1 7-518' 9-7/8 ------ f ?000 0 150 3000 4500 6000 7500 West( -)/East(+) 1 H-102L2wp24 Section View 0 0. 850- 1000 ,C 1700 X6300 10 3/4" x 13-1/2" 2000 'C 00 v � 2550 ~ 0 OO ° N � � J J O N p o 7-5/8" x 9-7/8" r- o �- O N 3400 ^o 00 0 0 0 0 0 0 0 0 0 0 0 0 0 o No 0 0 0 0 o = o 0 0 C v G) 0 W M N 0 o MCD 4250 4-1/2" x 6-3/4" G -1700 -850 0 850 1700 2550 3400 4250 5100 Vertical Section at 0.000 ?L2wp24 1000 10 3/4" x 13-1/2" 2000 7-5/8" x 9-7/8" O o O O \mob 00 (J O O O O O a O o o O O O O O O C) O O O W e 850 1]00 2550 VerticalYection at 0.000 v N a J N N J O ON � r- 2 = _ N N O O r O LO O co N O, t- �M fp M u o +"' W `- �� I� , � -7d 4-1/2" x 6-3/4" 3400 4250 5100 L2wp24 9-7/8" 0 p O o rn o rn ° m 00 o rn 750 1500 0 O 0 O N O O O O O O NP P N / 2217 3000 3750 4500 Verti I Section at 0.000 v N 3 4-1/2" x 6-3/4" J�' O O Q 1 P O T C') ,SPY � o� 0 LO W CO � M P 5250 a O t 2 ti 201] 1 H-102L1wp24 Measured Depth 0 1H-102 actual @ 92.62usft (Doyon 142) 0 0 N oro m I 0 m 5600 6400 7200 8000 8800 9600 10400 11200 Horizontal Departure "- 1-__.---! Equivalent Magnetic Distance 8250 9000 9750 10500 11250 81 Measured Depth ccepted by SURV Y PROGRAM Minor D.Oh From Dwlh T. SurveylPMn Tool 07.62 1009.26 1H.iM sM1- SLB _GWD70 GY Gc-ss 105036 1678.04 1KZW Srvy 2-SLB_MWD+GMAG MWD+IFR-AK-CA-SC 1777.33 7841.00 1W1M SM 3-SLBMWD+GMAG MWD+IFR-Ax CA -SC 7841.00 8199.62 iH-1ML2xy2411H-1MU) MWD -INC 8199.62 96W62 fH-loo 24 (M -MU) -ONLY MWD 0108621343451 1H-1ML2 P24(1H-16262) MWD+IFR-AK.CA .SC 41 0.37 3934.52 3492.18 4244.35 0.38 3932.36 3603.35 4245.08 0.38 3915.29 4042.98 4247.97 0.38 3913.72 4091.22 424829 0.38 3912.63 4150.50 4248 68 0.38 3908.13 4572.74 425145 0.38 3908.82 4673.27 4252.11 0.38 3912.32 4761.26 4252.69 0.38 3920.57 4910.56 4253.67 0.38 3925.12 4984.29 4254.15 oor �t4 �/zYq- 7.062 plan Summa 0 81 am ccepted by Minor Risked CS DeLapp SUO - 920 g K Hallford ez0o - 6309 0390 9580 am 0]40 300 6 60 3749 0930 0830 9100 0100 Was 9zao 9050 N5D DOW 270 90 e63D - 9e0a eWD ossa MD 10150 10150 10330 10330 100 10.500 t�70 240 a ' _. Y 120 100]0 - 11200 112M 11000 116M - 11970 11970 - 12M 210 -tr 150 12340 127M 180 12779 130]0 13070 13435 Magnetic Model & Date: BGGM20171-Sep-17 Magnetic North is 17.48° East of True North (Magnetic Declination) Target 1 H-102L.2O1.T1 091517 RP 1H -102L2 02.T2 091517 RP 1H -102L2 03J3 091517 RP iH-1021-204.74091517 RP IH -102U 05.75 091517 Csd 1 H-1021-2 06.T6 091517 RP 1H -102L2 07.77 091517 RP IH -102L2 08.T8 091517 RP 1 H -102L2 09.79 091517 RP 1H -102L2 10.710 091517 RP 1H -102L2 1I.T11 091517 RP DLS. -20° TF, for 12.42' i, 5.35' TF, for 302.88' i. -170.46• TF, for 157.08' LS, 126.77• TF for 72.66' 69•, for 49.44' LS, 42.75• TF for 51.16 i, 112.73• TF, for ease F. for 122.11' -12.15• TF for 124.24 , for 163.91' 5.04° TF, for 36.89' for 111.2' i 179 75' TF, for 48.27 '2'. for 59.29' 179.88' TF, for 100.53' I6•, for 88.07' 179.95° T5 for 73.87' for 54.46' UMolo9y Column PFROST T-3 K-15 UG -C "UG 13 UG A 1.1 Na TierCrtcadata is correct, ensured it's completeness, and all surrounding wells are assedignto the proper position, and I approve the scan and collision avoidance plan as set out in Permit Pack Steering the audit pack.) approve it as the basis for the final well plan and wellsite drawings. I I also acknowledqe that unless notified otherwise all tarqets have a 100 feet lateral repared by Ch V48`&y: ccepted by Approved by: CS DeLapp Huy Bui Anh Erik Sterk K Hallford x m N N 0 0 O 1 H-102LA.,vP24 Measured Depth _ 7-5/9° x 9-7/8' 1 H-102 actual @ 92.62usft (Doyon 142) i o o g o o O O O O O N J do , W m m W oOj No p (O t0 N � L do M � J � 4-1/2" x 6-3/4' 5600 6400 7200 8000 8800 9600 10400 11200 Horizontal Departure 60 L j 30- 1 3 0- I ' ' I ' ' F' I ' ' I 8250 9000 9750 10500 11250 Measured Depth 3epth From Depth To nIIIR!llt=u mAIAr III IO II UI l n„niillll 11 \\ JI I�IIgIII�� IAIY �WII�' WII I II IEqu 1050.36 1878.04 1H-102 SM 2-SLB_MWI%GMAG MWD+IFR-AK-CAZ-SC 177733 7841.0 1H-102 Soy 3 -SLB MWO+GMAG valent Magnelic Distal 7841.00 0199.62 H- 0I (l H-10212) MWD -INC I ' ' I ' ' F' I ' ' I 8250 9000 9750 10500 11250 Measured Depth 3epth From Depth To Sur e"Mlan T°ol 67.62 1009.26 iH-102 Srvy1�GLB_GWDTO GYUG0SS 1050.36 1878.04 1H-102 SM 2-SLB_MWI%GMAG MWD+IFR-AK-CAZ-SC 177733 7841.0 1H-102 Soy 3 -SLB MWO+GMAG MWD+IFRAK-AK-SC 7841.00 0199.62 H- 0I (l H-10212) MWD -INC 8199.62 969962 111-10I (1H-10212) -ONLY MWD 8199.6213434.51 iH-102L2wp24 (111-10212) MWD+IFR-AK-CAZ-SC I ' ' 1 12000 12750 DDI 7.06 Plan Summar "Y =00/ Ad TVD +N/ -S +E/ -W Dleg TF a VSod Target Annotation Lithology Column 0 7641 KOP: 15.9'/100' DLS, -20° TF, for 12.42' 2 7853.42 76.40 7841 8020 Hold for 20' Minor Risked 8020 - 8200 Start 6°/100' DLS, -5.35 TF, for 302.88' 90 48176.30 94.50 8200 8380 Hold for 150' 8380 8560 359.71 3882.61 336.10 4388.34 0. 0.00 336.10 Start 3°/100' DLS, -170.46° TF, for 157.08' 8No 8740 30 6 60 8740 8930 7 8898.79 89.85 358.93 3877.72 908.35 4378.69 .00 0.00 908.35 8930 9100 r 88971.45 89.20 359.80 3878.32 981.00 4377.88 9100 9280 T-3 99020.89 88.74 9200 9450 Hold for 264.51' 9450 9630 0.00 0,00 1294a8 Start 1.5°/100' DLS, 42 75 TF, for 51.16' 90 9630 9800 - 9800 9980 0 90 3885.92 1346.03 438 .28 1.50 42]51346.03 1 H -102L2 03 T3 091517 RP Adjust TF to 48.02°, far 66.83' 9900 10150 12 9403.40 89.97 1.65 3886.35 1412 84 43 1.76 1.50 48.021412.84 10330 i0150 0330 10500 240 .�' 120 10500 ,06,0 10670 - 1,830 ..'�% 355.00 3886.62 1945.07 384.21 112M 11600 116M - 11970 3.00 -89.99 2227.45 Hold for 188.01' 11970 - 12340 210 e 150 12340 12700 180 12700 --- 13070 351.00 3887.12 253 . 1 4268.10 3.50 92,15 2538.91 1 H-10212 0535 091517 csd 13070 - 13435 Magnetic Model & Date: BGGM20121-Sep-17 1810673.84 87.70 Magnetic North is 17.48° East of True North (Magnetic Declination) Magnetic DID & Field Strength: 80.95° 57489.47nT Sec MD Inc Ad TVD +N/ -S +E/ -W Dleg TF a VSod Target Annotation Lithology Column 1 7841.00 74.55 2.07 3862.64 -145.53 4385.48 0.00 .00 -145.53 KOP: 15.9'/100' DLS, -20° TF, for 12.42' 2 7853.42 76.40 1.38 3865.76 -133.52 4385.ed 15.90 0.00 -133.52 Hold for 20' 37873.42 76.40 1.38 3870.46 -114.08 4386.31 0.00 0.00 -114.08 Start 6°/100' DLS, -5.35 TF, for 302.88' 48176.30 94.50 359.71 3894.38 186.56 4389.10 6.0 -5.35 186.56 1 H-10212 01.T1 091517 RP Hold for 150' 58326,30 94.50 359.71 3882.61 336.10 4388.34 0. 0.00 336.10 Start 3°/100' DLS, -170.46° TF, for 157.08' 68483.38 89.85. 358.93 3876.65 493.01 4386.47 0 -170.46 493.01 Hold for 41541' PFROST 7 8898.79 89.85 358.93 3877.72 908.35 4378.69 .00 0.00 908.35 Start 1.5°/100' DLS, 12677° TF for 72.66' r 88971.45 89.20 359.80 3878.32 981.00 4377.88 1.50 126.77 981.00 1 H-10212 02T2 091517 RP Adjust TF to 128.69•, for 49.44' T-3 99020.89 88.74 0 38 3879.21 1030.44 4377. 1.50 128.69 1030,44 Hold for 264.51' 10 9285.40 88.74 0.38 3885.04 1294.88 4379. 0.00 0,00 1294a8 Start 1.5°/100' DLS, 42 75 TF, for 51.16' o 11 9336.57 89.30 0 90 3885.92 1346.03 438 .28 1.50 42]51346.03 1 H -102L2 03 T3 091517 RP Adjust TF to 48.02°, far 66.83' 12 9403.40 89.97 1.65 3886.35 1412 84 43 1.76 1.50 48.021412.84 Hold for 311.08 13 9714.48 89.97 1.65 3886.51 1723.79 90.69 0 00 0.00 1723.79 Start 3°/100' DLS, -90.01° TF, for 221.5' 14 9935.98 89.97 355.00 3886.62 1945.07 384.21 3.00 -90.01 1945.07 1 H-1 D212 01 091517 RP Adjust TF to .9.99*, for 2864 150222.38 89.97 346.41 3886.77 2227 4 4337.99 3.00 -89.99 2227.45 Hold for 188.01' 1610410.39 89.97 346 41 3886.86 2410. 4293.81 0.00 0.00 2410.19 Start 3.5'/100' DLS, 92.15° TF, for 131.29' 1710541.68 89.80 351.00 3887.12 253 . 1 4268.10 3.50 92,15 2538.91 1 H-10212 0535 091517 csd Adjust TF to 117.03°, for 132.16' K-15 1810673.84 87.70 355.13 3890.01 26 .03 4252.15 3,50 117.03 2670.03 Hold for 79.76! 1910753.59 87.70 355.13 3893.21 49,43 4245.38 0.00 0.00 2749.43 Start 3.5°/100' DLS, 112.73° TF, for 88.98' 200842.57 86.50 358.00 3897.72 838.13 4240.06 3.50 112.73 2838.13 11-1-110212 0636 091517 RP Adjust TF to 133.39', for 122.11' 2110964.68 83.57 1.12 3908.2 2959.75 4239.12 3.50 133.39 2959.75 Hold for 5304' 201017.73 83.57 1.12 3914. 3012.45 4240.15 0.00 0.00 3012.45 Start 2°/100' DLS, -12.15° TF, for 124.24' 2311141.97 86.00 0.60 392 . 2 3136.15 4242.01 2.00 -12.15 3136.15 iH-1021-2 GI 091517 RP Adjust TF to S.16°, for 163.91' 2411305.88 89.27 0.31 39 .29 3299.89 4243.31 2.00 -5.16 3299.89 Hold for 155.41' 2511461.28 89.27 0.31 34.28 3455.28 4244.14 0.00 0.00 3455.28 Start 2'/100' DLS, 5.04• TF, for 36.89' amo 2611498.18 90.00 0.37 934.52 3492.18 4244.35 2.00 5.04 3492.18 1 H-10212 08 T8 091517 RP Adjust TF to 0.18°, for 111.2' 2711609.38 92.22 0.3 3932.36 3603.35 4245.08 2.00 0.18 3603.35 Hold for 439.98' UG_C 2a2049.35 92.22 0. 3915.29 4042.98 4247.97 0.00 0.00 4042.98 Start 1.5/100' DLS, 179.75' TF, for 48.27' 2912097.62 91.50 8 3913.72 4091.22 4248.29 1.50 179.75 4091.22 1H-10212 09 39 091517 RP Adjust TF to -179.72°, for 59.29' nG B 302156.91 90.61 .38 3912.63 4150.50 4248.68 1.50 -179.72 4150.50 Hold for 422.28' 'j - UG 3112579.19 90.61 0.38 3908.13 4572.74 4251.45 0.00 0.00 4572.74 Start 2°/100' DLS, 179.88- TF, for 100.53' _A 321267972 88.60 0.38 3908.82 467327 4252.11 2.00 179.884673.27 1HA021210.T10091517 RP Adjust TF to .179.86*, for 86.07' �rNa 3312767.79 86. 0.38 3912.32 4761 25 4252.69 2.00 -179.86 4761.26 Hold for 149.54' 3412917.32 86 0.38 3920.57 4910.56 4253.67 0.00 0.00 4910.56 Start 1-/1001 DLS, 179,95* TF, for 73.87' 351 2991.19 8 .10 0.38 3925.12 4984.29 4254.15 1.00 179.95 4984.29 111-1021-2 11 311 091517 RP Adjust TF to 180°, for 54.46' - 361 3045.65 5.56 0.38 3929.08 5038.60 4254.51 1.00 180.00 5038.60 Hold for 388.9' 3713434.55 85.56 0.38 3959.22 6.3 4 57.06 0.00 0.00 5426.3 1 H-10212 12.TD 091517 RP T : 13439.55' MD 3959,22' WD - By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surrounding wells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.) approve it as the basis for the final well plan and wellsite drawings. I I also acknowledge that unless notified otherwise all targets have a 100 feet lateral -epared by Ch ORCSy: ocepted by Approved by: :S DeLapp Huy Bui Anh r Erik Sterk K Hallford ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad Rig: 1 H-102 500292358000 11-1-1021-2 Plan: 1 H-102L2wp24 Standard Proposal Report 18 September, 2017 i Steering Minor Risked ConocoPhillips b ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: Rig: IH -102 Wellbore: 11-1-10212 Design: iH-102L2wp24 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Rig: 1H-102 TVD Reference: iH-102 actual @ 92.62usft (Doyon 142) MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 1 H Pad Site Position: From: Position Uncertainty: Well Rig: 1H-102 Well Position Northing: Easting: Position Uncertainty 0.00 usft Wellhead Elevation: 54.00 usft Wellbore 11-1-10212 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (') CI (nT) BGGM2017 9121/2017 17.48 80.95 57,489.48 Design 11-1-1021-2wp24 Audit Notes: Version: Phase: PLAN Tie On Depth: Vertical Section: Depth From (TVD) +N/ -S +EI -W (usft) (usft) (usft) 3862 000 0.00 7,841.00 Direction PI 0.00 9/18/2017 10:26:30AM Page 2 COMPASS 5000.14 Build 85 Plan Survey Tool Program Date 9115/2017 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 7,841.00 8,199.62 1H-102L2wp24(1 H-1021.2) MWD-INC_ONLY MWD-INC—ONLY—FILLER 2 8,199.62 9,699.62 1H-102L2wp24(1 H-10212) MVJD MWD - Standard 3 8,199.62 13,434.51 1H-10212wp24(1 H-10212) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,841.00 Direction PI 0.00 9/18/2017 10:26:30AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Database: Company: Project: Site: Well: Wellbore: Design: Plan Sections OAKEDMP2 ConocoPhillips (Alaska) Inc. -Kupi Kupamk River Unit Kupamk 1H Pad Rig: 1 H-102 1H-1021-2 1H-102L2wp24 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Rig: 111-102 1 H-102 actual @ 92.62usft (Doyon 142) 1H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature Measured Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +Nl-S +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°I100usft) (°1100usft) (°1100usft) (°) Target 7,841.00 74.55 2.07 3,862.64 -145.53 4,385.48 0.00 0.00 0.00 0.00 7,853.42 76.40 1.38 3,865.76 -133.52 4,385.84 15.90 14.95 -5.59 -20.00 7,873.42 76.40 1.38 3,870.46 -114.08 4,386.31 0.00 0.00 0.00 0.00 8,176.30 94.50 359.71 3,894.38 186.56 4,389.10 6.00 5.97 -0.55 -5.35 1H-1021-201.710915 8,326.30 94.50 359.71 3,882.61 336.10 4,388.34 0.00 0.00 0.00 0.00 8,483.38 89.85 358.93 3,876.65 493.01 4,386.47 3.00 -2.96 -0.50 -170.46 8,898.79 89.85 358.93 3,877.72 908.35 4,378.69 0.00 0.00 0.00 0.00 8,971.45 89.20 359.80 3,878.32 981.00 4,377.88 1.50 -0.90 1.20 126.77 1H -1021202.T20915 9,020.89 88.74 0.38 3,879.21 1,030.44 4,377.96 1.50 -0.94 1.17 128.69 9,285.40 88.74 0.38 3,885.04 1,294.88 4,379.70 0.00 0.00 0.00 0.00 9,336.57 89.30 0.90 3,885.92 1,346.03 4,380.28 1.50 1.10 1.02 42.75 1H-1021-203.730915 9,403.40 89.97 1.65 3,886.35 1,412.84 4,381.76 1.50 1.00 1.11 48.02 9,714.48 89.97 1.65 3,886.51 1,723.79 4,390.69 0.00 0.00 0.00 0.00 9,935.98 89.97 355.00 3,886.62 1,945.07 4,384.21 3.00 0.00 -3.00 -90.01 1H-1021-204.740915 10,222.38 89.97 346.41 3,886.77 2,227.45 4,337.99 3.00 0.00 -3.00 -89.99 10,410.39 89.97 346.41 3,886.86 2,410.19 4,293.81 0.00 0.00 0.00 0.00 10,541.68 89.80 351.00 3,887.12 2,538.91 4,268.10 3.50 -0.13 3.50 92.15 1H-1021-205.750915 10,673.84 87.70 355.13 3,890.01 2,670.03 4,252.15 3.50 -1.59 3.13 117.03 10,753.59 87.70 355.13 3,893.21 2,749.43 4,245.38 0.00 0.00 0.00 0.00 10,842.57 86.50 358.00 3,897.72 2,838.13 4,240.06 3.50 -1.34 3.22 112.73 1H -1021206.T60915 10,964.68 83.57 1.12 3,908.29 2,959.75 4,239.12 3.50 -2.40 2.56 133.39 11,017.73 83.57 1.12 3,914.23 3,012.45 4,240.15 0.00 0.00 0.00 0.00 11,141.97 86.00 0.60 3,925.52 3,136.15 4,242.01 2.00 1.96 -0.42 -12.15 1H -1021-207.T70915 11,305.88 89.27 0.31 3,932.29 3,299.89 4,243.31 2.00 1.99 -0.18 -5.16 11,461.28 89.27 0.31 3,934.28 3,455.28 4,244.14 0.00 0.00 0.00 0.00 11,498.18 90.00 0.37 3,934.52 3,492.18 4,244.35 2.00 1.99 0.18 5.04 1H-1021208.780915 11,609.38 92.22 0.38 3,932.36 3,603.35 4,245.08 2.00 2.00 0.01 0.18 12,049.36 92.22 0.38 3,915.29 4,042.98 4,247.97 0.00 0.00 0.00 0.00 12,097.62 91.50 0.38 3,913.72 4,091.22 4,248.29 1.50 -1.50 0.01 179.75 1H -1021209.T90915 12,156.91 90.61 0.38 3,912.63 4,150.50 4,248.68 1.50 -1.50 -0.01 -179.72 12,579.19 90.61 0.38 3,908.13 4,572.74 4,251.45 0.00 0.00 0.00 0.00 12,679.72 88.60 0.38 3,908.82 4,673.27 4,252.11 2.00 -2.00 0.00 179.88 1H-1021-210.710091 12,767.79 86.84 0.38 3,912.32 4,761.26 4,252.69 2.00 -2.00 -0.01 -179.86 12,917.32 86.84 0.38 3,920.57 4,910.56 4,253.67 0.00 0.00 0.00 0.00 12,991.19 86.10 0.38 3,925.12 4,984.29 4,254.15 1.00 -1.00 0.00 179.95 1H -1021-211.T11091 13,045.65 85.56 0.38 3,929.08 5,038.60 4,254.51 1.00 -1.00 0.00 180.00 13,434.55 85.56 0.38 3,959.22 5,426.32 4,257.06 0.00 0.00 0.00 0.00 1H-1021-212.TD 091: 9/18201710:26:30AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: Rig: 1H-102 Wellbore: 11-1-10212 Design: 1H-102L2wp24 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Rig: 1H-102 1 H-102 actual @ 92.62usft (Doyon 142) 1 H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (') (') (usft) (usft) (usft) (usft) ('1100usft) ("/100usft) (°1100usft) 7,900.00 77.99 1.23 3,876.35 -88.17 4,386.90 -88.17 6.00 5.97 -0.57 8,000.00 83.97 0.67 3,892.02 10.53 4,388.53 10.53 6.00 5.97 -0.56 8,100.00 89.94 0.12 3,897.34 110.34 4,389.21 110.34 6.00 5.98 -0.55 8,176.30 94.50 359.71 3,894.38 186.56 4,389.10 186.56 6.00 5.98 -0.54 Hold for 150' 8,200.00 94.50 359.71 3,892.52 210.19 4,388.98 210.19 0.00 0.00 0.00 8,300.00 94.50 359.71 3,884.68 309.88 4,388.47 309.88 0.00 0.00 0.00 8,300.63 94.50 359.71 3,884.63 310.51 4,388.47 310.51 0.00 0.00 0.00 1H-1021-2 01.T1 091517 RP 8,326.30 94.50 359.71 3,882.61 336.10 4,388.34 336.10 0.00 0.00 0.00 Start 3°/100' DLS, -170.46° TF, for 157.08' 8,400.00 92.32 359.34 3,878.23 409.66 4,387.73 409.66 3.00 -2.96 -0.50 8,483.38 89.85 358.93 3,876.65 493.01 4,386.47 493.01 3.00 -2.96 -0.50 Hold for 415A1' 8,500.00 89.85 358.93 3,876.69 509.63 4,386.15 509.63 0.00 0.00 0.00 8,569.51 89.85 358.93 3,876.87 579.13 4,384.85 579.13 0.00 0.00 0.00 1H-102A401.T1 15O015 BW 8,600.00 89.85 358.93 3,876.95 609.61 4,384.28 609.61 0.00 0.00 0.00 8,636.93 89.85 358.93 3,877.04 646.54 4,383.59 646.54 0.00 0.00 0.00 1 H-1021-2 01.T1020917 RP 8,700.00 89.85 358.93 3,877.21 709.59 4,382.41 709.59 0.00 0.00 0.00 8,800.00 89.85 358.93 3,877.46 809.58 4,380.54 809.58 0.00 0.00 0.00 8,898.79 89.85 358.93 3,877.72 908.35 4,378.69 908.35 0.00 0.00 0.00 Start 1.5°/100' DLS, 126.77° TF, for 72.66' 8,900.00 89.84 358.94 3,877.72 909.56 4,378.66 909.56 1.50 -0.90 1.20 8,969.97 89.21 359.78 3,878.30 979.52 4,377.88 979.52 1.50 -0.90 1.20 11-1-1021-2 Poly (1) 8,970.31 89.21 359.78 3,878.30 979.86 4,377.88 979.86 0.00 0.00 0.00 11-1-1021-2 Poly (0) 8,970.31 89.21 359.78 3,878.30 979.86 4,377.88 979.86 0.01 0.00 0.00 1H-1021-1 Poly (0) -1H -102L1 Poly (1) 8,971.45 89.20 359.80 3,878.32 981.00 4,377.88 981.00 1.95 -1.17 1.56 Adjust TF to 128.69°, for 49.44' -1 H-1021-2 02.T2 091517 RP 9,000.00 88.93 0.13 3,878.79 1,009.55 4,377.86 1,009.55 1.50 -0.94 1.17 9,020.89 88.74 0.38 3,879.21 1,030.44 4,377.96 1,030.44 1.50 -0.94 1.17 Hold for 264.51' 9,100.00 88.74 0.38 3,880.95 1,109.52 4,378.48 1,109.52 0.00 0.00 0.00 9,136.80 88.74 0.38 3,881.77 1,146.31 4,378.72 1,146.31 0.00 0.00 0.00 IH -1021-2 02.72 020917 RP 9,197.58 88.74 0.38 3,883.11 1,207.08 4,379.12 1,207.08 0.00 0.00 0.00 1H -102A4 01.T1 16Feb15 BW -1 H -102A4 02.T2150ct15 BW 9,200.00 88.74 0.38 3,883.16 1,209.49 4,379.14 1,209.49 0.00 0.00 0.00 9,285.40 88.74 0.38 3,885.04 1,294.88 4,379.70 1,294.88 0.00 0.00 0.00 Start 1.5°1100' DLS, 42.75° TF, for 51.16' 9,300.00 88.90 0.53 3,885.34 1,309.47 4,379.82 1,309.47 1.50 1.10 1.02 9,336.57 89.30 0.90 3,885.92 1,346.03 4,380.28 1,346.03 1.50 1.10 1.02 Adjust TF to 48.02°, for 66.83' -1 H-1021-2 03.73 091517 RP 9,400.00 89.94 1.61 3,886.34 1,409.44 4,381.66 1,409.44 1.50 1.00 1.11 9,403.40 89.97 1.65 3,886.35 1,412.84 4,381.76 1,412.84 1.50 1.00 1.11 Hold for 311.08' 9,500.00 89.97 1.65 3,886.40 1,509.40 4,384.53 1,509.40 0.00 0.00 0.00 9,600.00 89.97 1.65 3,886.45 1,609.36 4,387.40 1,609.36 0.00 0.00 0.00 91182017 10.26:30AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kupamk River Unit Site: Kupamk 1H Pad Well: Rig: 1H-102 Wellborn: 11-1-10212 Design: 1H-102L2wp24 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Rig: 1 H-102 TVD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) MD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature 'fanned Survey Vertical Dogleg Build Tum +EI -W Measured Rate Rate Vertical (usft) (usft) Depth Inclination Azimuth Depth +Nl-S 1,709.32 (usft) (°) (°) (usft) (usft) 0.00 9,700.00 89.97 1.65 3,886.50 1,709.32 0.00 9,714.48 89.97 1.65 3,886.51 1,723.79 -3.00 Start 3°1100' DLS, -90.01° TF, for 221.5' 1,909.20 3.00 0.00 9,800.00 89.97 359.08 3,886.55 1,809.30 -3.00 9,849.17 89.97 357.60 3,886.57 1,858.45 4,362.92 11-1-1021-2 03.T3 020917 RP 3.00 0.00 -3.00 4,343.12 9,900.00 89.97 356.08 3,886.60 1,909.20 2,227.45 9,935.98 89.97 355.00 3,886.62 1,945.07 0.00 Adjust TF to .89.99°, for 28( -1H-1021-2 04.74 091517 RP 2,302.89 0.00 10,000.00 89.97 353.08 3,886.65 2,008.75 0.00 10,100.00 89.97 350.08 3,886.70 2,107.66 0.00 10,200.00 89.97 347.08 3,886.75 2,205.66 4,269.21 10,222.38 89.97 346.41 3,886.77 2,227.45 2,538.91 Hold for 188.01' -0.13 3.50 4,259.89 2,596.64 3.50 10,224.60 89.97 346.41 3,886.77 2,229.60 -1.59 1H-1021-2 04.T4 020917 RP 4,252.15 2,670.03 3.51 -1.59 10,300.00 89.97 346.41 3,886.80 2,302.89 0.00 10,400.00 89.97 346.41 3,886.85 2,400.09 10,410.39 89.97 346.41 3,886.86 2,410.19 Start 3.5°1100' DLS, 92.151 TF, for 131.29' 10,500.00 89.85 349.54 3,886.99 2,497.83 10,534.66 89.81 350.75 3,887.10 2,531.98 1H-1021-2 05.T5 091517 RP 10,541.68 89.80 351.00 3,887.12 2,538.91 Adjust TF to 117.03°, for 132.16' -1H-1021-2 05.T5 091517 csd 10,600.00 88.87 352.82 3,887.80 2,596.64 10,625.08 88.47 353.60 3,888.38 2,621.53 1H -102L2 OS.TS 020917 RP 10,673.84 87.70 355.13 3,890.01 2,670.03 Hold for 79.76' 10,687.25 87.70 355.13 3,890.55 2,683.39 1 H -102A4 03.73 150ct15 BW 10,687.26 87.70 355.13 3,890.55 2,683.40 1H-102A402.T2 16Feb15 BW 10,700.00 87.70 355.13 3,891.06 2,696.08 10,753.59 87.70 355.13 3,893.21 2,749.43 Start 3.5°1100' DLS, 112.73° TF, for 88.98' 10,800.00 87.07 356.63 3,895.33 2,795.67 10,842.57 86.50 358.00 3,897.72 2,838.13 Adjust TF to 133.39°, for 122.11' -1 1-1-1021-2 06.T6 091517 RP 10,900.00 85.12 359.47 3,901.92 2,895.38 10,928.89 84.43 0.21 3,904.55 2,924.15 11-1-1021-2 06.T6 020917 RP 10,964.68 83.57 1.12 3,908.29 2,959.75 Hold for 53.04' 11,000.00 83.57 1.12 3,912.24 2,994.83 11,011.83 83.57 1.12 3,913.57 3,006.59 1 H -102A4 03.73 16Feb15 BW 11,011.87 83.57 1.12 3,913.57 3,006.62 IH -102A4 04.T4150ct15 BW 4,249.93 Vertical Dogleg Build Tum +EI -W Section Rate Rate Rate (usft) (usft) (°1100usft) (°1100usft) (°/100usft) 4,390.27 1,709.32 0.00 0.00 0.00 4,390.69 1,723.79 0.00 0.00 0.00 4,391.23 1,809.30 3.00 0.00 -3.00 4,389.81 1,858.45 3.00 0.00 -3.00 4,387.01 1,909.20 3.00 0.00 -3.00 4,384.21 1,945.07 3.00 0.00 -3.00 4,377.56 2,008.75 3.00 0.00 -3.00 4,362.92 2,107.66 3.00 0.00 -3.00 4,343.12 2,205.66 3.00 0.00 -3.00 4,337.99 2,227.45 3.00 0.00 -3.00 4,337.47 2,229.60 0.00 0.00 0.00 4,319.75 2,302.89 0.00 0.00 0.00 4,296.25 2,400.09 0.00 0.00 0.00 4,293.81 2,410.19 0.00 0.00 0.00 4,275.14 2,497.83 3.50 -0.13 3.50 4,269.21 2,531.98 3.50 -0.13 3.50 4,268.10 2,538.91 3.50 -0.13 3.50 4,259.89 2,596.64 3.50 -1.59 3.12 4,256.93 2,621.53 3.51 -1.59 3.13 4,252.15 2,670.03 3.51 -1.59 3.13 4,251.01 2,683.39 0.00 0.00 0.00 4,251.01 2,683.40 0.01 0.00 0.00 4,249.93 2,696.08 0.00 0.00 0.00 4,245.38 2,749.43 0.00 0.00 0.00 4,242.05 2,795.67 3.50 -1.35 3.23 4,240.06 2,838.13 3.48 -1.34 3.22 4,238.79 2,895.38 3.50 -2.40 2.55 4,238.71 2,924.15 3.50 -2.40 2.56 4,239.12 2,959.75 3.50 -2.39 2.57 4,239.81 2,994.83 0.00 0.00 0.00 4,240.04 3,006.59 0.00 0.00 0.00 4,240.04 3,006.62 0.00 0.00 0.00 4.240.15 3,012.45 0.00 0.00 0.00 911812017 10:26:30AM Page 5 COMPASS 5000.14 Build 85 v" ( ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Coordinate Reference: Well Rig: 1 H-102 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Project: Kupawk River Unit MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kupawk 1 H Pad North Reference: True Well: Rig: 1H-102 Survey Calculation Method: Minimum Curvature Wellbore: 1H-10212 Rate Rate Design: 1H-102L2wp24 (usft) (usft) Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +NI -S +EbW Section Rate Rate Rate (usft) (1 (1) (usft) (usft) (usft) (usft) (°/100usft) ('/100usft) ('1100usft) Start 2°1100' DLS, -12.15' TF, for 124.24' 11,100.00 85.18 0.78 3,922.29 3,094.31 4,241.51 3,094.31 2.00 1.96 -0.42 11,141.97 86.00 0.60 3,925.52 3,136.15 4,242.01 3,136.15 2.00 1.96 -0.42 Adjust TF to -5.16°, for 163.91' -1 H-1021-2 07.77 091517 RP 11,200.00 87.16 0.50 3,928.98 3,194.07 4,242.57 3,194.07 2.00 1.99 -0.18 11,300.00 89.15 0.32 3,932.21 3,294.02 4,243.28 3,294.02 2.00 1.99 -0.18 11,305.88 89.27 0.31 3,932.29 3,299.89 4,243.31 3,299.89 2.00 1.99 -0.18 Hold for 155AV 11,385.82 89.27 0.31 3,933.32 3,379.83 4,243.73 3,379.83 0.00 0.00 0.00 11-1-1021-2 07.77 020917 RP 11,400.00 89.27 0.31 3,933.50 3,394.01 4,243.81 3,394.01 0.00 0.00 0.00 11,431.77 89.27 0.31 3,933.90 3,425.77 4,243.98 3,425.77 0.00 0.00 0.00 1H -102A4 04.T4 16Feb15 BW -1 H -102A4 05.T5150ct15 BW 11,461.28 89.27 0.31 3,934.28 3,455.28 4,244.14 3,455.28 0.00 0.00 0.00 Start 2'1100' DLS, 5.04' TF, for 36.89' 11,498.18 90.00 0.37 3,934.52 3,492.18 4,244.35 3,492.18 2.00 1.99 0.18 Adjust TF to 0.18°, for 111.2'. 11-1-1021-2 08.T8 091517 RP 11,500.00 90.04 0.37 3,934.52 3,494.00 4,244.36 3,494.00 2.00 2.00 0.01 11,600.00 92.04 0.38 3,932.71 3,593.97 4,245.02 3,593.97 2.00 2.00 0.01 11,609.38 92.22 0.38 3,932.36 3,603.35 4,245.08 3,603.35 2.00 2.00 0.01 Hold for 439.98' 11,610.99 92.22 0.38 3,932.30 3,604.95 4,245.09 3,604.95 0.00 0.00 0.00 1H-1021-2 08.T8 020917 RP 11,700.00 92.22 0.38 3,928.85 3,693.90 4,245.67 3,693.90 0.00 0.00 0.00 11,719.10 92.22 0.38 3,928.10 3,712.98 4,245.80 3,712.98 0.00 0.00 0.00 1H -102A4 05.T5 16Feb15 BW-1H-102A406.T6 15Oct15 BW 11,800.00 92.22 0.38 3,924.96 3,793.82 4,246.33 3,793.82 0.00 0.00 0.00 11,900.00 92.22 0.38 3,921.08 3,893.74 4,246.99 3,893.74 0.00 0.00 0.00 12,000.00 92.22 0.38 3,917.20 3,993.66 4,247.64 3,993.66 0.00 0.00 0.00 12,049.36 92.22 0.38 3,915.29 4,042.98 4,247.97 4,042.98 0.00 0.00 0.00 Start 1.6.1100' DLS, 179.75° TF, for 48.27' 12,097.62 91.50 0.38 3,913.72 4,091.22 4,248.29 4,091.22 1.50 -1.50 0.01 Adjust TF to -179.72°, for 59.29'- IH -1021-2 09.T9 091517 RP 12,100.00 91.46 0.38 3,913.66 4,093.60 4,248.30 4,093.60 1.50 -1.50 -0.01 12,117.02 91.21 0.38 3,913.26 4,110.62 4,248.42 4,110.62 1.50 -1.50 -0.01 11H-1021-2 09.T9 020917 RP 12,156.91 90.61 0.38 3,912.63 4,150.50 4,248.68 4,150.50 1.50 -1.50 -0.01 Hold for 422.28' 12,200.00 90.61 0.38 3,912.17 4,193.58 4,248.96 4,193.58 0.00 0.00 0.00 12,300.00 90.61 0.38 3,911.10 4,293.58 4,249.62 4,293.58 0.00 0.00 0.00 12,400.00 90.61 0.38 3,910.04 4,393.57 4,250.27 4,393.57 0.00 0.00 0.00 12,410.82 90.61 0.38 3,909.92 4,404.38 4,250.34 4,404.38 0.00 0.00 0.00 1 H -102A4 06.T6 16Feb15 BW 12,410.82 90.61 0.38 3,909.92 4,404.39 4,250.34 4,404.39 0.00 0.00 0.00 1H-102A407.T715Oct75 BW 12,500.00 90.61 0.38 3,908.97 4,493.56 4,250.93 4,493.56 0.00 0.00 0.00 12,579.19 90.61 0.38 3,908.13 4,572.74 4,251.45 4,572.74 0.00 0.00 0.00 Start 2'1100' DLS, 179.88° TF, for 100.53' 12,600.00 90.19 0.38 3,907.98 4,593.55 4,251.58 4,593.55 2.00 -2.00 0.00 12,679.72 88.60 0.38 3,908.62 4,673.27 4,252.11 4,673.27 2.00 -2.00 0.00 Adjust TF to -179.86', for 88.07' -11H-1021-2 10.T10 091517 RP 12,700.00 88.19 0.38 3,909.39 4,693.54 4,252.24 4,693.54 2.00 -2.00 0.00 911812017 10 26 30A Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kupamk River Unit Site: Kupawk 1H Pad Well: Rig: 1H-102 Wellbore: 11-1-1021-2 Design: 1 H-102L2wp24 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Planned survey Vertical Dogleg Build Measured +E/ -W Vertical Rate Depth Inclination Azimuth Depth +N/-5 (usft) (1) (°1100usft) (usft) (usft) 12,767.79 86.84 0.38 3,912.32 4,761.26 Hold for 149.54' 4,771.80 0.00 0.00 12,778.35 86.84 0.38 3,912.91 4,771.80 1H-1021-2 10.TD 020917 RP 0.00 4,252.88 4,789.83 12,796.39 86.84 0.38 3,913.90 4,789.81 1H -102A4 07.77 16Febl5 BW 0.00 0.00 0.00 12,796.40 86.84 0.38 3,913,90 4,789.83 1H -102A4 08.T8150ct15 BW 4,253.67 4,910.56 0.00 12,800.00 86.84 0.38 3,914.10 4,793.42 12,900.00 86.84 0.38 3,919.62 4,893.27 12,917.32 86.84 0.38 3,920.57 4,910.56 Start 1.1100' DLS, 179.95° TF, for 73.87' 1.00 -1.00 12,991.19 86.10 0.38 3,925.12 4,984.29 Adjust TF to 180°, for 54.46'- IH -1021-2 1l.T11 091517 RP 4,255.52 13,000.00 86.01 0.38 3,925.73 4,993.08 13,045.65 85.56 0.38 3,929.08 5,038.60 Hold for 388.9' 4,256.83 5,391.88 0.00 13,100.00 85.56 0.38 3,933.29 5,092.79 13,200.00 85.56 0.38 3,941.04 5,192.48 13,300.00 85.56 0.38 3,948.79 5,292.18 13,400.00 85.56 0.38 3,956.54 5,391.88 13,434.55 85.56 0.38 3,959.22 5,426.32 TD: 13434.55' MD, 3959.22' TVD -1 1-1-1021-2 12.TD 091517 RP ConocoPhillips Standard Proposal Report Well Rig: 111-102 1 H-102 actual ® 92.62usft (Doyon 142) 1 H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature 9/18201710:26:30AM Page 7 COMPASS 5000.14 Build 85 Vertical Dogleg Build Tum +E/ -W Section Rate Rate Rate (usft) (usft) ('/100usft) (°1100usft) (°1100usft) 4,252.69 4,761.26 2.00 -2.00 -0.01 4,252.76 4,771.80 0.00 0.00 0.00 4,252.88 4,789.81 0.00 0.00 0.00 4,252.88 4,789.83 0.00 0.00 0.00 4,252.90 4,793.42 0.00 0.00 0.00 4,253.56 4,893.27 0.00 0.00 0.00 4,253.67 4,910.56 0.00 0.00 0.00 4,254.15 4,984.29 1.00 -1.00 0.00 4,254.21 4,993.08 1.00 -1.00 0.00 4,254.51 5,038.60 1.00 -1.00 0.00 4,254.87 5,092.79 0.00 0.00 0.00 4,255.52 5,192.48 0.00 0.00 0.00 4,256.18 5,292.18 0.00 0.00 0.00 4,256.83 5,391.88 0.00 0.00 0.00 4,257.06 5,426.32 0.00 0.00 0.00 9/18201710:26:30AM Page 7 COMPASS 5000.14 Build 85 moi' ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 1 H-102 Company: ConocoPhillips (Alaska) Inc. -Kupi TVD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Project: Kupamk River Unit MD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Rig: 1 H-102 Survey Calculation Method: Minimum Curvature Wellbore: 111-10212 3,876.22 309.85 Design: 11-1-102L2wp24 by 8.43usft at 8300.63usft MD (3884.63 TVD, 310.51 N. 4388.47 E) Design Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +NlS +El -W -Shape (1) V) (usft) (usft) (usft) (usft) 1H-1021201.77091517 0.00 0.00 3,876.22 309.85 4,388.47 - plan misses target center by 8.43usft at 8300.63usft MD (3884.63 TVD, 310.51 N. 4388.47 E) - Circle (radius 100.00) 1H-1021202.72091517 0.00 0.00 3,878.32 981.00 4,377.88 - plan hits target center -Circle (radius 100.00) iH-1021203.T3091517 0.00 0.00 3,885.92 1,346.03 4,380.28 - plan hits target center -Circle (radius 100.00) 111-1021204.T4091517 0.00 0.00 3,886.62 1,945.07 4,384.21 - plan hits target center - Circle (radius 100.00) iH-1021_205.T5091517 0.00 0.00 3,887.12 2,538.64 4,308.10 - plan misses target center by 39.46usft at 10535.08usft MD (3887.10 TVD, 2532.39 N. 4269.14 E) - Circle (radius 100.00) 1 H-10212 05.T5 091517 0.00 0.00 3,887.12 2,538.91 4,268.10 - plan hits target center - Circle (radius 100.00) 1H -1021-206.T6091517 0.00 0.00 3,897.72 2,838.13 4,240.06 - plan hits target center - Circle (radius 100.00) 1H -1021-210.T1009151 0.00 0.00 3,908.82 4,673.27 4,252.11 - plan hits target center - Circle (radius 100.00) 1H -1021209.T9091517 0.00 0.00 3,913.72 4,091.22 4,248.29 - plan hits target center - Cirde (radius 100.00) 1H -1021211.T1109151 0.00 0.00 3,925.12 4,984.29 4,254.15 - plan hits target center - Circle (radius 100.00) 1H -1021207.T7091517 0.00 0.00 3,925.52 3,136.15 4,242.01 - plan hits target center - Circle (radius 100.00) 1H-1021208.78091517 0.00 0.00 3,934.52 3,492.18 4,244.35 - plan hits target center -Circle (radius 100.00) 1H-1021.2 Poly (1) 0.00 0.00 3,940.62 979.00 4,377.86 - plan misses target center by 62.32usft at 8970.31 usft MD (3878.30 TVD, 979.86 N, 4377.88 E) - Polygon Point 1 3,940.62 4,448.18 -250.82 Point 2 3,940.62 3,929.48 -154.21 Point 3 3,940.62 3,129.42 -159.47 Point 3,940.62 2,383.69 -214.37 Point 5 3,940.62 1,099.07 -142.80 Point 3,940.62 828.72 -94.57 Point 7 3,940.62 -71.35 -100.48 Point 8 3,940.62 -987.88 -36.49 Point 9 3,940.62 -989.52 213.53 Point 10 3,940.62 -73.32 199.54 Point 11 3,940.62 827.41 105.45 Point 12 3,940.62 1,096.77 207.23 Point 13 3,940.62 2,382.57 -44.36 Point 14 3,940.62 3,128.76 -59.46 91182017 10:26:30AM Page 8 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kupamk River Unit Site: Kuparuk I Pad Well: Rig: 111-102 Wellbore: 114-1021-2 Design: 1H-102L2wp24 romt .i o Point 16 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Rig: 1H-102 TVD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) MD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature 3,940.62 3,928.49 4 3,940.62 4,446.86 -50 1H-1021_2 Poly (0) 0.00 0.00 3,940.62 979.00 4,377 - plan misses target center by 62.32usft at 8970.3lusft MD (3878.30 TVD, 979.8E - Polygon (usft) Diameter Diameter Point 1 3,940.62 4,448.50 -300 Point 2 3,940.62 3,929.81 -204 Point 3,940.62 3,129.62 -189 Point 3,940.62 2,384.02 -264 Point 5 3,940.62 1,099.40 -192 Point 3,940.62 829.05 -144 Point 3,940.62 -71.02 -150 Point 3,940.62 -987.75 -56 Point 3,940.62 -990.18 313 Point 10 3,940.62 -73.98 299 Point 11 3,940.62 826.75 205 Point 12 3,940.62 1,096.77 207 Point 13 3,940.62 2,382.25 5 Point 14 3,940.62 3,128.57 -29 Point 15 3,940.62 3,928.17 45 Point 16 3,940.62 4,446.66 -20 1 H-1 02L2 12.TD 09151 i 0.00 - plan hits target center -Circle (radius 100.00) Casing Points Formations 0.00 3,959.22 5,426.32 4,257 Measured Vertical Casing Hole Depth Depth (usft) Diameter Diameter (usft) (use) Name (") C) 1,771 00 1,690.93 10 314" x 13-1/2 10-3/4 13-112 7.841.01 3,861.93 7-5/8" x 9-718" 7-5/8 9-7/8 13.434.55 3,958.41 4-1/2'x6-3/4" 4-1/2 6-3/4 Measured Vertical Depth Depth (usft) (usft) Name 1,687.50 1,620.02 PFROST 1,890.56 1,788,22 T-3 2,188.75 2,008.02 K-15 5,303.78 3,135.02 UG_C 6,153.13 3,382.22 UG_B 6,513.99 3,486.42 UG_A 6,928.59 3,610.32 Na 7,429.38 3,751.92 WS_D 7,602.14 3,798.72 WS_C 7,677.17 3,818.72 WS_B 7,806.89 3,853.32 AS—A4 7,877.57 3,870.62 WS_A4_Objective r 10,856.75 3,897.82 WS_A3 13,239.79 3,943.32 WS_A3_Objective / Dip Dip Direction Lithology V) �) 9/182017 10:26:30AM Page 9 COMPASS 5000.14 Build 85 Plan Annotations ConocoPhillips ConocoPhillips Measured Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 1 H-102 Company: ConocoPhillips (Alaska) Inc. -Kupl ND Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Project: Kupanuk River Unit MD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Site: Kupawk 1 H Pad North Reference: True Well: Rig: 1 H-102 Survey Calculation Method: Minimum Curvature Wellbore: 11-1-10212 7,873.42 3,870.46 Design: 1 H-102L2wp24 Start 6°/100' DLS, -5.35° TF, for 302.88' 8,176.30 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 7,841.00 3,862.64 -145.53 4,385.48 KOP: 15.9/100' DLS, -20° TF, for 12.42' 7,853.42 3,865.76 -133.52 4,385.84 Hold for 20' 7,873.42 3,870.46 -114.08 4,386.31 Start 6°/100' DLS, -5.35° TF, for 302.88' 8,176.30 3,894.38 186.56 4,389.10 Hold for 150' 8,326.30 3,882.61 336.10 4,388.34 Start 3°/100' DLS, -170.46° TF, for 157.08' 8,483.38 3,876.65 493.01 4,386.47 Hold for415.41' 8,898.79 3,877.72 908.35 4,378.69 Start 1.5.1100' DLS, 126:77° TF, for 72.66' 8,971.45 3,878.32 981.00 4,377.88 Adjust TF to 128.69°, for 49.44' 9,020.89 3,879.21 1,030.44 4,377.96 Hold for 264.51' 9,285.40 3,885.04 1,294.88 4,379.70 Start 1.5°/100' DLS, 42.75° TF, for 51.16' 9,336.57 3,885.92 1,346.03 4,380.28 Adjust TF to 48.02', for 66.83' 9,403.40 3,886.35 1,412.84 4,381.76 Hold for 311.08' 9,714.48 3,886.51 1,723.79 4,390.69 Start 3°/1 OO' DLS, -90.01° TF, for 221.5' 9,935.98 3,886.62 1,945.07 4,384.21 Adjust TF to -89.99°, for 286.4' 10,222.38 3,886.77 2,227.45 4,337.99 Hold for 188.01' 10,410.39 3,886.86 2,410.19 4,293.81 Start 3.5'1100' DLS, 92.15° TF, for 131.29' 10,541.68 3,887.12 2,538.91 4,268.10 Adjust TF to 117.03', for 132.16' 10,673.64 3,890.01 2,670.03 4,252.14 Hold for 79.76' 10,753.59 3,893.21 2,749.43 4,245.38 Start 3.5°/100' DLS, 112.73° TF, for 88.98' 10,842.57 3,897.72 2,838.13 4,240.06 Adjust TF to 133.39°, for 122.11' 10,964.68 3,908.29 2,959.75 4,239.12 Hold for 53.04' 11,017.73 3,914.23 3,012.45 4,240.15 Start 2°/100' DLS, -12.15° TF, for 124.24' 11,141.97 3,925.52 3,136.15 4,242.01 Adjust TF to -5.16°, for 163.91' 11,305.88 3,932.29 3,299.89 4,243.31 Hold for 155.41' 11,461.28 3,934.28 3,455.28 4,244.14 Start 2°1100' DLS, 5.04° TF, for 36.89' 11,498.18 3,934.52 3,492.18 4,244.35 Adjust TF to 0.18°, for 111.2' 11,609.38 3,932.36 3,603.35 4,245.08 Hold for 439.98' 12,049.36 3,915.29 4,042.98 4,247.97 Start 1.5°/100' DLS, 179.75° TF, for 48.27' 12,097.62 3,913.72 4,091.22 4,248.29 Adjust TF to -179.72°, for 59.29' 12,156.91 3,912.63 4,150.50 4,248.68 Hold for 422.28' 12,579.19 3,908.13 4,572.74 4,251.45 Start 2°/100' DLS, 179.88' TF, for 100.53' 12,679.72 3,908.82 4,673.27 4,252.11 Adjust TF to -179.86°, for 88.07' 12,767.79 3,912.32 4,761.26 4,252.69 Hold for 149.54' 12,917.32 3,920.57 4,910.56 4,253.67 Start 1'/100' DLS, 179.95° TF, for 73.87' 12,991.19 3,925.12 4,984.29 4,254.15 Adjust TF to 180°, for 54.46' 13,045.65 3,929.08 5,038.60 4,254.51 Hold for 388.9' 13,434.55 3,959.22 5,426.32 4,257.06 TD: 13434.55' MD, 3959.22' TVD 9/182017 10:26:30AM Page 10 COMPASS 5000.14 Build 85 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Rig: 111-1-102 Plan: 11-1-1021-2 500292358000 1 H-1021-2wp24 ConocoPhillips Clearance Summary Anticollision Report 15 September, 2017 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 11-1 Pad - Rig: 1H-102 - Plan: 1H-1021-2 - 1H-102L2wp24 Well Coordinates: 6,980,414.37 N, 1,689,609.08 E (70" 21' 27.68" N, 149° 36' 01.64" W) Datum Height: 11-1-102 actual @ 92.62usft (Doyon 142) Scan Range: 7,841.00 to 13,434.65 usft Measured Depth. Scan Radius is 1,539.59 usft. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation Is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 86 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 i Anti-Collision ConocoPhillips ConocoPhillips Anticollision Report for Rig: 1 H-102 -1 H-102L2wp24 ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Trav, Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: KuparuklH Pad -Rig: IH -102 -Plan: 1H-1021_2-1H-102L2wp24 Scan Range: 7,841.00 to 13,434.66 usft. Measured Depth. Scan Radius is 1,539.59 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 -Wallbare Name - Design (usft) (usft) (usft) (usft) usft Kuparuk 1H Pad 1H -05 -1H -05-1H-05 10,632.44 1,384.21 10,632.44 1,172.53 6,825.00 6.539 Clearance Factor Pass - Major Risk 1 H-05 - 1 H-105 - 1 H-105 10,701.94 413.12 10,701.94 297.85 7,300.00 3.584 Centre Distance Pass - Major Risk 1H -05 -1H -105-1H-105 10,761.99 429.55 10,761.99 283.57 7,425.00 2.943 Clearance Factor Pass - Major Risk 1H-118-1H-118-iH-118 12,053.83 976.23 12,053.83 797.98 7,150.00 5.477 Centre Distance Pass - Major Risk 1H -118 -1H -118-1H-118 12,075,61 976.53 12,075.61 797.62 7,175.00 5.458 Clearance Factor Pass - Major Risk Plan: 1H -103 -Plan: 1H-10311-1H-103L1wp21 12,379.74 1,192.17 12,379.74 979.98 13,755.59 5.619 Clearance Factor Pass - Major Risk Plan: 1H -103 -Plan: 1H-1031_3-1H-1031_3wp21 12,354.81 1,190.91 12,354.81 993.29 13,691.68 6.026 Clearance Factor Pass - Major Risk Plan: 1H -103 -Plan: 1H-1031-4-1H-103L4wp2l(new 1 12,325.54 1,194.96 12,325.54 1,000.70 13,599.94 6.151 Clearance Factor Pass - Major Risk Plan: 1H -109 -Plan: 1H-109-1H-109wp21 8,718.58 1,008,59 8,716.58 871.28 6,600.00 7.346 Centre Distance Pass - Major Risk Plan: IH -109 -Plan: 1H-109-1H-109wp21 8,856.01 1,010.20 8,856.01 869.66 6,750.00 7.188 Clearance Factor Pass - Major Risk Plan: 1H-111 - Plan: 1H-111 - 1H-111wp22 8,324.47 431.98 8,324.47 327.13 6,425.00 4.120 Centre Distance Pass- Major Risk Plan: iH-111 - Plan: 1 H-111 - 1H-111wp22 8,325.35 433.39 8,325.35 326.21 6,450.00 4.044 Clearance Factor Pass- Major Risk Plan: IH -113 -Plan: 1H-113-1H-113wp21 8,465.47 770.77 8,465.47 673.98 6,350.00 7.963 Centre Distance Pass - Major Risk Plan: 1H -113 -Plan: IH-113-1H-113wp21 8,467.78 772.31 8,467.78 672.98 6,400.00 7.775 Clearance Factor Pass - Major Risk Plan: 1H -114 -Plan: I H-114 - 1 H-114wp22 10,681.72 888.10 10,681.72 741.20 6,975.00 6.045 Centre Distance Pass - Major Risk Plan: 1H -114 -Plan: 1 H-1 14 - 1 H-11 4wp22 10,727.68 888.44 10,727.68 741.01 7,025.00 6.026 Clearance Factor Pass - Major Risk Plan: 1H -115 -Plan: 1H-115-iH-115wp21 9,495.24 736.15 9,495.24 634.59 6,500.00 7.249 Centre Distance Pass - Major Risk Plan: 1H -115 -Plan: 1H-115-iH-115wp21 9,520.84 738.51 9,520.84 631.67 6,575.00 6.912 Clearance Factor Pass - Major Risk Plan: 1H -116 -Plan: IH-116-iH-tt6wp21 9,577.63 492.28 9,577.63 385.57 6,575.00 4.613 Centre Distance Pass - Major Risk Plan: 1H -116 -Plan: 1H-116-1H-116wp21 9,593.59 494.66 9,593.59 382.20 6,625.00 4.399 Clearance Factor Pass - Major Risk Plan: 1H -120 -Plan: 1H-120-1H-120wp21 10,150.66 810.97 10,150.66 711.64 6,625.00 8.164 Centre Distance Pass - Major Risk Plan: IH -120 -Plan: 1H-120-1H-120wp21 10,155.11 811.56 10,155.11 711.02 6,650.00 8.073 Clearance Factor Pass - Major Risk Plan: iH-121 - Plan: 1 H-121 - 1H-121wp20 10,742.37 717.52 10,742.37 615.91 6,750.00 7.062 Centre Distance Pass- Major Risk Plan: 1H -121 -Plan: IH-121-1H-121wp20 10,762.63 719.21 10,762.63 614.77 6,800.00 6.886 Clearance Factor Pass - Major Risk Plan: 1H -122 -Plan: IH-122-1H-122wp20 11,641.84 592.10 11,641.84 478.36 7,225.00 5.205 Centre Distance Pass - Major Risk Plan: 1H -122 -Plan: 1H-122-1H-122wp20 11,699.73 598.01 11,699.73 474.21 7,325.00 4.831 Clearance Factor Pass - Major Risk Plan: IH -123 -Plan: 1H-123-iH-123wp20 12,538.44 395,34 12,538.44 272.29 7,750.00 3.213 Centre Distance Pass - Major Risk Plan: 1H -123 -Plan: 1H-123-lH-123wp20 12,602.90 403.62 12,602.90 265.07 7,850.00 2.913 Clearance Factor Pass - Major Risk 15 September, 2017 - 14.:56 Page 2 of 5 COMPASS ConocoPhillips Anticollision Report for Rig: 1H-102 - 1 H-102L2wp24 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad -Rig: 1H -102 -Plan: 11-1-10212-1H-102L2wp24 Scan Range: 7,841.00 to 13,434.55 usft. Measured Depth. Scan Radius is 1,519.59 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Site Name Comparison Well Name - Wellbore Name - Design Plan: 1H-124- Plan: 1H-124- 1 H-124wp20 Plan: 1H-125- Plan: 1H-125- 1 H-125wp20 Rig: 1H-102- 1H -102-1H-102 Rig: 1H-102- 1H -102-1H-102 Rig: 11-f-102-11-1-10211 - 11-1-1021-1 Rig: IH -102-11-1-10211 -1H-1021-1 T13:11-1-118-11-1-118-11-1-118 TD: iH-118 - 1 H-118 - 1 H-118 Survey too/ Program ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Depth Distance Depth Separation Depth Factor Minimum Separation Warning (usft) (usft) (usft) (usft) can 8,199.62 1H-102L2wp24 MWD-INC_ONLY 13,431.16 339.07 13,431.16 186.52 8,175.00 2.223 Clearance Factor Pass - Major Risk 13,434.50 1,345.34 13,434.50 1,152.81 7,450.00 6.988 Clearance Factor Pass -Major Risk 8,162.27 56.81 8,162.27 50.26 8,175.00 8.678 Centre Distance Pass -Major Risk 12,951.97 104.08 12,951.97 31.86 12,960.00 1.441 Clearance Factor Pass - Major Risk 8,142.98 36.07 8,142.98 30.12 8,150.00 6.065 Centre Distance Pass - Major Risk 12,053.82 976.23 12,053.82 797.99 7,150.00 5.477 Centre Distance Pass - Major Risk 12,075.61 976.54 12,075.61 797.62 7,175.00 5.458 Clearance Factor Pass - Major Risk From To Survey/Plan Survey Tool (usft) (waft) 67.62 1,009.26 GYD-GC-SS 1,050.36 1,678.04 MWD+IFR-AK-CAZ-SC 1,777.33 7,841.00 MWD+IFR-AK-CAZ-SC 7,841.00 8,199.62 1H-102L2wp24 MWD-INC_ONLY 8,199.62 9,699.62 iH-102L2wp24 MWD 81199.62 13,434.51 1H-102L2wp24 MWD+IFR-AK-CAZ-SC 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. 15 September. 2017 - 14:56 Page 3 of 5 COMPASS ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Rig: 11-1-102 Plan: 11-1-1021-2 500292358000 1 H-102L2wp24 ConocoPhillips Clearance Summary Anticollision Report 15 September, 2017 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference( Reference Design: Kuparuk 1H Pad - Rig: 1H -102 -Plan: 114-1021-2-1H-102L2wp24 Well Coordinates: 5,980,414.37 N, 1,689,609.08 E (70° 21' 27.58" N, 149° 36' 01.64" W) Datum Height: 1H-102 actual @ 92.62usft (Doyon 142) Scan Range: 7,841.00 to 13,434.55 usft. Measured Depth. ly Scan Radius is 1,539.69 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited R■ Geodetic Scale Factor Applied Version: 5000.14 Build: 85 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 Minor Risked ConocoPhillips ConocoPhillips ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Rig: 1H-102-1H-102L2wp24 10,632.44 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) 6,825.00 Reference Design: Kuparuk 1H Pad - Rig: 1H -102 -Plan: 114-1021-2-1H.102LZWp24 Clearance Factor Scan Range: 7,841.00 to 13,434.55 usft. Measured Depth. 1H -05 -1H -105-1H-105 Scan Radius is 1,639.69 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is Unlimited 413.12 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 10,632.44 1,384.21 10,632.44 1,172.53 6,825.00 6.539 Clearance Factor Pass - Major Risk 1H -05 -1H -105-1H-105 10,701.94 413.12 10,701.94 297.85 7,300.00 3.584 Centre Distance Pass - Major Risk 1H -05 -1H -105-1H-105 10,761.99 429.55 10,761.99 283.57 7,425.00 2.943 Clearance Factor Pass - Major Risk 1H -118 -1H -116-1H-118 12,053.83 976.23 12,053.83 797.98 7,150.00 5.477 Centre Distance Pass - Major Risk 1H -118 -1H -118-1H-118 12,075.61 976.53 12,075.61 797.62 7,175.00 5.458 Clearance Factor Pass - Major Risk Plan: 1H -103 -Plan: 1H-103L1-1H-103L1wp21 12,379.74 1,192.17 12,379.74 979.98 13,755.59 5.619 Clearance Factor Pass - Major Risk Plan: 1H -103 -Plan: 1H-1031_3-1H-103L3Wp21 12,354.81 1,190.91 12,354.81 993.29 13,691.68 6.026 Clearance Factor Pass - Major Risk Plan: 1H -103 -Plan: 1 H-1 031.4 - 1 H-1 03L4wp21 (new 1 12,325.54 1,194.96 12,325.54 1,000.70 13,599.94 6.151 Clearance Factor Pass - Major Risk Plan: 1H -109 -Plan: 1H-109. 1H-109wp21 8,718.58 1,008.59 8,718.58 871.28 6,600.00 7.346 Centre Distance Pass - Major Risk Plan: 1H -109 -Plan: 1H-109-1H-109wp21 8,856.01 1,010.20 8,656.01 869.66 6,750.00 7.188 Clearance Factor Pass - Major Risk Plan: 1H -111 -Plan: 1H-111-1H-111wp22 8,324.47 431.98 8,324.47 327.13 6,425.00 4.120 Centre Distance Pass - Major Risk Plan: 1 H-111 - Plan: 1 H-111 - 1H-111wP22 8,325.35 433.39 8,325.35 326.21 6,450.00 4.044 Clearance Factor Pass- Major Risk Plan: 1H -113 -Plan: 1H-113-1H-113wp21 8,465.47 770.77 8,465.47 673.98 6,350.00 7.963 Centre Distance Pass - Major Risk Plan: 1H -113 -Plan: 1H-113-1H-113wp21 8,467.78 772.31 8,467.78 672.98 6,400.00 7.775 Clearance Factor Pass - Major Risk Plan: 1H -114 -Plan: 1 H-114 - 1 H-114wp22 10,681.72 888.10 10,681.72 741.20 6,975.00 6.045 Centre Distance Pass - Major Risk Plan: 1H -114 -Plan: 1H-114-1H-114wp22 10,727.68 868.44 10,727.68 741.01 7,025.00 6.026 Clearance Factor Pass - Major Risk Plan: 1H -115 -Plan: 1H-115-1H-115wp21 9,495.24 736.15 9,495.24 634.59 6,500.00 7.249 Centre Distance Pass - Major Risk Plan: 1H -115 -Plan: 1H-115-1H-115wp21 9,520.84 738.51 9,520.84 631.67 6,575.00 6.912 Clearance Factor Pass - Major Risk Plan: 1H -116 -Plan: 1H-116-1H-116Wp21 9,577.63 492.28 9,577.63 385.57 6,575.00 4.613 Centre Distance Pass - Major Risk Plan: 1H -116 -Plan: 1H-116-1H-116wp21 9,593.59 494.66 9,593.59 382.20 6,625.00 4.399 Clearance Factor Pass - Major Risk Plan: 1H -120 -Plan: 11-1-120-1H-120wp21 10,150.66 810.97 10,150.66 711.64 6,625.00 8.164 Centre Distance Pass - Major Risk Plan: 1H -120 -Plan: 1H-120-1H-120wp21 10,155.11 811.56 10,155.11 711.02 6,650.00 6.073 Clearance Factor Pass - Major Risk Plan: 1H -121 -Plan: 1H-121-1H-121wp20 10,742.37 717.52 10,742.37 615.91 6,750.00 7.062 Centre Distance Pass - Major Risk Plan: 1H -121 -Plan: 1 H-1 21 - 1 H-121WP20 10,762.63 719.21 10,762.63 614.77 6,800.00 6.886 Clearance Factor Pass - Major Risk Plan: 1H -122 -Plan: 1H-122-1H-122wp20 11,641.84 592.10 11,641.84 478.36 7,225.00 5.205 Centre Distance Pass - Major Risk Plan: 1H -122 -Plan: 1H-122-1H-122wp20 11,699.73 598.01 11,699.73 474.21 7,325.00 4.831 Clearance Factor Pass - Major Risk Plan: 1H -123 -Plan: 1H-123-1H-123wp20 12,538.44 395.34 12,538.44 272.29 7,750.00 3.213 Centre Distance Pass - Major Risk Plan: 1H -123 -Plan: 1H-123-1H-123wp20 12,602.90 403.62 12,602.90 265.07 7,850.00 2.913 Clearance Factor Pass - Major Risk 15 September, 2017 - 14:56 Page 2 or5 COMPASS `-' ConocoPhillips To (usft) (usft) ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Rig: 1 H-102 -1 H-1O2L2wp24 1,009.26 1,050.36 1,678.04 1,777.33 Trav, Cylinder North Proximity Scan on Current Survey Data (North Reference) 7,841.00 8,199.62 1H-102L2wp24 8,199.62 9,699.62 Reference Design: Kupamk1H Pad -Rig: 1H -102 -Plan: 1H-102L2-1H-102L2wp24 8,199.62 13,434.51 1H-102L2wp24 Scan Range: 7,841.00 to 13,434.65 usft. Measured Depth. Scan Radius Is 1,539.59 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 Plan: 1H -124 -Plan: 1 H-124 - 1 H-124wp20 13,431.16 339.07 13,431.16 186.52 8,175.00 2.223 Clearance Factor Pass - Major Risk Plan: 1H -125 -Plan: 1H-125-1H-125wp20 13,434.50 1,345.34 13,434.50 1,152.81 7,450.00 6.988 Clearance Factor Pass - Major Risk Rig: 1H -102 -1H -102-1H-102 8.162.27 56.81 8.162.27 54.52 8,175.00 24.804 Clearance Factor Pass - Minor 1120 Minor Risked Rig: 1H -102 -1H -102L1 -1H -102L1 8.142.98 36.07 8,142.98 33.99 8,150.00 17.338 Clearance Factor Pass - Minor 1120 TO 1H -118 -1H -118-1H-118 12.053.82 976.23 12,053.82 797.99 7,150.00 5.477 Centre Distance Pass - Major Risk TD: 1H -118 -1H -118-1H-118 12.075.61 976.54 12,075.61 797.62 7,175.00 5.458 Clearance Factor Pass - Major Risk Survey tool orouram From To (usft) (usft) 67.62 1,009.26 1,050.36 1,678.04 1,777.33 7,841.00 7,841.00 8,199.62 1H-102L2wp24 8,199.62 9,699.62 1H-102L2wp24 8,199.62 13,434.51 1H-102L2wp24 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. SurveylPlan Survey Tool GYD-GC-SS MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD-INC—ONLY MWD MWD+IFR-AK-CAZ-SC 15 September, 2017 - 14:58 Page 3 of 5 COMPASS Ladder View 1 H- 1 0 2 L 2w 2 4 The Reference Well is along the X-axis. p rror Ellipses are the Sum of the Reference and Offset Well Errors a 130 0 M `m a m d 0 U 6 65-- 0- 08000 8000 8800 9600 10400 11200 12000 12800 Displayed interval could be less than entire well:Measured Dept14841.00 To 13434.55 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 67.62 1009.26 1H-102 Srvy 1 - SLB_GWD70 (1H43M-GC-SS 3862.85141.01 7-5/8" x 9-7/8" 1050.36 1678.04 1H-102 Srvy 2 - SLB _MWD+GMA(MWE IffIq-AK-CAZ-SC 3959123-434.55 4-1/2" x 6-3/4" 1777.33 7841.00 1 H-102 Srvy 3 - SLB_MWD+GMAG4[NB+1IM-AK-CAZ-SC 7841.00 8199.62 1H-102L2wp24 (1H-1021-2) MWD -INC _ONLY 8199.62 9699.62 1H-102L2wp24 (11-1-10212) MWD 8199.6213434.51 1H-102L2wp24 (11-1-1021-2) MWD+IFR-AK-CAZ-SC 7 60 c 0 `m m N m N 30 r U 0 m c d U - E9uivalenl Magnetic Mstanm 8000 8800 9600 10400 11200 12000 12800 13600 Partial Measured Depth 1 H-102L2wp24 TC View SURVEY PROGRAM SEC I ION DE [AILS From To Tool MD Inc AZI TVD Dleg TFace Target Annotation 67.62 1009.26 GVD-GC-SS 7841.00 74.55 2.07 3862.64 0.00 0.00 KOP: 15.9°/100' DLS, .20° TF, for 12.42' 1050.36 1678.04 MWD+IFR-AK-CAZ-SC 7853.42 76.40 1.38 3865.76 15.90 -20.00 Hold for 20' 1777.33 7841.00 MWD.IFR-AK-CAZ-SC 7873.42 76.40 1.38 3870.46 0.00 0.00 Start 6°/100' DLS, -5.35° TF, for 302.88' 7841.00 8199.62 MWD-INC_ONLY 8176.30 94.50 359.71 3894.38 6.00 -5.35 1H -1021201.T1091517 RP Hold for 150' 8199.62 9699.62 MWD 8326.30 94.50 359.71 3882.61 0.00 0.00 Start 3°/100' DLS, -170.46° TF, for 157.08' 8199.62 13434.51 MWD+IFR-AK-CAZ-SC 8483.38 89.85 358.93 3876.65 3.00 -170.46 Hold for 415.41' 8898.79 89.85 358.93 3877.72 0.00 0.00 Start 1.5°/100' DLS, 126.77' TF, for 72.66' 8971.45 89.20 359.80 3878.32 1.50 126.77 1H -102L2 02.72 091517 RP Adjust TF to 128.69°, for 49.44' 9020.89 88.74 0.38 3879.21 1.50 128.69 Hold for 264.51' 9285.40 88.74 0.38 3885.04 0.00 0.00 Start 1.5°/100' DLS, 42.75° TF, for 51.16' 9336.57 89.30 0.90 3885.92 1.50 42.75 1 H-10212 03.T3 091517 RP Adjust TF to 48.02°, for 66.83' 9403.40 89.97 1.65 3886.35 1.50 48.02 Hold for 311.08' 9714.48 89.97 1.65 3886.51 0.00 0.00 Start 3°/100' DLS, -90.01 ° TF, for 221.5' 9935.98 89.97 355.00 3886.62 3.00 -90.01 1H-1021-2 04.74 091517 RP Adjust TF to .89.99', for 286.4' 10222.38 89.97 346.41 3886.77 3.00 -89.99 Hold for 188.01' 10410.39 89.97 346.41 3886.86 0.00 0.00 Start 3.5°/100' DES, 92.15° TF, for 131.29' 10541.68 89.80 351.00 3887.12 3.50 92.15 1H-1021-2 05.T5 091517 csd Adjust TF to 117.03', for 132.16 10673.84 87.70 355.13 3890.01 3.50 117.03 Hold for 79.76' 10753.59 87.70 355.13 3893.21 0.00 0.00 Start 3.5°/100' DES, 112.73° TF, for 88.98' 10842.57 10964.68 11017.73 11141.97 86.50 83.57 83.57 86.00 358.00 1.12 1.12 0.60 3897.72 3908.29 3914.23 3925.52 3.50 3.50 0.00 2.00 112.73 133.39 0.00 -12.15 1 H-10212 06.76 091517 RP 1H-1021207.77091517 RP Adjust TF to 133.39°, for 122.11' Hold for 53.04' Start 2°/100' DLS, -12.15° TF, for 124.24' Adjust TF to .5.16', for 163.91' CASING DEIAILS TVD MD Name 3862.65 7841.01 7-5/8" x 9-7/8" 11305.88 89.27 0.31 3932.29 2.00 -5.16 Hold for 155.41' 3959.22 13434.55 4-1/2" x 6.3/4" 11461.28 89.27 0.31 3934.28 0.00 0.00 Start 2°/100' DIES, 5.04° TF, for 36.89' 11498.18 90.00 0.37 3934.52 2.00 5.04 1 H-10212 08.T8 091517 RP Adjust TF to 0.18°, for 111.2' 11609.38 92.22 0.38 3932.36 2.00 0.18 Hold for 439.98' 12049.35 92.22 0.38 3915.29 0.00 0.00 Stan 1.5°/100' DLS, 179.75° TF, for 48.27' 12097.62 91.50 0.38 3913.72 1.50 179.75 1H -102L2 09.T9 091517 RP Adjust TF to .179.72', for 59.29' 12156.91 90.61 0.38 3912.63 1.50 -179.72 Hold for 422.28' 12579.19 90.61 0.38 3908.13 0.00 0.00 Stan 2'/100' DLS, 179.88° TF, for 100.53' 12679.72 88.60 0.38 3908.82 2.00 179.88 1H -1021210.T10091517 RP Adjust TF to .179.86', for 88.07' 12767.79 86.84 0.38 3912.32 2.00 -179.86 Hold for 149.54' 12917.32 86.84 0.38 3920.57 0.00 0.00 Start 1'/100' DLS, 179.95° TF, for 73.87' 12991.19 86.10 0.38 3925.12 1.00 179.95 1H-1021-2 11.711 091511 RP Adjust TF to 180', for 54.46 13045.65 85.56 0.38 3929.08 1.00 180.00 Hold for 388.9' 13434.55 85.56 0.38 3959.22 0.00 0.00 1H-10212 12.TD 091517 RP TD: 13434.55' MD, 3959.22' TVD 0 330 30 150 0 7841 120 7841 - 8020 8020 - 8200 300 90 60 8200- 8380 8380 8560 8560 -8740 Minor Risked 60 8740 - 8930 8930 9100 9100-9280 3 9280 9450 90 9450- 9630 270 ' 9630- 9800 9800 9980 9980- 10150 10150 - 10330 H-10211 �' 10330 - 10500 10500- 10870 10870- 11230 240 �I„ 1 20 11230 11600 1H-102___ 11600 - 11970 11970- 12340 12340 12700 12700 13070 150 13070- 13435 210 150 180 Easting (2500 usft/in) H 1H-125wp20 1H-124wp20 1H-123wp20 IH-122wp20 1 H-121 1 / H-1- H-120wp21 1H-101Liwp28 1H-101wp28.1 1H-101L2wp28 1H-101L3wp28 1H-14 1H-1 L2wp2 1H-101L4wp28 - - 1H-7 -102L1 1 103L3w 1 - 1H-,005 _ - 1H-103 wp21 --_-_ -- 1H-1 3Liwp21 1H-103wp23 0 1H-103L2wp21 1H- p22 1H-115wp21 1 6wp21 -1 9wp21 H-12 1H-113wp21 Kuparuk 1H Pad 1 .1 1wp22 / 1H-104wp21 1 4 H-21 - 1H-710wp23 1H-104Liwp22 1H 1H-13 -- 1H-104L2wp22 1 1H-104L3wp22 1H-104L4wp22 1 H-106 !1H-107 2 1H 11 1 H-09 Easting (2500 usft/in) 1 H-102L2w 23 Surface Location CPA6 Coordinate Converter From: - - - -i To: — - - - Datum: NAD83 Region: alaska Datum: NAD27 .� Region: jalaska 1 r' Latitude/Longitude (Decimal Degrees • r Lalitude/Longitude IDecimal Degrees I ' UTM Zone: F South r UTM Zone: True f- South State Plane Zone: q • Units: us-ft • r7 State Plane Zone: q • Units: - Legal Description (NAD27 only) r' Legal Description (NAD27 only) Starting Coordinates: ----- - - - - - EndingCoordinates: -- - -- - - ---- X: i 1669609.08 --- x' f 549577.455558541 5980414.37 I Y: j 59M662.56352101 Ttansfdrm € Quit Help 1H-102L2w 23 Surface Location C3 CPA( Coordinate Converter o QR g. From: - To: -- Datum: NApg3 Region: alaska Datum: NAD27 Region: jalaska • r Latitude/Longitude IDecimalDegrees, I C` Latitude/Longitude IDecimalDegrees w C UTM Zorre I-- r South r True r South C UTM Zone: ( — G State Plane Zone: q Units: us-ft C' State Plane Zone: q Units: us-ft r Legal Description (NAD27 only) C Legal Description (NAD27 only) Starting Coordinates: ----- --- - X: 11689609.08 Legal Description -- Township: 012 I"J Range: oto I` J Y: 5980414.37 iMeridian: U Section: 33 L 40.519229 FEL FN. 764.65061 Transform Qua Help 1H-1 : Drilling Hazards Su'. mare 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 j 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 Strat Running Sands and Gravels Low Maintain planned mud parameters, increase mud weight, use weighted sweeps. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight. Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, LCM. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out. - 6 -3/4" Open Hole / 4-1/2" Liner Intervals Hazard Risk Level Mitigation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud 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 Reoloizical certainty 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 Drilling Hazards Summary.doc 6/20/2017 9:22:47 AM Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, September 20, 2017 2:39 PM To: Kelsey.Hallford@conocophillips.com Cc: Loepp, Victoria T (DOA) (victoria.loepp@alaska.gov) Subject: KRU 1 H-1021-2 (PTD 217-101): Permit to Drill Application (REVISED) Good afternoon Kelsey, Please resubmit the following schematic diagrams for the application: • 1H-102 Producer Schematic • Drill Site 1H • Northing and Easting Map • 1H-102L2wp24 Plan View • 1H-102L2wp24 Section View • 1H-102L2wp24 Plan Summary These documents were enlarged, spanning two pages, with information cut off at the margins. These schematics may be submitted via email to me. 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.bettis(a@alaska.gov. TRANSMITTAL LETTER CHECKLIST WELL NAME: XAL" / h _ /p (, Z fy 1 l 1 PTD: I7 'development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: " ajJdJ POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK=60-69) TEXT FOR APPROVAL LETTER The permit is for a new wellbore segment of existing well Permit No. Z� API No. 50-�- (�- Qom, gits Production should continue to be reported as a function of the original are API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- _) from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Cg=anv 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 cau ht and 10' sample intervals through !Eget 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 (Comnanv Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing proEam. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be nm: In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 da s after completion, sus ension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 PTD#:2171010 Company CONOCOPHILLIPS ALASKA,. IS._ _ __ ___ Initial Class/Type Well Name: KUPARUK RIV UNIT 1H -102L2 Program DEV Well bore seg 66 DEV / 1 -OIL GeoArea 890. _ — Unit 11_1_6.0 On/Off Shore On — Annular Disposal ❑ Administration 17 Nonconven, gas conforms to AS31.05.0300A.A),0.2.A-D) NA 1 Permit. fee attached - NA 2 Lease number appropriate. Yes ADL0025639, Surf Loc & Top Prod Interv; ADL0025636,. TD. 3 Unique well name and number _ _ Yes KRU 1H-1021.2 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 406C contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells Yes CO 406C has no interwell spacing. restrictions. 7 Sufficient acreage available in drilling unit Yes _ 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes Wellbore will be more than 500' from an external property line where ownership or landownership changes. 10 Operator has appropriate. bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative. approval Yes PKB 9/20/2017 13 Can permit be approved before 15 -day wait Yes _ 14 Well located within area and. strata authorized by Injection Order# (put 10# in comments) (For NA 15 All wells. within 1/4 mile area of review identified (For service well only) NA. 16 Pre -produced injector: duration of pre production less than 3 months (For service well only) NA 18 Conductor string provided _ _ _ NA Conductor set in KRU 1 H-102 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in KRU 1H-102 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing will be set and fully cemented in KRU. 1 H-102 21 CMT vol adequate to tie-in long string to surf csg. NA 22 CMT will cover all known_ productive horizons No Productive interval will be completed with. slotted liner 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all waste to approved disposal wells 25 If. a. re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation. proposed Yes Anti -collision analysis complete; 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 1746 psig(8.4 ppg EMW); will drill w/ 8.8-9.5 ppg EMW VTL 9/25/2017 29 BOPEs,_do they meet regulation Yes _ 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 1348 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 H28 measures required 34 Mechanical. condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen. sulfide measures No Wells on 1 H -Pad are H2S-bearing. 1-12S measures required. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is 8.53 ppg EMW; will be drilled using 8.8 to 9.5 ppg mud. Appr Date 37 Seismic analysis of shallow gas zones NA PKB 9/20/2017 38 Seabed condition survey (if off -shore) NA 39 Contact namelphone for weekly progress reports [exploratory only] NA Onshore development well to. be drilled.. Geologic Engineering Public Revision: Footage increased to TD 13,435' MD. VTL 9/25/17 Commissioner: Date: Commissioner Date Co iss er Date - 9 �z�1� THE STATE °fALASKA GOVERNOR BILL WALKER G. Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU IH -102L2 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-101 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Surface Location: 40.52' FNL, 764.65' FEL, SEC. 33, T12N, R10E, UM Bottomhole Location: 549.8' FNL, 1780.8' FEL, SEC. 27, 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, Hollis S. French l Chair DATED this day of July, 2017. STATE OF ALASKA RECEIVED AL 4A OIL AND GAS CONSERVATION COME ,. ON MN 2 9 7017 PERMIT TO DRILL 1 a. Type of Work: b. Proposed Well Class: Exploratory - Gas LJ Service- WAG LJ Service - Disp L 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test ❑ Development - Oil ❑� Service- Winj ❑ Single Zone ❑' Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ ReentryEll Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: Existing, cement to surface 13.5" 10.75" 5. Bond: Blanket Y I Single Well 1 11. Well Name and Number: ConocoPhillios 1700 914 sx 11.0 Lead, 145 sx 12.0 Tail Bond No. 50_59_1 Rn AU KRU 1H-1021-2 P.O. Box 100360 Anchorage, AK 99510-0360 ace: 40.52' FNL, 764.65' FEL, Sec 33, T 12N, R010E, UM of Productive Horizon: 163.34' FNL, 1675.95' FEL, Sec 34, T 12N, R010E, UM I Depth: 549.8' FNL, 1780.8' FEL, Sec 27, T 12N, R010E, UM ncatinn of Well !State Rase Plane Coordinates - NAD 271 MD: 12522 ' TVD: >uk River Field Salk Oil Pool SHL - 4515'; BHL - 584' Surface: x-549577.46 y- 5980662.56 Zone- 4 GL / BF Elevation above MSL (ft): 54 Ito Same Pool: 1015 16. Deviated wells: Kickoff depth: 7677 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 93.15 degrees Downhole: 1714 psi Surface: 1327 psi 18. Casing Program: Specifications Top - Setting Depth - Bottom 20. Attachments: Property Plat ❑ er Sketch DivrteSketch Cement Quantity, c.f. or sacks Hole Casing Weight Grade 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 7677 Surface Surface 7677 3871 644 sx 15.8 Class G 6.75" 4.5" 11.6# L-80 IBTM 4995 7527 3740 12522 3905 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 r_1 No ❑� 20. Attachments: Property Plat ❑ er Sketch DivrteSketch BDl e ing Program Time v. Depth rlot Seabed Report Drilling Fluid Program e Shallow Hazard Analysi's 20 AAC 25.050 ementse requ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be Kelsey Hallford deviated from without prior written approval. Contact Name:1 Authorized Name: G. Alvord Contact Email: kelsey.hall @cono phillips.com Authorized Title: Alaska Drilling Contact Phone: 1-907-265-1577 %Manager Authorized Signature: Date: 20 -Jun -17 Commission Use Only Permit to Drill API Number: J2619'n Permit Approval See cover letter for other Number: a —'d 50- O O ' — Q v Date: y _ -7 - l —'( requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methan gas hydrates, or gas contained in shales: Other: y=O p 3� O 5 % Sam1plllees� req'd: Yes No; Mud log req'd: Yes No u 4/ %O �c/r� L 1,. Z�__FJS asures: Yes No❑. Directional svy req'd: Yes No❑ r�N n t/lR ✓ Q9 VC a�f vy '7"Cr' J "i' ST 7 ` SpacinLg e�xE/e✓pt,_,2nUq'd: Yes ❑ No,L1J( Inclination -only svy req'd: Yes ❑ N, W Post initial injection MIT req'd: Yes El No CJ APPROVED BY 4 1 —1l I 4pproved by: COMMISSIONER THE COMMISSION Date: TL Submit Form and �,V1or 110401.3 y�sed 5/� lrll!♦r i{ ypli�l fq1' 2r months from the date of approval per 20 AAC 25.005(g) Attachments in Duplicate Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone(907)265-1577 Email: kelsev.hallford(c)conocophillips.com June 28, 2017 Alaska Oil and Gas Conservation Commission 333 West 71 Avenue, Suite 100 Anchorage, Alaska 99501 E-CEIVED JUN 2 9 2017 AOGCC Re: Application for Permit to Drill, West Sak Producer, 1H -102L2 Dear Commissioner: Application for Permit to Drill, Well 1H -102L2 Saved: 28 -Jun -17 low, i Conoco Phiilips 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 third 6-3/4" production lateral, 1H -102L2, will be milled out of the 1H-102 intermediate casing and be geo-steered in the West Sak A4 sand, lined with 4-1/2" slotted liner. The subsequent production laterals will again be drilled with 6-3/4" hole and lined with 4-1/2" slotted liner in the following order: West Sak B and D sand. A separate PTD application will be submitted for each lateral: 1 H-102, 1 H - 102L1, 1H-IO2L2, 1H-IO2L3, and 1H-IO2L4laterals. 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. Sincerely, Kelsey Hallfo d Drilling Engi er Application for Permit to Drill Document Kuparuk Well 1H -102L2 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 1H -102L2 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for it Permit to Drill unat be accompanied by each of the Jol/raring items, except far an hear already mi tle with the commission told identified in the application: (2) a plat identifying dee property and the properh's owners and showing (A)the coordinates of the proposed location of the well at the surface. at the top of each objectire formation. and at total depth, referenced to governmental section lines. (D) the coordinates of Ute proposed location of Nie well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic San ev in the National Oceanic and Annosphei is Administration: (C) the proposed depth of the well at the top oJ'each obfecnve formation and at total depth: Location at Surface 40.52' FNL, 764.65' FEL, Sec 33, T 12N, ROlOE, UM NGS Coordinates Northings: 5980662.56' Eastings: 549577.46' RKB Elevation 93' AMSL Pad Elevation 54' AMSL Location at Surface Casing 349.45 FNL, 466.77 FEL, Sec 33, T12N, ROME, UM NGS Coordinates Northings: 5980355.65' Eastings: 549878.04' Measured De th, RKB: 1794' Total Vertical De th, RKB: 1700' Total Vertical De th, SS: 1 1607' Location at Intermediate Casing 4743.15' FNL, 1667.16' FEL, Sec 27, T12N, ROME, UM NGS Coordinates Northings: 5981270.1' Eastings: 553949.3' Measured De th, RKB: 8325' Total Vertical Depth,RKB. 4004' Total Vertical Depth, SS.' 1 3911' Location at Total Depth 549.8' FNL, 1780.8' FEL, Sec 27, T12N, ROIOE, UM NGS Coordinates Northings: 5985461' Eastings: 553798.7' Measured De th, RKB: 12522' Total Vertical De th, RKB: 3905' Total Vertical Depth, SS 1 3812' and (D) other ipfon iatmr required by 20 AAC 25.050(1): Reauirements of 20 AAC 25.050(bl If a well is to be intentionally deviated, the applicatton(or a Permit to Drill (Form 10-401) must (1) include a plat, eh'uirn to a satiable scale, shmring the path of the proposed wellbore. including all adjacent wellbores itith(n 200 feel of any portion of the proposed cell: Please see Attachment: Directional Plan And QJfor all wellswithin 200feet of the proposedwellbore (A) list the names of1he operators mi -those wells, to the erten than those names ar'e Anmrn mdiscoverable in public records, and show that each natned operator has been furnished a copy of the application by ceritfled mail: at- (B) r(R) suite that the applicant is the only affected owner. The Applicant is the only affected owner. r Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill most be acconrymried by each of the, following items, except for an item already on file a iNr the commission and identified in the apphcoinin: (3) a dingrmn and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037. as applicable: Please reference BOP schematics on file for Doyon 142. 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 fma Permit to Drill most be accompanied by each of the,following items. ercep for an item already or file ii nh the commission and identified in the application: (4) information on drilling /acarus. including (4) the maxinttmn downhole pressure that mov be encountered. criteria used to determine it, and marionon potential sinyace pressure based on a methane gradient: The maximum potential surface pressure (MPSP) while drilling 1 H-1 02L2 is calculated using an estimated maximum reservoir pressure of 1714 psi (based on 1 H -05A pressure at a 4005.2' TVD reference datum), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Sak A4 sand window at 3871' TVD: A4 Sand Estimated. BHP = 1,714 psi A4 Sand estimated depth = 3,871' TVD Gas Gradient = 0.10 psi/ft Hydrostatic of full gas column = 387 psi MPSP = BHP — gas column = 1,327 psi (B) data on potential gas cones: as per 20 AAC 25.005 (e)(4)(A) (3,871' TVD * 0.10 psi/ft) (1,714 psi — 387 psi) The wellbore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes ojhole in such as abnormally geo-pressured strata, lost circulation -ones, and cones that ha, e a propensity for differential snicking; See attached 1H -102L2 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An applimtomfor' a Permit to Drill must be accompanied by each of the follmving items, erceptjor an item already on file with the commission and identivied in the application: (5) a description of the procedure jor conducting formation integrity tests, as required under 20 AAC 25.030x): A procedure is on file with the commission for performing FIT/LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items. except jor an item already on file with the commission and idennifled in the application: (6) a complete proposed curing and cementing progran ns required by 20 AAC 25.030, and a descrip/ion ofany slotted linerIn e-peryorated liner. or screen to be installed Casing and Cement Program Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 42" 20" 94# H40 Welded 80 Surface I 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 r7677 Surface Surface 7677 3871 644 sx 15.8 Cass G 6.75" 4.5" 11.6# L-80 IBTM 4995 7527 3740 12522 3905 WA: Un-cernenled slotted liner r Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Penia to Drill must be accompanied by each of the following items, except for an item alread)on file it id, the commission and identifted in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25035, unless this requirement is waived by the Commission under 20 AAC 25.035(h)(2), Please reference attachment for diverter schematic. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill unea be accompanied by each of the following items, except for an ilem ahead) on file with the commission and identified in the application: (8) a drilling fluid program, indudmg a diagram and description of the drifting 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 FlowPro 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 applicitoon fin it permit to Drdi muss he acc'oinpmiied b}each of the follou ing items. ercep(for an item airead) on file it th 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 1 H-102 and 1H -102L 1 Application for Permit to Drill. I. With 6-3/4" bit, motor, GR/Res, and magnets, and drill —200' of new hole in the A4 sand. POOH. 2. Pick up 6-3/4" RSS lateral drilling assembly with GR, Res, periscope and RIH. 3. Drill lateral to A4 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 window just below the top of the B 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 -102L2 PTD & begin 1H -102L3 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 nmsic be accompanied bJ' each cJ the fallowing items. exceptfor an dear in, ead} on file tirith the commission laid identified in the applicalion: (1 J) a geneivl descophon o/ hon die operator plans to dispose of di illing anal and catlings and it swiennoa afwhether the opern of intends to request authorL-ation udder 20 AAC 25. 080jor an annular disposal operation in the yell.: Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well at the IB Facility. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 BOP Ram Placement Attachment 2 Well Schematic Attachment 3 Diverter Layout Diaeram Attachment 4 Directional Plan Attachment 5 Drilline Hazards Summary Attachment 6 Cement Summaries Fixed BOP configuration for West Sak Operations Vass 2 SOP Optioni#1 Um :r_� 7{I(NIF1I nc n Oo 81 InsulatedC9MB Casing, 20", 94tl, K55 0312" WT a_ -A99 MD 10-3/4',455x, 1.80, H3d563 Wellhead /Tubing Head /Tree, 13-3/8"x4-'h',i,000 lot 1H-102 Producer DRAFT Tole, Suing4-12", 12.6 0, L -W TXP Gas Lift Mandrel, 4 - In" s I" w/ dummy valve Gas Lift Mandrel, 4-12"sl"s/SOV 4-X" SSD with 3112- DB Nipple profile Schematic 1794' MD 11700'TVD Permanent Dmn Hole Gauge Tubing Seal Aseemblv a ZXP Prckv L4 "D"Sand Willow C ]204' MD 13753' TVD Landing nipple gofile 75 iN inc 6-3/4"Dsand lmeml m S 14425'MD/380V WD� .. .• 4-12__1166 IBTM LN, Slotted Liner N _____ _ ............................. --------- ...............--_..---- gan __ __ en0 L3`B"Sand Windoo 1_, 74R'MD/3820'TVD Swell Padcrs� 63/4'8sand lateral_ ' B 75.5P inc••• 14444' MD/ 3859' TVD n i 4Stked aeBaker Hook Hanger ••.• 4-12" Sloll<d Liner IL661BTM L80 Level3.lunefian SYstems.... __------------------------------------------------------------------------ ........____._._...._• L2-A4-Sm,d W ndme 4Q767T MD / 3871' TVD 631" A4 sand lateral ZXP Porker •••, 759°Inc •.• __ _••� II2 SIonW Linea II W181T- L80 12522'MD/3905'TVD- • --------------------------------------------------------- LI 'AY Sand Wmdow r, 7834' MD/3910'WD, • 7557-i. '•, 6-3/4" A3 sarxi lateral Lateral Eng, Module •. 4-12"Slated Litrcq 11.661BTM L80_'.•__________•••••••._•••_-____---- __ ________ 12526 _MD/ 3964' WD 5 Tubing SM Asa<mbb •• ......... ME ................................................................ Landiugnipplepmfle 6 3/4"A2 sand lmcral _ ZXP ker> 4-1/2"Sloned Lln<r. 1166 IBTM L80 par ______________•••••--- - Qi26_MD/4015't'VD _-___-_ 7-5/S". 297X, L-80, Hp063, CcB _ _______------------ _____________________--- 8325'MD14004'ND v ................... ..................................... .........................' .- ConocoPhillips TITLE: DS1H LAYOUT DRAWING Alaska, Inc. DRAWN BY: ALKET MICI DATE: Ds-m-zDn REN 1 F I ' m u DI 1 H-102L2wp23 6.968 UG -C I� .._L...._.__nn L6 3000 6000 9000 Depth Reference: Plan: 54+39 @ 93.00usfl(Doyon 142) 0 20"x42" Rig: DOYan 142 -$� coon dao ]SIfi" x 9-]R' 4-10x&314' Ad $ o Q ^m o�Ica 3. ry h nm 0 1500 3000 4500 61600 7500 Horizontal Departure i 2]0 I 10000 12000 249 Pad Elevation: 54.00 CASING DETAILS TVD MD Name 3870.94 ]6]6.91 7518" x 91 3904.71 12521.83 4-12"x6-314" SECTION DUALS Sea MD Inc At TVD +N1 -S +E' -W DI, TFace VSacl Target 1 ]6]6.90 ]5.5] 0.00 3870.94 -54.25 4369.05 0.00 0.00 -1H.252 ]689.]0 ]].Bt 0.00 3873.91 -41.60 401 15.90 0.00 41.80 3]]09.]0 77.61 0.00 3078.20 -22.28 438905 000 0.00 -22.26 4 0021.02 93.15 0.88 3903.22 207.08 4371.45 5.00 3.27 207.08 50319.4] 9].15 0.88 3888.04 585.05 4376.01 000 0.00 585.05 6 0380.85 90.12 038 3885.09 64619 4376.68 5.00 -170.60 648.39 IK102U11020917 RP 7 8880.73 90.12 0.38 3084.05 1146.26 4379.96 0.00 0.00 1146.26 IK102U 02.T2 020917 RP 0 8911.28 08.51 0.38 as 4.15 11 Mal 4380.18 2.00 100.00 1118.81 9 9592]4 89.51 0.38 3890.00 1858.23 4384.61 0.00 000 1858.23 1Kt02L203.T30109D RP 10 9600.91 09.54 0.22 3890.07 185840 4384.68 2.00 -]882 186640 11 991 09.54 0.22 3893.08 M41.36 4386.10 0.00 000 2241]6 1H -102U N74 020917 RP 12 10321.84 85.55 N2.J3 3904.98 2581.79 4333.88 5.24 -99.72 2501.79 13 10378.76 08.55 342.33 3908.39 2635.02 4316.fi6 0.00 0.00 2635.82 1410671.25 09.67 357.33 391808 292231 4265.24 5.24 78.55 2922.71 1H -102U 06.]6020917 RP 15 11005.]5 09.67 357.333920.43 3336.76 4245.96 0.00 0.00 3336.]6 16 1122503 92.00 0.80 391040 3475.97 4243.70 30056.13 3475.97 17 11331.96 92.00 0.90 3914.66 358282 4245.20 0.00 9.W 3582.82 8 11353.3] 92.00 (Laos 391191 3604.22 424542 2.00 49.78 360432 1H-1021 ORI 020317 RIP 19 11366.13 92.26 0.36 391344 3816.97 4245.50 200 0.03 3816.97 20 11746Al2 92.26 0.38 3098.43 3997.36 4248.00 0.00 0.00 3997.36 21 11859.]9 90.00 0.38 3886.20 4110.30 4248.74 2.00 -180.00 4110.30 iH-102L209.T9020017 RP 22 1189].]0 89.24 0.38 389x45 4148.21 4246.99 2.00 180.00 4148.21 23 12521.83 89.24 0.38 3904.71 47]2.2] 4253.09 0.00 0.00 4772.27 IK102U 10JD 020917 RP Plan Summary l 0T6]] SURVEY PROGRAM 177 _ 7870 epth From Depth To Survey/Plan Tool 39.00 700.00 1H-102wp23 (Plan: 111-102) GYD-GC-SS 700.00 1794.10 1H-102wp23 (Plan: 1H-102) MWD+IFR-AK-CAZSC 1794.10 ]6]6.90 1H-102wp23 (Plan: 1H-102) MWD+IFR-AK-CAZSC ]6]6.90 8026.90 111-1021.2wp23(Plan: 111-10212) MWDANC_ONLY 8026.90 9526.90 1H-1021-2wp23diren: 1H-10212) MWD 8026.90 12521.83 1H-102L2wp23 (Plan: lH-ID212) MWD+IFR-AK-CAZ-SC i 2]0 I 10000 12000 249 Pad Elevation: 54.00 CASING DETAILS TVD MD Name 3870.94 ]6]6.91 7518" x 91 3904.71 12521.83 4-12"x6-314" SECTION DUALS Sea MD Inc At TVD +N1 -S +E' -W DI, TFace VSacl Target 1 ]6]6.90 ]5.5] 0.00 3870.94 -54.25 4369.05 0.00 0.00 -1H.252 ]689.]0 ]].Bt 0.00 3873.91 -41.60 401 15.90 0.00 41.80 3]]09.]0 77.61 0.00 3078.20 -22.28 438905 000 0.00 -22.26 4 0021.02 93.15 0.88 3903.22 207.08 4371.45 5.00 3.27 207.08 50319.4] 9].15 0.88 3888.04 585.05 4376.01 000 0.00 585.05 6 0380.85 90.12 038 3885.09 64619 4376.68 5.00 -170.60 648.39 IK102U11020917 RP 7 8880.73 90.12 0.38 3084.05 1146.26 4379.96 0.00 0.00 1146.26 IK102U 02.T2 020917 RP 0 8911.28 08.51 0.38 as 4.15 11 Mal 4380.18 2.00 100.00 1118.81 9 9592]4 89.51 0.38 3890.00 1858.23 4384.61 0.00 000 1858.23 1Kt02L203.T30109D RP 10 9600.91 09.54 0.22 3890.07 185840 4384.68 2.00 -]882 186640 11 991 09.54 0.22 3893.08 M41.36 4386.10 0.00 000 2241]6 1H -102U N74 020917 RP 12 10321.84 85.55 N2.J3 3904.98 2581.79 4333.88 5.24 -99.72 2501.79 13 10378.76 08.55 342.33 3908.39 2635.02 4316.fi6 0.00 0.00 2635.82 1410671.25 09.67 357.33 391808 292231 4265.24 5.24 78.55 2922.71 1H -102U 06.]6020917 RP 15 11005.]5 09.67 357.333920.43 3336.76 4245.96 0.00 0.00 3336.]6 16 1122503 92.00 0.80 391040 3475.97 4243.70 30056.13 3475.97 17 11331.96 92.00 0.90 3914.66 358282 4245.20 0.00 9.W 3582.82 8 11353.3] 92.00 (Laos 391191 3604.22 424542 2.00 49.78 360432 1H-1021 ORI 020317 RIP 19 11366.13 92.26 0.36 391344 3816.97 4245.50 200 0.03 3816.97 20 11746Al2 92.26 0.38 3098.43 3997.36 4248.00 0.00 0.00 3997.36 21 11859.]9 90.00 0.38 3886.20 4110.30 4248.74 2.00 -180.00 4110.30 iH-102L209.T9020017 RP 22 1189].]0 89.24 0.38 389x45 4148.21 4246.99 2.00 180.00 4148.21 23 12521.83 89.24 0.38 3904.71 47]2.2] 4253.09 0.00 0.00 4772.27 IK102U 10JD 020917 RP Plan Summary l Hold for 499.88' Start 2°1100 MS. 180°TIF. for 30.56' Hold far 681.46 Start 2°11 W' DLG -781 TF for 8.1]' Hold for 374eT Start 5.24°1100 MS, -99.]2°TF, for 316.08' Hold! for 56.82' Stan 5.24Y1 OY DLS, 70.55° TF, for 29249' Held for 414.5' Start 3 -MOO' DIS. 56.13° TF, for 13938' Hold for 106.92' Start 21100'DLS, Hai T5 for 2141' Most TF to 0°, or 12.76' Hold for 380.69' Stan 2°1100 DLS. -180° V. for 112.97' Mlual TF 10-180°, for 37.91' Hold feiri 3' TO 12521.83' MD. 391 TVD K-15 3135.4 OG C 3382.6 uc B 488.6 US A 3610.] Na 311 7 selective _AS By signing this I adanow0etlge Mat I have been informed of all risks, checked that the data Is whi ensured it's wmpkteness, and all sunoundmg wells are assigned to the proper position and 1 approve the scan and and vaiddidle mavens, I iii ganknooded- that mae, notified oth imunaa ��A' te, 1100 fast leaned ads Prepared by Checked by Acceptetl by: j Approved by: Bnl Pofnis Huy Bui Anh Erik Stell t Hallford, Phelps 0T6]] 0 177 _ 7870 - vo 30 7870 si 8080 - U40 ,..0 8240 - Use 3430- W20 60 8620 - 8050 8wo - eand 9000 - 9150 9150 9300 9300 - 9450 90 94`4 - 9300 9600 - 9750 97W - 9900 9900 - lea5 10050 1020 k long - 10-49 120 10490 - 1070 10]80 - 110i 11070 - tt �YY,�`. �L�`ySaaO,n�i50 113W - 118 210 •_, 11650 1194 190 11940 1223 12230 - 1252 T Magneik Model: BGGM201i Magnetic MOCM Date: 1] MagDecYnation17.63. TO Convert a MagreMc Direction to aTme DirMion. Add 1].63°East 16204 PFROST Annotation KOP: 15.9.11M DLS, 0° T5 for 128 1700.8 Hold for 20' Shin 51100' DLS, 3.27° TF, for 311.32' T-3 Hold for 298.45' Start 5.11 OMS -1]06°TF, for 61 37' 2008.4 Hold for 499.88' Start 2°1100 MS. 180°TIF. for 30.56' Hold far 681.46 Start 2°11 W' DLG -781 TF for 8.1]' Hold for 374eT Start 5.24°1100 MS, -99.]2°TF, for 316.08' Hold! for 56.82' Stan 5.24Y1 OY DLS, 70.55° TF, for 29249' Held for 414.5' Start 3 -MOO' DIS. 56.13° TF, for 13938' Hold for 106.92' Start 21100'DLS, Hai T5 for 2141' Most TF to 0°, or 12.76' Hold for 380.69' Stan 2°1100 DLS. -180° V. for 112.97' Mlual TF 10-180°, for 37.91' Hold feiri 3' TO 12521.83' MD. 391 TVD K-15 3135.4 OG C 3382.6 uc B 488.6 US A 3610.] Na 311 7 selective _AS By signing this I adanow0etlge Mat I have been informed of all risks, checked that the data Is whi ensured it's wmpkteness, and all sunoundmg wells are assigned to the proper position and 1 approve the scan and and vaiddidle mavens, I iii ganknooded- that mae, notified oth imunaa ��A' te, 1100 fast leaned ads Prepared by Checked by Acceptetl by: j Approved by: Bnl Pofnis Huy Bui Anh Erik Stell t Hallford, Phelps @&bS MPA L Tkl*0/. LL 0 c®onto 'o mn p:. J A Ex., EYe vh sw 9w.3ui— III 8LNud G P.1, IH lCIt 2.p o,.lx. a �1 a. IHPIL +"�_®©t, t,06®:. fin$ axlozu.vn ®odd d0lhi�°! 0 �tBn1 d �, m, uswlmw i 0 ua I rc m i a 11 W. 9 a s us u f OW exmlWNA� I s M1n1x lOtpam�ex�'t.. i — d i PO l 111 I rc m i W. I 1 I 1 NPcnnN/1 12 1, wu�.mE x,ax ul, E ate' o lmol. 6 Hlt , ueMn � ,OSI1rpD 1+ Wx Im�31 m WOJ- FY0 6M3I Mm'kp}I$)5)5 �y l0 oavaam. pj]S ES$5 M1W.RP VLAa __q Ic.TIOfi nsc !A xlt2bODOM It83,6^PSE "4 C 9 5?7 xl[iIAN]Mn WZi]a/I }yi ]Y �= ® ,.:_nil m •] V a.x "' ,}wm x.,0213roTf6L•, �9 %>�x "' '^ p _ e :; : � ®_ Im d c & o q F tl R � ei rmrw I -Po d PO l 111 rmrw I -Po asWin) 1R-25 iR-24 1R-16 tqR-0p I BBL11-01 I1R-01BL1 -01 PB1 1R-27 1R -29L1 R -29L1-01 `1R-0 rr 1H-20 1H -125.p20 1H-124wp20 iH-123wp20 1H-122wp20 ^^ ` / 1H-121 IH -1 l iH-120wP2t 2L1 l 4Ll 11H-01 ld- 2 H-08 1H-02 1 7 Easting (2500 1C-156wpO66-5 5 %1 C-15gyxplgl I H-102L2wp23 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 4-1/2" x 6 -3T -,J12522 4500 - 1H-102L210.TD 020917 P 1H-102L2wp23 12000 1H -102L2 09.T9 020917 P 2 08.T8 020917 P H -1L2 07.T7 020917p 02 3000 - kJ -102L2 06.76 020917 P -13&2 05.T5 020917 P r 1 H-1 02L2 04.74 020917 P 0 z 500 1 H-1 02L2 03.T3 020917 P t 5 9000 0 w - 1 H -102L2 02.72 020917 P 1 - 2L2 01.71 020917 P o° 0 0- 20" x 42"------ 7-5/8" x 9-7/8"- r ry°oo 00 �o 10-3/4" x 13-1/2" o0 7000 7 O O O h -1500 0 0 -1500 0 1500 3000 4500 6000 West( -)/East(+) 1 H®102L2wp23 3720 Section View 0 650 T 1300 1950 2600 3250 3900 4550 Vertical Section at 0.00' 5200 M N 3780 7-5/8" x 9-7/8" 3 � N O WS_ A4_ Objective 3840 WS—A3 4-1/2" x 6-3/4" L I O n O O O O U O i I O m 3900 � O N F— O S 3960 /— 0 650 T 1300 1950 2600 3250 3900 4550 Vertical Section at 0.00' 5200 ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-102 (formerly 31) Plan: 11-1-1021-2 Plan: 1 H-102L2wp23 Standard Proposal Report 28 June, 2017 H Database: EDM Production Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kupamk 1 H Pad Well: Plan: 1 H-102 (formerly 31) Wellbore: Plan: 1H-10212 Design: 11-1-1021-2wp23 SLB Standard Proposal Report Local Co-ordinate Reference: Well Plan: 1 H-102 (formerly 31) TVD Reference: Plan: 54+39 Q 93.00usft (Doyon 142) MO Reference: Plan: 54+39 Q 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 Well Plan: 1 H-102 (formerly 31) Well Position +N/ -S 0.00 usft +E/ -W 0.00 usft Position Uncertainty 0.00 usft Wellbore Plan: 1H-1021-2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength l9 (°) (nT) BGGM2017 6/21/2017 17.63 80.95 57,498 Design i H-10212wp23 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,676.90 Vertical Section: Depth From (TVD) -NI-S +El -W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 0.00 6282017 9:51:38AM 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. -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: Kuparuk 1H Pad North Reference: True Well: Plan: 1H-102 (fonnerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-1021-2 Tum Design: 1H-102L2wp23 Azimuth Depth Plan Sections Measured Vertical TVD Dogleg Build Tum Depth Inclination Azimuth Depth system -NI-S +Fj-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°1100usft) (°1100usft) (°1100usft) (°) 7,676.90 75.57 0.00 3,870.94 3,777.94 -54.25 4,369.05 0.00 0.00 0.00 0.00 7,689.70 77.61 0.00 3,873.91 3,760.91 -41.80 4,369.05 15.90 15.90 0.00 0.00 7,709.70 77.61 0.00 3,878.20 3,785.20 -22.26 4,369.05 0.00 0.00 0.00 0.00 8,021.02 93.15 0.88 3,903.22 3,610.22 287.08 4,371.45 5.00 4.99 0.28 3.27 8,319.47 93.15 0.88 3,886.84 3,793.84 585.05 4,376.01 0.00 0.00 0.00 0.00 8,380.85 90.12 0.38 3,885.09 3,792og 646.39 4,376.68 5.00 4.93 -0.82 -170.60 6,880.73 90.12 0.38 3,884.05 3,791.05 1,146.26 4,379.96 0.00 0.00 0.00 0.00 8,911.28 89.51 0.38 3,884.15 3,791.15 1,176.81 4,380.16 2.00 -2.00 0.00 180.00 9,592.74 89.51 0.38 3,890.00 3,797.00 1,858.23 4,384.64 0.00 0.00 0.00 0.00 9,600.91 89.54 0.22 3,890.07 3,797.07 1,866.40 4,384.68 2.00 0.39 -1.96 -78.82 9,975.88 89.54 0.22 3,893.08 3,800.08 2,241.36 4,386.10 0.00 0.00 0.00 0.00 10,321.94 86.55 342.33 3,904.98 3,811.98 2,581.79 4,333.88 5.24 -0.86 -5.17 -99.72 10,378.76 86.55 342.33 3,908.39 3,815.39 2,635.82 4,316.66 0.00 0.00 0.00 0.00 10,671.25 89.67 357.33 3,918.08 3,825.08 2,922.71 4,265.24 5.24 1.07 5.13 78.55 11,085.75 89.67 357.33 3,920.43 3,827.43 3,336.76 4,245.96 0.00 0.00 0.00 0.00 11,225.03 92.00 0.80 3,918.40 3,825.40 3,475.97 4,243.70 3.00 1.67 2.49 56.13 11,331.96 92.00 0.80 3,914.66 3,821.66 3,582.82 4,245.20 0.00 0.00 0.00 0.00 11,353.37 92.00 0.38 3,913.91 3,820.91 3,604.22 4,245.42 2.00 0.01 -2.00 -89.78 11,366.13 92.26 0.38 3,913.44 3,820.44 3,616.97 4,245.50 2.00 2.00 0.00 0.00 11,746.82 92.26 0.38 3,898.43 3,805.43 3,997.36 4,246.00 0.00 0.00 0.00 0.00 11,859.79 90.00 0.38 3,896.20 3,803.20 4,110.30 4,248.74 2.00 -2.00 0.00 -180.00 11,897.70 69.24 0.38 3,896.45 3,803.45 4,148.21 4,248.99 2.00 -2.00 0.00 180.00 12,521.83 89.24 0.38 3,904.71 3,811.71 4,77227 4,253.09 0.00 0.00 0.00 0.00 828/2017 9:51.38AM 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: ConowPhillips (Alaska) Inc. -Kupl TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 Q 93.00usft (Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Plan: 111-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 111-1021-2 DLS Vert Section Design: 1H-102L2wp23 (usft) usft Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W DLS Vert Section (usft) (•) 0 (usft) usft (usft) (usft) 3,777.94 7,676.90 75.57 0.00 3,870.94 3,777.94 -54.25 4,369.05 0.00 -54.25 KOP: 15.9°1100' DLS, 0° TF, for 12.8' 7,676.91 75.57 0.00 3,870.94 3,777.94 -54.24 4,369.05 0.01 -54.24 7518" x 9-7/8" 7,677.14 75.57 0.00 3,871.00 3,778.00 .54.01 4,369.05 0.00 -54.01 WS -A4 -Objective 7,689.70 77.61 0.00 3,873.91 3,780.91 -41.80 4,369.05 16.21 -41.80 Hold for 20' 7,700.00 77.61 0.00 3,876.12 3,783.12 -31.74 4,369.05 0.00 -31.74 7,709.70 77.61 0.00 3,678.20 3,785.20 -22.26 4,369.05 0.00 -22.26 Start 5°/100' DLS, 3.27° TF, for 311.32' 7,800.00 82.11 0.26 3,894.10 3,601.10 66.60 4,369.25 5.00 66.60 7,633.43 83.78 0.35 3,898.20 3,605.20 99.77 4,369.43 5.00 99.77 WS_A3 7,900.00 87.11 0.54 3,903.49 3,810.49 166.13 4,369.95 5.00 166.13 8,000.00 92.10 0.82 3,904.18 3,611.18 266.09 4,371.14 5.00 266.09 8,021.02 93.15 0.88 3,903.22 3,810.22 287.08 4,371.45 5.00 287.08 Hold for 298AS' 8,100.00 93.15 0.88 3,898.89 3,805.89 365.93 4,372.65 0.00 365.93 8,200.00 93.15 0.88 3,893.40 3,800.40 465.77 4,374.18 0.00 465.77 8,300.00 93.15 0.88 3,887.91 3,794.91 565.61 4,375.71 0.00 565.61 8,319.47 93.15 0.88 3,886.84 3,793.84 585.05 4,376.01 0.00 585.05 Start 5°1100' DLS, -170.6° TF, for 61.37' 8,380.85 90.12 0.38 3,885.09 3,792.09 646.39 4,376.68 5.00 646.39 Hold for 499.88' 8,400.00 90.12 0.38 3,885.05 3,792.05 665.54 4,376.81 0.00 665.54 8,500.00 90.12 0.38 3,884.84 3,791.84 765.54 4,377.46 0.00 765.54 8,600.00 90.12 0.38 3,884.63 3,791.63 865.54 4,378.12 0.00 865.54 8,700.00 90.12 0.38 3,884.43 3,791.43 965.53 4,378.78 0.00 965.53 8,800.00 90.12 0.38 3,884.22 3,791.22 1,065.53 4,379.43 0.00 1,065.53 8,680.73 90.12 0.38 3,884.05 3,791.05 1,146.26 4,379.96 0.00 1,146.26 Start 2.1100' DLS, 180° TF, for 30.66' 8,900.00 89.73 0.38 3,884.07 3,791.07 1,165.53 4,380.09 2.00 1,165.53 8,911.28 89.51 0.38 3,884.15 3,791.15 1,176.81 4,380.16 2.00 1,176.81 Hold for 681.46' 9,000.00 89.51 0.38 3,884.91 3,791.91 1,265.52 4,380.75 0.00 1,265.52 9,100.00 89.51 0.38 3,885.77 3,792.77 1,365.52 4,381.40 0.00 1,365.52 9,200.00 89.51 0.38 3,886.63 3,793.63 1,465.51 4,382.06 0.00 1,465.51 9,300.00 89.51 0.38 3,887.49 3,794.49 1,565.50 4,362.72 0.00 1,565.50 9,400.00 89.51 0.38 3,888.35 3,795.35 1,665.50 4,383.37 0.00 1,665.50 9,500.00 89.51 0.38 3,689.20 3,796.20 1,765.49 4,384.03 0.00 1,765.49 9,592.74 89.51 0.38 3,890.00 3,797.00 1,858.23 4,384.64 0.00 1,858.23 Start 2°1100' DLS, -78.82° TF, for 8.17' 9,600.00 89.54 0.23 3,890.06 3,797.06 1,865.49 4,384.68 2.00 1,865.49 9,600.91 89.54 0.22 3,690.07 3,797.07 1,866.40 4,364.68 2.00 1,866.40 828/2017 9:51.38AM Page 4 COMPASS 5000.1 Build 74 Database: EDM Production Local Coordinate Reference: Company: ConowPhillips (Alaska) Inc. -Kupi TVD Reference: Project: Kupamk River Unit MD Reference: Site: Kuparuk 1 Pad North Reference: Well: Plan: 1 H-102 (formerly 31) Survey Calculation Method: Wellbore: Plan: 1H -102L2 Azimuth Design: 1H-102L2wp23 -NI-S 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 Planned Survey Measured Vertical Depth inclination Azimuth Depth TVDss -NI-S +E/ -W DLS Vert Section (usft) (_) (I (usft) usft (usft) (usft) 3,797.86 9,700.00 89.54 0.22 3,890.86 3,797.86 1,965.48 4,385.06 0.00 1,965.48 9,800.00 89.54 0.22 3,891.67 3,798.67 2,065.48 4,385.43 0.00 2,065.48 9,900.00 89.54 0.22 3,892.47 3,799.47 2,165.48 4,385.81 0.00 2,165.48 9,975.88 89.54 0.22 3,893.08 3,800.08 2,241.36 4,386.10 0.00 2,241.36 Start 6.24'/100' OLS, -99.72° TF, for 346.06' 10,000.00 89.33 358.97 3,893.32 3,800.32 2,285.47 4,385.92 5.24 2,265.47 10,100.00 88.45 353.81 3,695.26 3,802.26 2,365.22 4,379.63 5.24 2,365.22 10,200.00 87.58 348.64 3,898.73 3,805.73 2,463.95 4,364.39 5.24 2,463.95 10,300.00 86.73 343.46 3,903.69 3,810.69 2,560.85 4,340.32 5.24 2,560.85 10,321.94 86.55 342.33 3,904.98 3,811.98 2,581.79 4,333.88 5.24 2,581.79 Hold for 56.82' 10,378.76 86.55 342.33 3,908.39 3,815.39 2,635.82 4,316.66 0.00 2,635.82 Start 5.24.1100' DLS, 78.55" TF, for 292.49' 10,400.00 86.77 343.42 3,909.63 3,816.63 2,656.09 4,310.42 5.24 2,656.09 10,500.00 87.83 348.55 3,914.34 3,821.34 2,752.97 4,286.24 5.24 2,752.97 10,600.00 68.90 353.68 3,917.20 3,624.20 2,851.70 4,270.81 5.24 2,851.70 10,671.25 89.67 357.33 3,918.08 3,825.08 2,922.71 4,265.24 5.24 2,922.71 Hold for 414.5' 10,700.00 89.67 357.33 3,918.24 3,825.24 2,951.43 4,263.90 0.00 2,951.43 10,800.00 89.67 357.33 3,918.81 3,825.61 3,051.32 4,259.25 0.00 3,051.32 10,900.00 89.67 357.33 3,919.38 3,826.38 3,151.21 4,254.60 0.00 3,151.21 11,000.00 69.67 357.33 3,919.95 3,826.95 3,251.10 4,249.95 0.00 3,251.10 11,085.75 89.67 357.33 3,920.43 3,827.43 3,336.76 4,245.96 0.00 3,336.76 Start 3.1100' DLS, 66.13° TF, for 139.28' 11,100.00 89.91 357.69 3,920.49 3,827.49 3,350.99 4,245.34 3.00 3,350.99 11,200.00 91.58 0.18 3,919.18 3,826.18 3,450.96 4,243.48 3.00 3,450.96 11,225.03 92.00 0.80 3,918.40 3,825.40 3,475.97 4,243.70 3.00 3,475.97 Hold for 106.92' 11,300.00 92.00 0.80 3,915.78 3,822.78 3,550.89 4,244.75 0.00 3,550.89 11,331.96 92.00 0.80 3,914.66 3,821.66 3,582.82 4,245.20 0.00 3,582.82 Start 2.1100' DLS, -89.78° TF, for 21AV 11,353.37 92.00 0.38 3,913.91 3,820.91 3,604.22 4,245.42 2.00 3,604.22 Adjust TF to 0°, for 12.76' 11,366.13 92.26 0.38 3,913.44 3,820.44 3,616.97 4,245.50 2.00 3,616.97 Hold for 380.69' 11,400.00 92.26 0.38 3,912.10 3,819.10 3,650.82 4,245.73 0.00 3,650.82 11,500.00 92.26 0.38 3,908.16 3,815.16 3,750.74 4,246.38 0.00 3,750.74 11,600.00 92.26 0.38 3,904.22 3,611.22 3,850.66 4,247.04 0.00 3,850.66 11,700.00 92.26 0.38 3,900.27 3,807.27 3,950.58 4,247.69 0.00 3,950.58 11,746.82 92.26 0.38 3,898.43 3,805.43 3,997.36 4,248.00 0.00 3,997.36 Start 2°/100' DLS, -180° TF, for 112.97' 11,800.00 91.20 0.38 3,896.82 3,803.82 4,050.51 4,248.35 2.00 4,050.51 11,859.79 90.00 0.38 3,896.20 3,803.20 4,110.30 4,248.74 2.00 4,110.30 Atljust TF to -180°, for 37.91' 6/28/2017 9:51:38AM Page 5 COMPASS 5000.1 Build 74 Database: EDM Production Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kupamk River Unit Site: Kupanik 1H Pad Well: Plan: 1H-102 (formerly 31) Wellbore: Plan: 1H -102L2 Design: 1H-102L2wp23 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 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +NIS +El -W DLS Vert Section (usft) (I (_) (usft) usft (usft) (usft) 3,803.46 11,897.70 69.24 0.38 3,896.45 3,803.45 4,148.21 4,248.99 2.00 4,148.21 Hold for 624.13' 11,900.00 89.24 0.38 3,896.48 3,803.48 4,150.50 4,249.01 0.00 4,150.50 12,000.00 89.24 0.38 3,897.80 3,804.80 4,250.49 4,249.66 0.00 4,250.49 12,100.00 89.24 0.38 3,899.13 3,806.13 4,350.48 4,250.32 0.00 4,350.48 12,200.00 89.24 0.38 3,900.45 3,807.45 4,450.47 4,250.98 0.00 4,450.47 12,300.00 89.24 0.38 3,901.77 3,808.77 4,550.46 4,251.63 0.00 4,550.46 12,400.00 89.24 0.38 3,903.10 3,810.10 4,650.45 4,252.29 0.00 4,650.45 12,500.00 89.24 0.38 3,904.42 3,811.42 4,750.44 4,252.95 0.00 4,750.44 12,521.83 89.24 0.38 3,904.71 3,811.71 4,772.27 4,253.09 0.00 4,772.27 TD: 12521.83' MD, 3904.71' TVD.4-112" x 6-314" 6/282017 9:51:36AM Page 6 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: IH -102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H -102L2 - plan misses target center by 151.76usft at 12521.83usft MD (3904.71 TVD, 4772.27 N, 4253.09 E) Design: 1H-102L2wp23 1H-1021208.TB 020917 RP 0.00 0.00 3,913.91 3,604.22 4,245.42 Targets 4,401.35 Target Name -hWmiss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W -shape (°) (°) (usft) (usft) (usft) 1H-1021-209,79020917 RP 0.00 0.00 3,896.20 4,110.30 4,248.74 - plan hits target center - Circle (radius 100.00) 4,384.64 11-1-1021210.TD 020917 RP 0.00 0.00 3,904.71 4,772.27 4,253.09 - plan hits target center - Circle (radius 100.00) 4,394.93 iH-102A407.T716Feb15 BW 0.00 0.00 3,906.00 4,789.28 4,403.89 - plan misses target center by 151.76usft at 12521.83usft MD (3904.71 TVD, 4772.27 N, 4253.09 E) -Circle (radius 100.00) 4,403.89 1H-1021208.TB 020917 RP 0.00 0.00 3,913.91 3,604.22 4,245.42 - plan hits target center - Circle (radius 100.00) 4,379.96 1 H-10212 04.74 020917 RP 0.00 0.00 3,893.08 2,241.36 4,386.10 - plan hits target center - Circle (radius 100.00) 4,243.95 iH-102A403.T316Febl 5 BW 0.00 0.00 3,918.00 3,003.15 4,392.16 - plan misses target center by 130,53usft at 10745.69usft MD (3918.50 TVD, 2997.07 N, 4261.77 E) - Circle (radius 100.00) 4,380.36 1H-102A406.T615Octl 5 BW 0.00 0.00 3,908.12 3,711.20 4,396.81 - plan misses target center by 150.69usft at 11461.49usft MD (3909.68 TVD, 3712.25 N, 4246.13 E) - Circle (radius 100.00) iH-102A404.T416Feb15 BW 0.00 0.00 3,918.00 3,425.18 4,394.93 - plan misses target center by 151.40usft at 11171.43usft MD (3919.85 TVD, 3422.39 N, 4243.57 E) - Circle (radius 100.00) 1H -102A4 06.76 16Febl5 BW 0.00 0.00 3,897.00 4,403.25 4,401.35 - plan misses target center by 150.71 usft at 12153.73usft MD (3899.84 TVD, 4404.20 N, 4250.67 E) -Circle (radius 100.00) 1H-102A407.T71SOW 5 BW 0.00 0.00 3,896.49 4,403.25 4,401.35 - plan misses target center by 150.72usft at 12153.72usft MD (3899.84 TVD, 4404.20 N, 4250.67 E) - Circle (radius 100.00) 1H-102A402.T216Febl 5 BW 0.00 0.00 3,894.00 2,695.12 4,390.14 - plan misses target center by 89.02usft at 10417.82usft MD (3910.61 TVD, 2673.18 N. 4305.48 E) -Circle (radius 100.00) 1H- 10212 0333 020917 RP 0.00 0.00 3,890.00 1,858.23 4,384.64 - plan hits target center - Circle (radius 100.00) iH-102A405.T515Oci15 BW 0.00 0.00 3,917.88 3,425.18 4,394.93 - plan misses target center by 151.40usft at 11171.43usft MD (3919.85 TVD, 3422.39 N, 4243.57 E) - Circle (radius 100.00) 1H-102A4083815Octl5 BW 0.00 0.00 3,906.27 4,789.28 4,403.89 - plan misses target center by 151.76usft at 12521.83usft MD (3904.71 TVD, 4772.27 N, 4253.09 E) - Circle (radius 100.00) 1H-1021202.72020917 RP 0.00 0.00 3,884.05 1,146.26 4,379.96 - plan hits target center - Circle (radius 100.00) 1H-102120TT7020917 RP 0.00 0.00 3,920.68 3,379.99 4,243.95 - plan misses target center by 0.49usft at 11129.02usft MD (3920.41 TVD, 3380.00 N, 4244.35 E) -Circle (radius 100.00) 1H-102A401,T116Febl 5 BW 0.00 0.00 3,686.00 1,207.01 4,380.36 628/2017 9:51 38A Page 7 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 1 H-102 (formerly 31) Company: ConocePhillips (Alaska) Inc. -Kupl TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Site: Kupamk 1 H Pad North Reference: True Well: Plan: 1 H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H -102L2 - Circle (radius 100.00) Design: 1H-102L2wp23 - plan misses target center by 1.67usft at 8941.50usft MD (3884.41 TVD, 1207.03 N. 4380.36 E) 1H-1021-20171020917RP 0.00 0.00 3,685.09 646.39 4,376.68 - plan hits target center - Circle (radius 100.00) Vertical Vertical 1H-102A401.T1150ctl 5 BW 0.00 0.00 3,879.12 578.96 4,376.24 - plan misses target center by 8.05usft at 8313.82usft MD (3887.15 TVD, 579.41 N, 4375.92 E) Depth Depth SS - Circle (radius 100.00) Dip Direction 1H-102A403.T3150ctl 5 BW 0.00 0.00 3,893.76 2,695.12 4,390.14 - plan misses target center by 89.07usft at 10417.81 usft MD (3910.61 TVD, 2673.17 N. 4305.48 E) Lithology (°) (°) -Circle (radius 100.00) 3,853.70 1 H-10212 06.76 020917 RP 0.00 0.00 3,918.08 2,922.71 4,265.24 - plan hits target center 3,610.70 - Circle (radius 100.00) 1H-102A402.T2150ctl 5 BW o.o0 0.00 3,886.08 1,207.01 4,380.36 - plan misses target center by 1.67usft at 8941.50usft MD (3884.41 TVD, 1207.03 N. 4380.36 E) - Circle (radius 100.00) 2,008.40 1H-102A4053516Feb15 BW 0.00 0.00 3,908.00 3,711.20 4,396.81 - plan misses target center by 150.69usft at 11461.49usft MD (3909.68 TVD, 3712.26 N, 4246.13 E) 3,135.40 - Circle (radius 100.00) 111-1021205.T5020917 RP 0.00 0.00 3,904.54 2,629.40 4,336.01 - plan misses target center by 16.78usft at 10366.56usft MD (3907.66 TVD, 2624.22 N, 4320.36 E) - Circle (radius 100.00) 3,799.10 1H-102A404.T4150ctl 5 BW 0.00 0.00 3,918.31 3,003.15 4,392.16 - plan misses target center by 130.53usft at 10745.70usft MD (3918.50 TVD, 2997.08 N, 4261.77 E) 3,486.80 - Circle (radius 100.00) 7,676.91 3,870.94 7-5/8" x 9-7/8" 7-5/8 9-7/8 12,521.83 3,904.71 4-1/2"x6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (°) (°) 7,607.72 3,853.70 WS A4 6,706.09 3,610.70 Na 7,200.81 3,752.30 WS_D 2,195.08 2,008.40 K-15 5,166.08 3,135.40 UG -C 7,468.87 3,819.10 WS -13 7,388.62 3,799.10 WS_C 6,319.91 3,486.80 UG_A 7,677.14 3,871.00 WS -A4 -Objective 5,975.61 3,382.60 UG_B 1,903.05 1,788.60 T-3 7,833.43 3,898.20 WS A3 1,697.35 1,620.40 PFROST 6128/2017 9:51:36AM 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: 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 (formedy 31) Survey Calculation Method: Minimum Curvature Wellborn: Plan: 1H-1021-2 4,369.05 KOP: 15.9"/100' DLS, 0° TF, for 12.8' Design: 1H-102L2wp23 -41.80 4,369.05 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NIS +•E/ -W (usft) (usft) (usft) (usft) Comment 7,676.90 3,870.94 -54.25 4,369.05 KOP: 15.9"/100' DLS, 0° TF, for 12.8' 7,689.70 3,873.91 -41.80 4,369.05 Hold for 20' 7,709.70 3,876.20 -22.26 4,369.05 Start 5"/100' DLS, 3.27° TF, for 311.32' 8,021.02 3,903.22 287.08 4,371.45 Hold for 298.45' 8,319.47 3,886.84 585.05 4,376.01 Start 5"/100' DLS, -170.6° TF, for 61.37' 8,380.85 3,885.09 646.39 4,376.68 Hold for 499.88' 8,880.73 3,884.05 1,146.26 4,379.96 Start 2°/100' DLS, 180° TF, for 30.56' 8,911.28 3,884.15 1,176.81 4,380.16 Hold for 681.46' 9,592.74 3,890.00 1,858.23 4,384.64 Start 2°/100' DLS, -78.82° TF, for 8.17' 9,600.91 3,890.07 1,866 40 4,384.68 Hold for 374.97' 9,975.88 3,893.08 2,241.36 4,386.10 Start 5.24°/100' DLS, -99.72° TF, for 346.06' 10,321.94 3,904.98 2,581.79 4,333.88 Hold for 56.82' 10,378.76 3,908.39 2,635.82 4,316.66 Start 5.24-/100' DLS, 78.55° TF, for 292.49' 10,671.25 3,918.08 2,922.71 4,265.24 Hold for 414.5' 11,085.75 3,920.43 3,336.76 4,245.96 Start 3°/100' DLS, 56.13° TF, for 139.28' 11,225.03 3,918.40 3,475.97 4,243.70 Hold for 106.92' 11,331.96 3,914.66 3,582.82 4,245.20 Start 21100'DLS,-89.78' TF, for 21.41' 11,353.37 3,913.91 3,604.22 4,245.42 Adjust TF to 0", for 12.76' 11,366.13 3,913.44 3,616.97 4,245.50 Hold for 380.69' 11,746.82 3,898.43 3,997.36 4,248.00 Start 2`/100' DLS, -180" TF, for 112.97' 11,859.79 3,896.20 4,110.30 4,248.74 Adjust TF to -180', for 37.91' 11,897.70 3,896.45 4,148.21 4,248.99 Hold for 624.13' 12,521.83 3,904.71 4,772.27 4,253.09 TD: 12521.83' MD, 3904.7l'TVD 6/28/2017 9:51:38AM Page 9 COMPASS 50001 Build 74 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1 H-102 (formerly 31 Plan: 1 H-1 02L2 50103xxxxx00 1H-102L2wp23 Clearance Summary Anticollision Report 28 June, 2017 Tmv, Cylinder North Proximity Scan on Current Survey Data North Reference) ZReference Design: Kuparuk IH Pad -PIan: 1H-1 o2)formerly3l)-PIam 1H-10212 1H-102L2wp23 Well Coartlinates: Datum Height Plan: 50+39@93.00usft (Doyon 162) Scan Range: 7,676.90 to 12,521.03 usk. Measured Depth. Scan Radius is 1,66038 raft. Clearance Factor c miff is Unlimited. Max Ellipse tiep icatmo is Unliarred Geodetic Scale FactorApplied Version: 5000.1 Build: 76 Scan Type: GLOBAL FILTER APPLIED. All wellpalhs within 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Plan: 1H-102 (formerly 31)-1H-102L2wp23 Rev. Cylinder North Proximity Scan on Current Survey Data (North Reference) assurance Design: Kuparuk 1H Pad- Plan: 1H402(formerly 31)-Plan: 114-10212-111-10211.2vry23 Scan Range: 7,676.90 to 12,521.83 use. Measured Depth. Scan Radius is 1,448.28 usn. Clearance Factor cursor Is Unlimited. Max Ellipse separation is Unlimited Measured Minimum @M... send Ellipse *Measured Clearance Summary Based on Sae Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (near loan) (sent (.-ft) use Kuparuk 1H Pad 1H-05-111-05-iH-05 10,532.14 1,407.13 10,532.14 1,202.04 6,950.00 6.861 Centre Distance Pass - Major Risk 1H-05-1H-05.1H-o5 10,539.14 1,407,21 10,539.14 1,201.97 6,97500 6.856 Clearance Factor Pass - Major Risk 1H-05-1H-105-iH-1 05 10,453.38 42326 10,453.38 313.11 7,35000 3.643 Centre Distance Pass - Major Risk 111-05-1H-105-1H-105 10,498.34 438.17 10,498.34 305.91 7,450.00 3.348 Clearance Factor Pass Major Risk Plan: 1H-102(formedy 3l)-Plan: 1H-102-1H-102ny2 -- Plan :1 H-102 (b.edy 3l) - PIan:1H-102L1-1 H.102L - PIan IH-102 (Mn tedy 3l) - Plan:111-10211- IM-102L - - Plan :1H-102acrinedy3l)-Plan : iH-10213-111-1021 7,699.18 23.91 7,699.18 20.06 7,70000 6,211 Centre Distance Pass - Major Risk Plan'. 1H-102(formerly 31)-Plan: 1H-10213-1H-102L -- Plan:lH-102(k.rIy3l)-PIan: IHa02L4-1H-102L 7,693.04 8778 7,693.04 77,51 7)00.00 8.550 Centre Distance Pass - Major Risk Plea: 111-102(tormeriy 3l)-Plan : 1 H-102L4-1H-102L 12,513.81 113.08 12(513.81 28.79 12,500.00 1.42 Clearance Factor Pass - Major Risk Plan: 1H-1 D3(tormeriy 197, 33)-Plan : 1&1031_1-111 12,122.61 1,197.32 12.122,61 1,002.98 13,75000 6.161 Clearance Factor Pass - Major Risk Plan: 1H-103(formerly 104, 33)-Plan. 1W103L3-111 12,00795 1,203.76 12,087.95 1,014.95 13,675.00 6,376 Clearance Factor Pass - Major Risk Plan: 1H-103(fonnery 104, 33)-Plan'. 111-1031.4-111 12,049.92 1,211.94 12,049.92 1,025.19 13,575.00 6.490 Clearance Factor Pass - Major Risk Plan:111-109(bmretly110,30C)-PIan:111-109-111-1 8,29291 1,002.02 8.292.91 876.98 6,45000 8,014 Centre Distance Pass - Major Risk Plan : 1 H-109(formary 110, 300)-Plan: 1 H-109-1H-1 8,46009 1,00393 8,460.09 87564 6,62500 7.825 Clearance Jamar Peas -Mejm Risk Plan : 1H-111(formerly 109, 32D)-Plan: IH-111-1H-1 806250 45552 8,082.60 358.02 6,400.00 4672 Centre Distance Pass - Major Risk Plan : 1H-111 dernuly 109, 32D)-Plan: 111-111-1H-1 8,064.12 453.22 8,064.12 357.05 6,425.00 4600 Clearance Factor Pass Major Risk PIan:1H-113(fomrd 112,348)-PIan:1H-113-1H-1 8,252.57 788.59 8,25257 69322 6,350.00 8269 Centre Distance Pass - Major Risk Plea. 111-113 (formerly 112, 34B)-Plan: 111-113-1H-1 8,254.70 709.09 0,254]0 69268 6375.00 8.185 Clearance Factor Pass - Major Risk Plot. IH-114(tormzdy 30B, 116)-PIan: 111414. 114-1 10,60000 916.98 tD,600.00 777.34 7,125.00 6,488 Centre Distance Pass - Major Risk Plan, 1 H-114(formerly308, 116)-Plan: 1H-114-1H-1 10,624.66 919.79 10,624.66 777.16 7,17500 6449 Clearance Factor Pass - Major Risk Plan, 1H-115(formerly 115, MA. 114)-Plan: 1H-115- 9,229.85 737.47 9,229.85 637.89 8500.00 7406 Centre Distance Pass - Major Risk PIan:111-115(fotmsriy 115,34A, 114)-Plao_11-1-115- 9,24599 73863 9,24599 63604 6,5%.00 7.200 Clearance Factor Pass - Major Risk PIan:111-116(formerly 114,328, 115)-Pbn'. 111-116- 9,314.58 49495 9,31450 390.62 6,575.00 4.744 Centre Distance Pass - Major Risk Plan: 11r-116(fomredy 114,32B, 115)-Plan: 1H-116- 9,32966 49784 9,329.66 388.51 6,625.00 4.553 Cusco. Factor Pass - Major Risk Plan: IH-118 (formerly 30A, 119)-Plan: 1H-118-111-1 12,190.02 1,006.81 12,190.02 830.09 7,550.00 5,597 Centre Distance Pass - Major Risk Plan: 1 HA 18(fomwdy 30A, 119)-Plan: 1H-118-1H-1 12,307.14 1,007.87 12,307.14 828.41 7,675.00 5,616 Clearance Factor Pass - Major Risk 28June,2017- 9:53 Page Por5 COMPASS ConceoPhillips (Alaska) Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1H-102 (formerly 31) - 1H-102L2wp23 Sureey Tool (.an) (dsel 3900 700.00 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) 700.00 1,794.10 MW 1FR-AK-CAZSC 1,794.10 7,676.90 MWD*IFRA-GAZ-SC 7,673.90 8,028.90 1H-102L2wp23 MWD -INC ONLY Reference Design: Kupamk 1H Pact -Plan:iH-102 (formedy 31) Plan: 1H-102L2-1H-1021.2wp23 8,02890 12,52183 IH-t02L2wp23 MWD+1FR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie -an points. Calculated ellipses incorporate surface errors. Son Range: 7,676.90 to 12,521.83 use. Measured Depth. Distance Behveen centres is the straight line distance beMmen wellborn centres. Clearance Factor= Distance Between Proles / (Distance Between Profiles - Ellipse Seomkon). All $When Dominates were ceicplated using the Minimum Curvature method. Use Radius is 1,448.28 kill Clearance Factor cousin 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 (usel (uso) (use) (use) can Plan :1H-120(Al035, fomredy 117) -Plan: 1H -120-1H 9.94062 809.40 9,94082 71060 6,675,00 8.192 Centre Distance Pass - Major Risk Plan :1H -120(A1035, formats 117) -Plan: 1H -120-1H 9,950.31 809.96 9,950.31 710.01 6,700.00 8.103 Clearance Factor Pass - Major Risk Plan IH -121(A 1W4, furmedy 119) -Plan: 1 H 21.1H 10,47745 729.31 10,477.45 6l 6,)]500 7,333 Centre Distance Pass - Major Risk Plan. 1 HA 21 (At OU. formerly 119) -Plan'. 1H-121-iH 10,49833 730.08 10,49833 620.31 6,825.00 7.174 Clearance Factor Pass - Major Risk PIan:1H-122(A1003, fsimrerty A194g)-Plan)tH-122 11,384.81 574.86 1130081 462.28 7,22500 5.107 Came Distance Pass - Major Risk Pin'.1H-l220%IO33,JomknIA1040)-Plan 1H-122 11,428.22 57885 11,420.22 458.95 7,300.00 4.028 Clearance Factor Pass - Major Risk Plan: 1H -123(A1032, Imierly A1033) -Plan: lH-123 12,256.05 38849 12,25805 271.34 7,725.00 3.315 Centre Distance Pass - Major Risk Pial 1H-123(A1D32, formerly A1033) -Plan: 1H-123 12,34091 39087 12,340.91 262.77 7,850.00 2,931 Clearance Factor Pass - Major Risk Plan: 1H -124(A1031, formerly A1036)-PIan: 1H-124 12,504.12 05173 12,504.12 694.00 7,275.00 5.138 Clearance Factor Pass - Major Risk Sumey fool 0mytern From To sureeyrPlan Sureey Tool (.an) (dsel 3900 700.00 GYD6GSS 700.00 1,794.10 MW 1FR-AK-CAZSC 1,794.10 7,676.90 MWD*IFRA-GAZ-SC 7,673.90 8,028.90 1H-102L2wp23 MWD -INC ONLY 8,02890 9,526.90 1H-102L2wp23 MWD 8,02890 12,52183 IH-t02L2wp23 MWD+1FR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie -an points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Behveen centres is the straight line distance beMmen wellborn centres. Clearance Factor= Distance Between Proles / (Distance Between Profiles - Ellipse Seomkon). All $When Dominates were ceicplated using the Minimum Curvature method. 28 June, 2017 - 9. 53 Page 3 of 5 COMPASS ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1 H-102 (formerly 31) Plan: 1 H-1021-2 50103xxxxx00 1H-102L2wp23 Clearance Summary Anticollision Report 28 June, 2017 True. Cylinder North Proximity Scan on Current Survey Data (North Reference) ZReference Design: Kuporm, l H Pad -Plan :1H-102)formerly 311 Plan: 1H402L2-1H-102L2wp23 Well Caoindimes: Datum Height: Plan: 50+39@ 93.00usf1Boyce 142) Scan Range: 7,676.90 to 12,521.83 usfl. Measured Depth, Scan Radius is 1,44838 unit[. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale FactorApplied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED: All wellpalhs within 200'+ 10011000 of reference Scan Type'. 25.00 ConocoPhillips (Alaska) Inc. -Kupl Kulpi River Unit Anticollision Report for Plan: 1 H-102 (formerly 31) -1 H-102L2wp23 iHA03(lipmedy 104,33) -Plan: 11-10314-1H 12,049.92 1,211.94 12,049.92 Tmv. Cylinder North Proximity Scan on Current Survey Data (North Reference) 13.57500 6,490 Clearance Factor Pass - Major Risk Plana Reference Design: Kuparuk 1H Pad -Plan: 1H-102 (formerly 31) -Plan: 11-10212 -IRA 022wp23 0,292.91 1,002.02 8,292.91 876.98 6.45000 Scan Range: 7,676.90 to 12,521.83 ust. Measured Depth. Centre Distance Pass -Major Risk Plan'. IH-109((ormedy1f0,30C)-Man:iH409-1H-1 8,460.09 Scan Radius is 1,448.28 usR. Clearance Factor Mott is Unlimited Max Ellipse Separation is Unlimited 8.46009 875.64 6,625.00 7825 Monitored Minimum @Measureall Ellipse @Measured Llcaronce Summary Rased on 455.52 She Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Mame - Wellbore Name -Design (.an) (usR) Wall) (dart use 357.05 6,425.00 Kuparuk 1H Pad Clearance Factor Pass -Major Risk Pian'. 1H-113(formerly 112, 34B) -Plan: 1H -113-1H-1 8,252.57 1H -05 -1H -05-1H-05 10,532.14 1,407.13 10,532.14 1,202.04 6.950.00 8.861 Co. Distance Pass - Major Rex 1H -05-111-05-1H-05 10,539.14 1,40]21 10.53914 1,201.97 6,975.00 6.856 Clearance Factor Pass - Major Risk 1H-05-111-105-iH-10 10,453.38 423.26 10,453.38 313.11 7,350.00 3,843 Centre Distance Pass -Major Risk iH-05-iH-105-1H-105 10,490.34 435.17 10,49834 305.91 7,450.00 3.348 Clearance Factor Pass - Major Risk Plan: 11-1-102 (formedy 31) - Plan: 111-102 -1 H-102"2 Major Risk Plan. 1H-114(fomaly 30B. 116) -Plan: 1H -114-1H-1 10,62466 - - Plan: IH-102(fonnedy 3l) -Plan: iH-10211-1H-102L 7,175.00 6449 Clearance Factor Pass - -- Plan: Plan :1H-102(formerly 31) -Plan: 11 -10213 -1H -102L 7,699.18 2391 7,699.18 22.44 7)00.00 16.282 Clearence Fadaf Pass - Minor 1150 Plan: 1H-102(formerly 31) -Plan: 1H -10214 -1H -102L 7,69304 87,78 7,69304 84.19 7,70000 24471 Clearance Factor Pass - Minor 1150 Plan: 1 H403(frinedy 104. 33) -Plan: 1H-103L1-iH 12,122.81 1,197.32 12.122.61 1,00298 13,750.00 6.161 Clearance Factor Pass - Major Risk Plan: 1 HA 03(fmmely 104, 33) -Plan: 1H-10L3-iH 12,087.95 1,203.76 12,087.95 1,01495 13,675.00 6.376 Clarence Factor Pass - Major Risk Plan: iHA03(lipmedy 104,33) -Plan: 11-10314-1H 12,049.92 1,211.94 12,049.92 1.02$.19 13.57500 6,490 Clearance Factor Pass - Major Risk Plana H-109(fonnedy 110, WC) - Plan: 1 H -109-1H-1 0,292.91 1,002.02 8,292.91 876.98 6.45000 6.014 Centre Distance Pass -Major Risk Plan'. IH-109((ormedy1f0,30C)-Man:iH409-1H-1 8,460.09 1,00393 8.46009 875.64 6,625.00 7825 Clearance Factor Pass - Major Risk Plana H-111(formerly109,32D)-Plan: i H-111-111-1 8,062.60 455.52 8,06260 358.02 6,400.00 4.672 Centre Distance Pass - Major Risk Rhin 1H-11t(formerly 109, 32D) -Plan: i H -111-1H-1 8,04.12 456.22 8,064.12 357.05 6,425.00 4.600 Clearance Factor Pass -Major Risk Pian'. 1H-113(formerly 112, 34B) -Plan: 1H -113-1H-1 8,252.57 700.59 8,252.57 69322 6,350.00 8.269 Centre Distance Pass - Major Risk Plan. 1H-113(formerly 112, 348). Plan: IH -113-1H-1 8,254]0 78909 8,254,70 692.68 6,3750 8.185 Clearance Factor Pass - Major Risk Plana H-114(fomary 30B, Its). Plan: IH -114-1H-1 10,600.00 918.98 10,60000 777.34 7,12500 6A88 Canine Distance Pass - Major Risk Plan. 1H-114(fomaly 30B. 116) -Plan: 1H -114-1H-1 10,62466 919.79 10.62408 777.16 7,175.00 6449 Clearance Factor Pass - Major Risk Plan: 1H-115(formerly 115, 34A, 114) -Plan. 1 H-115- 9,229.85 737.47 9,229.85 63789 6,50.00 7.406 Centre Distance Pass - Major Risk Plan :1H-115(formerly 115, 34A, 114) -Plan: iH-115- 9,24599 738.63 9.245.99 636.04 6,550.00 7,200 Clearance Factor Pass -Major Risk Plan 1H-116(fomrody 114,32B, 115) -Plan: 111-116- 9,31458 494.95 9,314.58 39002 6,5750 4,744 Centre Distance Pass - Major Risk Plan 1H-116 comrady 114. 32B, 115) -Plan. 1H-116- 9,32966 497.84 9,329.66 38051 6,6250 4553 Clearance Factor Pass - Major Risk Plan, 1H-118 hormerty 30A, 119) -Plan: 1H -118-1H-1 12,190.02 1,06.81 12,190.02 830.09 7,550.00 5.697 Cealre Distance Pass - Major Risk Plan: IH-118(formerly30A, 119) -Plan: 1H -118-1H-1 12,307.14 1,07.87 4,307.14 82541 7,675.00 5816 Clearance Factor Pass - Major Risk Plan: 111420(A1035, formerly 117) -Plan: 1H -120-1H 9,940.62 80.40 9,940.62 710.60 6,675.00 8.192 Centre Distance Pass - Major Risk Plana H-120(Al 035, formerly 117) -Plan: IH -120-1H 9,950.31 809.96 9,95031 710.01 6,70.00 8.103 Clearance Factor Pass - Major Risk Plan:IH-121(A1034, formerly 119)- Plan: i H-121-iH 10,477.45 72931 10,47745 629.86 6,775.00 7.333 Centre Distance Pass - Major Risk 28 June. 2017- 9'58 Page 20/5 COMPASS Conocophillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Plan: 11-1-102 (formerly 31) -1 H-1O2L2wp23 Tmv. Cylinder NOM Proximity Scan on Current Survey Data INOdh Reference) Reference Design: KuparuM 1 Pad - Plan: 1H-102 romerly 3l) -Plan: 1H-1021.2-iH-10212wp23 Scan Range: 7,676.90 ro 12,521.83 usn. Measured Depth. Scan Radius is 1,448.28 usX. Clearance Factor cutoff is Unlimited. Max Ellipse Separsnon is Unlimited Measured Minimum aMeasumd Ellipse gMsicasnN Clearance Summary Based on Sae Name Depth Distance Depth Separation Depth Facto, Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (deft) (deal tush) deft Plan. 1H -121(A1034, formerly 119) -Plan: IH -121-1H 10,498.33 730.08 10,49833 62831 6,825.00 7.174 Clearance Fedor Pass - Major Rrsk PIan:lH-122(A1033,f r[y A1040)-Plen'. 1H-122 11,384.81 574.86 11,38481 462.28 7,225.00 5.107 Centre Distance Pass - Major Risk Plan: 1H-122(At 033, formerly A1040)-PIan: 1H-122 11,428.22 57885 11428.22 458.95 7,300.00 4.828 Claimants Factor Pass - Major Risk Plan: 1H -123(A1032, formerly A1033) -Plan: 111-123 12,256D5 38849 12,256.05 271.34 7,725.00 3316 Can" Distance Pass - Major Risk Plan: 1H-123(At 032. armory A1033) -Plan. 1H-123 12,340.91 39887 12,340.91 262.77 7,850D0 2.931 Clearance Factor Pass - Major Risk Plan: 1H-124(At 031. formerly A1OW) -Plan: 1H-124 12,504.12 06173 12,504.12 694.00 7,275,00 5.138 Clearance Fedor Pass - Major Risk Survey root aroarant From To Surveyplan Survey Tool draft (torl 3900 700D0 GYD-GC-SS 700.00 1]94.10 MVJD+IFR-AK-CAZSC 1,794.10 7,676.90 MWD-1FR-AK-CAZ-SC 767690 8,026.90 1H-102L2wp23 MW0.1NC_0NLY 0,02690 9,52890 1H-102Uep23 MWD 81026.90 12,521.83 111-1021Jwp23 MyYDHFR-AK-CAZ-SC Ellipse ener terns are correlated across surrey tool lie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance unseen ellipsoids. Distance Between centres is the straight Ane distance basemen wellbore centres. Clearance Fedor= Distance Between Profiles I (Distance Basemen Profiles- Ellipse Separation). All station wordinates ware calculated using me Minimum Curvature method, 28 June, 2017- 9:56 Page3ol5 COMPASS r Ladder 1 r Error Ellipses are the Sum of the Reference and Offset Well Errors. . � '911mlllllllmml�� 'Illlllllppoi . Ilnlllll A111111111111111111jIIIIIIIIIIp111111111N®-11n1n.- °�°!='IIUIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII111111111111NjiIIIIIIIIIIII ------- -_ _--.....nlleplllalnn.•.— mmI�I�I IIIIIIII� �II ��IIIIIIIIIIIIIIIIIIIII[II� II��hIIIIIIIIIIIIIIIIIIIIIII� /lo'' o p� Illlllllllln..- .ullltln... 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I�IIIIII�������IIIIIIIIII � �IIIIIII��IIII� % I�IIIIIIIIIIIIII� :110 8500 •1.11. 111 .. 011 Partiald Depth Ladder View 1 H-102L2wp23 The Reference Well is along the x-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. 300- 00 150U 150— C) o m I U i i Epurv<IaM Ma9eaii< Oislan<'e j 6 7700 8400 9100 9800 10500 11200 11900 12600 Displayed interval could be less than entire well:Measured Depth7676.90 To 12521.83 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 3870.94 7676.91 7-5/8"x 9-7/8" 700.00 1794.10 1H-102wp23 (Plan: 1H-102) MWD+IFR-AK-CAZ-SC 3904.71 12521.83 4-1/2"x6-3/4" 1794.10 7676.90 1H-102wp23 (Plan: 1H-102) MWD+IFR-AK-CAZ-SC 7676.90 8026.90 1H-102L2wp23 (Plan: 11H-10212) MWD-INC_ONLY 8026.90 9526.90 1H-102L2wp23 (Plan: 1H -102L2) MWD 8026.90 12521.83 1H-102L2wp23 (Plan: 1H -102L2) MWD+IFR-AK-CAZ-SC A s 60 I � c 0 M n m U m E 30- 0 0 d c U1 U Ewiwam Maga.u<0inen<e 0 - 8000 8500 9000 9500 10000 10500 11000 Partial Measured Depth 1H-102L2wp23 - 7870 MD Inc Azi TVD Dleg TFace Target - 8620 8620 - 8850 8850 - 9000 7676.90 - 9150 75.57 9300 0.00 3870.94 9450 0.00 0.00 - 9750 9750 - 9900 9900 10050 10050 - 7676.90 To 12521.83 7689.70 - 10490 77.61 10780 0.00 3873.91 11070 - 15.90 0.00 11650 11650 11940 11940 12230 12230 - 12522 7709.70 77.61 0.00 3878.20 0.00 0.00 8021.02 8319.47 93.15 93.15 0.88 0.88 3903.22 3886.84 5.00 0.60 3.27 0.00 9:56].Iu D¢ 28 2017 8380.85 8880.73 90.12 90.12 0.38 0.38 3885.09 3884.05 5.00 0.00 -170.60 0.00 1H -102L2 1H -102L2 01 02.T2 Tl 020917 020917 RP RP CASING DETAILS 8911.28 9592.74 89.51 89.51 0.38 0.38 3884.15 3890.00 2.00 0.00 180.00 0.00 1H -102L2 03.T3 020917 RP TVD MD Name 3870.94 7676.91 7-518' x 9-718' 9600.91 89.54 0.22 3890.07 2.00 -78.82 3984.71 12521.83 4-112" x 6-314" 9975.88 89.54 0.22 3893.08 0.00 0.00 1H -102L2 04.T4 020917 RP 10321.94 86.55 342.33 3904.98 5.24 -99.72 10378.76 86.55 342.33 3908.39 0.00 0.00 10671.25 11085.75 11225.03 89.67 89.67 92.00 357.33 357.33 0.80 3918.08 3920.43 3918.40 5.24 0.00 3.00 78.55 0.00 56.13 1H -102L2 06.76 020917 RP Ml- ux 11331 92.00 0.80 3914.66 0.00 0.00 11353.37 .96 92.00 0.38 3913.91 2.00 -89.78 111-102L2 08.T8 020917 RP 6.98 ] �X-IBnm]] del en: n ap.IK a..Y�-u M.. 1.'..1 o.]m-.X-rua 11366.13 92.26 0.38 3913.44 2.00 0.00 e.Xe uen.n �x.iui]x"wi r 11746.82 92.26 0.38 3898.43 0.00 0.00 11859.79 90.00 0.38 3896.20 2.00 -180.00 1H.102L2 09.T9 020917 RP 11897.70 89.24 0.38 3896.45 2.00 180.00 12521.83 89.24 0.38 3904.71 0.00 0.00 1H -102L2 10.11) 020917 RP -90/ 01360 7677 - 7870 7870 - 8060 8060 - 8240 8240 8430 8430 - 8620 8620 - 8850 8850 - 9000 9000 - 9150 9150 9300 9300 - 9450 9450 - 9600 9600 - 9750 9750 - 9900 9900 10050 10050 - 10200 10200 - 10490 10490 - 10780 10780 11070 11070 - 11360 11360 - 11650 11650 11940 11940 12230 12230 - 12522 6BD1fBP7 1 H-1 02L2wp23 f MD 8060 Inc Azi 8240 TVD Dleg TFace Target 8850 8850 -"- 9000 9000 7676.90 9150 75.57 9300 - 0.00 3870.94 9600 0.00 0.00 9750 - 9900 9900 - 10050 10050 - 39.00 To 12521.83 7689.70 10490 77.61 10780 0.00 3873.91 11070 - 15.90 0.00 11650 11650 11940 11940 12230 12230 7709.70 77.61 0.00 3878.20 0.00 0.00 8021.02 8319.47 93.15 93.15 0.88 0.88 3903.22 3886.84 5.00 0.00 3.27 0.00 9:57, June 28 2017 8380.85 8880.73 90.12 90.12 0.38 0.38 3885.09 3884.05 5.00 0.00 -170.60 0.00 1H -102L2 1H -102L2 01. 02. T1 T2 020917 RP 020917 RP CASING DETAILS 8911.28 9592.74 89.51 89.51 0.38 0.38 3884.15 3890.00 2.00 0.00 180.00 0.00 1H -102L2 03.T3 020917 RP TVDMD Name 3870.94 7676.91 7-5/8- x 9-7/8! 9600.91 89.54 0.22 3890.07 2.00 -78.82 3984.71 12521.83 4-1/2^ x 6-3/4" 9975.88 89.54 0.22 3893.06 0.00 0.00 1H -102L2 04.T4 020917 RP 10321.94 86.55 342.33 3904.98 5.24 -99.72 10378.76 86.55 342.33 3906.39 0.00 0.00 10671.25 11085.75 11225.03 89.67 89.67 92.00 357.33 357.33 0.80 3918.08 3920.43 3918.40 5.24 0.00 3.00 78.55 0.00 56.13 1H -102L2 06.T6 020917 RP wanr. w rNx.n +xin:,ii Ana: +xa.xi 11331 92.00 0.80 3914.66 0.00 0.00 + +azi .96 11353.37 92.00 0.38 3913.91 2.00 -89.78 1H -102L2 08.78 020917 RP �ii�: mnaui wxn.x. 11366.13 92.26 0.38 3913.44 2.00 0.00 +xsv.ez I.A. 11746.82 92.26 0.38 3898.43 0.00 0.60 11859.79 90.00 0.38 3896.20 2.60 -180.00 1H -102L2 09.T9 020917 RP 11897.70 89.24 0.38 3896.45 2.00 180.00 12521.83 89.24 0.38 3904.71 0.00 0.00 1H -102L2 10.TD 020917 RP -90/ 0/360 7677 - 7870 7870 - 8060 8060 8240 8240 8430 8430 - 8620 8620 - 8850 8850 -"- 9000 9000 9150 9150 9300 9300 - 9450 9450 - 9600 9600 9750 9750 - 9900 9900 - 10050 10050 - 10200 10200 10490 10490 10780 10780 11070 11070 - 11360 11360 - 11650 11650 11940 11940 12230 12230 12522 -180/180 110:58, June 28 201] 1 Kuparuk 1H P( (2500 us Win) Easting (2500 usW;n) Iwp20 1H-120wp21 AC Flipbook ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-102 (formerly 31) 50103xxxxx00 Plan: 11-1-1021-2 Plan: 1 H-102L2wp23 Error Ellipse Survey Report 28 June, 2017 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kupamk River Unit Site: Kupanik 1H Pad Well: Plan: 1H-102 (formerly 31) Wellbore: Plan: 111-10212 Design: 1H-102L2wp23 SLB Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1H-102 (formerly 31) Plan: 54+39 Qa 93.00usft (Doyon 142) Plan: 54+39 Q 93.00usft (Doyon 142) True Minimum Curvature 1.00 sigma EDM Production Survey Tool Program Date 6/28/2017 "Moth veMcal From To veNw (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 700.00 1H-102wp23 (Plan: 1 H-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 7,676.90 1 H-1 02wp23 (Plan: 1 H-102) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 7,676.90 8,026.90 1 H-1 02L2wp23 (Plan: 1 H-10212) MWD -INC -ONLY MWD -INC -ONLY -FILLER 8,026.90 9,525.90 1H-1021-2wp23(Plan: 1 H-10212) MWD MWD - Standard 8,026.90 12,521.83 1 H-1 0212wp23 (Plan: 1 H-10212) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC Position uncertainty and bias at survey station Measumd Inclination "Moth veMcal Righside Labral veNw Magniluce semimajor eemiminor Depth earth Ertof Blas Emr Blas Ersor also of Bus Error Ertor Aalmuth Tool (us") C) C) (usill (ucn) (uaff) (usnl lural lase) (soft) (.oft) loan) (usft) (') 7,67690 75.57 000 3870.94 11.15 -1.44 1022 244 9.18 159 293 2439 8.87 102.91 MWDNFR-AK-CAZ-SC(1, 3) 767691 7557 0.00 3,870.94 11.15 444 1022 2.44 9.18 1.59 2.93 2439 8.87 10291 M�1NC_ONLY(1, 4) 7,677.14 759 0.00 3,871.00 11.15 -144 10.22 244 918 1.59 293 2439 8.87 102.91 MWPINC_ONLY (1, 4) 7,609.70 77.61 0.00 3,87391 10.74 -147 10.24 2.44 9.17 159 2.93 24,50 896 102.53 MWD -INC ONLY (1, 4) 7,709.70 77,61 OW 3,87820 1074 -1,47 1024 244 9.17 1.59 2.94 24.50 898 102.54 MWD -INC ONLY n. 4) 7,833.43 8318 0.35 3,890.20 9.39 -1.58 12.12 243 921 161 2.97 24.55 11.06 103.62 MM -INC _ONLY (1. 4) 8,021.02 93.15 088 3,903.22 9.21 -1.61 18.37 2.43 9.25 1.61 2.98 2406 17.29 111.26 MWD -INC _ONLY (1, 4) 8,31947 93.15 0.08 3.888.84 9.28 -164 21.71 2.00 an 160 2.67 2464 21.08 11499 am n. 5) 8,380.85 90.12 0.38 3,885.09 9.35 -1.60 21.87 191 9.35 1.60 2.60 24.50 21.37 113.13 MM (1, 5) 8,88073 90.12 0.38 3,88405 9,75 -160 24.52 1.05 975 180 2.17 2502 23.55 36.33 MM (1, 51 8,911.28 89.51 038 3.884.15 9.81 -Ise 24.68 100 879 160 2.15 25.22 23.50 35.03 MM (1, 5) 9.592.74 89.51 038 3,8900D 970 -1.59 22.94 244 9.68 180 323 24.34 22.65 114.12 MMHFR-AK-OAZ-W(2.5) 9.600.91 89.54 022 3,89007 9.70 -1.59 2295 2.44 9.68 160 324 2433 2267 114.08 MWD+1FR-AK-CAZ-so(2. 5) 9,97588 89.54 0.22 3.893.08 991 -1.59 2377 2.44 9.89 160 3.33 24.19 23.66 11742 MWD+IFR-AK-CAZ-&C(2, 5) 10,321.94 86.55 342.33 3,904.98 10.27 -1.55 24.15 2.84 10.13 1.61 3.40 2427 23.94 20.12 MWD+1FR-AK-CAZSC(2, 5) 10,37878 86.55 342.33 3,908.39 10.31 Ass 2423 2a4 1017 1.61 341 2439 2390 1770 MP AFR-AK-CAZ-8C(2, 5) 10,671.25 8987 35733 3,91808 10.40 -161 24.81 247 10.39 1.62 349 24.97 2372 18.52 MWDNFR-AK-CPZ-SC(2,5) 11,08575 8967 357.33 3,92043 10,76 .1,61 2605 247 10.75 1.62 3.61 26.32 23.59 1629 MM.lFR-AK-CAZ-6C(2,5) 11,225.03 92.00 0.80 3,91840 10.83 -110 2853 2.33 10.87 162 365 26]4 23.55 16.23 MMMFR-AK-CAZ-SC(2, 5) 11.331.96 92.00 080 3,91468 10.93 -1.70 2687 2.33 10.98 1.82 368 27.10 23.53 16.08 MW IFR-AK-CAZ-SC(2.5) 11,353.37 92.00 0.38 3,913.91 1095 -1,70 28.92 2.35 1100 1.62 3.69 27.17 23.53 1811 MWD+IFR-M-CAZ-SC(2. 5) 11.366.13 92.26 0.38 3,91344 10.96 1,71 M95 235 1101 162 3.69 27.20 23.52 16.12 MWD+IFR-AR-CAZ-SC(2, 5) 11.746.83 9226 038 3,898.43 11.34 -1,71 28.33 2.35 11.39 181 3PA 2864 23.45 15.15 MWDNFR-AK-CAZSC(2,5) 11,859.79 9000 0.38 3,896.20 11.51 -161 2844 235 11.51 1.61 384 28,79 MAl 1580 MWD+IFR-AK-CAZ-SC(2,5) 11,897.71 89.24 0.38 3,89645 11.58 -1.57 28.45 2.35 1155 1.61 385 28.81 23.39 16.10 MMHFR-AK-CAZ-SC(2, 5) 12.521.83 89.24 038 3,90471 1227 -1,57 30.92 235 12.25 181 4.08 31.33 23.30 14.39 MW0NFR-AK-0AZ-SC(2.5) 6/2812017 12:51:55PM Page 2 COMPASS 5000.1 Build 74 Pool Report �1H-102L2wp23 Surface Location n, CPAI Coordinate Converter •' rte:• ..From. Datum: NAD83 Region: alaska I- Latitude/Longitude Decimal Degrees r UTM Zone: r South r State Plane Zone: F4--':] Units: us -ft r Legal Description (NAD27 only) - Starting Coordinates: - X: 11689609.08 Y: 15980414.37 -- To. Datum: NAD27 Region: .alaska r Latitude/Longitude IDecimal Degrees r UTM Zone: True South r State Plane Zone: 14 J Units: us ft r Legal Description (NAD27 only) Ending Coordinates: X: 549577.455558541 Y: 5980662.56352101 .Transform Quit Help 11H-102L2wp23 Surface Location ftCPAI Coordinate Converter l.� From: Datum: .NAD83 Region: alaska r Latitude/Longitude DecimalDegrees—� r UTM Zone: F— ( South r State Plane Zone: I' �1 Units: us ft . f' Legal Description ft,JAD-27 only) Starting Coordinates: --------- X: 11689609.08 Y: 15980414.37 To Datum: NAD27 Region: alaska .. C LatitudelLongitude Decimal Degrees UTM Zone: Tnre iW South C' State Plane Zone: F4 Units: us ft C-` Legal Description (NAD27 only) Legal Description -- - - -- Township: 012 FN—, -1 Range: 010 Meridian.- U w- Section: 33 FNL 140,519229 IFEL 764.65061 .................. T........................................ Help ran., Quit I1H-102L2wp23 Surface Casing . CPA[ Coordinate Converter Datum: FA—D83 +', Rcgion: jalaska + r Latitude/Longitude Decimal Degrees f UTM Zone: - - r South i G State Plane Zone:jq � Units: r- Legal Description (NAD27 only) I. Starting Coordinates: X 11689909.67 y 15980107.45 To Datum: NAD27 Rcgion: alaska + LatitudOl-ongitude Decimal Degrees + C UTM Zone: True f- South * State Plane Zone: I4 Units: us -ft + (` Legal Description (NAD27 only) -EndingCoordinates,------- ------ --- --- X: 549878.038975245 Y: 5983355 64507016 - - Tian dorm ' OUR I Help 1H-102L2w 23 Surface Casing M CPAi Coordinate Converter I = i 0 From: Datum: FN—AD-83------1 Region: (alaska I- Latitude/Longitude Decimal Degrees r UTM Zone: r South State Plane Zone: q �- Units: us -ft + T Legal Dascriotinr� 11=1.43r anl�;l Starting Coordinates: X: 11689909.67 Y: 5980107.45 To Datum:NAD27 Region: alaska r Latitude/Longitude Decimal Degrees r UTM Zone: True F- South r State Plane Zone: Units: us -ft + P Legal Description (NAD27 only) Legal Township: 012 Range: 010 Meridian:j� Section: 33 FNL 349.44826 IFEL 1 1466.76527 1. Transform _fQWit Help 11H-102L2wp23 Kick-off Point I [ n. CPA! Coordinate Converter From.- -- - -- Datum: —AD 8-- F 3Region: alaska r Latitude/Longitude IDecimal Degrees r UTM Zone: F_ F south C•' State Plane Zone: F-] Units: us -ft _:j r Legal Description (NAD27 only) To: Datum: FTE7_Region:— — — -- - Falaska • LatitudelLongitude DecimalDegrees • UTM Zone: True r- South State Plane Zone: [4---�,D Units: r Legal Description (NAD27 only) Starting Coordinates:F Ending Coordinates: * 11693977.97 X 1553946.279132679 * 15980388.82 Y: 5988636 .93148139 I IIH-102L2wp23 Kick-off Point [ M CPAICoordinate Converter From: Datum: FZFa93 Region: —IaTk a (- Latitude/Longitude PecimalDegrees r UTM Zone: F_ South 0- State Plane Zone: Units: Starting Coordinates: - X 11693977.97 Y: 1566631319.82 .Transform Quit_j Help___ To: Datum: FN—AD27- _L__] Region: faIask_a-:] t' Latitude/Longitude I Decimal Degrees • UTM Zone:ffrue F South • State Plane Zone: f47_71 Units: us —ft r Legal Description (NAD27 only) -Legal Description Township: f0-12 f -N--,-1 Range: oto Meridian: ju I Section: 34 JFNL -1 196,327691 IFEL 11675.7968 Quit Help IH-102L2wp23 Top of Production 13 CPAI Coordinate Converter From Datum: FZ83—Rogion: Ftlask—,--�-D • Latitude/Longitude DecimalDegrees • UTM Zone:F— r- South G State Plane Zone: F---] Units: us -ft r' Legal Description [NAD27 only) To Datum: FA-6 27 -- -D Rogi.n: jala'k. • Latitude/Longitude DecimalDegrees • UTM Zone: f—True r- South C State Plane Zone: Units:[us �ft, Legal Description (NAD27 only) Starting Coordinates: — r Ending Coordinates: - - - - - X' 11693978.41 X: 1553946.718650664 Y: 15980321.83 Y: 5980569.94306236 TramforrcQuit I Help 1H-102L2wp23 Top of Production M CPAI Coordinate Converter From Datum: FNA—DS3-----j Region: lalaska -1 I — I — r Latitude/Longitude IDecimal De;rees r UTM Zone:— r South r- State Plane Zone:F4----,] Units: Fu -s -f t - r Legal Starting Coordinates: - -- ---I X 1169397841 Y: 15980321 F12 WWOl To. Datum: FAD21- Region: F--,;�k-a-- r Latitude/Longitude Decimal Degrees UTM Zone: I—True F South State Plane Zone:F7D- Units: t-- Legal Description (NAD27 only) Legal Description ------------- -- Township: F01-2 � Range: 0-16 fE7, Meridian: JU Section: 34 1163.33574 IFEL 11675.9485 '410��, - .. ........ I T ran Quit Help I1H-102L2wp23 TD CPAI Coordinate Converter From: Datum: NAD 83 . Region: alaska r Latitude/Longitude IDecimal Degrees r UTM Zone: r— T` South is State Plane Zone: q Units: us -ft C" Legal Description (NAD27 only) Starting Coordinates: To: Datum: NADP?-]- Region: alaska . r Latitude/Longitude Decimal Degrees * UTM Zone: Tru, f- South G State Plane Zane:q Units: us -ft r Legal Description [NAD27 only) Ending Coordinates: X ji9958A,33 X 553798.675343993 Y: 15985214.00 Y: 5985461.99986081 r ....... ....... .... :........_........................ Transform Quit Help 11H-102L2wp23 TD M CPAS Coordinate Converter From: Datum: r NAD83 . Region: alaska r Latitude/Longitude Decimal Degrees r UTM Zone: f- South r� State Plane Zone: F-�-:] Units: us -ft . i LegalDescripiiori!NAD27rnipl Starting Coordinates: --- -------- X: 1693830.33 Y: 15985214.00 To Datum: INAD27 Region: jolaska t` Latitude/Longitude Decimal Degrees • UTM Zone: True r South i State Plane Zane: Units: us -ft C Legal Description (NAD27 only) Legal Description ---- - Township: 012 FN-,-] Range: f010 E Meridian: Section: 27 FNL 549.84406 fFEL 1780.7663 ... Transform Quit Help N£LIHGPE i]AGET OEiNI51M.V C6G+DtlUT Wme M85B9 GrtI. ReOwz IN.f01 fµfNt]N.ry0RGB1>PP Sfl9a05 tlrtlepteYmc iM.Wl Ne QYtlme lW.Wl 1wlmu a.]a ox9en PP a. wwm.:lmoG �n in m. Baaawa: l9Bom Y9iM i.1PaeW'. loo.am GFIe QIa@W'. K10RL3IT 0=917 RP Crtla pvPw:IW.Oy 'w" f1.mT3a]oRLB PP GNe Y fml. MMau. 1330 Oq I IKIORLI(Si50RM1PP 103430].T]03G91]RP 3BM60 My peYu'. 10].07) GNe McQxn:.IWIG� iK1N1119.T]49R1)PP CImIa 3BN.]I GrvH Ph9u['.1]N.tO� 13:19, June 282077 1 H-102L2wp23 'NCLWOPE Mm0220).iEOAiI]PP i RGE10Ei L3luW COO eNIE5) 'H=1 ° ')PP Yyp ° °° Cntle lgywa'.IW.W) °�� °�'� "leem Quarter Mile View IMI0313 B.i80d'91]PPP INI03L3 m.T.02ND PP lUe 34.1 ONeIReJwe 1W.� OMe1P us:1W 0% wlNumie V6%]a+ 9e5e.N CveelPe3uv IW.o01 INIel2 t e T...t] AP J9lG.11 RtlalPaPus IW W) RE 0 it 0m9; PP Grtle to tox2 m iNP 3 W GMo Marius: t]M.WI cwa Macas:lmaal ik10 TI OMII PP INI03U13IO10 10030311 PO G'r¢I¢ JB]O6B JPOn )r CiNe(Pk'wa:IN.NI Citle Me]Iw: 13A.W1 8000 6000 C / IH�va I� H-002L w�23' u X1> (=)4000 -- ......... O_ >3+ g L 02000- CO 0- J-2000-4000 -2000- -4000 -2000 0 2000 4000 6000 8000 10000 12000 8000 C_ N 7 04000 0 N '62000- z t O Cf) Q -2000-. -4000 -2000 —. F --F — — — — — — — — — F-- 0 2000 4000 6000 8000 10000 12000 &�.pa N85+9 CNe1FMIue:1M.Wl wioilzoi.n oiMii Ra Yel OS C41e r(1Mw:1 W 0'.9 uu. �R.aw lMam MiNLL W.i10N91]IiP firth p.aw. 100.0]1 iH10Il3M�rt OM1]RP 91808 I91]91 gNe1Ra0N'. 100.W1 GNe (iia0lue'. 100.N1 N10T303.i90t091]RP 181630 GNe1Ra0Y.'. 1K10]1316i0OF 71 1] RP GNe ]Y IN10930ti1 MM;, Ne(Re UV$ MM I.w NSIReyu[1]MM) 10313 Ki8VW1]RP ]WaSa =00.Ye0Yeh.'1MMS LI O3W1]RP ig13060 1N1ML310it1Y]Mi]RP qi<le &WlT CMe1R. 1PlM1 Qmle lPtlui'1d10.0>) —. F --F — — — — — — — — — F-- 0 2000 4000 6000 8000 10000 12000 1 H-102L2wp23 Section View 0 0 3700 3750- -------- -- --- 3800 � WS_A4_Object e-------------_ _------- m U X3850 WS—A3 - S_A3 WS—A3 � _ o o o ~ -5/8 x 9-7/6" 3900 _ O r - ,_ _ - - - -"� _ WS 3..Objecti '_ M m - -3 -1/2" x 6-3/4" N O WS 2 3950 N' -800 o 0 1600 2400 3200 4000 4800 5600 Vertical Section at 0.000 Tollerable Collision Risk Worksheet ConocoPhillips Alaska Tolerable Collision Risk Worksheet based on Rev. t - 29 Jul 99 Use this sheet to describe a well interference scenario where QRA may be applicable. Check firs( that the scenario really is different from those described on existing worksheets. Prepared by: Kelsey Hanford ' q _�' Authorized by: Dan Bearden -- r _ -. Z'- ConocoPhillips Alaska, Inc Drilling Anti -Collision Management Generic name of scenario: Collision with other laterals In mulll4ateral well (A3 with A2. A4 with A3 and A2. B with A4. A3, and A2, D with B. A4, A3 and A2) Description: (Be epee Include alltadors which affect either the cost of collision or the cost of reducin the nsk Well 1H-102 A3, A4, B and D laterals fail anti collision with one another in the horizontal legs of the well base on WP21. The four upper laterals will be geosteerad using periscope so risk of leaving the zone is minimal. There ism immediate danger to life or impact on the environment if wen 1H- 102 intersects itself. If IH -102 intersects Itseff there would be damage to the liner and swell packers. No risk of a well control Issue exists because well IH -102 lateral that Is being drilled is above the previous placed laterals (upper laterals have the same or stghlly higher PP) and is ))eing tlnlletl from the main bare with kill weight mud in the hole. ryl The laterals fan with the mother bore at the kick ori point, but we are intentionally side tracking. We will be kicking off with motors to keep us in the target sands. Do the consequences the Are of collision include a Cares Qre risk to personnel or the consequences ^- environment? of collision List all the consequences of I I Cru / wllision and the necessary remedial aGion: No HSE risks exist with IH -102 intersecting itself while dmling. An economic concern exists and It would be the cast of damage to the completion equipment that has already bean placed in the lower laterals poor to dolling the upper laterals and the impact it may have on future production from the well If necessary the lateral that had been tlnlletl into can be isolated and production shut off (loss of lateral) which is worst case scenario. The biggest chance of getting lost' is when crossing faults, there are three fault crossings in 1 H-102, but since the lower laterals will have already dulled across the fault the exact throw argue fault will be known so the fault crossing can be planned for. I(we do gel out of zona we can determine what zone we are In based on real time logs and cuttings and then steer back Into the correct zone. How mould the probability of collision or the severity of the consequences be reduced? How might this impact the drilling operation? cost: Estimate the total cost of substantially reducing V = $0 the risk 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 I C_ $10,000,000 Is there a practical way to substantially reduce Oft 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 It V F i than close approach tolerances need not be set C Iv C - 1 then Tolerable Collision Risk =l in C l VF Tolerable Collision Risk = 1 in 23 Estimate the total cost of substantially reducing V = $0 the risk 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 I C_ $10,000,000 Is there a practical way to substantially reduce Oft 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 It V F i than close approach tolerances need not be set C Iv C - 1 then Tolerable Collision Risk =l in C l VF Tolerable Collision Risk = 1 in 23 As -built REV I DATE I BY I CN I APP I DESCRIPTION IREVI DATE BY t,,. IAPP DESCRIPTION 1 2/05/0 MRT I CC I IRev. Per K05014ACS 12 02/01/11 JAH I LGM I Rev. Per K170005ACS N25 30 29 28� 25 10 _ 36 31 1H i RCS 32 33 34 35 36 TI 2NS0 T11N OE 6 5 4 3 2 1 ®120 1 `" ASP GRID NORTH 0119 2 cpei 10 c 0118 s 9 �F 12 00117 T C40 0116 0115 18 7 1 615 14 13 0114 Ia LEGEND 0113 1e in 24 0112 24 19 20 21 2 23 0 AS—BUILT CONDUCTOR 0.111 6110 VICINITY MAP • EXISTING CONDUCTOR 0109 SCALE: 1° = 2 MILES 0104 0108 0103 28 27 0107 33 34 0102 0106 0101 NOTES: 1. BASIS OF LOCATION AND ELEV. IS DS1H MONUMENTATION PER LOUNSBURY & ASSOC. DS1 H 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 3. ELEVATIONS ARE B.P.M.S.L. •UGNU 01 4. ALL CONDUCTORS ARE LOCATED WITHIN 914 PROTRACTED SECTIONS 28 AND 33, •5 TOWNSHIP 12 NORTH, RANGE 10 EAST, •20 912 UMIAT MERIDIAN, ALASKA. 019 922 •11 5. DATES OF SURVEY: 12-26-16 THRU •17 010 1-31-17 FIELD BOOKS L16-35, L16-40, 06 L17-02 & 117-03. •16 •21 •15 •13 6. ALL DISTANCES SHOWN ARE GROUND. •1 •9 •2 •7 •3 •18 GRAPHIC SCALE 0 100 200 400 • 8 •4 1 inch = 200 ft. SEE SHEET 2 & 3 FOR COORDINATE TABLE LOUNSBURY & ASSOCUTES, INC. SORWYSRS RNCINRRRS PWNNMS 46, AREA: 1H MODULE: XXXX UNIT: 01 ConocoPhilli S DS1H WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS 0ALK6108d31 DRAWING No. PART REV: 2/05/05 CEA—D1HX-6108D31 1 OF 3 2 1 1 102/01/17 JAH I LGM I ]Create Per K170005ACS I I I I I I 1 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 X Lot. Long. F.S.L F.E.L. O.G. PAD *103 5,980,722.55' 549,573.20' N 70' 21' 29.220" W 149' 35' 50.536" 19' 768' 48.0' 54.1' *104 5,980,782.43' 549,568.74' N 70' 21' 29.809" W 149' 35' 50.655" 79' 772' 48.0' 54.1' *108 5,980,752.52' 549,570.98' N 70' 21' 29.515" W 149' 35' 50.595" 49' 770' 48.0' 54.0' *109 5,980,812.20' 549,566.50' N 70' 21' 30.102" W 149' 35' 50.714" 109' 774' 48.0' 54.0' *110 5,980,842.21' 549,564.40' N 70' 21' 30.398" W 149' 35' 50.770" 139' 776' 48.0' 54.0' *111 5,980,872.05' 549,562.21' N 70' 21' 30.691" W 149' 35' 50.828" 169' 778' 48.0' 54.1' *112 5,980,902.08' 549,559.94' N 70' 21' 30.987" W 149' 35' 50.889" 199' 780' 48.0' 54.0' *113 5,980,932.00' 549,557.76' N 70' 21' 31.281" W 149' 35' 50.947" 229' 782' 48.0' 54.0' *114 5,980,961.86' 549,555.50' N 70' 21' 31.575" W 149' 35' 51.006" 259' 784' 48.0' 54.1' *115 5,980,991.68' 549,553.43' N 70' 21' 31.868" W 149' 35' 51.062" 289' 786' 48.0' 54.1' *116 5,981,021.61' 549,551.58' N 70' 21' 32.163" W 149' 35' 51.110" 319' 787' 48.0' 54.1' *117 5,981,051.73' 549,548.80' N 70' 21' 32.459" W 149' 35' 51.185" 349' 790' 48.0' 54.0' *118 59981,081.22' 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 0 ... SURVEYOR'S CERTIFICATE 49th 6 V °:♦♦�� 1 HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY '• •"„",...'.......,•„"':' .. DONE BY ME OR UNDER MY DIRECT SUPERVISION AND -MIAH F. CORNELL/ �= THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION LS -12663" ARE CORRECT AS OF JANUARY 31, 2017 o �w LOUNSBURY /��FESSIONA��' �� h ASSOCIATES, INC. ,�'�l<"`'•• YOM ENGINEERS PLANNERS AREA: IH MODULE: XXXX UNIT. D1 ConocoPhillips DS1H WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADLK6108d31 12/27/16 DRAWING NO. CEA -D1 HX -6108D31 PART: 3 OF 3 REV: 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 IH -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. 1H-102 only has AC challenges between its laterals, we will be utilizing periscope to maintain colo ical certain to stay within zone. Casing wear Moderate Maintain low dog legs in the surface interval and utilize super sliders for drilling, milling, and liner running operations to minimize casing wear. Consider logging casing thickness to calibrate casing we model. Getting Liner to Bottom Moderate Properly clean hole on the trip out with the BHA, perform clean out run if necessary, utilize super sliders for weight transfer, monitor torque and drag. Whipstock Retrieval Moderate A dedicated clean out run prior to attempting to pull whipstock can be used to reduce the risk of fishing operations. 05 Attachment - 1H-102 Onlling Hazards Summary.dm 6/20/2017 9:22.47 AM IH -102 Cement Calculations Hole Size ft (TOC) 1 ft (Bott 42 i 39 80 9.95 1 45.5 8325 1 7.625 Surface Cement: Surface to 1,794' MD Capacities: 15.8ppg Class G yielding 1.16ft^3/sk Lead 1.91 ft3/ sx of 11.0 ppg DeepCRETE Capacities XS%for open hole and annulus: Tail 2.28 ft3/ sx of 12.0 DeepCRETE OH 0.177045 Permafrost (PF) depth 1620 ft 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 3.67 bbls Total Length 500 ft bbls 500 x 0.06478288 x 1.5 48.6 Shoe Track 80 ft sx.,...... 80 x 0.09617496 x 1 7.7 Open Hole 10 x 0.17704488 x 1.5 2.7 Total 59 bbl 331 ft3 145 sx Lead Top Tail Cement to Conductor 1294 ft 1294 x 0.06478288 x 3.5 293.4 bbl Conductor Length 80 ft 80 x 0.22021323 17.6 bbl Total: 311 bbl 1746 ft3 914 sx Intermediate Cement: Cement from 8,325' MD to 5,900' MD Slurry: Capacities: 15.8ppg Class G yielding 1.16ft^3/sk 9-7/8" x 7-5/8" 0.03825 XS%for open hole and annulus: 40% 9-7/8" OH 0.094731 7-5/8"ST 0.045916 Annulus Cement 2425 x 0.03825044 x 1.4 129.86 bbls Rathole Cement 2 x 0.09473055 x 1.4 0.27 bbls Shoe Track 80 x 0.0459157 x 1 3.67 bbls Total 134 bbls 751 ft3 ..648 sx.,...... TRANSMITTAL LETTER CHECKLIST WELL NAME: KP,(.&- /1+-1o2,1,2_ PTD: dui -/131 development _Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: xuarug 2 POOL: 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. AU— pq 7-1 API No. 50-1993 - 13590 -M - Q p. (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throw target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RN_UNIT 1H-1021-2 _ — Program DEV — _ Well bore seg Q PTD#:2171010 Company CONOCOPHILLIPS ALASKA_1NC._ _ _ Initial Class/Type _ DEV LPEND _GeoArea 890 __ Unit 1116.0 On/Off Shore -On _ Annular Disposal ❑ Administration 17 Nonconven. gas conformsto AS31.059300.1.A),0.2.A-0) NA 1 Permit fee attached. _ _ _ NA NA 2 Lease number appropriate Yes ADL0025639, entire wellbore, �3 Unique well name and number Yes _ KRU 11-1-1021.2 CMT. vol adequate to tie-in long string to surf csg. 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 406C contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells.... Yes CO 406C has no interwell spacing restrictions - 7 Sufficient acreage available in drilling unit Yes Yes 8 If. deviated, is wellbore plat included _ Yes If a re -drill, has a 10-403 for abandonment been approved 9 Operator only affected party Yes Wellbore. will be more than 500'from. an external property line where ownership or landownership changes. 10 Operator has. appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order _ Yes 12 Permit can be issued without administrative approval Yes Yes PKB 7/3/2017 13 Can permit be approved before 15 -day wait Yes BOPEs, do they meet regulation 14 Well located within area and strata authorized by Injection Order # (put 10# in. comments) (For NA.... 30 15 All wells. within 1/4. mile area of review identified (For service well only) _ _ NA 16 Pre -produced injector:. duration of pre -production less than 3 months (For service well only) NA. _ 18 Conductor string. provided NA Conductor set in KRU 1 H-102. Engineering 19 Surface casing protects all. known USDWs NA Surface casing set in KRU 1H-102. 20 CMT vol adequate to circulate. on conductor & surf csg NA _ Surface casing will be set and fully cemented in. KRU.1 H-102. 21 CMT. vol adequate to tie-in long string to surf csg. NA _ 22 CMT will cover all known. productive horizons No Productive interval will be completed with slotted liner 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all waste to approved disposal wells 25 If a re -drill, has a 10-403 for abandonment been approved NA. 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; 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 1746 psig(8.4 ppg EMW); will drill w/ 8.8-9.5 ppg EMW VTL 7/6/2017 29 BOPEs, do they meet regulation Yes _ 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 1348 psig; will test BOPS to 3500 psig 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable. Yes H2S measures required 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Wells on 1H -Pad are H2S-bearing. 1-12S measures. required. Geology 36 Data presented on potential overpressure zones _ Yes Expected reservoir pressure is 8,56 ppg EMW; will be drilled using 8.8 to 9.5. ppg mud. Appr Date 37 Seismic analysis of shallow gas zones NA PKB 7/3/2017 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly. progress reports. [exploratory only] NA Onshore development well to. be drilled. Geologic Engineering Public Commissioner: Date: Co fission r: Date Co r Date
